[Title 40 CFR ]
[Code of Federal Regulations (annual edition) - July 1, 2003 Edition]
[From the U.S. Government Printing Office]



[[Page i]]

          

                    40


          Parts 64 to 71

                         Revised as of July 1, 2003

Protection of Environment





          Containing a Codification of documents of general 
          applicability and future effect
          As of July 1, 2003
          With Ancillaries
          Published by
          Office of the Federal Register
          National Archives and Records
          Administration

A Special Edition of the Federal Register



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                     U.S. GOVERNMENT PRINTING OFFICE
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                            Table of Contents



                                                                    Page
  Explanation.................................................       v

  Title 40:
          Chapter I - Environmental Protection 
          Agency (Continued)                                         3
  Finding Aids:
      Material Approved for Incorporation by Reference........     307
      Table of CFR Titles and Chapters........................     309
      Alphabetical List of Agencies Appearing in the CFR......     327
      List of CFR Sections Affected...........................     337



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                     ----------------------------

                     Cite this Code: CFR
                     To cite the regulations in 
                       this volume use title, 
                       part and section number. 
                       Thus, 40 CFR 64.1 refers 
                       to title 40, part 64, 
                       section 1.

                     ----------------------------

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                               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

    The contents of the Federal Register are required to be judicially 
noticed (44 U.S.C. 1507). The Code of Federal Regulations is prima facie 
evidence of the text of the original documents (44 U.S.C. 1510).

HOW TO USE THE CODE OF FEDERAL REGULATIONS

    The Code of Federal Regulations is kept up to date by the individual 
issues of the Federal Register. These two publications must be used 
together to determine the latest version of any given rule.
    To determine whether a Code volume has been amended since its 
revision date (in this case, July 1, 2003), consult the 
``List of CFR Sections Affected (LSA),'' 
which is issued monthly, and the ``Cumulative List of 
Parts Affected,'' which appears in the Reader Aids section 
of the daily Federal Register. These two lists will identify the Federal 
Register page number of the latest amendment of any given rule.

EFFECTIVE AND EXPIRATION DATES

    Each volume of the Code contains amendments published in the Federal 
Register since the last revision of that volume of the Code. Source 
citations for the regulations are referred to by volume number and page 
number of the Federal Register and date of publication. Publication 
dates and effective dates are usually not the same and care must be 
exercised by the user in determining the actual effective date. In 
instances where the effective date is beyond the cut-off date for the 
Code a note has been inserted to reflect the future effective date. In 
those instances where a regulation published in the Federal Register 
states a date certain for expiration, an appropriate note will be 
inserted following the text.

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.

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Many agencies have begun publishing numerous OMB control numbers as 
amendments to existing regulations in the CFR. These OMB numbers are 
placed as close as possible to the applicable recordkeeping or reporting 
requirements.

OBSOLETE PROVISIONS

    Provisions that become obsolete before the revision date stated on 
the cover of each volume are not carried. Code users may find the text 
of provisions in effect on a given date in the past by using the 
appropriate numerical list of sections affected. For the period before 
January 1, 2001, consult either the List of CFR Sections Affected, 1949-
1963, 1964-1972, 1973-1985, or 1986-2000, published in 11 separate 
volumes. For the period beginning January 1, 2001, 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 
established by statute and allows Federal agencies to meet the 
requirement to publish regulations in the Federal Register by referring 
to materials already published elsewhere. For an incorporation to be 
valid, the Director of the Federal Register must approve it. The legal 
effect of incorporation by reference is that the material is treated as 
if it were published in full in the Federal Register (5 U.S.C. 552(a)). 
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) 741-6010.

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.

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REPUBLICATION OF MATERIAL

    There are no restrictions on the republication of material appearing 
in the Code of Federal Regulations.

INQUIRIES

    For a legal interpretation or explanation of any regulation in this 
volume, contact the issuing agency. The issuing agency's name appears at 
the top of odd-numbered pages.
    For inquiries concerning CFR reference assistance, call 202-741-6000 
or write to the Director, Office of the Federal Register, National 
Archives and Records Administration, Washington, DC 20408 or e-mail 
info@fedreg.nara.gov.

SALES

    The Government Printing Office (GPO) processes all sales and 
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register. The NARA site also contains links to GPO Access.

                              Raymond A. Mosley,
                                    Director,
                          Office of the Federal Register.

July 1, 2003.



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                               THIS TITLE

    Title 40 - Protection of Environment is composed of 
twenty-nine 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 
(63.1200-63.1439), part 63 (63.1440-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, 2003.

    Chapter I - Environmental Protection Agency appears in 
all twenty-nine volumes. An alphabetical Listing of Pesticide Chemicals 
Index appears in parts 150-189. 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.

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[[Page 1]]



                TITLE 40 - PROTECTION OF ENVIRONMENT




                    (This book contains parts 64-71)

  --------------------------------------------------------------------
                                                                    Part

chapter i - Environmental Protection Agency 
  (Continued)...............................................          64

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      CHAPTER I - ENVIRONMENTAL PROTECTION AGENCY (CONTINUED)




  --------------------------------------------------------------------


  Editorial Note: 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, parts 61-62, part 63 (63.1-63.599), 
part 63 (63.600-63.1199), part 63 (63.1200-63.1439), part 63 (63.1440-
end) parts 64-71, parts 72-80, parts 81-85, part 86 (86.1-86.599-99), 
part 86 (86.600-1 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.

          SUBCHAPTER C - AIR PROGRAMS (CONTINUED)
Part                                                                Page
64              Compliance assurance monitoring.............           5
65              Consolidated Federal air rule...............          16
66              Assessment and collection of noncompliance 
                    penalties by EPA........................         137
67              EPA approval of State noncompliance penalty 
                    program.................................         151
68              Chemical accident prevention provisions.....         157
69              Special exemptions from requirements of the 
                    Clean Air Act...........................         192
70              State operating permit programs.............         206
71              Federal operating permit programs...........         251

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              SUBCHAPTER C - AIR PROGRAMS (CONTINUED)





PART 64 - COMPLIANCE ASSURANCE MONITORING--Table of Contents




Sec.
64.1 Definitions.
64.2 Applicability.
64.3 Monitoring design criteria.
64.4 Submittal requirements.
64.5 Deadlines for submittals.
64.6 Approval of monitoring.
64.7 Operation of approved monitoring.
64.8 Quality improvement plan (QIP) requirements.
64.9 Reporting and recordkeeping requirements.
64.10 Savings provisions.

    Authority: 42 U.S.C. 7414 and 7661-7661f.

    Source: 62 FR 54940, Oct. 22, 1997, unless otherwise noted.



Sec. 64.1  Definitions.

    The following definitions apply to this part. Except as specifically 
provided in this section, terms used in this part retain the meaning 
accorded them under the applicable provisions of the Act.
    Act means the Clean Air Act, as amended by Pub.L. 101-549, 42 U.S.C. 
7401, et seq.
    Applicable requirement shall have the same meaning as provided under 
part 70 of this chapter.
    Capture system means the equipment (including but not limited to 
hoods, ducts, fans, and booths) used to contain, capture and transport a 
pollutant to a control device.
    Continuous compliance determination method means a method, specified 
by the applicable standard or an applicable permit condition, which:
    (1) Is used to determine compliance with an emission limitation or 
standard on a continuous basis, consistent with the averaging period 
established for the emission limitation or standard; and
    (2) Provides data either in units of the standard or correlated 
directly with the compliance limit.
    Control device means equipment, other than inherent process 
equipment, that is used to destroy or remove air pollutant(s) prior to 
discharge to the atmosphere. The types of equipment that may commonly be 
used as control devices include, but are not limited to, fabric filters, 
mechanical collectors, electrostatic precipitators, inertial separators, 
afterburners, thermal or catalytic incinerators, adsorption devices 
(such as carbon beds), condensers, scrubbers (such as wet collection and 
gas absorption devices), selective catalytic or non-catalytic reduction 
systems, flue gas recirculation systems, spray dryers, spray towers, 
mist eliminators, acid plants, sulfur recovery plants, injection systems 
(such as water, steam, ammonia, sorbent or limestone injection), and 
combustion devices independent of the particular process being conducted 
at an emissions unit (e.g., the destruction of emissions achieved by 
venting process emission streams to flares, boilers or process heaters). 
For purposes of this part, a control device does not include passive 
control measures that act to prevent pollutants from forming, such as 
the use of seals, lids, or roofs to prevent the release of pollutants, 
use of low-polluting fuel or feedstocks, or the use of combustion or 
other process design features or characteristics. If an applicable 
requirement establishes that particular equipment which otherwise meets 
this definition of a control device does not constitute a control device 
as applied to a particular pollutant-specific emissions unit, then that 
definition shall be binding for purposes of this part.
    Data means the results of any type of monitoring or method, 
including the results of instrumental or non-instrumental monitoring, 
emission calculations, manual sampling procedures, recordkeeping 
procedures, or any other form of information collection procedure used 
in connection with any type of monitoring or method.
    Emission limitation or standard means any applicable requirement 
that constitutes an emission limitation, emission standard, standard of 
performance or means of emission limitation as defined under the Act. An 
emission limitation or standard may be expressed in terms of the 
pollutant, expressed either

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as a specific quantity, rate or concentration of emissions (e.g., pounds 
of SO2 per hour, pounds of SO2 per million British 
thermal units of fuel input, kilograms of VOC per liter of applied 
coating solids, or parts per million by volume of SO2) or as 
the relationship of uncontrolled to controlled emissions (e.g., 
percentage capture and destruction efficiency of VOC or percentage 
reduction of SO2). An emission limitation or standard may 
also be expressed either as a work practice, process or control device 
parameter, or other form of specific design, equipment, operational, or 
operation and maintenance requirement. For purposes of this part, an 
emission limitation or standard shall not include general operation 
requirements that an owner or operator may be required to meet, such as 
requirements to obtain a permit, to operate and maintain sources in 
accordance with good air pollution control practices, to develop and 
maintain a malfunction abatement plan, to keep records, submit reports, 
or conduct monitoring.
    Emissions unit shall have the same meaning as provided under part 70 
of this chapter.
    Exceedance shall mean a condition that is detected by monitoring 
that provides data in terms of an emission limitation or standard and 
that indicates that emissions (or opacity) are greater than the 
applicable emission limitation or standard (or less than the applicable 
standard in the case of a percent reduction requirement) consistent with 
any averaging period specified for averaging the results of the 
monitoring.
    Excursion shall mean a departure from an indicator range established 
for monitoring under this part, consistent with any averaging period 
specified for averaging the results of the monitoring.
    Inherent process equipment means equipment that is necessary for the 
proper or safe functioning of the process, or material recovery 
equipment that the owner or operator documents is installed and operated 
primarily for purposes other than compliance with air pollution 
regulations. Equipment that must be operated at an efficiency higher 
than that achieved during normal process operations in order to comply 
with the applicable emission limitation or standard is not inherent 
process equipment. For the purposes of this part, inherent process 
equipment is not considered a control device.
    Major source shall have the same meaning as provided under part 70 
or 71 of this chapter.
    Monitoring means any form of collecting data on a routine basis to 
determine or otherwise assess compliance with emission limitations or 
standards. Recordkeeping may be considered monitoring where such records 
are used to determine or assess compliance with an emission limitation 
or standard (such as records of raw material content and usage, or 
records documenting compliance with work practice requirements). The 
conduct of compliance method tests, such as the procedures in appendix A 
to part 60 of this chapter, on a routine periodic basis may be 
considered monitoring (or as a supplement to other monitoring), provided 
that requirements to conduct such tests on a one-time basis or at such 
times as a regulatory authority may require on a non-regular basis are 
not considered monitoring requirements for purposes of this paragraph. 
Monitoring may include one or more than one of the following data 
collection techniques, where appropriate for a particular circumstance:
    (1) Continuous emission or opacity monitoring systems.
    (2) Continuous process, capture system, control device or other 
relevant parameter monitoring systems or procedures, including a 
predictive emission monitoring system.
    (3) Emission estimation and calculation procedures (e.g., mass 
balance or stoichiometric calculations).
    (4) Maintenance and analysis of records of fuel or raw materials 
usage.
    (5) Recording results of a program or protocol to conduct specific 
operation and maintenance procedures.
    (6) Verification of emissions, process parameters, capture system 
parameters, or control device parameters using portable or in situ 
measurement devices.
    (7) Visible emission observations.
    (8) Any other form of measuring, recording, or verifying on a 
routine basis

[[Page 7]]

emissions, process parameters, capture system parameters, control device 
parameters or other factors relevant to assessing compliance with 
emission limitations or standards.
    Owner or operator means any person who owns, leases, operates, 
controls or supervises a stationary source subject to this part.
    Part 70 or 71 permit shall have the same meaning as provided under 
part 70 or 71 of this chapter, provided that it shall also refer to a 
permit issued, renewed, amended, revised, or modified under any federal 
permit program promulgated under title V of the Act.
    Part 70 or 71 permit application shall mean an application 
(including any supplement to a previously submitted application) that is 
submitted by the owner or operator in order to obtain a part 70 or 71 
permit.
    Permitting authority shall have the same meaning as provided under 
part 70 or 71 of this chapter.
    Pollutant-specific emissions unit means an emissions unit considered 
separately with respect to each regulated air pollutant.
    Potential to emit shall have the same meaning as provided under part 
70 or 71 of this chapter, provided that it shall be applied with respect 
to an ``emissions unit'' as defined under 
this part in addition to a ``stationary 
source'' as provided under part 70 or 71 of this chapter.
    Predictive emission monitoring system (PEMS) means a system that 
uses process and other parameters as inputs to a computer program or 
other data reduction system to produce values in terms of the applicable 
emission limitation or standard.
    Regulated air pollutant shall have the same meaning as provided 
under part 70 or 71 of this chapter.



Sec. 64.2  Applicability.

    (a) General applicability. Except for backup utility units that are 
exempt under paragraph (b)(2) of this section, the requirements of this 
part shall apply to a pollutant-specific emissions unit at a major 
source that is required to obtain a part 70 or 71 permit if the unit 
satisfies all of the following criteria:
    (1) The unit is subject to an emission limitation or standard for 
the applicable regulated air pollutant (or a surrogate thereof), other 
than an emission limitation or standard that is exempt under paragraph 
(b)(1) of this section;
    (2) The unit uses a control device to achieve compliance with any 
such emission limitation or standard; and
    (3) The unit has potential pre-control device emissions of the 
applicable regulated air pollutant that are equal to or greater than 100 
percent of the amount, in tons per year, required for a source to be 
classified as a major source. For purposes of this paragraph, 
``potential pre-control device emissions'' 
shall have the same meaning as ``potential to 
emit,'' as defined in Sec. 64.1, except that 
emission reductions achieved by the applicable control device shall not 
be taken into account.
    (b) Exemptions - (1) Exempt emission limitations or 
standards. The requirements of this part shall not apply to any of the 
following emission limitations or standards:
    (i) Emission limitations or standards proposed by the Administrator 
after November 15, 1990 pursuant to section 111 or 112 of the Act.
    (ii) Stratospheric ozone protection requirements under title VI of 
the Act.
    (iii) Acid Rain Program requirements pursuant to sections 404, 405, 
406, 407(a), 407(b), or 410 of the Act.
    (iv) Emission limitations or standards or other applicable 
requirements that apply solely under an emissions trading program 
approved or promulgated by the Administrator under the Act that allows 
for trading emissions within a source or between sources.
    (v) An emissions cap that meets the requirements specified in 
Sec. 70.4(b)(12) or Sec. 71.6(a)(13)(iii) of this 
chapter.
    (vi) Emission limitations or standards for which a part 70 or 71 
permit specifies a continuous compliance determination method, as 
defined in Sec. 64.1. The exemption provided in this paragraph 
(b)(1)(vi) shall not apply if the applicable compliance method includes 
an assumed control device emission reduction factor that could be 
affected by the actual operation and maintenance of the control device

[[Page 8]]

(such as a surface coating line controlled by an incinerator for which 
continuous compliance is determined by calculating emissions on the 
basis of coating records and an assumed control device efficiency factor 
based on an initial performance test; in this example, this part would 
apply to the control device and capture system, but not to the remaining 
elements of the coating line, such as raw material usage).
    (2) Exemption for backup utility power emissions units. The 
requirements of this part shall not apply to a utility unit, as defined 
in Sec. 72.2 of this chapter, that is municipally-owned if the 
owner or operator provides documentation in a part 70 or 71 permit 
application that:
    (i) The utility unit is exempt from all monitoring requirements in 
part 75 (including the appendices thereto) of this chapter;
    (ii) The utility unit is operated for the sole purpose of providing 
electricity during periods of peak electrical demand or emergency 
situations and will be operated consistent with that purpose throughout 
the part 70 or 71 permit term. The owner or operator shall provide 
historical operating data and relevant contractual obligations to 
document that this criterion is satisfied; and
    (iii) The actual emissions from the utility unit, based on the 
average annual emissions over the last three calendar years of operation 
(or such shorter time period that is available for units with fewer than 
three years of operation) are less than 50 percent of the amount in tons 
per year required for a source to be classified as a major source and 
are expected to remain so.



Sec. 64.3  Monitoring design criteria.

    (a) General criteria. To provide a reasonable assurance of 
compliance with emission limitations or standards for the anticipated 
range of operations at a pollutant-specific emissions unit, monitoring 
under this part shall meet the following general criteria:
    (1) The owner or operator shall design the monitoring to obtain data 
for one or more indicators of emission control performance for the 
control device, any associated capture system and, if necessary to 
satisfy paragraph (a)(2) of this section, processes at a pollutant-
specific emissions unit. Indicators of performance may include, but are 
not limited to, direct or predicted emissions (including visible 
emissions or opacity), process and control device parameters that affect 
control device (and capture system) efficiency or emission rates, or 
recorded findings of inspection and maintenance activities conducted by 
the owner or operator.
    (2) The owner or operator shall establish an appropriate range(s) or 
designated condition(s) for the selected indicator(s) such that 
operation within the ranges provides a reasonable assurance of ongoing 
compliance with emission limitations or standards for the anticipated 
range of operating conditions. Such range(s) or condition(s) shall 
reflect the proper operation and maintenance of the control device (and 
associated capture system), in accordance with applicable design 
properties, for minimizing emissions over the anticipated range of 
operating conditions at least to the level required to achieve 
compliance with the applicable requirements. The reasonable assurance of 
compliance will be assessed by maintaining performance within the 
indicator range(s) or designated condition(s). The ranges shall be 
established in accordance with the design and performance requirements 
in this section and documented in accordance with the requirements in 
Sec. 64.4. If necessary to assure that the control device and 
associated capture system can satisfy this criterion, the owner or 
operator shall monitor appropriate process operational parameters (such 
as total throughput where necessary to stay within the rated capacity 
for a control device). In addition, unless specifically stated otherwise 
by an applicable requirement, the owner or operator shall monitor 
indicators to detect any bypass of the control device (or capture 
system) to the atmosphere, if such bypass can occur based on the design 
of the pollutant-specific emissions unit.
    (3) The design of indicator ranges or designated conditions may be:
    (i) Based on a single maximum or minimum value if appropriate (e.g., 
maintaining condenser temperatures a certain number of degrees below the 
condensation temperature of the applicable compound(s) being processed) 
or

[[Page 9]]

at multiple levels that are relevant to distinctly different operating 
conditions (e.g., high versus low load levels).
    (ii) Expressed as a function of process variables (e.g., an 
indicator range expressed as minimum to maximum pressure drop across a 
venturi throat in a particulate control scrubber).
    (iii) Expressed as maintaining the applicable parameter in a 
particular operational status or designated condition (e.g., position of 
a damper controlling gas flow to the atmosphere through a by-pass duct).
    (iv) Established as interdependent between more than one indicator.
    (b) Performance criteria. The owner or operator shall design the 
monitoring to meet the following performance criteria:
    (1) Specifications that provide for obtaining data that are 
representative of the emissions or parameters being monitored (such as 
detector location and installation specifications, if applicable).
    (2) For new or modified monitoring equipment, verification 
procedures to confirm the operational status of the monitoring prior to 
the date by which the owner or operator must conduct monitoring under 
this part as specified in Sec. 64.7(a). The owner or operator 
shall consider the monitoring equipment manufacturer's requirements or 
recommendations for installation, calibration, and start-up operation.
    (3) Quality assurance and control practices that are adequate to 
ensure the continuing validity of the data. The owner or operator shall 
consider manufacturer recommendations or requirements applicable to the 
monitoring in developing appropriate quality assurance and control 
practices.
    (4) Specifications for the frequency of conducting the monitoring, 
the data collection procedures that will be used (e.g., computerized 
data acquisition and handling, alarm sensor, or manual log entries based 
on gauge readings), and, if applicable, the period over which discrete 
data points will be averaged for the purpose of determining whether an 
excursion or exceedance has occurred.
    (i) At a minimum, the owner or operator shall design the period over 
which data are obtained and, if applicable, averaged consistent with the 
characteristics and typical variability of the pollutant-specific 
emissions unit (including the control device and associated capture 
system). Such intervals shall be commensurate with the time period over 
which a change in control device performance that would require actions 
by owner or operator to return operations within normal ranges or 
designated conditions is likely to be observed.
    (ii) For all pollutant-specific emissions units with the potential 
to emit, calculated including the effect of control devices, the 
applicable regulated air pollutant in an amount equal to or greater than 
100 percent of the amount, in tons per year, required for a source to be 
classified as a major source, for each parameter monitored, the owner or 
operator shall collect four or more data values equally spaced over each 
hour and average the values, as applicable, over the applicable 
averaging period as determined in accordance with paragraph (b)(4)(i) of 
this section. The permitting authority may approve a reduced data 
collection frequency, if appropriate, based on information presented by 
the owner or operator concerning the data collection mechanisms 
available for a particular parameter for the particular pollutant-
specific emissions unit (e.g., integrated raw material or fuel analysis 
data, noninstrumental measurement of waste feed rate or visible 
emissions, use of a portable analyzer or an alarm sensor).
    (iii) For other pollutant-specific emissions units, the frequency of 
data collection may be less than the frequency specified in paragraph 
(b)(4)(ii) of this section but the monitoring shall include some data 
collection at least once per 24-hour period (e.g., a daily inspection of 
a carbon adsorber operation in conjunction with a weekly or monthly 
check of emissions with a portable analyzer).
    (c) Evaluation factors. In designing monitoring to meet the 
requirements in paragraphs (a) and (b) of this section, the owner or 
operator shall take into account site-specific factors including the 
applicability of existing monitoring equipment and procedures,

[[Page 10]]

the ability of the monitoring to account for process and control device 
operational variability, the reliability and latitude built into the 
control technology, and the level of actual emissions relative to the 
compliance limitation.
    (d) Special criteria for the use of continuous emission, opacity or 
predictive monitoring systems. (1) If a continuous emission monitoring 
system (CEMS), continuous opacity monitoring system (COMS) or predictive 
emission monitoring system (PEMS) is required pursuant to other 
authority under the Act or state or local law, the owner or operator 
shall use such system to satisfy the requirements of this part.
    (2) The use of a CEMS, COMS, or PEMS that satisfies any of the 
following monitoring requirements shall be deemed to satisfy the general 
design criteria in paragraphs (a) and (b) of this section, provided that 
a COMS may be subject to the criteria for establishing indicator ranges 
under paragraph (a) of this section:
    (i) Section 51.214 and appendix P of part 51 of this chapter;
    (ii) Section 60.13 and appendix B of part 60 of this chapter;
    (iii) Section 63.8 and any applicable performance specifications 
required pursuant to the applicable subpart of part 63 of this chapter;
    (iv) Part 75 of this chapter;
    (v) Subpart H and appendix IX of part 266 of this chapter; or
    (vi) If an applicable requirement does not otherwise require 
compliance with the requirements listed in the preceding paragraphs 
(d)(2)(i) through (v) of this section, comparable requirements and 
specifications established by the permitting authority.
    (3) The owner or operator shall design the monitoring system subject 
to this paragraph (d) to:
    (i) Allow for reporting of exceedances (or excursions if applicable 
to a COMS used to assure compliance with a particulate matter standard), 
consistent with any period for reporting of exceedances in an underlying 
requirement. If an underlying requirement does not contain a provision 
for establishing an averaging period for the reporting of exceedances or 
excursions, the criteria used to develop an averaging period in (b)(4) 
of this section shall apply; and
    (ii) Provide an indicator range consistent with paragraph (a) of 
this section for a COMS used to assure compliance with a particulate 
matter standard. If an opacity standard applies to the pollutant-
specific emissions unit, such limit may be used as the appropriate 
indicator range unless the opacity limit fails to meet the criteria in 
paragraph (a) of this section after considering the type of control 
device and other site-specific factors applicable to the pollutant-
specific emissions unit.



Sec. 64.4  Submittal requirements.

    (a) The owner or operator shall submit to the permitting authority 
monitoring that satisfies the design requirements in Sec. 
64.3. The submission shall include the following information:
    (1) The indicators to be monitored to satisfy 
Sec.Sec. 64.3(a)(1)-(2);
    (2) The ranges or designated conditions for such indicators, or the 
process by which such indicator ranges or designated conditions shall be 
established;
    (3) The performance criteria for the monitoring to satisfy 
Sec. 64.3(b); and
    (4) If applicable, the indicator ranges and performance criteria for 
a CEMS, COMS or PEMS pursuant to Sec. 64.3(d).
    (b) As part of the information submitted, the owner or operator 
shall submit a justification for the proposed elements of the 
monitoring. If the performance specifications proposed to satisfy 
Sec. 64.3(b)(2) or (3) include differences from manufacturer 
recommendations, the owner or operator shall explain the reasons for the 
differences between the requirements proposed by the owner or operator 
and the manufacturer's recommendations or requirements. The owner or 
operator also shall submit any data supporting the justification, and 
may refer to generally available sources of information used to support 
the justification (such as generally available air pollution engineering 
manuals, or EPA or permitting authority publications on appropriate 
monitoring for various types of control devices or capture systems). To 
justify the appropriateness of the monitoring elements proposed, the 
owner

[[Page 11]]

or operator may rely in part on existing applicable requirements that 
establish the monitoring for the applicable pollutant-specific emissions 
unit or a similar unit. If an owner or operator relies on presumptively 
acceptable monitoring, no further justification for the appropriateness 
of that monitoring should be necessary other than an explanation of the 
applicability of such monitoring to the unit in question, unless data or 
information is brought forward to rebut the assumption. Presumptively 
acceptable monitoring includes:
    (1) Presumptively acceptable or required monitoring approaches, 
established by the permitting authority in a rule that constitutes part 
of the applicable implementation plan required pursuant to title I of 
the Act, that are designed to achieve compliance with this part for 
particular pollutant-specific emissions units;
    (2) Continuous emission, opacity or predictive emission monitoring 
systems that satisfy applicable monitoring requirements and performance 
specifications as specified in Sec. 64.3(d);
    (3) Excepted or alternative monitoring methods allowed or approved 
pursuant to part 75 of this chapter;
    (4) Monitoring included for standards exempt from this part pursuant 
to Sec. 64.2(b)(1)(i) or (vi) to the extent such monitoring is 
applicable to the performance of the control device (and associated 
capture system) for the pollutant-specific emissions unit; and
    (5) Presumptively acceptable monitoring identified in guidance by 
EPA. Such guidance will address the requirements under 
Sec.Sec. 64.4(a), (b), and (c) to the extent 
practicable.
    (c)(1) Except as provided in paragraph (d) of this section, the 
owner or operator shall submit control device (and process and capture 
system, if applicable) operating parameter data obtained during the 
conduct of the applicable compliance or performance test conducted under 
conditions specified by the applicable rule. If the applicable rule does 
not specify testing conditions or only partially specifies test 
conditions, the performance test generally shall be conducted under 
conditions representative of maximum emissions potential under 
anticipated operating conditions at the pollutant-specific emissions 
unit. Such data may be supplemented, if desired, by engineering 
assessments and manufacturer's recommendations to justify the indicator 
ranges (or, if applicable, the procedures for establishing such 
indicator ranges). Emission testing is not required to be conducted over 
the entire indicator range or range of potential emissions.
    (2) The owner or operator must document that no changes to the 
pollutant-specific emissions unit, including the control device and 
capture system, have taken place that could result in a significant 
change in the control system performance or the selected ranges or 
designated conditions for the indicators to be monitored since the 
performance or compliance tests were conducted.
    (d) If existing data from unit-specific compliance or performance 
testing specified in paragraph (c) of this section are not available, 
the owner or operator:
    (1) Shall submit a test plan and schedule for obtaining such data in 
accordance with paragraph (e) of this section; or
    (2) May submit indicator ranges (or procedures for establishing 
indicator ranges) that rely on engineering assessments and other data, 
provided that the owner or operator demonstrates that factors specific 
to the type of monitoring, control device, or pollutant-specific 
emissions unit make compliance or performance testing unnecessary to 
establish indicator ranges at levels that satisfy the criteria in 
Sec. 64.3(a).
    (e) If the monitoring submitted by the owner or operator requires 
installation, testing, or other necessary activities prior to use of the 
monitoring for purposes of this part, the owner or operator shall 
include an implementation plan and schedule for installing, testing and 
performing any other appropriate activities prior to use of the 
monitoring. The implementation plan and schedule shall provide for use 
of the monitoring as expeditiously as practicable after approval of the 
monitoring in the part 70 or 71 permit pursuant to Sec. 64.6, 
but in no case shall the schedule for completing installation

[[Page 12]]

and beginning operation of the monitoring exceed 180 days after approval 
of the permit.
    (f) If a control device is common to more than one pollutant-
specific emissions unit, the owner or operator may submit monitoring for 
the control device and identify the pollutant-specific emissions units 
affected and any process or associated capture device conditions that 
must be maintained or monitored in accordance with Sec. 
64.3(a) rather than submit separate monitoring for each pollutant-
specific emissions unit.
    (g) If a single pollutant-specific emissions unit is controlled by 
more than one control device similar in design and operation, the owner 
or operator may submit monitoring that applies to all the control 
devices and identify the control devices affected and any process or 
associated capture device conditions that must be maintained or 
monitored in accordance with Sec. 64.3(a) rather than submit a 
separate description of monitoring for each control device.



Sec. 64.5  Deadlines for submittals.

    (a) Large pollutant-specific emissions units. For all pollutant-
specific emissions units with the potential to emit (taking into account 
control devices to the extent appropriate under the definition of this 
term in Sec. 64.1) the applicable regulated air pollutant in 
an amount equal to or greater than 100 percent of the amount, in tons 
per year, required for a source to be classified as a major source, the 
owner or operator shall submit the information required under 
Sec. 64.4 at the following times:
    (1) On or after April 20, 1998, the owner or operator shall submit 
information as part of an application for an initial part 70 or 71 
permit if, by that date, the application either:
    (i) Has not been filed; or
    (ii) Has not yet been determined to be complete by the permitting 
authority.
    (2) On or after April 20, 1998, the owner or operator shall submit 
information as part of an application for a significant permit revision 
under part 70 or 71 of this chapter, but only with respect to those 
pollutant-specific emissions units for which the proposed permit 
revision is applicable.
    (3) The owner or operator shall submit any information not submitted 
under the deadlines set forth in paragraphs (a)(1) and (2) of this 
section as part of the application for the renewal of a part 70 or 71 
permit.
    (b) Other pollutant-specific emissions units. For all other 
pollutant-specific emissions units subject to this part and not subject 
to Sec. 64.5(a), the owner or operator shall submit the 
information required under Sec. 64.4 as part of an application 
for a renewal of a part 70 or 71 permit.
    (c) The effective date for the requirement to submit information 
under Sec. 64.4 shall be as specified pursuant to paragraphs 
(a)-(b) of this section and a permit reopening to require the submittal 
of information under this section shall not be required pursuant to 
Sec. 70.7(f)(1)(i) of this chapter, provided, however, that, 
if a part 70 or 71 permit is reopened for cause by EPA or the permitting 
authority pursuant to Sec. 70.7(f)(1)(iii) or (iv), or 
Sec. 71.7(f) or (g), the applicable agency may require the 
submittal of information under this section for those pollutant-specific 
emissions units that are subject to this part and that are affected by 
the permit reopening.
    (d) Prior to approval of monitoring that satisfies this part, the 
owner or operator is subject to the requirements of Sec. 
70.6(a)(3)(i)(B).



Sec. 64.6  Approval of monitoring.

    (a) Based on an application that includes the information submitted 
in accordance with Sec. 64.5, the permitting authority shall 
act to approve the monitoring submitted by the owner or operator by 
confirming that the monitoring satisfies the requirements in 
Sec. 64.3.
    (b) In approving monitoring under this section, the permitting 
authority may condition the approval on the owner or operator collecting 
additional data on the indicators to be monitored for a pollutant-
specific emissions unit, including required compliance or performance 
testing, to confirm the ability of the monitoring to provide data that 
are sufficient to satisfy the requirements of this part and to confirm 
the appropriateness of an indicator

[[Page 13]]

range(s) or designated condition(s) proposed to satisfy Sec. 
64.3(a)(2) and (3) and consistent with the schedule in Sec. 
64.4(e).
    (c) If the permitting authority approves the proposed monitoring, 
the permitting authority shall establish one or more permit terms or 
conditions that specify the required monitoring in accordance with 
Sec. 70.6(a)(3)(i) of this chapter. At a minimum, the permit 
shall specify:
    (1) The approved monitoring approach that includes all of the 
following:
    (i) The indicator(s) to be monitored (such as temperature, pressure 
drop, emissions, or similar parameter);
    (ii) The means or device to be used to measure the indicator(s) 
(such as temperature measurement device, visual observation, or CEMS); 
and
    (iii) The performance requirements established to satisfy 
Sec. 64.3(b) or (d), as applicable.
    (2) The means by which the owner or operator will define an 
exceedance or excursion for purposes of responding to and reporting 
exceedances or excursions under Sec.Sec. 64.7 and 
64.8 of this part. The permit shall specify the level at which an 
excursion or exceedance will be deemed to occur, including the 
appropriate averaging period associated with such exceedance or 
excursion. For defining an excursion from an indicator range or 
designated condition, the permit may either include the specific 
value(s) or condition(s) at which an excursion shall occur, or the 
specific procedures that will be used to establish that value or 
condition. If the latter, the permit shall specify appropriate notice 
procedures for the owner or operator to notify the permitting authority 
upon any establishment or reestablishment of the value.
    (3) The obligation to conduct the monitoring and fulfill the other 
obligations specified in Sec.Sec. 64.7 through 64.9 
of this part.
    (4) If appropriate, a minimum data availability requirement for 
valid data collection for each averaging period, and, if appropriate, a 
minimum data availability requirement for the averaging periods in a 
reporting period.
    (d) If the monitoring proposed by the owner or operator requires 
installation, testing or final verification of operational status, the 
part 70 or 71 permit shall include an enforceable schedule with 
appropriate milestones for completing such installation, testing, or 
final verification consistent with the requirements in Sec. 
64.4(e).
    (e) If the permitting authority disapproves the proposed monitoring, 
the following applies:
    (1) The draft or final permit shall include, at a minimum, 
monitoring that satisfies the requirements of Sec. 
70.6(a)(3)(i)(B);
    (2) The permitting authority shall include in the draft or final 
permit a compliance schedule for the source owner to submit monitoring 
that satisfies Sec.Sec. 64.3 and 64.4, but in no 
case shall the owner or operator submit revised monitoring more than 180 
days from the date of issuance of the draft or final permit; and
    (3) If the source owner or operator does not submit the monitoring 
in accordance with the compliance schedule as required in paragraph 
(e)(2) of this section or if the permitting authority disapproves the 
monitoring submitted, the source owner or operator shall be deemed not 
in compliance with part 64, unless the source owner or operator 
successfully challenges the disapproval.



Sec. 64.7  Operation of approved monitoring.

    (a) Commencement of operation. The owner or operator shall conduct 
the monitoring required under this part upon issuance of a part 70 or 71 
permit that includes such monitoring, or by such later date specified in 
the permit pursuant to Sec. 64.6(d).
    (b) Proper maintenance. At all times, the owner or operator shall 
maintain the monitoring, including but not limited to, maintaining 
necessary parts for routine repairs of the monitoring equipment.
    (c) Continued operation. Except for, as applicable, monitoring 
malfunctions, associated repairs, and required quality assurance or 
control activities (including, as applicable, calibration checks and 
required zero and span adjustments), the owner or operator shall conduct 
all monitoring in continuous operation (or shall collect data at all 
required intervals) at all times that

[[Page 14]]

the pollutant-specific emissions unit is operating. Data recorded during 
monitoring malfunctions, associated repairs, and required quality 
assurance or control activities shall not be used for purposes of this 
part, including data averages and calculations, or fulfilling a minimum 
data availability requirement, if applicable. The owner or operator 
shall use all the data collected during all other periods in assessing 
the operation of the control device and associated control system. A 
monitoring malfunction is any sudden, infrequent, not reasonably 
preventable failure of the monitoring to provide valid data. Monitoring 
failures that are caused in part by poor maintenance or careless 
operation are not malfunctions.
    (d) Response to excursions or exceedances. (1) Upon detecting an 
excursion or exceedance, the owner or operator shall restore operation 
of the pollutant-specific emissions unit (including the control device 
and associated capture system) to its normal or usual manner of 
operation as expeditiously as practicable in accordance with good air 
pollution control practices for minimizing emissions. The response shall 
include minimizing the period of any startup, shutdown or malfunction 
and taking any necessary corrective actions to restore normal operation 
and prevent the likely recurrence of the cause of an excursion or 
exceedance (other than those caused by excused startup or shutdown 
conditions). Such actions may include initial inspection and evaluation, 
recording that operations returned to normal without operator action 
(such as through response by a computerized distribution control 
system), or any necessary follow-up actions to return operation to 
within the indicator range, designated condition, or below the 
applicable emission limitation or standard, as applicable.
    (2) Determination of whether the owner or operator has used 
acceptable procedures in response to an excursion or exceedance will be 
based on information available, which may include but is not limited to, 
monitoring results, review of operation and maintenance procedures and 
records, and inspection of the control device, associated capture 
system, and the process.
    (e) Documentation of need for improved monitoring. After approval of 
monitoring under this part, if the owner or operator identifies a 
failure to achieve compliance with an emission limitation or standard 
for which the approved monitoring did not provide an indication of an 
excursion or exceedance while providing valid data, or the results of 
compliance or performance testing document a need to modify the existing 
indicator ranges or designated conditions, the owner or operator shall 
promptly notify the permitting authority and, if necessary, submit a 
proposed modification to the part 70 or 71 permit to address the 
necessary monitoring changes. Such a modification may include, but is 
not limited to, reestablishing indicator ranges or designated 
conditions, modifying the frequency of conducting monitoring and 
collecting data, or the monitoring of additional parameters.



Sec. 64.8  Quality improvement plan (QIP) requirements.

    (a) Based on the results of a determination made under 
Sec. 64.7(d)(2), the Administrator or the permitting authority 
may require the owner or operator to develop and implement a QIP. 
Consistent with Sec. 64.6(c)(3), the part 70 or 71 permit may 
specify an appropriate threshold, such as an accumulation of exceedances 
or excursions exceeding 5 percent duration of a pollutant-specific 
emissions unit's operating time for a reporting period, for requiring 
the implementation of a QIP. The threshold may be set at a higher or 
lower percent or may rely on other criteria for purposes of indicating 
whether a pollutant-specific emissions unit is being maintained and 
operated in a manner consistent with good air pollution control 
practices.
    (b) Elements of a QIP:
    (1) The owner or operator shall maintain a written QIP, if required, 
and have it available for inspection.
    (2) The plan initially shall include procedures for evaluating the 
control performance problems and, based on the results of the evaluation 
procedures, the owner or operator shall modify the plan to include 
procedures for

[[Page 15]]

conducting one or more of the following actions, as appropriate:
    (i) Improved preventive maintenance practices.
    (ii) Process operation changes.
    (iii) Appropriate improvements to control methods.
    (iv) Other steps appropriate to correct control performance.
    (v) More frequent or improved monitoring (only in conjunction with 
one or more steps under paragraphs (b)(2)(i) through (iv) of this 
section).
    (c) If a QIP is required, the owner or operator shall develop and 
implement a QIP as expeditiously as practicable and shall notify the 
permitting authority if the period for completing the improvements 
contained in the QIP exceeds 180 days from the date on which the need to 
implement the QIP was determined.
    (d) Following implementation of a QIP, upon any subsequent 
determination pursuant to Sec. 64.7(d)(2) the Administrator or 
the permitting authority may require that an owner or operator make 
reasonable changes to the QIP if the QIP is found to have:
    (1) Failed to address the cause of the control device performance 
problems; or
    (2) Failed to provide adequate procedures for correcting control 
device performance problems as expeditiously as practicable in 
accordance with good air pollution control practices for minimizing 
emissions.
    (e) Implementation of a QIP shall not excuse the owner or operator 
of a source from compliance with any existing emission limitation or 
standard, or any existing monitoring, testing, reporting or 
recordkeeping requirement that may apply under federal, state, or local 
law, or any other applicable requirements under the Act.



Sec. 64.9  Reporting and recordkeeping requirements.

    (a) General reporting requirements. (1) On and after the date 
specified in Sec. 64.7(a) by which the owner or operator must 
use monitoring that meets the requirements of this part, the owner or 
operator shall submit monitoring reports to the permitting authority in 
accordance with Sec. 70.6(a)(3)(iii) of this chapter.
    (2) A report for monitoring under this part shall include, at a 
minimum, the information required under Sec. 70.6(a)(3)(iii) 
of this chapter and the following information, as applicable:
    (i) Summary information on the number, duration and cause (including 
unknown cause, if applicable) of excursions or exceedances, as 
applicable, and the corrective actions taken;
    (ii) Summary information on the number, duration and cause 
(including unknown cause, if applicable) for monitor downtime incidents 
(other than downtime associated with zero and span or other daily 
calibration checks, if applicable); and
    (iii) A description of the actions taken to implement a QIP during 
the reporting period as specified in Sec. 64.8. Upon 
completion of a QIP, the owner or operator shall include in the next 
summary report documentation that the implementation of the plan has 
been completed and reduced the likelihood of similar levels of 
excursions or exceedances occurring.
    (b) General recordkeeping requirements. (1) The owner or operator 
shall comply with the recordkeeping requirements specified in 
Sec. 70.6(a)(3)(ii) of this chapter. The owner or operator 
shall maintain records of monitoring data, monitor performance data, 
corrective actions taken, any written quality improvement plan required 
pursuant to Sec. 64.8 and any activities undertaken to 
implement a quality improvement plan, and other supporting information 
required to be maintained under this part (such as data used to document 
the adequacy of monitoring, or records of monitoring maintenance or 
corrective actions).
    (2) Instead of paper records, the owner or operator may maintain 
records on alternative media, such as microfilm, computer files, 
magnetic tape disks, or microfiche, provided that the use of such 
alternative media allows for expeditious inspection and review, and does 
not conflict with other applicable recordkeeping requirements.



Sec. 64.10  Savings provisions.

    (a) Nothing in this part shall:
    (1) Excuse the owner or operator of a source from compliance with 
any existing emission limitation or standard, or

[[Page 16]]

any existing monitoring, testing, reporting or recordkeeping requirement 
that may apply under federal, state, or local law, or any other 
applicable requirements under the Act. The requirements of this part 
shall not be used to justify the approval of monitoring less stringent 
than the monitoring which is required under separate legal authority and 
are not intended to establish minimum requirements for the purpose of 
determining the monitoring to be imposed under separate authority under 
the Act, including monitoring in permits issued pursuant to title I of 
the Act. The purpose of this part is to require, as part of the issuance 
of a permit under title V of the Act, improved or new monitoring at 
those emissions units where monitoring requirements do not exist or are 
inadequate to meet the requirements of this part.
    (2) Restrict or abrogate the authority of the Administrator or the 
permitting authority to impose additional or more stringent monitoring, 
recordkeeping, testing, or reporting requirements on any owner or 
operator of a source under any provision of the Act, including but not 
limited to sections 114(a)(1) and 504(b), or state law, as applicable.
    (3) Restrict or abrogate the authority of the Administrator or 
permitting authority to take any enforcement action under the Act for 
any violation of an applicable requirement or of any person to take 
action under section 304 of the Act.



PART 65 - CONSOLIDATED FEDERAL AIR RULE--Table of Contents




                   Subpart A - General Provisions

Sec.
65.1 Applicability.
65.2 Definitions.
65.3 Compliance with standards and operation and maintenance 
          requirements.
65.4 Recordkeeping.
65.5 Reporting requirements.
65.6 Startup, shutdown, and malfunction plan and procedures.
65.7 Monitoring, recordkeeping, and reporting waivers and alternatives.
65.8 Procedures for approval of alternative means of emission 
          limitation.
65.9 Availability of information and confidentiality.
65.10 State authority.
65.11 Circumvention and prohibited activities.
65.12 Delegation of authority.
65.13 Incorporation by reference.
65.14 Addresses.
65.15-65.19 [Reserved]

Table 1 to Subpart A of Part 65 - Applicable 40 CFR Parts 
          60, 61, and 63 General Provisions
Table 2 to Subpart A of Part 65 - Applicable Referencing 
          Subpart Provisions

Subpart B [Reserved]

                    Subpart C - Storage Vessels

65.40 Applicability.
65.41 Definitions.
65.42 Control requirements.
65.43 Fixed roof with an internal floating roof (IFR).
65.44 External floating roof (EFR).
65.45 External floating roof converted into an internal floating roof.
65.46 Alternative means of emission limitation.
65.47 Recordkeeping provisions.
65.48 Reporting provisions.
65.49-65.59 [Reserved]

                     Subpart D - Process Vents

65.60 Applicability.
65.61 Definitions.
65.62 Process vent group determination.
65.63 Performance and group status change requirements.
65.64 Group determination procedures.
65.65 Monitoring.
65.66 Recordkeeping provisions.
65.67 Reporting provisions.
65.68-65.79 [Reserved]

Table 1 to Subpart D of Part 65 - Concentration for Group 
          Determination
Table 2 to Subpart D of Part 65 - TRE Parameters for NSPS 
          Referencing Subparts
Table 3 to Subpart D of Part 65 - TRE Parameters for HON 
          Referencing Subparts

                     Subpart E - Transfer Racks

65.80 Applicability.
65.81 Definitions.
65.82 Design requirements.
65.83 Performance requirements.
65.84 Operating requirements.
65.85 Procedures.
65.86 Monitoring.
65.87 Recordkeeping provisions.
65.88-65.99 [Reserved]

                    Subpart F - Equipment Leaks

65.100 Applicability.
65.101 Definitions.

[[Page 17]]

65.102 Alternative means of emission limitation.
65.103 Equipment identification.
65.104 Instrument and sensory monitoring for leaks.
65.105 Leak repair.
65.106 Standards: Valves in gas/vapor service and in light liquid 
          service.
65.107 Standards: Pumps in light liquid service.
65.108 Standards: Connectors in gas/vapor service and in light liquid 
          service.
65.109 Standards: Agitators in gas/vapor service and in light liquid 
          service.
65.110 Standards: Pumps, valves, connectors, and agitators in heavy 
          liquid service; pressure relief devices in liquid service; and 
          instrumentation systems.
65.111 Standards: Pressure relief devices in gas/vapor service.
65.112 Standards: Compressors.
65.113 Standards: Sampling connection systems.
65.114 Standards: Open-ended valves or lines.
65.115 Standards: Closed vent systems and control devices; or emissions 
          routed to a fuel gas system or process.
65.116 Quality improvement program for pumps.
65.117 Alternative means of emission limitation: Batch processes.
65.118 Alternative means of emission limitation: Enclosed-vented process 
          units.
65.119 Recordkeeping provisions.
65.120 Reporting provisions.
65.121-65.139 [Reserved]

Table 1 to Subpart F of Part 65 -  Batch Process 
          Monitoring Frequency for Equipment Other Than Connectors

Subpart G - Closed Vent Systems, Control Devices, and Routing to a 
                      Fuel Gas System or a Process

65.140 Applicability.
65.141 Definitions.
65.142 Standards.
65.143 Closed vent systems.
65.144 Fuel gas systems and processes to which storage vessel, transfer 
          rack, or equipment leak regulated material emissions are 
          routed.
65.145 Nonflare control devices used to control emissions from storage 
          vessels or low-throughput transfer racks.
65.146 Nonflare control devices used for equipment leaks only.
65.147 Flares.
65.148 Incinerators.
65.149 Boilers and process heaters.
65.150 Absorbers used as control devices.
65.151 Condensers used as control devices.
65.152 Carbon adsorbers used as control devices.
65.153 Absorbers, condensers, carbon adsorbers, and other recovery 
          devices used as final recovery devices.
65.154 Halogen scrubbers and other halogen reduction devices.
65.155 Other control devices.
65.156 General monitoring requirements for control and recovery devices.
65.157 Performance test and flare compliance determination requirements.
65.158 Performance test procedures for control devices.
65.159 Flare compliance determination and monitoring records.
65.160 Performance test and TRE index value determination records.
65.161 Continuous records and monitoring system data handling.
65.162 Nonflare control and recovery device monitoring records.
65.163 Other records.
65.164 Performance test and flare compliance determination notifications 
          and reports.
65.165 Initial Compliance Status Reports.
65.166 Periodic reports.
65.167 Other reports.
65.168-65.169 [Reserved]

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

    Source: 65 FR 78285, Dec. 14, 2000, unless otherwise noted.



                   Subpart A - General Provisions



Sec. 65.1  Applicability.

    (a) The provisions of this subpart apply to owners or operators 
expressly referenced to this part from a subpart of 40 CFR part 60, 61, 
or 63 for which the owner or operator has chosen to comply with the 
provisions of this part as an alternative to the provisions in the 
referencing subpart as specified in paragraph (b) of this section.
    (b) Owners or operators may choose to comply with this part for any 
regulated source subject to a referencing subpart.
    (c) Compliance with this part instead of the referencing subparts 
does not alter the applicability of the referencing subparts. This part 
applies to only the equipment, process vents, storage vessels, or 
transfer operations to which the referencing subparts apply. This part 
does not extend applicability to equipment, process vents, storage 
vessels, or transfer operations that are not regulated by the 
referencing subpart.
    (d) The provisions of 40 CFR part 60, subpart A; 40 CFR part 61, 
subpart A;

[[Page 18]]

and 40 CFR part 63, subpart A, that are listed in table 1 of this 
subpart still apply to owners or operators of regulated sources 
expressly referenced to this part. The owner or operator shall comply 
with the provisions in table 1 of this subpart in the column 
corresponding to the referencing subpart. All provisions of 40 CFR part 
60, subpart A; 40 CFR part 61, subpart A; and 40 CFR part 63, subpart A, 
not expressly referenced in table 1 of this subpart do not apply, and 
the provisions of this part apply instead, except that provisions which 
were required to be met prior to implementation of this part 65 still 
apply.
    (e) The provisions of the referencing subparts that are listed in 
table 2 of this subpart still apply to owners or operators of regulated 
sources expressly referenced to this part. The owner or operator shall 
comply with the provisions in table 2 of this subpart in the row 
corresponding to the referencing subpart. All provisions of the 
referencing subparts not expressly referenced in table 2 to this subpart 
do not apply and the provisions of this part apply instead, except that 
provisions which were required to be met prior to implementation of this 
part 65 still apply.
    (f) Implementation date. Owners or operators who choose to comply 
with this part shall comply by the dates specified in paragraph (f)(1) 
of this section, as applicable, and shall meet the requirement in 
paragraph (f)(2) of this section.
    (1) Owners or operators shall implement this part as specified in an 
implementation schedule or at initial startup. The implementation date 
shall be established by mutual agreement with the Administrator or 
delegated authority. The implementation schedule shall be included in 
the source's title V permit. For non-title V sources, the implementation 
schedule shall be proposed by the source in the Initial Notification for 
Part 65 Applicability as specified in Sec. 65.5(c).
    (2) There shall be no gaps in compliance between compliance with the 
referencing subpart and compliance with this part.
    (g) Transitioning out of this part. Owners or operators who decide 
to no longer comply with this part and to comply with the provisions in 
the referencing subpart instead shall comply with the following, as 
applicable:
    (1) This transition shall be carried out on a date established in a 
title V permit or if the source is not a title V source, by a date 
established by agreement with the Administrator or delegated authority. 
The transition date shall be proposed in a title V permit amendment, or 
for non-title V sources, in a periodic report or separate notice.
    (2) There shall be no gaps in compliance between compliance with 
this part and compliance with the referencing subpart provisions.
    (h) Overlap with other subparts of this part. When provisions of 
another subpart of this part conflict with the provisions of this 
subpart, the provisions of the other subpart shall apply.
    (i) Equipment assignment procedures. If specific items of equipment 
(pumps, compressors, agitators, pressure relief devices, sampling 
connection systems, open-ended valves or lines, valves, connectors, 
instrumentation systems, surge control vessels, and bottoms receivers) 
that are part of a process unit complying with this part are managed by 
different administrative organizations (for example, different 
companies, affiliates, departments, divisions, etc.), those items of 
equipment may be aggregated with any process unit within the plant site.



Sec. 65.2  Definitions.

    All terms used in this part shall have the meaning given them in the 
Act and in this section. If a term is defined both in this section and 
in other parts that reference the use of this part, the term shall have 
the meaning given in this section for purposes of this part. If a term 
is not defined in the Act or in this section, the term shall have the 
meaning given in the referencing subpart for purposes of this part. The 
terms follow:
    Act means the Clean Air Act (42 U.S.C. 7401 et seq.).
    Administrator means the Administrator of the United States 
Environmental Protection Agency (EPA) or his or her authorized 
representative (for

[[Page 19]]

example, a State that has been delegated the authority to implement the 
provisions of this part).
    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).
    Automated continuous parameter monitoring system means a continuous 
parameter monitoring system that automatically both records the measured 
data and calculates hourly averages.
    Automated monitoring and recording system means any means of 
measuring values of monitored parameters and creating a hard copy or 
computer record of the measured values that does not require manual 
reading of monitoring instruments and manual transcription of data 
values. Automated monitoring and recording systems include, but are not 
limited to, computerized systems, strip charts, and circular charts.
    Batch process means a process in which the equipment is fed 
intermittently or discontinuously. Processing then occurs in this 
equipment after which the equipment is generally emptied. Examples of 
industries that use batch processes include pharmaceutical production 
and pesticide production.
    Batch product-process equipment train means the collection of 
equipment (for example, connectors, reactors, valves, pumps) configured 
to produce a specific product or intermediate by a batch process.
    Boiler means any enclosed combustion device that extracts useful 
energy in the form of steam and is not an incinerator or a process 
heater. Boiler also means any industrial furnace as defined in 40 CFR 
260.10.
    Bottoms receiver means a tank that collects distillation bottoms 
before the stream is sent for storage or for further downstream 
processing.
    By compound means by individual stream components, not carbon 
equivalents.
    Car-seal means a seal that is placed on a device that is used to 
change the position of a valve (for example, from opened to closed) in 
such a way that the position of the valve cannot be changed without 
breaking the seal.
    Closed vent system means a system that is not open to the atmosphere 
and is composed of piping, ductwork, connections, and, if necessary, 
flow inducing devices that transport gas or vapor from an emission point 
to a control device. A closed vent system does not include the vapor 
collection system that is part of any tank truck or railcar or the 
loading arm or hose that is used for vapor return. For transfer racks, 
the closed vent system begins at, and includes, the first block valve on 
the downstream side of the loading arm or hose used to convey displaced 
vapors.
    Closed vent system shutdown means a work practice or operational 
procedure that stops production from a process unit or part of a process 
unit during which it is technically feasible to clear process material 
from a closed vent system or part of a closed vent system consistent 
with safety constraints and during which repairs can be effected. An 
unscheduled work practice or operational procedure that stops production 
from a process unit or part of a process unit for less than 24 hours is 
not a closed vent system shutdown. An unscheduled work practice or 
operational procedure that would stop production from a process unit or 
part of a process unit for a shorter period of time than would be 
required to clear the closed vent system or part of the closed vent 
system of materials and start up the unit, and would result in greater 
emissions than delay of repair of leaking components until the next 
scheduled closed vent system shutdown, is not a closed vent system 
shutdown. The use of spare equipment and technically feasible bypassing 
of equipment without stopping production are not closed vent system 
shutdowns.
    Closed-loop system means an enclosed system that returns process 
fluid to a process.
    Closed-purge system means a system or combination of systems and 
portable containers to capture purged liquids. Containers must be 
covered or closed when not being filled or emptied.
    Combustion device means an individual unit of equipment, such as a 
flare, incinerator, process heater, or

[[Page 20]]

boiler, used for the combustion of organic emissions.
    Compliance date means the date by which a regulated source is 
required to be in compliance with a relevant standard, limitation, 
prohibition, or any federally enforceable requirement established by the 
Administrator (or a State with an approved permit program) pursuant to 
the Act.
    Connector means flanged, screwed, or other joined fittings used to 
connect two pipelines or a pipeline and a piece of equipment. A common 
connector is a flange. Joined fittings welded completely around the 
circumference of the interface are not considered connectors for the 
purpose of this regulation. For the purpose of reporting and 
recordkeeping, connector means joined fittings that are not 
inaccessible, ceramic, or ceramic-lined (for example, porcelain, glass, 
or glass-lined) as described in Sec. 65.108(e)(2).
    Continuous parameter monitoring system or CPMS means the total 
equipment that may be required to meet the data acquisition and 
availability requirements of this part used to sample, condition (if 
applicable), analyze, and provide a record of process or control system 
parameters.
    Continuous record means documentation, either in hard copy or 
computer-readable form, of data values measured at least once every 15 
minutes and recorded at the frequency specified in Sec. 
65.161(a).
    Continuous seal means a seal that is designed to form a continuous 
closure that completely covers the space between the wall of the storage 
vessel and the edge of the floating roof. A continuous seal may be a 
vapor-mounted, liquid-mounted, or metallic shoe seal. A continuous seal 
may be constructed of fastened segments so as to form a continuous seal.
    Control device means any combustion device, recovery device, or any 
combination of these devices used to comply with this part. Such 
equipment or devices include, but are not limited to, absorbers, carbon 
adsorbers, condensers, incinerators, flares, boilers, and process 
heaters. For process vents (as defined in this section), recovery 
devices are not considered control devices except for the recovery 
devices specified in Sec. 65.63(a)(2)(ii). A fuel gas system 
is not a control device. For a steam stripper, a primary condenser is 
not considered a control device.
    Control system means the combination of the closed vent system and 
the control devices used to collect and control vapors or gases from a 
regulated source.
    Day means a calendar day.
    Distance piece means an open or enclosed casing through which the 
piston rod travels, separating the compressor cylinder from the 
crankcase.
    Double block and bleed system means two block valves connected in 
series with a bleed valve or line that can vent the line between the two 
block valves.
    Ductwork means a conveyance system such as those commonly used for 
heating and ventilation systems. It is often made of sheet metal and 
often has sections connected by screws or crimping. Hard-piping is not 
ductwork.
    Emission point means an individual process vent, storage vessel, 
transfer rack, wastewater stream, or equipment leak.
    Empty or emptying means the removal of the stored liquid from a 
storage vessel. Storage vessels where stored liquid is left on the 
walls, as bottom clingage, or in pools due to bottom irregularities are 
considered empty. Lowering of the stored liquid level, so that the 
floating roof is resting on its legs, as necessitated by normal vessel 
operation (for example, when changing stored material or when 
transferring material out of the vessel for shipment) is not considered 
emptying.
    Equipment means each of the following that is subject to control 
under the referencing subpart: pump, compressor, agitator, pressure 
relief device, sampling connection system, open-ended valve or line, 
valve, connector, and instrumentation system; and any control devices or 
systems used to comply with subpart F of this part.
    Equivalent method means any method of sampling and analyzing for an 
air pollutant that has been demonstrated to the Administrator's 
satisfaction to have a consistent and quantitatively known relationship 
to the reference method under specified conditions.
    External floating roof or EFR means a pontoon-type (noncontact) or 
double-

[[Page 21]]

deck-type (contact) roof that is designed to rest on the stored liquid 
surface in a storage vessel with no fixed roof.
    Failure, EFR (referred to as EFR failure) is defined as any time the 
external floating roof's primary seal has holes, tears, or other 
openings in the shoe, seal fabric, or seal envelope; 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 stored liquid surface from the 
atmosphere; or a slotted membrane has more than 10 percent open area.
    Failure, internal floating roof type A (referred to as IFR type A 
failure) means any time, as determined during visual inspection through 
roof hatches, in which the internal floating roof is not resting on the 
surface of the stored liquid inside the storage vessel and is not 
resting on the leg supports; or there is stored liquid on the floating 
roof; or there are holes, tears, or other openings in the seal or seal 
fabric; or there are visible gaps between the seal and the wall of the 
storage vessel.
    Failure, internal floating roof type B (referred to as IFR type B 
failure) means any time, as determined during internal inspections, the 
internal floating roof's primary seal has holes, tears, or other 
openings in the seal or the seal fabric; or the secondary seal (if one 
has been installed) has holes, tears, or other openings in the seal or 
the seal fabric; or the gaskets no longer close off the stored liquid 
surface from the atmosphere; or a slotted membrane has more than 10 
percent open area.
    Fill or filling means the introduction of liquids into a storage 
vessel, but not necessarily to complete capacity.
    First attempt at repair, for the purposes of subparts F and G of 
this part, means to take action for the purpose of stopping or reducing 
leakage of organic material to the atmosphere, followed by monitoring as 
specified in Sec. 65.104(b) and Sec. 65.143(c), as 
appropriate, to verify whether the leak is repaired, unless the owner or 
operator determines by other means that the leak is not repaired.
    Fixed roof means a roof that is mounted (for example, permanently 
affixed) on a storage vessel in a stationary manner and that does not 
move with fluctuations in stored liquid level.
    Flame zone means the portion of the combustion chamber in a boiler 
or process heater occupied by the flame envelope.
    Floating roof means a roof consisting of an external floating roof 
or an internal floating roof that is designed to rest upon and is 
supported by the stored liquid and is equipped with a continuous seal.
    Flow indicator means a device that indicates whether gas flow is 
present in a line, or whether the valve position would allow gas flow to 
be present in a line.
    Fuel gas means gases that are combusted to derive useful work or 
heat.
    Fuel gas system means the offsite and onsite piping and flow and 
pressure control system that gathers gaseous stream(s) generated by 
onsite operations, may blend them with other sources of gas, and 
transports the gaseous stream for use as fuel gas in combustion devices 
or in-process combustion equipment, such as furnaces and gas turbines, 
either singly or in combination.
    Group 1 process vent means a process vent for which the flow rate is 
greater than or equal to 0.011 standard cubic meter per minute (0.39 
cubic feet per minute); the total concentration is greater than or equal 
to the appropriate value in table 1 of subpart D of this part, and the 
total resource effectiveness index value, calculated according to 
Sec. 65.64(h) is less than or equal to 1.0.
    Group 2A process vent means a process vent that is not Group 1 or 
Group 2B for which monitoring and recordkeeping are required to 
demonstrate a total resource effectiveness index value greater than 1.0.
    Group 2B process vent means a process vent that is not Group 1 or 
Group 2A for which monitoring and recordkeeping are not required to 
demonstrate a total resource effectiveness index value greater than 4.0, 
or which is exempt from control requirements due to the vent stream's 
flow rate, regulated material concentration, or total resource 
effectiveness index value.
    Halogenated vent stream or halogenated stream means, for purposes of

[[Page 22]]

this part, a vent stream determined to be halogenated by the procedures 
specified in Sec. 65.85(c) for transfer racks and in 
Sec. 65.64(g) for process vents, as applicable.
    Halogens and hydrogen halides means hydrogen chloride (HCl), 
chlorine (Cl2), hydrogen bromide (HBr), bromine 
(Br2), and hydrogen fluoride (HF).
    Hard-piping means pipe or tubing that is manufactured and installed 
using good engineering judgment and standards, such as ASME B31.3, 
Process Piping (available from the American Society of Mechanical 
Engineers, PO Box 2900, Fairfield, NJ 07007-2900).
    High-throughput transfer racks means those transfer racks that 
transfer greater than or equal to a total of 11.8 million liters per 
year (3.12 million gallons per year) of liquid containing regulated 
material.
    In food/medical service means that a piece of equipment in regulated 
material service contacts a process stream used to manufacture a Food 
and Drug Administration-regulated product where leakage of a barrier 
fluid into the process stream would cause any of the following:
    (1) A dilution of product quality so that the product would not meet 
written specifications;
    (2) An exothermic reaction that is a safety hazard;
    (3) The intended reaction to be slowed down or stopped; or
    (4) An undesired side reaction to occur.
    In gas/vapor service means that a piece of equipment in regulated 
material service contains a gas or vapor when in operation.
    In heavy liquid service means that a piece of equipment in regulated 
material service is not in gas/vapor service or in light liquid service.
    In light liquid service means that a piece of equipment in regulated 
material service contains a liquid that meets the following conditions:
    (1) The vapor pressure of one or more of the organic compounds is 
greater than 0.3 kilopascals at 20 C (0.04 pounds per 
square inch at 68 F);
    (2) The total concentration of the pure organic compound 
constituents having a vapor pressure greater than 0.3 kilopascals at 20 
C (0.04 pounds per square inch at 68 F) is 
equal to or greater than 20 percent by weight of the total process 
stream; and
    (3) The fluid is a liquid at operating conditions. (Note: Vapor 
pressures may be determined by standard reference texts or American 
Society for Testing and Materials (ASTM) D-2879, available from American 
Society for Testing and Materials, 1916 Race Street, Philadelphia, 
Pennsylvania 19103; or University Microfilms International, 300 North 
Zeeb Road, Ann Arbor, Michigan 48106.)
    In liquid service means that a piece of equipment in regulated 
material service is not in gas/vapor service.
    In regulated material service means, for the purposes of the 
equipment leak provisions of subpart F of this part, equipment which 
meets the definition of ``in volatile organic compound 
service,'' ``in volatile hazardous air 
pollutant service,'' ``in benzene 
service,'' ``in vinyl chloride 
service,'' or ``in organic hazardous air 
pollutant service'' as defined in the referencing subpart.
    In vacuum service means that equipment is operating at an internal 
pressure that is at least 5 kilopascals (0.7 pounds per square inch) 
below ambient pressure.
    In-situ sampling systems means nonextractive samplers or in-line 
samplers.
    Incinerator means an enclosed combustion device that is used for 
destroying organic compounds. Auxiliary fuel may be used to heat waste 
gas to combustion temperatures. Any energy recovery section present is 
not physically formed into one manufactured or assembled unit with the 
combustion section; rather, the energy recovery section is a separate 
section following the combustion section and the two are joined by ducts 
or connections carrying flue gas. This energy recovery section 
limitation does not apply to an energy recovery section used solely to 
preheat the incoming vent stream or combustion air.
    Initial startup means, for new or reconstructed sources, the first 
time the source begins production. For additions or changes not defined 
as a new source by an applicable referencing subpart, initial startup 
means the first time additional or changed equipment is put into 
operation. Initial startup does not

[[Page 23]]

include operation solely for testing equipment. Initial startup does not 
include subsequent startup (as defined in this section) of process units 
following malfunctions or process unit shutdowns. Except for equipment 
leaks, initial startup also does not include subsequent startups (as 
defined in this section) of process units following changes in product 
for flexible operation units or following recharging of equipment in 
batch operation.
    Instrumentation system means a group of equipment components used to 
condition and convey a sample of the process fluid to analyzers and 
instruments for the purpose of determining process operating conditions 
(for example, composition, pressure, flow). Valves and connectors are 
the predominant type of equipment used in instrumentation systems; 
however, other types of equipment may also be included in these systems. 
Only valves nominally 0.5 inches and smaller in diameter and connectors 
nominally 0.75 inches and smaller in diameter are considered 
instrumentation systems for the purposes of subpart F of this part.
    Intermediate change to monitoring means a modification to federally 
required monitoring involving ``proven 
technology'' (generally accepted by the scientific 
community as equivalent or better) that is applied on a site-specific 
basis and that may have the potential to decrease the stringency of the 
associated emission limitation or standard. Though site-specific, an 
intermediate change may set a national precedent for a source category 
and may ultimately result in a revision to the federally required 
monitoring. Examples of intermediate changes to monitoring include, but 
are not limited to:
    (1) Use of a continuous monitoring system (CEMS) in lieu of a 
parameter monitoring approach;
    (2) Decreased frequency for non-continuous parameter monitoring or 
physical inspections;
    (3) Changes to quality control requirements for parameter 
monitoring; and
    (4) Use of an electronic data reduction system in lieu of manual 
data reduction.
    Intermediate change to test method means a within-method 
modification to a federally enforceable test method involving 
``proven technology'' (generally accepted by 
the scientific community as equivalent or better) that is applied on a 
site-specific basis and that may have the potential to decrease the 
stringency of the associated emission limitation or standard. Though 
site-specific, an intermediate change may set a national precedent for a 
source category and may ultimately result in a revision to the federally 
enforceable test method. In order to be approved, an intermediate change 
must be validated according to EPA Method 301 (40 CFR part 63, appendix 
A) to demonstrate that it provides equal or improved accuracy or 
precision. Examples of intermediate changes to a test method include, 
but are not limited to:
    (1) Modifications to a test method's sampling procedure including 
substitution of sampling equipment that has been demonstrated for a 
particular sample matrix; and use of a different impinger absorbing 
solution;
    (2) Changes in sample recovery procedures and analytical techniques, 
such as changes to sample holding times and use of a different 
analytical finish with proven capability for the analyte of interest; 
and
    (3) ``Combining'' a federally required 
method with another proven method for application to processes emitting 
multiple pollutants.
    Internal floating roof or IFR means a pontoon-type (noncontact) or 
double-deck-type (contact) roof that is designed to rest or float on the 
stored liquid surface inside a storage vessel that has a fixed roof.
    Liquid-mounted seal means a foam-or liquid-filled continuous seal 
mounted in contact with the stored liquid.
    Liquids dripping means any visible leakage from a seal including 
dripping, spraying, misting, clouding, and ice formation. Indications of 
liquids dripping include puddling or new stains that are indicative of 
an existing evaporated drip.
    Loading cycle means the time period from the beginning of filling a 
tank truck or railcar until flow to the control device ceases as 
determined by the flow indicator.
    Low-throughput transfer racks means those transfer racks that 
transfer less

[[Page 24]]

than a total of 11.8 million liters per year (3.12 million gallons per 
year) of liquid containing regulated material.
    Major change to monitoring means a modification to federally 
required monitoring that uses ``unproven technology or 
procedures'' (not generally accepted by the scientific 
community) or is an entirely new method (sometimes necessary when the 
required monitoring is unsuitable). A major change to monitoring may be 
site-specific or may apply to one or more source categories and will 
almost always set a national precedent. Examples of major changes to 
monitoring include, but are not limited to:
    (1) Use of a new monitoring approach developed to apply to a control 
technology not contemplated in the applicable regulation in this part;
    (2) Use of a predictive emission monitoring system (PEMS) in place 
of a required continuous emission monitoring system (CEMS);
    (3) Use of alternative calibration procedures that do not involve 
calibration gases or test cells;
    (4) Use of an analytical technology that differs from that specified 
by a performance specification;
    (5) Decreased monitoring frequency for a continuous emission 
monitoring system, continuous opacity monitoring system, predictive 
emission monitoring system, or continuous parameter monitoring system;
    (6) Decreased monitoring frequency for a leak detection and repair 
program; and
    (7) Use of alternative averaging times for reporting purposes.
    Major change to test method means a modification to a federally 
enforceable test method that uses ``unproven technology or 
procedures'' (not generally accepted by the scientific 
community) or is an entirely new method (sometimes necessary when the 
required test method is unsuitable). A major change to a test method may 
be site-specific or may apply to one or more source categories and will 
almost always set a national precedent. In order to be approved, a major 
change must be validated according to EPA Method 301 (40 CFR part 63, 
appendix A). Examples of major changes to a test method include, but are 
not limited to:
    (1) Use of an unproven analytical finish;
    (2) Use of a method developed to fill a test method gap;
    (3) Use of a new test method developed to apply to a control 
technology not contemplated in the applicable regulation in this part; 
and
    (4) Combining two or more sampling/analytical methods (at least one 
unproven) into one for application to processes emitting multiple 
pollutants.
    Malfunction means any sudden, infrequent, and not reasonably 
preventable failure of air pollution control equipment, monitoring 
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. Malfunctions that do not affect 
a regulated source or compliance with this part are not malfunctions for 
purposes of this part.
    Metallic shoe seal or mechanical shoe seal means metal sheets that 
are held vertically against the wall of the storage vessel by springs, 
weighted levers, or other mechanisms and connected to the floating roof 
by braces or other means. A flexible coated fabric (envelope) spans the 
annular space between the metal sheet and the floating roof.
    Minor change to monitoring means:
    (1) A modification to federally required monitoring that:
    (i) Does not decrease the stringency of the compliance and 
enforcement measures of the relevant standard;
    (ii) Has no national significance (e.g., does not affect 
implementation of the applicable regulation in this part for other 
affected sources, does not set a national precedent, and individually 
does not result in a revision to the monitoring requirements); and
    (iii) Is site-specific, made to reflect or accommodate the 
operational characteristics, physical constraints, or safety concerns of 
an affected source.
    (2) Examples of minor changes to monitoring include, but are not 
limited to:
    (i) Modifications to a sampling procedure, such as use of an 
improved sample conditioning system to reduce maintenance requirements;
    (ii) Increased monitoring frequency; and

[[Page 25]]

    (iii) Modification of the environmental shelter to moderate 
temperature fluctuation and thus protect the analytical instrumentation.
    Minor change to test method means:
    (1) A modification to a federally enforceable test method that:
    (i) Does not decrease the stringency of the emission limitation or 
standard;
    (ii) Has no national significance (e.g., does not affect 
implementation of the applicable regulation in this part for other 
affected sources, does not set a national precedent, and individually 
does not result in a revision to the test method); and
    (iii) Is site-specific, made to reflect or accommodate the 
operational characteristics, physical constraints, or safety concerns of 
an affected source.
    (2) Examples of minor changes to a test method include, but are not 
limited to:
    (i) Field adjustments in a test method's sampling procedure, such as 
a modified sampling traverse or location to avoid interference from an 
obstruction in the stack, increasing the sampling time or volume, use of 
additional impingers for a high moisture situation, accepting 
particulate emission results for a test run that was conducted with a 
lower than specified temperature, substitution of a material in the 
sampling train that has been demonstrated to be more inert for the 
sample matrix; and
    (ii) Changes in recovery and analytical techniques such as a change 
in quality control/quality assurance requirements needed to adjust for 
analysis of a certain sample matrix.
    Nonautomated monitoring and recording system means manual reading of 
values measured by monitoring instruments and manual transcription of 
those values to create a record. Nonautomated systems do not include 
strip charts nor circular charts.
    Nonrepairable means that it is technically infeasible to repair a 
piece of equipment from which a leak has been detected without a process 
unit shutdown.
    One-hour period means the 60-minute period commencing on the hour.
    Onsite or on-site means, with respect to records required to be 
maintained by this part, that the records are stored at a location 
within a plant site that encompasses the regulated source. Onsite 
includes, but is not limited to, storage at the regulated source to 
which the records pertain, or storage in central files elsewhere at the 
plant site.
    Open-ended valve or line means any valve except relief valves having 
one side of the valve seat in contact with process fluid and one side 
open to the atmosphere, either directly or through open piping.
    Organic monitoring device means a device used to indicate the 
concentration level of organic compounds based on a detection principle 
such as infrared, photo ionization, or thermal conductivity.
    Owner or operator means any person who owns, leases, operates, 
controls, or supervises a regulated source or a stationary source of 
which a regulated source is a part.
    Part 70 permit means any permit issued, renewed, or revised pursuant 
to part 70 of this chapter.
    Performance test means the collection of data resulting from the 
execution of a test method (usually three emission test runs) used to 
demonstrate compliance with a relevant emission standard as specified in 
the performance test section of the relevant standard.
    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 
part 71 of this chapter.
    Permitting authority means one of the following:
    (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) and part 71 of this 
chapter.
    Plant site means all contiguous or adjoining property that is under 
common control, including properties that are

[[Page 26]]

separated only by a road or other public right-of-way. Common control 
includes properties that are owned, leased, or operated by the same 
entity, parent entity, subsidiary, or any combination thereof.
    Polymerizing monomer means, for the purposes of this part, a 
compound which may form polymer buildup in pump mechanical seals 
resulting in rapid mechanical seal failure.
    Pressure release means the emission of materials resulting from the 
system pressure being greater than the set pressure of the relief 
device. This release can be one release or a series of releases over a 
short time period.
    Pressure relief device or valve means a device used to prevent 
operating pressures from exceeding the maximum allowable working 
pressure of the process equipment. A common pressure relief device is a 
spring-loaded pressure relief valve. Devices that are actuated either by 
a pressure of less than or equal to 2.5 pounds per square inch gauge or 
by a vacuum are not pressure relief devices.
    Primary fuel means the fuel that provides the principal heat input 
to the device. To be considered primary, the fuel must be able to 
sustain operation without the addition of other fuels.
    Process heater means an enclosed combustion device that transfers 
heat liberated by burning fuel directly to process streams or to heat 
transfer liquids other than water. A process heater may, as a secondary 
function, heat water in unfired heat recovery sections.
    Process unit means the equipment specified in the definitions of 
process unit or chemical manufacturing process unit in the applicable 
referencing subpart. If the referencing subpart does not define process 
unit, then, for the purposes of this part, process unit means the 
equipment assembled and connected by pipes or ducts to process raw 
materials and to manufacture an intended product.
    Process unit shutdown means a work practice or operational procedure 
that stops production from a process unit or part of a process unit 
during which it is technically feasible to clear process material from a 
process unit or part of a process unit consistent with safety 
constraints and during which repairs can be effected. An unscheduled 
work practice or operational procedure that stops production from a 
process unit or part of a process unit for less than 24 hours is not a 
process unit shutdown. An unscheduled work practice or operational 
procedure that would stop production from a process unit or part of a 
process unit for a shorter period of time than would be required to 
clear the process unit or part of the process unit of materials and 
start up the unit, and would result in greater emissions than delay of 
repair of leaking components until the next scheduled process unit 
shutdown is not a process unit shutdown. The use of spare equipment and 
technically feasible bypassing of equipment without stopping production 
are not process unit shutdowns.
    Process vent means a process vent or vent stream as they are defined 
in the referencing subpart.
    Recovery device means an individual unit of equipment capable of and 
normally used for the purpose of recovering chemicals for fuel value 
(i.e., net positive heating value), use, reuse, or for sale for fuel 
value, use, or reuse. Equipment capable of and used for the purpose of 
recovering chemicals, but not normally for use, reuse or sale, are not 
recovery devices but are control devices. Examples of equipment that may 
be recovery devices include absorbers, carbon adsorbers, condensers, 
oil-water separators or organic-water separators, or organic removal 
devices such as decanters, strippers, or thin-film evaporation units.
    Reference method means any method of sampling and analyzing for an 
air pollutant as specified in an applicable subpart, the appendices to 
40 CFR part 60 or 63, or in appendix B of 40 CFR part 61.
    Referencing subpart means 40 CFR part 60, subparts Ka, Kb, VV, DDD, 
III, NNN, and RRR; 40 CFR part 61, subparts V, Y, and BB; and 40 CFR 
part 63, subparts G and H.
    Regulated material means, for the purposes of this part, the 
material regulated by the specific referencing subpart, including 
volatile organic liquids (VOL), volatile organic compounds (VOC), 
organic hazardous air pollutants (HAP's), benzene, vinyl chloride,

[[Page 27]]

or other chemicals or groups of chemicals.
    Regulated source means, for the purposes of this part, the 
stationary source, the group of stationary sources, or the portion of a 
stationary source that is regulated by a relevant standard or other 
requirement established pursuant to this part, or 40 CFR part 60, 61, or 
63.
    Relief device or valve means a device or valve used only to release 
an unplanned, nonroutine discharge. A relief device or valve discharge 
can result from an operator error, a malfunction such as a power failure 
or equipment failure, or other unexpected cause that requires immediate 
venting of gas from process equipment in order to avoid safety hazards 
or equipment damage.
    Repaired means, for the purposes of subparts F and G of this part, 
that equipment meets the following conditions:
    (1) Is adjusted, or otherwise altered, to eliminate a leak as 
defined in the applicable section of this part; and
    (2) Unless otherwise specified in applicable provisions of this 
part, is monitored as specified in Sec. 65.104(b) and 
Sec. 65.143(c) to verify that emissions from the equipment are 
below the applicable leak definition.
    Routed to a process or route to a process means the emissions are 
conveyed to any enclosed portion of a process unit where the emissions 
are predominantly recycled and/or consumed in the same manner as a 
material that fulfills the same function in the process and/or 
transformed by chemical reaction into materials that are not regulated 
materials and/or incorporated into a product; and/or recovered.
    Run means one of a series of emission or other measurements needed 
to determine emissions for a representative operating period or cycle as 
specified in this part. Unless otherwise specified, a run may be either 
intermittent or continuous within the limits of good engineering 
practice.
    Sampling connection system means an assembly of equipment within a 
process unit used during periods of representative operation to take 
samples of the process fluid. Equipment used to take nonroutine grab 
samples is not considered a sampling connection system.
    Secondary fuel means a fuel fired through a burner other than the 
primary fuel burner that provides supplementary heat in addition to the 
heat provided by the primary fuel.
    Sensor means a device that measures a physical quantity or the 
change in a physical quantity, such as temperature, pressure, flow rate, 
pH, or liquid level.
    Set pressure means, for the purposes of subparts F and G of this 
part, the pressure at which a properly operating pressure relief device 
begins to open to relieve atypical process system operating pressure.
    Shutdown means the cessation of operation of a regulated source (for 
example, chemical manufacturing process unit or a reactor, air oxidation 
reactor, distillation unit) and equipment required or used to comply 
with this part, or the emptying and degassing of a storage vessel. 
Shutdown is defined here for purposes including, but not limited to, 
periodic maintenance, replacement of equipment, or repair. Shutdown does 
not include the routine rinsing or washing of equipment in batch 
operation between batches.
    Simultaneous loading means, for a shared control device, loading of 
regulated materials from more than one transfer arm at the same time so 
that the beginning and ending times of loading cycles coincide or 
overlap and there is no interruption in vapor flow to the shared control 
device.
    Single-seal system means, for the purposes of subpart C of this 
part, a floating roof having one continuous seal. This seal may be a 
vapor-mounted, liquid-mounted, or metallic shoe seal.
    Specific gravity monitoring device means a unit of equipment used to 
monitor specific gravity and having a minimum accuracy of 
�0.02 specific gravity units.
    Startup means the setting into operation of a regulated source (for 
example, chemical manufacturing process unit or a reactor, air oxidation 
reactor, distillation unit, a storage vessel after emptying and 
degassing) and/or equipment required or used to comply with this part. 
Startup includes initial startup, operation solely for testing

[[Page 28]]

equipment, the recharging of equipment in batch operation, and 
transitional conditions due to changes in product for flexible operation 
units.
    State means all non-Federal authorities, including local agencies, 
interstate associations, and statewide programs, that have delegated 
authority to implement the provisions of this part; the referencing 
subparts; and/or the permit program established under part 70 of this 
chapter. The term State shall have its conventional meaning where clear 
from the context.
    Steam jet ejector means a steam nozzle that discharges a high-
velocity jet across a suction chamber that is connected to the equipment 
to be evacuated.
    Stuffing box pressure means the fluid (liquid or gas) pressure 
inside the casing or housing of a piece of equipment, on the process 
side of the inboard seal.
    Surge control vessel means feed drums, recycle drums, and 
intermediate vessels. Surge control vessels are used within a process 
unit (as defined in the specific subpart that references this part) when 
in-process storage, mixing, or management of flow rates or volumes is 
needed to assist in production of a product.
    Temperature monitoring device means a unit of equipment used to 
monitor temperature and having a minimum accuracy of �1 
percent of the temperature being monitored expressed in degrees Celsius 
or �1.2 degrees Celsius ( C), whichever is 
greater.
    Title V permit means any permit issued, renewed, or revised pursuant 
to Federal or State regulations established under 40 CFR part 70 or 71 
to implement title V of the Act (42 U.S.C. 7661).
    Total organic compounds or TOC means those compounds measured 
according to the procedures specified in Sec. 65.64(c) and 
Sec. 65.158(b)(3)(ii)(A), as applicable. Those compounds that 
the Administrator has determined do not contribute appreciably to the 
formation of ozone and that are specifically excluded from the 
definition of volatile organic compound at 40 CFR 51.100(s), as amended, 
are to be excluded for the purposes of measuring the hourly emission 
rate as required in Sec. 65.64(f) for process vents subject to 
subpart III, NNN, or RRR of part 60 of this chapter.
    Total resource effectiveness index value or TRE index value means a 
calculated value used to determine whether control is required for a 
process vent. It is based on process vent flow rate, emission rate of 
regulated material, net heating value, and corrosion properties 
(halogenated compound content), as quantified by the equations given 
under Sec. 65.64(h).
    Vapor balancing system means a piping system that is designed to 
collect regulated material vapors displaced from tank trucks or railcars 
during loading and to route the collected regulated material vapors to 
the storage vessel from which the liquid being loaded originated, or to 
another storage vessel connected by a common header; or to compress and 
route to a process or a fuel gas system the collected regulated material 
vapors.
    Vapor-mounted seal means a continuous seal that is mounted so that 
there is a vapor space between the stored liquid and the bottom of the 
seal.
    Visible emission means the observation of an emission of opacity or 
optical density above the threshold of vision.



Sec. 65.3  Compliance with standards and operation and maintenance requirements.

    (a) Requirements. (1) Except as provided in paragraph (a)(2) of this 
section, the emission standards and established parameter ranges of this 
part shall apply at all times except during periods of startup, shutdown 
(as defined in Sec. 65.2), malfunction, or nonoperation of the 
regulated source (or specific portion thereof) resulting in cessation of 
the emissions to which this part applies. However, if a startup, 
shutdown, malfunction, or period of nonoperation of one portion of a 
regulated source does not affect the ability of a particular emission 
point to comply with the specific provisions to which it is subject, 
then that emission point shall still be required to comply with the 
applicable provisions of this part during the startup, shutdown, 
malfunction, or period of nonoperation.

[[Page 29]]

For example, if there is an over pressure in the reactor area, a storage 
vessel in a chemical manufacturing process unit would still be required 
to be controlled in accordance with subpart C of this part. Similarly, 
the degassing of a storage vessel would not affect the ability of a 
process vent to meet the requirements of subpart D or G of this part.
    (2) Sections 65.106 through 65.118 shall apply at all times except 
during periods of startup or shutdown (as defined in Sec. 
65.2), malfunction, process unit shutdown (as defined in Sec. 
65.2), or nonoperation of the regulated source (or specific portion 
thereof) in which the lines are drained and depressurized resulting in 
cessation of the emissions to which subpart F of this part applies.
    (3) During startups, shutdowns, and malfunctions when the emission 
standards of this part do not apply pursuant to paragraphs (a)(1) and 
(2) of this section, the owner or operator shall implement, to the 
extent reasonably available, measures to prevent or minimize emissions 
in excess of those that would have occurred if there were no startup, 
shutdown, or malfunction and the owner or operator complied with the 
relevant provisions of this part. The measures to be taken shall be 
identified in the applicable startup, shutdown, and malfunction plan and 
may include, but are not limited to, air pollution control technologies, 
recovery technologies, work practices, pollution prevention, monitoring, 
and/or changes in the manner of operation of the regulated source. 
Backup control devices are not required but may be used if available. 
This paragraph (a)(3) does not apply to Group 2A or Group 2B process 
vents.
    (4) Malfunctions shall be corrected as soon as practical after their 
occurrence in accordance with the startup, shutdown, and malfunction 
plan required in Sec. 65.6(a). This paragraph (a)(4) does not 
apply to Group 2A or Group 2B process vents.
    (5) Operation and maintenance requirements established pursuant to 
section 112 of the Act are enforceable independent of emissions 
limitations or other requirements in relevant standards.
    (b) Compliance determination procedures. - (1) 
Parameter monitoring: Compliance with operating conditions. The 
parameter monitoring data for emission points that are required to 
perform continuous monitoring shall be used to determine compliance with 
the required operating conditions for the monitored control devices or 
recovery devices. For each excursion, except for excused excursions and 
as provided for in paragraph (b)(2) of this section, the owner or 
operator shall be deemed to have failed to have applied the control in a 
manner that achieves the required operating conditions. Excused 
excursions are provided for in Sec. 65.156(d)(2).
    (2) Parameter monitoring: Excursions. If the conditions of paragraph 
(b)(2)(i) or (ii) of this section are met, an excursion is not a 
violation and, in cases where continuous monitoring is required, the 
excursion does not count toward the number of excused excursions. 
Nothing in this paragraph (b)(2) shall be construed to allow or excuse a 
monitoring parameter excursion caused by any activity that violates 
other applicable provisions of this part.
    (i) During periods of startup, shutdown, or malfunction (and the 
source is operated during such periods in accordance with the source's 
startup, shutdown, and malfunction plan as required by Sec. 
65.6(a)), a monitoring parameter is outside its established range or 
monitoring data cannot be collected; or
    (ii) During periods of nonoperation of the regulated source or 
portion thereof (resulting in cessation of the emissions to which the 
monitoring applies).
    (3) Operation and maintenance procedures. Determination of whether 
acceptable operation and maintenance procedures are being used will be 
based on information available to the Administrator that may include, 
but is not limited to, monitoring results, review of operation and 
maintenance procedures (including the startup, shutdown, and malfunction 
plan, if applicable, required in Sec. 65.6(a), as applicable), 
review of operation and maintenance records, inspection of the regulated 
source, and alternatives approved as specified in Sec. 65.7.
    (4) Emissions standards. Paragraphs (b)(4)(i) and (ii) of this 
section shall

[[Page 30]]

govern the use of data, tests, and requirements to determine compliance 
with emissions standards. Paragraphs (b)(4)(i) and (ii) do not apply to 
Group 2A or Group 2B process vents. Compliance with design, equipment, 
work practice, and operational standards, including those for equipment 
leaks, shall be determined according to paragraph (b)(5) of this 
section.
    (i) Performance test. The Administrator will determine compliance 
with emission standards of this part based on the results of performance 
tests conducted according to the procedures specified in subpart G of 
this part, unless otherwise specified in a subpart of this part.
    (ii) Operation and maintenance requirements. The Administrator will 
determine compliance with emission standards of this part by evaluation 
of an owner or operator's conformance with operation and maintenance 
requirements, including the evaluation of monitoring data, as specified 
in subparts of this part.
    (5) Design, equipment, work practice, or operational standards. 
Paragraphs (b)(5)(i) and (ii) do not apply to Group 2A or Group 2B 
process vents.
    (i) Records and inspection. The Administrator will determine 
compliance with design, equipment, work practice, or operational 
standards by review of records, inspection of the regulated source, and 
other procedures specified in this part.
    (ii) Operation and maintenance. The Administrator will determine 
compliance with design, equipment, work practice, or operational 
standards by evaluation of an owner or operator's conformance with 
operation and maintenance requirements as specified in paragraph (a) of 
this section, in other subparts of this part, and in applicable 
provisions of Sec. 65.6(b).
    (c) Finding of compliance. The Administrator will make a finding 
concerning a regulated source's compliance with an emission standard, 
design standard, work practice, operational standard or operating and 
maintenance requirement as specified in paragraphs (a) and (b) of this 
section upon obtaining all the compliance information required by the 
relevant standard (including the written reports of performance test 
results, monitoring results, and other information, if applicable) and 
any information available to the Administrator needed to determine 
whether proper operation and maintenance practices are being used. 
Standards in this part and methods of determining compliance are given 
in metric units followed by the equivalents in English units. The 
Administrator will make findings of compliance with the standards of 
this part using metric units.
    (d) Compliance times. All terms that define a period of time for 
completion of required tasks (for example, weekly, monthly, quarterly, 
annually) unless specified otherwise in the section or paragraph that 
imposes the requirement refer to the standard calendar periods.
    (1) Notwithstanding time periods specified for completion of 
required tasks, time periods may be changed by mutual agreement between 
the owner or operator and the Administrator as specified in 
Sec. 65.5(h)(3) (for example, a period could begin on the 
compliance date or another date, rather than on the first day of the 
standard calendar period). For each time period that is changed by 
agreement, the revised period applies until it is changed. A new request 
is not necessary for each recurring period.
    (2) When the period specified for compliance is a standard calendar 
period, if the initial compliance date occurs after the beginning of the 
period, compliance shall be required according to the schedule specified 
in the following paragraphs, as appropriate:
    (i) Compliance shall be required before the end of the standard 
calendar period within which the compliance deadline occurs if there 
remain at least 3 days for tasks that must be performed weekly, at least 
2 weeks for tasks that must be performed monthly, at least 1 month for 
tasks that must be performed each quarter, or at least 3 months for 
tasks that must be performed annually; or
    (ii) In all other cases, compliance shall be required before the end 
of the first full standard calendar period after the period within which 
the initial compliance deadline occurs.
    (3) In all instances where a provision requires completion of a task 
during

[[Page 31]]

each of multiple successive periods, an owner or operator may perform 
the required task at any time during the specified period provided the 
task is conducted at a reasonable interval after completion of the task 
during the previous period.



Sec. 65.4  Recordkeeping.

    (a) Maintaining notifications, records, and reports. Except as 
provided in paragraph (b) of this section, the owner or operator of each 
regulated source subject to this part shall keep copies of 
notifications, reports, and records required by this part for the length 
of time specified in the following, as applicable:
    (1) If an owner or operator is required to obtain or operate a 
regulated source under a title V permit, then all applicable 
notifications, reports, and records for that regulated source shall be 
maintained for at least 5 years, except for the records required in 
Sec. 65.47(b) for storage vessel capacity, Sec. 
65.104(e)(2) for valve and connector monitoring, and Sec. 
65.163(d)(1) for closed vent system design specifications.
    (2) If an owner or operator is not required to obtain or operate a 
regulated source under a title V permit, then all notifications, 
reports, and records for that regulated source required by this part 
shall be maintained for at least 2 years, except for the records 
required in Sec. 65.47(b) for storage vessel capacity, 
Sec. 65.104(e)(2) for valve and connector monitoring, and 
Sec. 65.163(d)(1) for closed vent system design 
specifications.
    (b) Copies of reports. If an owner or operator submits reports to 
the applicable EPA Regional Office, the owner or operator is not 
required to maintain copies of those reports. If the EPA Regional Office 
has waived the requirement of Sec. 65.5(g)(1) for submittal of 
copies of reports, the owner or operator is not required to maintain 
copies of the waived reports. Paragraph (b) of this section applies only 
to reports and not the underlying records which must be maintained as 
specified throughout this part.
    (c) Availability of records. All applicable records shall be 
maintained in such a manner that they can be readily accessed and are 
suitable for inspection as specified in the following:
    (1) Except as specified in paragraph (c)(2) of this section, records 
of the most recent 2 years shall be retained onsite or shall be 
accessible to an inspector while onsite. The records of the remaining 3 
years, where required, may be retained offsite.
    (2) For sources referenced to this part from 40 CFR part 63, subpart 
G or H, the most recent 6 months of records shall be retained on site or 
shall be accessible to an inspector while onsite from a central location 
by computer or other means that provides access within 2 hours after a 
request. The remaining 4 and one-half years of records, where required, 
may be retained offsite.
    (3) Records specified in paragraph (c)(1) or (2) of this section may 
be maintained in hard copy or computer-readable form including, but not 
limited to, on paper, microfilm, computer, computer disk, magnetic tape, 
or microfiche.



Sec. 65.5  Reporting requirements.

    (a) Required reports. Each owner or operator of a regulated source 
subject to this subpart shall submit the following reports, as 
applicable:
    (1) A Notification of Initial Startup described in paragraph (b) of 
this section.
    (2) An Initial Notification for Part 65 Applicability described in 
paragraph (c) of this section.
    (3) An Initial Compliance Status Report described in paragraph (d) 
of this section.
    (4) Periodic reports described in paragraph (e) of this section.
    (5) Other reports shall be submitted as specified elsewhere in this 
part.
    (6) Startup, Shutdown, and Malfunction Reports described in 
Sec. 65.6(c).
    (b) Notification of Initial Startup. (1) Contents. Any owner or 
operator of a regulated source which elects to comply with this part at 
initial startup shall send the Administrator written notification of the 
actual date of initial startup of a regulated source.
    (2) Due date. The notification of the actual date of initial startup 
shall be postmarked within 15 days after such date.

[[Page 32]]

    (c) Initial Notification for Part 65 Applicability. Owners or 
operators of regulated sources that have been subject to a 40 CFR part 
60, 61, or 63 standard, and who wish to comply with this part, and who 
are not operating the regulated source under an approved title V permit 
shall notify the Administrator of their intent. The notice shall include 
the information specified in paragraphs (c)(1) through (7) of this 
section, as applicable, and may accompany the application for a 
construction permit for the regulated source. This notification may be 
waived by the Administrator.
    (1) Identification of the storage vessels subject to subpart C of 
this part.
    (2) Identification of the process vents subject to subpart D of this 
part, including process vent group status as specified in Sec. 
65.62(a).
    (3) Identification of the process vents subject to 40 CFR part 60, 
subpart DDD, complying with requirements of subpart G of this part.
    (4) Identification of the transfer racks subject to subpart E of 
this part.
    (5) For equipment leaks, identification of the process units subject 
to subpart F of this part.
    (6) The proposed implementation schedule specified in Sec. 
65.1(f)(1) for sources identified in paragraphs (c)(1) through (5) of 
this section.
    (7) Process unit identification. As an alternative to requirements 
specified in paragraphs (c)(1) through (4) of this section, the process 
units can be identified instead of the individual pieces of equipment. 
For this alternative, the kind of emission point in the process unit 
that will comply must also be identified.
    (d) Initial Compliance Status Report - (1) Contents. 
The owner or operator shall submit an Initial Compliance Status Report 
for each regulated source subject to this part containing the 
information specified in the subparts of this part. Unless the required 
information has already been submitted under requirements of the 
applicable referencing subpart, this information can be submitted as 
part of a title V permit application or amendment.
    (2) Due date. The owner or operator shall submit the Initial 
Compliance Status Report for each regulated source within 240 days after 
the applicable compliance date specified in the referencing subparts, or 
within 60 days after the completion of the initial performance test or 
initial compliance determination, whichever is earlier. Initial 
compliance Status Reports may be combined for multiple regulated sources 
as long as the due date requirements for all sources covered in the 
combined report are met.
    (e) Periodic reports. The owner or operator of a source subject to 
monitoring requirements of this part or to other requirements of this 
part where periodic reporting is specified, shall submit a periodic 
report.
    (1) Contents. Periodic reports shall include all information 
specified in subparts of this part.
    (2) Due date. The periodic report shall be submitted semiannually no 
later than 60 calendar days after the end of each 6-month period. The 
first report shall be submitted as specified in the following, as 
applicable:
    (i) The first report shall be submitted no later than the last day 
of the month that includes the date 8 months after the date the source 
became subject to this part or since the last part 60, 61, or 63 
periodic report was submitted for the applicable requirement, whichever 
is earlier.
    (ii) For sources electing to comply with the CAR at initial startup, 
the first report shall cover the 6 months after the Initial Compliance 
Status Report is due. The first report shall be submitted no later than 
the last day of the month that includes the date 8 months after the 
Initial Compliance Status Report is due.
    (3) Overlap with title V reports. Information required by this part, 
which is submitted with a title V periodic report, need not also be 
included in a subsequent periodic report required by this part. The 
title V report shall be referenced in the periodic report required by 
this part.
    (f) General report content. All reports and notifications submitted 
pursuant to this part, including reports that combine information from 
this part and a referencing subpart, shall include the following 
information:

[[Page 33]]

    (1) The name, address, and telephone number (fax number may also be 
provided) of the owner or operator.
    (2) The name, address and telephone number of the person to whom 
inquiries should be addressed, if different than the owner/operator.
    (3) The address (physical location) of the reporting facility.
    (4) Identification of each regulated source covered in the 
submission and identification of which subparts (referencing subparts 
and this part 65) options from this part are applicable to that 
regulated source. Summaries and groupings of this information are 
permitted.
    (g) Report and notification submission - (1) 
Submission. All reports and notifications required under this part shall 
be sent to the Administrator at the appropriate EPA Regional Office and 
to the delegated State authority, except that requests for permission to 
use an alternative means of emission limitation as provided for in 
Sec. 65.8(a) shall be submitted to the Director of the EPA 
Office of Air Quality Planning and Standards, U.S. Environmental 
Protection Agency, MD-10, Research Triangle Park, North Carolina, 27711. 
The EPA Regional Office may waive the requirement to receive a copy of 
any reports or notifications at its discretion.
    (2) Submission of copies. If any State requires a notice that 
contains all the information required in a report or notification listed 
in this part, an owner or operator may send the appropriate EPA Regional 
Office a copy of the report or notification sent to the State to satisfy 
the requirements of this part for that report or notification.
    (3) Method of submission. Wherever this subpart specifies 
``postmark'' dates, submittals may be sent 
by methods other than the U.S. Mail (for example, by fax or courier). 
Submittals shall be sent on or before the specified date.
    (4) Submission by electronic media. If acceptable to both the 
Administrator and the owner or operator of a source, reports may be 
submitted on electronic media.
    (h) Adjustment to timing of submittals and review of required 
communications - (1) Alignment with title V submission. An 
owner or operator may submit periodic reports required by this part on 
the same schedule as the title V periodic report for the facility. The 
owner or operator using this option need not obtain prior approval, but 
must assure no reporting gaps from the last periodic report for the 
relevant standards. The owner or operator shall clearly identify the 
change in reporting schedule in the first report filed under paragraph 
(h) of this section. The requirements of paragraph (e) of this section 
are not waived when implementing this change.
    (2) Request for adjustment. An owner or operator may arrange by 
mutual agreement (which may be a standing agreement) with the 
Administrator a common schedule on which periodic reports required by 
this part shall be submitted throughout the year as long as the 
reporting period is not extended. 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 practical 
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. A request for a change to the periodic reporting schedule 
need only be made once for every schedule change and not once for every 
semiannual report submitted.
    (3) Approval of request for adjustment. 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 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) Notification of delay. If the Administrator is unable to meet a 
specified deadline, the owner or operator will be notified of any 
significant delay and informed of the amended schedule.
    (i) Unless already submitted in a previous report, an owner or 
operator shall report in a title V permit application or as otherwise 
specified by the permitting authority, the information listed in 
paragraphs (i)(1) through (5) of this section. This information shall be

[[Page 34]]

submitted to the Administrator if the regulated source is not a title V 
source.
    (1) A list designating each emission point complying with subparts C 
through G of this part and whether each process vent is Group 1, Group 
2A, or Group 2B.
    (2) The control technology or method of compliance that will be 
applied to each emission point.
    (3) A statement that the compliance demonstration, monitoring, 
inspection, recordkeeping, and reporting provisions in subparts C 
through G of this part that are applicable to each emission point will 
be implemented beginning on the date of compliance as specified in the 
referencing subpart.
    (4) The monitoring information in Sec. 65.162(e) if, for 
any emission point, the owner or operator of a source seeks to comply 
through use of a control technique other than those for which monitoring 
parameters are specified in Sec.Sec. 65.148 through 
65.154.
    (5) Any requests for alternatives to the continuous operating 
parameter monitoring and recordkeeping provisions, as specified in 
Sec. 65.162(d).



Sec. 65.6  Startup, shutdown, and malfunction plan and procedures.

    (a) Paragraphs (b) and (c) of this section do not apply to Group 2A 
or Group 2B process vents.
    (b) Startup, shutdown, and malfunction plan. (1) Description and 
purpose of plan. The owner or operator of a regulated source shall 
develop and implement a written startup, shutdown, and malfunction plan 
that describes, in detail, procedures for operating and maintaining the 
regulated source during periods of startup, shutdown, and malfunction 
and a program of corrective action for malfunctioning process and air 
pollution control equipment used to comply with the relevant standard. 
The plan shall also address routine or otherwise predictable CPMS 
malfunctions. This plan shall be developed by the owner or operator by 
the regulated source's implementation date as specified in 
Sec. 65.1(f), or for sources referenced from 40 CFR part 63, 
subpart F, by the compliance date specified in that subpart. The 
requirement to develop and implement this plan shall be incorporated 
into the source's title V permit. This requirement is optional for 
equipment that must comply with subpart F of this part. It is not 
optional for equipment equipped with a closed vent system and control 
device subject to subpart G of this part. The purposes of the startup, 
shutdown, and malfunction plan are described in the following:
    (i) To ensure that owners or operators are prepared to correct 
malfunctions as soon as practical after their occurrence in order to 
minimize excess emissions of regulated material (excess emissions are 
defined in Sec. 65.3(a)(4)); and
    (ii) To reduce the reporting burden associated with periods of 
startup, shutdown, and malfunction (including corrective action taken to 
restore malfunctioning process and air pollution control equipment to 
its normal or usual manner of operation).
    (2) Operation of source. During periods of startup, shutdown, and 
malfunction, the owner or operator of a regulated source shall operate 
and maintain such source (including associated air pollution control 
equipment and CPMS) in accordance with the procedures specified in the 
startup, shutdown, and malfunction plan developed under paragraph (b)(1) 
of this section.
    (3) Use of additional procedures. To satisfy the requirements of 
this section to develop a startup, shutdown, and malfunction plan, the 
owner or operator may use the regulated source's standard operating 
procedures (SOP) manual, or an Occupational Safety and Health 
Administration (OSHA) or other plan, provided the alternative plans meet 
all the requirements of this section and are made available for 
inspection when requested by the Administrator.
    (4) Revisions to the plan. Based on the results of a determination 
made under Sec. 65.3(b)(3), the Administrator may require that 
an owner or operator of a regulated source make changes to the startup, 
shutdown, and malfunction plan for that source. The Administrator may 
require reasonable revisions to a startup, shutdown, and malfunction 
plan, if the Administrator finds that the plan is inadequate as 
specified in the following:
    (i) Does not address a startup, shutdown, and malfunction event of 
the

[[Page 35]]

CPMS, the air pollution control equipment, or the regulated source that 
has occurred; or
    (ii) Fails to provide for the operation of the regulated source 
(including associated air pollution control equipment and CPMS) during a 
startup, shutdown, and malfunction event in a manner consistent with 
good air pollution control practices for minimizing emissions to the 
extent practical; or
    (iii) Does not provide adequate procedures for correcting 
malfunctioning process and/or air pollution control equipment as quickly 
as practicable; or
    (iv) Does not provide adequate measures to prevent or minimize 
excess emissions to the extent practical as specified and defined in 
Sec. 65.3(a)(4).
    (5) Additional malfunction plan requirements. If the startup, 
shutdown, and malfunction plan fails to address or inadequately 
addresses an event that meets the characteristics of a malfunction but 
was not included in the startup, shutdown, and malfunction plan at the 
time the owner or operator developed the plan, the owner or operator 
shall revise the startup, shutdown, and malfunction plan within 45 days 
after the event to include detailed procedures for operating and 
maintaining the regulated source during similar malfunction events, and 
a program of corrective action for similar malfunctions of process or 
air pollution control equipment or CPMS.
    (6) Retain plan on site. The current plan must be kept on site at 
all times.
    (c) Periodic startup, shutdown, and malfunction reports. During the 
reporting period, reports shall only be required for startup, shutdown, 
and malfunction during which excess emissions as defined in 
Sec. 65.3(a)(4) occur. A startup, shutdown, and malfunction 
report can be submitted as part of a periodic report required under 
Sec. 65.5(e), or on a more frequent basis if specified 
otherwise in a relevant standard or as established otherwise by the 
permitting authority in the source's title V permit. The startup, 
shutdown, and malfunction report shall be delivered or postmarked by the 
30th day following the end of each calendar half (or other calendar 
reporting period, as appropriate), unless the information is submitted 
with the periodic report. The report shall include the following 
information, as appropriate:
    (1) The name, title, and signature of the owner or operator or other 
responsible official certifying its accuracy.
    (2) The number of startup, shutdown, malfunction events and the 
total duration of all periods of startup, shutdown, and malfunction for 
the reporting period.
    (3) If actions taken by an owner or operator during a startup, 
shutdown, and malfunction of a regulated source, or of a control device 
or monitoring system required for compliance (including actions taken to 
correct a malfunction) are consistent with the procedures specified in 
the source's startup, shutdown, and malfunction plan, then the owner or 
operator shall state such information in a startup, shutdown, and 
malfunction report.
    (4) If at any time an action taken by an owner or operator, during a 
startup, shutdown, or malfunction (including actions taken to correct a 
malfunction) during which excess emissions occur, as defined in 
Sec. 65.3(a)(4), is not consistent with the procedures 
specified in the regulated source's startup, shutdown, and malfunction 
plan, the owner or operator shall report the actions taken for that 
event as part of the periodic report. The report shall explain the 
circumstances of the event, the reasons for not following the startup, 
shutdown, and malfunction plan, and whether any excess emissions and/or 
parameter monitoring exceedances are believed to have occurred.



Sec. 65.7  Monitoring, recordkeeping, and reporting waivers and alternatives.

    (a) Waiver of recordkeeping or reporting 
requirements - (1) Waiver application. The owner or 
operator may apply for a waiver from recordkeeping or reporting 
requirements if the regulated source is achieving the relevant 
standard(s), or the source is operating under an extension of compliance 
under 40 CFR 63.6(i), or a waiver of compliance under 40 CFR 61.10(b), 
or the owner or operator has requested an extension or waiver of 
compliance and the Administrator is still considering that request. The 
waiver application shall be submitted in writing to the Administrator.

[[Page 36]]

    (2) Extension of compliance request. If an application for a waiver 
of recordkeeping or reporting is made, the application shall accompany 
the request for an extension of compliance under 40 CFR 63.6(i) or the 
request for a waiver of compliance under 40 CFR 61.10(b), any required 
compliance progress report or compliance status report required in the 
source's title V permit application or a permit modification 
application, or a periodic report required under this part, whichever is 
applicable. The application shall include whatever information the owner 
or operator considers useful to convince the Administrator that a waiver 
of recordkeeping or reporting is warranted.
    (3) Approval or denial of waiver. The Administrator will approve or 
deny a request for a waiver of recordkeeping or reporting requirements 
when performing one of the following actions:
    (i) Approves or denies an extension of compliance under 40 CFR 
63.6(i) or a waiver of compliance under 40 CFR 61.10(b); or
    (ii) Makes a determination of compliance following the submission of 
a required compliance status report or periodic report; or
    (iii) Makes a determination of suitable progress toward compliance 
following the submission of a compliance progress report, whichever is 
applicable.
    (4) Waiver conditions. A waiver of any recordkeeping or reporting 
requirement granted under this paragraph (a) may be conditioned on other 
recordkeeping or reporting requirements deemed necessary by the 
Administrator.
    (5) Waiver cancellation. Approval of any waiver granted under this 
section shall not abrogate the Administrator's authority under the Act 
or in any way prohibit the Administrator from later canceling the 
waiver. The cancellation will be made only after notice is given to the 
owner or operator of the regulated source.
    (b) Requests for approval of alternative monitoring or 
recordkeeping. An owner or operator may submit a written request for 
approval to use alternatives to the monitoring or recordkeeping 
provisions of this part. For process vents and transfer racks, except 
low-throughput transfer racks, the provisions in paragraph (c) of this 
section shall govern the review and approval of requests. In addition, 
the application shall include information justifying the owner or 
operator's request for an alternative monitoring or recordkeeping 
method, such as the technical or economic infeasibility, or the 
impracticality, of the regulated source using the required method. For 
storage vessels and low throughput transfer racks, owners and operators 
shall comply with the requirements of Sec. 65.145(b) for 
preparing and submitting a design evaluation. For equipment leaks, 
owners and operators shall comply with the recordkeeping requirements of 
Sec. 65.163(d).
    (c) Approval or denial of request to use alternative monitoring or 
recordkeeping. The Administrator will notify the owner or operator of 
approval or intention to deny approval of the request to use an 
alternative monitoring or recordkeeping method within 90 calendar days 
after receipt of the original request and within 30 calendar days after 
receipt of any supplementary information that is submitted. Before 
disapproving any request to use an alternative method, the Administrator 
will notify the applicant of the Administrator's intention to disapprove 
the request together with the following:
    (1) Notice of the information and findings on which the intended 
disapproval is based; and
    (2) Notice of opportunity for the owner or operator to present 
additional information to the Administrator before final action on the 
request. At the time the Administrator notifies the applicant of the 
intention to disapprove the request, the Administrator will specify how 
much time the owner or operator will have after being notified of the 
intended disapproval to submit the additional information.
    (d) Use of an alternative monitoring or recordkeeping method. (1) 
The owner or operator of a regulated source is subject to the monitoring 
and recordkeeping requirements of the relevant standard unless 
permission to use an alternative monitoring or recordkeeping method 
requested under paragraph (b) of this section or Sec. 
65.162(d) has been granted by the Administrator.

[[Page 37]]

Once an alternative is approved, the owner or operator shall use the 
alternative for the emission points or regulated sources cited in the 
approval and shall meet the monitoring and recordkeeping requirements of 
the relevant standard for all other emission points or regulated 
sources.
    (2) If the Administrator approves the use of an alternative 
monitoring or recordkeeping method for a regulated source under 
paragraph (c) of this section, the owner or operator of such source 
shall continue to use the alternative monitoring or recordkeeping method 
unless he or she receives approval from the Administrator to use another 
method.
    (3) If the Administrator finds reasonable grounds to dispute the 
results obtained by an alternative monitoring or recordkeeping method, 
requirement, or procedure, the Administrator may require the use of a 
method, requirement, or procedure specified in the relevant standard. If 
the results of the specified and alternative methods, requirements, or 
procedures do not agree, the results obtained by the specified method, 
requirement, or procedure shall prevail.



Sec. 65.8  Procedures for approval of alternative means of emission limitation.

    (a) Alternative means of emission limitation. An owner or operator 
may request a determination of equivalence for an alternative means of 
emission limitation to the requirements of design, equipment, work 
practice, or operational standards of this part. If, in the judgment of 
the Administrator, an alternative means of emission limitation will 
achieve a reduction in regulated material emissions at least equivalent 
to the reduction in emissions from that source achieved under any 
design, equipment, work practice, or operational standards (but not 
performance standards) in this part, the Administrator will publish in 
the Federal Register a notice permitting the use of the alternative 
means for purposes of compliance with that requirement.
    (1) The notice may condition the permission on requirements related 
to the operation and maintenance of the alternative means.
    (2) Any such notice shall be published only after public notice and 
an opportunity for a hearing.
    (b) Content of submittal. (1) In order to obtain approval, any 
person seeking permission to use an alternative means of compliance 
under this section shall collect, verify, and submit to the 
Administrator information showing that the alternative means achieves 
equivalent emission reductions. An owner or operator seeking permission 
to use an alternative means of compliance who has not previously 
performed testing shall also submit a proposed test plan. If the owner 
or operator seeks permission to use an alternative means of compliance 
based on previously performed testing, they shall submit the results of 
that testing, a description of the procedures followed in testing or 
monitoring, and a description of pertinent conditions during testing or 
monitoring.
    (2) The owner or operator who requests an alternative means of 
emission limitation shall submit a description of the proposed testing, 
monitoring, recordkeeping, and reporting that will be used and the 
proposed basis for demonstrating compliance.
    (3) For storage vessels, the owner or operator shall include the 
results of actual emissions tests using full-size or scale-model storage 
vessels that accurately collect and measure all regulated material 
emissions using a given control technique, and that accurately simulate 
wind and account for other emission variables such as temperature and 
barometric pressure, or an engineering analysis that the Administrator 
determines is an accurate method of determining equivalence.
    (4) For proposed alternatives to equipment leak requirements, the 
owner or operator shall also submit the information and meet the 
requirements for alternative means of emission limitation specified in 
Sec. 65.102(b) (alternative means of emission limitation).
    (c) Manufacturers of equipment used to control equipment leaks of a 
regulated material may request a determination of equivalence for an 
alternative means of emission limitation for equipment leaks, as 
specified in Sec. 65.102(c).

[[Page 38]]

    (d) Compliance. If the Administrator makes a determination that a 
means of emission limitation is a permissible alternative to the 
requirements of design, equipment, work practice, or operational 
standards of this part, the owner or operator shall either comply with 
the alternative or comply with the requirements of this part.



Sec. 65.9  Availability of information and confidentiality.

    (a) 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. With the 
exception of information protected under part 2 of this chapter, all 
reports, records, and other information collected by the Administrator 
under this part are available to the public. In addition, a copy of each 
permit application, compliance plan (including the schedule of 
compliance), initial compliance status report, periodic report, and 
title V permit is available to the public, consistent with protections 
recognized in section 503(e) of the Act.
    (b) Confidentiality. (1) If an owner or operator is required to 
submit information entitled to protection from disclosure under section 
114(c) of the Act, the owner or operator may submit such information 
separately. The requirements of section 114(c) shall apply to such 
information.
    (2) The contents of a title V permit shall not be entitled to 
protection under section 114(c) of the Act; however, information 
submitted as part of an application for a title V permit may be entitled 
to protection from disclosure.



Sec. 65.10  State authority.

    (a) The provisions of this part shall not be construed in any manner 
to preclude any State or political subdivision thereof from adopting and 
enforcing any emission standard or limitation applicable to a regulated 
source, provided that such standard, limitation, prohibition, or other 
regulation is not less stringent than the standard applicable to such a 
regulated source.
    (b) The provisions of this part shall not be construed in any manner 
to preclude any State or political subdivision thereof from requiring 
the owner or operator of a regulated source to obtain permits, licenses, 
or approvals prior to initiating construction, modification, or 
operation of such a regulated source.



Sec. 65.11  Circumvention and prohibited activities.

    (a) Circumvention. (1) No owner or operator subject to the 
provisions of this part shall build, erect, install, or use any article, 
machine, equipment, or process to conceal an emission that would 
otherwise constitute noncompliance with a relevant standard. Such 
concealment includes, but is not limited to, the following:
    (1) The use of diluents to achieve compliance with a relevant 
standard based on the concentration of a pollutant in the effluent 
discharged to the atmosphere; and
    (2) The fragmentation of an operation for the purpose of avoiding 
regulation by a relevant standard.
    (b) Prohibited activities. (1) No owner or operator subject to the 
provisions of this part shall operate any regulated source in violation 
of the requirements of this part except under the following provisions:
    (i) An extension or waiver of compliance granted by the 
Administrator under an applicable part; or
    (ii) An extension of compliance granted under an applicable part by 
a State with an approved permit program; or
    (iii) An exemption from compliance granted by the President under 
section 112(i)(4) of the Act.
    (2) After the effective date of an approved permit program in a 
State, no owner or operator of a regulated source in that State who is 
required under an applicable part to obtain a title V permit shall 
operate such source except in compliance with the provisions of this 
part and the applicable requirements of the permit program in that 
State.
    (3) An owner or operator of a regulated source who is subject to an 
emission standard promulgated under this part or a referencing part 
shall comply with the requirements of that standard

[[Page 39]]

by the date(s) established in the applicable subpart(s) (including this 
subpart) regardless of whether the following criteria are met:
    (i) A title V permit has been issued to that source; or
    (ii) If a title V permit has been issued to that source, whether 
such permit has been revised or modified to incorporate the emission 
standard.
    (c) Severability. Notwithstanding any requirement incorporated into 
a title V permit obtained by an owner or operator subject to the 
provisions of this part, the provisions of this part are federally 
enforceable.



Sec. 65.12  Delegation of authority.

    (a) In delegating implementation and enforcement authority to a 
State under sections 111(c) and 112(l) 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 that will not be delegated to States: 
Sec.Sec. 65.8, 65.46, 65.102, 65.156(b)(l)(ii), and 
65.158(a)(2)(ii).



Sec. 65.13  Incorporation by reference.

    (a) The materials listed in this section are incorporated by 
reference in the corresponding sections noted. These incorporations by 
reference were approved by the Director of the Federal Register in 
accordance with 5 U.S.C. 552(a) and 1 CFR part 51. These materials are 
incorporated as they exist on the date of the approval, and notice of 
any change in these materials will be published in the Federal Register. 
The materials are available for purchase at the corresponding addresses 
noted in paragraph (b) of this section, and all are available for 
inspection at the Office of the Federal Register, 800 North Capitol 
Street, NW, Suite 700, Washington, DC; at the Air and Radiation Docket 
and Information Center, U.S. EPA, 401 M Street, SW., Washington, DC; and 
at the EPA Library (MD-35), U.S. EPA, Research Triangle Park, North 
Carolina.
    (b) The materials listed in this paragraph (b) are available for 
purchase from at least one of the following addresses: American Society 
for Testing and Materials (ASTM), 1916 Race Street, Philadelphia, 
Pennsylvania 19103; or University Microfilms International, 300 North 
Zeeb Road, Ann Arbor, Michigan 48106.
    (1) ASTM D1946-77, Standard Method for Analysis of Reformed Gas by 
Gas Chromatography, IBR approved December 14, 2000 for 
Sec.Sec. 65.64(e)(2) and 65.147(a)(4)(i) and 
(b)(3)(ii).
    (2) ASTM D2382-76, Standard Test Method for Heat of Combustion of 
Hydrocarbon Fuels by Bomb Calorimeter (High-Precision Method). IBR 
approved December 14, 2000 for Sec.Sec. 65.64(e)(1) 
and 65.147(b)(3)(ii).



Sec. 65.14  Addresses.

    (a) All requests, reports, applications, notifications, and other 
communications submitted pursuant to this part, except as specified 
under Sec. 65.5(g)(1), shall be sent to the Administrator at 
the appropriate EPA Regional Office indicated in the following list:

Region I (Connecticut, Maine, Massachusetts, New Hampshire, Rhode 
Island, Vermont), Director, Air Management Division, U.S. Environmental 
Protection Agency, John F. Kennedy Federal Building, Boston, 
Massachusetts 02203.
Region II (New Jersey, New York, Puerto Rico, Virgin Islands), Director, 
Air and Waste Management Division, U.S. Environmental Protection Agency, 
290 Broadway, New York, New York 10007.
Region III (Delaware, District of Columbia, Maryland, Pennsylvania, 
Virginia, West Virginia), Director, Air and Waste Management Division, 
U.S. Environmental Protection Agency, 841 Chestnut Building, 
Philadelphia, Pennsylvania 19107.
Region IV (Alabama, Florida, Georgia, Kentucky, Mississippi, North 
Carolina, South Carolina, Tennessee), Director, Air and Waste Management 
Division, U.S. Environmental Protection Agency, 61 Forsyth Street, 
Atlanta, Georgia 30303.
Region V (Illinois, Indiana, Michigan, Minnesota, Ohio, Wisconsin), 
Director, Air Management Division, U.S. Environmental Protection Agency, 
77 West Jackson Boulevard, Chicago, Illinois 60604-3507.
Region VI (Arkansas, Louisiana, New Mexico, Oklahoma, Texas); Director; 
Compliance Assurance and Enforcement Division; U.S. Environmental 
Protection Agency, 1445 Ross Avenue, Dallas, Texas 75202.
Region VII (Iowa, Kansas, Missouri, Nebraska), Director, Air and Toxics 
Division, U.S. Environmental Protection Agency, 726 Minnesota Avenue, 
Kansas City, Kansas 66101.

[[Page 40]]

Region VIII (Colorado, Montana, North Dakota, South Dakota, Utah, 
Wyoming), Director, Air and Waste Management Division, U.S. 
Environmental Protection Agency, 999 18th Street, Suite 500, Denver, 
Colorado 80295.
Region IX (American Samoa, Arizona, California, Guam, Hawaii, Nevada), 
Director, Air and Waste Management Division, U.S. Environmental 
Protection Agency, 75 Hawthorne Street, San Francisco, California 94105.
Region X (Alaska, Oregon, Idaho, Washington), Director, Air and Waste 
Management Division, U.S. Environmental Protection Agency, 1200 Sixth 
Avenue, Seattle, Washington 98101.

    (b) All information required to be submitted to the Administrator 
under this part shall also be submitted to the appropriate State agency 
of any State to which authority has been delegated under section 112(l) 
of the Act. The mailing addresses for State agencies are listed as 
follows:
    (1) Alabama. Air Pollution Control Division, Air Pollution Control 
Commission, 645 S. McDonough Street, Montgomery, Alabama 36104.
    (2) Alaska. Department of Environmental Conservation, 3220 Hospital 
Drive, Juneau, Alaska 99811.
    (3) Arizona. Arizona Department of Health Services, 1740 West Adams 
Street, Phoenix, Arizona 85007.
    (4) Arkansas. Chief, Division of Air Pollution Control, Arkansas 
Department of Pollution Control and Ecology, 8001 National Drive, P.O. 
Box 9583, Little Rock, Arkansas 72209.
    (5) California. (i) Amador County Air Pollution Control District, 
P.O. Box 430, 810 Court Street, Jackson, California 95642.
    (ii) Bay Area Air Pollution Control District, 939 Ellis Street, San 
Francisco, California 94109.
    (iii) Butte County Air Pollution Control District, P.O. Box 1229, 
316 Nelson Avenue, Oroville, California 95965.
    (iv) Calaveras County Air Pollution Control District, Government 
Center, El Dorado Road, San Andreas, California 95249.
    (v) Camino del Rimedio, Santa Barbara, California 93110.
    (vi) Colusa County Air Pollution Control District, 751 Fremont 
Street, Colusa, California 95952.
    (vii) El Dorado Air Pollution Control District, 330 Fair Lane, 
Placerville, California 95667.
    (viii) Fresno County Air Pollution Control District, 1221 Fulton 
Mall, Fresno, California 93721.
    (ix) Glenn County Air Pollution Control District, P.O. Box 351, 720 
North Colusa Street, Willows, California 95988.
    (x) Great Basin Unified Air Pollution Control District, 157 Short 
Street, suite 6, Bishop, California 93514.
    (xi) Imperial County Air Pollution Control District, County Services 
Building, 939 West Main Street, El Centro, California 92243.
    (xii) Kern County Air Pollution Control District, 1601 H Street, 
suite 250, Bakersfield, California 93301.
    (xiii) Kings County Air Pollution Control District, 330 Campus 
Drive, Hanford, California 93230.
    (xiv) Lake County Air Pollution Control District, 255 North Forbes 
Street, Lakeport, California 95453.
    (xv) Lassen County Air Pollution Control District, 175 Russell 
Avenue, Susanville, California 96130.
    (xvi) Madera County Air Pollution Control District, 135 West 
Yosemite Avenue, Madera, California 93637.
    (xvii) Mariposa County Air Pollution Control District, Box 5, 
Mariposa, California 95338.
    (xviii) Mendocino County Air Pollution Control District, County 
Courthouse, Ukiah, California 94582.
    (xix) Merced County Air Pollution Control District, P.O. Box 471, 
240 East 15th Street, Merced, California 95340.
    (xx) Modoc County Air Pollution Control District, 202 West 4th 
Street, Alturas, California 96101.
    (xxi) Monterey Bay Unified Air Pollution Control, 1164 Monroe 
Street, Suite 10, Salinas, California 93906.
    (xxii) Nevada County Air Pollution Control District, H.E.W. Complex, 
Nevada City, California 95959.
    (xxiii) North Coast Unified Air Quality Management District, 5630 
South Broadway, Eureka California 95501.
    (xxiv) Northern Sonoma County Air Pollution Control District, 134 
``A'' Avenue, Auburn, California 95448.
    (xxv) Placer County Air Pollution Control District, 11491 
``B'' Avenue, Auburn, California 95603.

[[Page 41]]

    (xxvi) Shasta County Air Pollution Control District, 2650 Hospital 
Lane, Redding, California 96001.
    (xxvii) Sierra County Air Pollution Control District, P.O. Box 286, 
Downieville, California 95936.
    (xxviii) Siskiyou County Air Pollution Control District, 525 South 
Foothill Drive, Yreka, California 96097.
    (xxix) South Coast Air Quality Management District, 9150 Flair 
Drive, El Monte, California 91731.
    (xxx) Stanislaus County Air Pollution Control District, 1030 Scenic 
Drive, Modesto, California 95350.
    (xxxi) Sutter County Air Pollution Control District, Sutter County 
Office Building, 142 Garden Highway, Yuba City, California 95991.
    (xxxii) Tehama County Air Pollution Control District, P.O. Box 38, 
1760 Walnut Street, Red Bluff, California 96080.
    (xxxiii) Tulare County Air Pollution Control District, County Civic 
Center, Visalia, California 93277.
    (xxxiv) Tuolumne County Air Pollution Control District, 9 North 
Washington Street, Sonora, California 95370.
    (xxxv) Ventura County Air Pollution Control District, 800 South 
Victoria Avenue, Ventura, California 93009.
    (xxxvi) Yolo-Solano Air Pollution Control District, P.O. Box 1006, 
323 First Street, i5, Woodland, California 95695.
    (6) Colorado. Department of Health, Air Pollution Control Division, 
4210 East 11th Avenue, Denver, Colorado 80220.
    (7) Connecticut. Bureau of Air Management, Department of 
Environmental Protection, State Office Building, 165 Capitol Avenue, 
Hartford, Connecticut 06106.
    (8) Delaware. Delaware Department of Natural Resources and 
Environmental Control, Tatnall Building, P.O. Box 1401, Dover, Delaware 
19901.
    (9) Florida. Florida Bureau of Air Quality Management, Department of 
Environmental Regulation, Twin Towers Office Building, 2600 Blair Stone 
Road, Tallahassee, Florida 32301.
    (10) Georgia. Environmental Protection Division, Department of 
Natural Resources, 270 Washington Street, SW., Atlanta, Georgia 30334.
    (11) Hawaii. (i) Hawaii Department of Health, 1250 Punchbowl Street, 
Honolulu, Hawaii 96813.
    (ii) Hawaii Department of Health (mailing address), Post Office Box 
3378, Honolulu, Hawaii 96801.
    (12) Idaho. Idaho Division of Environmental Quality 601 Pole Line 
Rd. Ste.  2 Twin Falls, Idaho 83301.
    (13) Illinois. Illinois Environmental Protection 
Agency - Bureau of Air 1340 North Ninth St., Springfield 
Illinois 62702 1021 North Grand Avenue East (mailing address) P.O. Box 
19276 62794-9276.
    (14) Indiana. Indiana Department of Environmental Management, 105 
South Meridian Street, P.O. Box 6015, Indianapolis, Indiana 46206.
    (15) Iowa. Iowa Department of Natural Resources, Environmental 
Protection Division, Henry A. Wallace Building, 900 East Grand, Des 
Moines, Iowa 50319.
    (16) Kansas. Kansas Department of Health and Environment, Bureau of 
Air Quality and Radiation Control, Forbes Field, Topeka, Kansas 66620.
    (17) Kentucky. Kentucky Division of Air Pollution Control, 
Department for Natural Resources and Environmental Protection, U.S. 127, 
Frankfort, Kentucky 40601.
    (18) Louisiana. Program Administrator, Air Quality Division, 
Louisiana Department of Environmental Quality, P.O. Box 44096, Baton 
Rouge, Louisiana 70804.
    (19) Maine. Bureau of Air Quality Control, Department of 
Environmental Protection, State House, Station No. 17, Augusta, Maine 
04333.
    (20) Maryland. Bureau of Air Quality and Noise Control, Maryland 
State Department of Health and Mental Hygiene, 201 West Preston Street, 
Baltimore, Maryland 21201.
    (21) Massachusetts. Division of Air Quality Control, Department of 
Environmental Protection, One Winter Street, 7th floor, Boston, 
Massachusetts 02108.
    (22) Michigan. Air Pollution Control Division, Michigan Department 
of Natural Resources, Stevens T. Mason Building, 8th Floor, Lansing, 
Michigan 48926.

[[Page 42]]

    (23) Minnesota. Minnesota Pollution Control Agency, Division of Air 
Quality, 520 Lafayette Road, St. Paul, Minnesota 55155.
    (24) Mississippi. Bureau of Pollution Control, Department of Natural 
Resources, P.O. Box 10385, Jackson, Mississippi 39209.
    (25) Missouri. Missouri Department of Natural Resources, Division of 
Environmental Quality, P.O. Box 176, Jefferson City, Missouri 65102.
    (26) Montana. Department of Health and Environmental Services, Air 
Quality Bureau, Cogswell Building, Helena, Montana 59601.
    (27) Nebraska. Nebraska Department of Environmental Control, P.O. 
Box 94877, State House Station, Lincoln, Nebraska 68509.
    (28) Nevada. Nevada Department of Conservation and Natural 
Resources, Division of Environmental Protection, 201 South Fall Street, 
Carson City, Nevada 89710.
    (29) New Hampshire. Air Resources Division, Department of 
Environmental Services, 64 North Main Street, Caller Box 2033, Concord, 
New Hampshire 03302-2033.
    (30) New Jersey. New Jersey Department of Environmental Protection, 
John Fitch Plaza, P.O. Box 2807, Trenton, New Jersey 08625.
    (31) New Mexico. Director, New Mexico Environmental Improvement 
Division, Health and Environment Department, 1190 St. Francis Drive, 
Santa Fe, New Mexico 87503.
    (32) New York. New York State Department of Environmental 
Conservation, 50 Wolf Road, Albany, New York 12233, Attention: Division 
of Air Resources.
    (33) North Carolina. North Carolina Environmental Management 
Commission, Department of Environment and Natural Resources, Division of 
Air Quality, P.O. Box 29580, Raleigh, North Carolina 27626-0580.
    (34) North Dakota. State Department of Health and Consolidated 
Laboratories, Division of Environmental Engineering, State Capitol, 
Bismarck, North Dakota 58505.
    (35) Ohio. Ohio Environmental Protection Agency, Central District 
Office, Air Pollution Unit, P.O. Box 1049, Columbus, Ohio 43266-0149.
    (36) Oklahoma. Oklahoma State Department of Health, Air Quality 
Service, P.O. Box 53551, Oklahoma City, Oklahoma 73152.
    (37) Oregon. Department of Environmental Quality, Yeon Building, 522 
SW. Fifth, Portland, Oregon 97204.
    (38) Pennsylvania. Department of Environmental Resources, Post 
Office Box 2063, Harrisburg, Pennsylvania 17120.
    (39) Rhode Island. Division of Air and Hazardous Materials, 
Department of Environmental Management, 291 Promenade Street, 
Providence, Rhode Island 02908.
    (40) South Carolina. Office of Environmental Quality Control, 
Department of Health and Environmental Control, 2600 Bull Street, 
Columbia, South Carolina 29201.
    (41) South Dakota. Department of Water and Natural Resources, Office 
of Air Quality and Solid Waste, Joe Foss Building, 523 East Capitol, 
Pierre, South Dakota 57501-3181.
    (42) Tennessee. Division of Air Pollution Control, Tennessee 
Department of Public Health, 256 Capitol Hill Building, Nashville, 
Tennessee 37219.
    (43) Texas. Texas Natural Resource Conservation Commission, P.O. Box 
13087, Austin, Texas 78711-3087.
    (44) Utah. Department of Health, Bureau of Air Quality, 288 North 
1460 West, P.O. Box 16690, Salt Lake City, Utah 84116-0690.
    (45) Vermont. Air Pollution Control Division, Agency of Natural 
Resources, Building 3 South, 103 South Main Street, Waterbury, Vermont 
05676.
    (46) Virginia. Virginia State Air Pollution Control Board, Room 
1106, Ninth Street Office Building, Richmond, Virginia 23219.
    (47) Washington. Department of Ecology, Olympia, Washington 98504.
    (48) West Virginia. Air Pollution Control Commission, 1558 
Washington Street, East, Charleston, West Virginia 25311.
    (49) Wisconsin. Wisconsin Department of Natural Resources, P.O. Box 
7921, Madison, Wisconsin 53707.
    (50) Wyoming. Wyoming Department of Environmental Quality Air 
Division, 122 West 25th St. - 4th Floor, Cheyenne, Wyoming 
82002.



Sec.Sec. 65.15-65.19  [Reserved]

[[Page 43]]

Table 1 to Subpart A of Part 65 - Applicable 40 CFR Parts 
                    60, 61, and 63 General Provisions

------------------------------------------------------------------------
 
-------------------------------------------------------------------------
A. 40 CFR part 60, subpart A provisions for referencing subparts Ka, Kb,
                       VV, DDD, III, NNN, and RRR
------------------------------------------------------------------------
                          Sec. 60.1,
                          Sec. 60.2,
                          Sec. 60.5,
                          Sec. 60.6,
                 Sec. 60.7(a)(1), and (a)(4),
                          Sec. 60.14,
                          Sec. 60.15,
                          Sec. 60.16
 B. 40 CFR part 61, subpart A provisions for referencing subparts Y, V,
                                 and BB
------------------------------------------------------------------------
                          Sec. 61.01,
                          Sec. 61.02,
                          Sec. 61.05,
                          Sec. 61.06,
                          Sec. 61.07,
                          Sec. 61.08,
                    Sec. 61.10(b), and (c),
               Sec. 61.11, Sec. 61.15
C. 40 CFR part 63, subpart A provisions for referencing subparts G and H
------------------------------------------------------------------------
 Sec. 63.1(a)(1), (a)(2), (a)(3), (a)(13), (a)(14), (b)(2) and
                                 (c)(4)
                           Sec. 63.2
    Sec. 63.5 (a)(1), (a)(2), (b), (d)(1)(ii), (d)(3)(i)a,
  (d)(3)(iii) a, (d)(3)(iv) a, (d)(3)(v) a, (d)(3)(vi) a, (d)(4), (e),
                           (f)(1), and (f)(2)
 Sec. 63.6 (a), (b)(3), (c)(5), (i)(1), (i)(2), (i)(4)(i)(A),
                 (i)(5) through (i)(14), (i)(16) and (j)
 Sec. 63.9(a)(2), (b)(4)(i) b, (b)(4)(ii), (b)(4)(iii), (b)(5)
                             b, (c) and (d)
                       Sec. 63.10(d)(4)
                         Sec. 63.12(b)
 
------------------------------------------------------------------------
a These provisions do not apply to equipment leaks.
b The notifications specified in 40 CFR 63.9(b)(4)(i) and 63.9(b)(5)
  shall be submitted at the times specified in this part 65.

 Table 2 to Subpart A of Part 65 - Applicable Referencing 
                           Subpart Provisions

------------------------------------------------------------------------
 If you have been referenced  from
               * * *                     You must comply with * * *
------------------------------------------------------------------------
40 CFR part 60, subpart Ka........  60.110a, 60.111a, and 60.115a
40 CFR part 60, subpart Kb........  60.110b, 60.111b, 60.116b(c), (e),
                                     (f)(1), and (g)
40 CFR part 60, subpart VV........  60.480, 60.481, 60.482-1(a),
                                     60.485(d), (e), and (f), and
                                     60.486(i) and (j), 60.488, and
                                     60.489
40 CFR part 60, subpart DDD.......  60.560(a), (b) and (d) through (j),
                                     60.561, 60.562-1, 60.562-2, and
                                     60.565(g)(1)
40 CFR part 60, subpart III.......  60.610(a), (b) and (d), 60.611,
                                     60.616, 60.617
40 CFR part 60, subpart NNN.......  60.660(a), (b), (c)(1) through
                                     (c)(3), (c)(5), (d), 60.661,
                                     60.666, and 60.667
40 CFR part 60, subpart RRR.......  60.700(a), (b), (c)(1), (c)(3),
                                     (c)(5), (c)(6), (c)(7), (d),
                                     60.701, 60.706, 60.707
40 CFR part 61, subpart V.........  61.240, 61.241, 61.245(d), 61.246(i)
                                     and (j), and 61.247(a) and (f)
40 CFR part 61, subpart Y.........  61.270, 61.271(d)(2), and 61.274(a)
40 CFR part 61, subpart BB........  61.300 and 61.301
40 CFR part 63, subpart G For       63.100, 63.101, 63.104 and 63.105 of
 process vents, group 1 storage      subpart F and 63.110 and 63.111 of
 vessels, and group 1 transfer       subpart G
 racks.
40 CFR part 63, subpart H.........  63.100, 63.101, 63.104 and 63.105 of
                                     subpart F, and 63.160, 63.161,
                                     63.180(d) of subpart H
------------------------------------------------------------------------


[[Page 44]]

Subpart B [Reserved]



                    Subpart C - Storage Vessels



Sec. 65.40  Applicability.

    (a) The provisions of this subpart and of subpart A of this part 
apply to control of regulated material emissions from surge control 
vessels, bottoms receivers, and other storage vessels where a 
referencing subpart references the use of this subpart for such 
emissions control.
    (b) If a physical or process change is made that causes a storage 
vessel to fall outside the criteria in the referencing subpart that 
required the storage vessel to control emissions of regulated material, 
the owner or operator may elect to no longer comply with the provisions 
of this subpart. Instead, the owner or operator shall comply with any 
applicable provisions of the referencing subpart.



Sec. 65.41  Definitions.

    All terms used in this subpart shall have the meaning given them in 
the Act and in subpart A of this part. If a term is defined in both 
subpart A of this part and in other subparts that reference the use of 
this subpart, the term shall have the meaning given in subpart A of this 
part for purposes of this subpart.



Sec. 65.42  Control requirements.

    (a) For each storage vessel to which this subpart applies, the owner 
or operator shall comply with the requirements of paragraph (b) or (c) 
of this section.
    (b) For each storage vessel storing a liquid for which the maximum 
true vapor pressure of the total regulated material in the liquid is 
less than 76.6 kilopascals (10.9 pounds per square inch), the owner or 
operator shall reduce regulated material emissions to the atmosphere as 
provided in any one of the paragraphs (b)(1) through (7) of this 
section.
    (1) Internal floating roof (IFR). Operate and maintain a fixed roof 
and internal floating roof meeting the requirements of Sec. 
65.43.
    (2) External floating roof (EFR). Operate and maintain an external 
floating roof meeting the requirements of Sec. 65.44.
    (3) EFR converted to IFR. Operate and maintain an external floating 
roof converted to an internal floating roof meeting the requirements of 
Sec. 65.45.
    (4) Closed vent system and flare. Operate and maintain a closed vent 
system and flare as specified in Sec. 65.142(a)(1). Periods of 
planned routine maintenance of the flare during which the flare does not 
meet the specifications of Sec. 65.147 shall not exceed 240 
hours per year. The specifications and requirements in Sec. 
65.147 for flares do not apply during periods of planned routine 
maintenance or during a control system malfunction. The owner or 
operator shall report the periods of planned routine maintenance as 
specified in Sec. 65.166(d).
    (5) Closed vent system and control device. Operate and maintain a 
closed vent system and control device as specified in the following and 
Sec. 65.142(a)(2):
    (i) Except as provided in paragraph (b)(5)(ii) of this section, the 
control device shall be designed and operated to reduce inlet emissions 
of regulated material by 95 percent or greater.
    (ii) For owners or operators referenced to this part from 40 CFR 
part 63, subpart G, and if the owner or operator of a storage vessel can 
demonstrate that a control device installed on the storage vessel on or 
before December 31, 1992 is designed to reduce inlet emissions of total 
organic HAP by greater than or equal to 90 percent but less than 95 
percent, then the control device is required to be operated to reduce 
inlet emissions of total organic HAP by 90 percent or greater.
    (iii) Periods of planned routine maintenance of the control device, 
during which the control device does not meet the specifications of 
paragraph (b)(5)(i) or (ii) of this section, shall not exceed 240 hours 
per year. The owner or operator shall report the periods of planned 
routine maintenance as specified in Sec. 65.166(d).
    (iv) The requirements in paragraph (b)(5)(i) of this section for 
control devices do not apply during periods of planned routine 
maintenance or during a control system malfunction.
    (6) Route to process or fuel gas system. Route the emissions to a 
process or a

[[Page 45]]

fuel gas system as specified in Sec. 65.142(a)(3). Whenever 
the owner or operator bypasses the fuel gas system or process, the owner 
or operator shall comply with the recordkeeping requirement in 
Sec. 65.163(b)(3). Bypassing is permitted if the owner or 
operator complies with one or more of the following conditions:
    (i) The liquid level in the storage vessel is not increased;
    (ii) The emissions are routed through a closed vent system to a 
control device complying with paragraph (b)(4) or (5) of this section; 
or
    (iii) The total aggregate amount of time during which the emissions 
bypass the fuel gas system or process during the calendar year without 
being routed to a control device, for all reasons (except startups/
shutdowns/malfunctions or product changeovers of flexible operation 
units and periods when the storage vessel has been emptied and 
degassed), does not exceed 240 hours.
    (7) Equivalent requirements. Comply with an equivalent to the 
requirements in any one of the paragraphs (b)(1) through (6) of this 
section, as provided in Sec. 65.46.
    (c) For each storage vessel storing a liquid for which the maximum 
true vapor pressure of the total regulated material in the liquid is 
greater than or equal to 76.6 kilopascals (10.9 pounds per square inch), 
the owner or operator shall meet the requirements in paragraph (b)(4), 
(5), or (6) of this section, or equivalent as provided in Sec. 
65.46.



Sec. 65.43  Fixed roof with an internal floating roof (IFR).

    (a) IFR design requirements. The owner or operator who elects to 
control storage vessel regulated material emissions by using a fixed 
roof and an internal floating roof shall comply with the design 
requirements in paragraphs (a)(1) through (4) of this section.
    (1) The internal floating roof shall be designed to float on the 
stored liquid surface except when the floating roof must be supported by 
the leg supports.
    (2) Except as provided in paragraph (a)(3) of this section, the 
internal floating roof shall be equipped with a closure device between 
the wall of the storage vessel and the floating roof edge and shall 
consist of one of the following devices:
    (i) A liquid-mounted seal.
    (ii) A metallic shoe seal.
    (iii) Two continuous seals mounted one above the other. The lower 
seal may be vapor-mounted.
    (3) If the internal floating roof is equipped with a vapor-mounted 
seal as of December 31, 1992, paragraph (a)(2) of this section does not 
apply until the next time the storage vessel is emptied and degassed, or 
by April 22, 2004, whichever occurs first.
    (4) Except as provided in paragraph (a)(4)(viii) of this section, 
each internal floating roof shall meet the following specifications:
    (i) Each opening in a noncontact internal floating roof except for 
automatic bleeder vents (vacuum breaker vents) and rim space vents is to 
provide a projection below the stored liquid surface.
    (ii) Except for leg sleeves, automatic bleeder vents, rim space 
vents, column wells, ladder wells, sample wells, and stub drains, each 
opening shall be equipped with a gasketed cover or gasketed lid.
    (iii) Each penetration of the internal floating roof shall be a 
sample well. Each sample well shall have a slit fabric cover that covers 
at least 90 percent of the opening.
    (iv) Each automatic bleeder vent and rim space vent shall be 
gasketed.
    (v) Each penetration of the internal floating roof that allows for 
passage of a ladder shall have a gasketed sliding cover.
    (vi) 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.
    (vii) Covers on each access hatch and each gauge float well shall be 
designed to be bolted or fastened when they are closed.
    (viii) If the internal floating roof does not meet any one of the 
specifications listed in paragraphs (a)(4)(i) through (vii) of this 
section as of December 31, 1992, the requirement for meeting those 
specifications does not apply until the next time the storage vessel is 
emptied and degassed, or by April 22, 2004, whichever occurs first.

[[Page 46]]

    (b) IFR operational requirements. The owner or operator using a 
fixed roof and an internal floating roof shall comply with the following 
operational requirements:
    (1) The internal floating roof shall float on the stored liquid 
surface at all times except when the floating roof must be supported by 
the leg supports.
    (2) When the floating roof is resting on the leg supports, the 
process of filling or refilling shall be continuous and shall be 
accomplished as soon as practical and the owner or operator shall 
maintain the record specified in Sec. 65.47(e).
    (3) Automatic bleeder vents are to be set 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.
    (4) Each cover, access hatch, gauge float well, or lid on any 
opening in the internal floating roof shall be maintained in a closed 
position at all times (i.e., no visible gaps) except when the device is 
in actual use. Prior to filling the storage vessel, rim space vents are 
to be set to open only when the internal floating roof is not floating, 
or when the pressure beneath the rim seal exceeds the manufacturer's 
recommended setting.
    (c) IFR inspection requirements. To demonstrate compliance, the 
owner or operator shall visually inspect the internal floating roof, the 
primary seal, and the secondary seal (if one is in service) according to 
paragraphs (c)(1) through (4) of this section and maintain records of 
the IFR inspection results as specified in Sec. 65.47(c)(1).
    (1) Single seal. For vessels equipped with a single-seal system, the 
owner or operator shall perform the following inspections:
    (i) Visually inspect for IFR type A failures, the internal floating 
roof, and the seal through manholes and roof hatches on the fixed roof 
no less frequently than once every 12 months.
    (ii) Visually inspect for IFR type B failures, the internal floating 
roof, the seal, gaskets, slotted membranes, and sleeve seals (if any) 
each time the storage vessel is emptied, but no less frequently than 
once every 10 years.
    (2) Double seal. For vessels equipped with two continuous seals 
mounted one above the other, the owner or operator shall perform either 
the inspection required in paragraph (c)(2)(i) of this section or the 
inspections required in paragraph (c)(2)(ii) of this section:
    (i) Visually inspect for IFR type B failures, the internal floating 
roof, the primary seal, the secondary seal, gaskets, slotted membranes, 
and sleeve seals (if any) each time the storage vessel is emptied, but 
no less frequently than once every 5 years; or
    (ii) Visually inspect the internal floating roof and the other 
components as specified in the following:
    (A) For IFR type A failures, inspect the secondary seal through 
manholes and roof hatches on the fixed roof no less frequently than once 
every 12 months; and
    (B) For IFR type B failures, inspect the primary seal, the secondary 
seal, gaskets, slotted membranes, and sleeve seals (if any) each time 
the vessel is emptied, but no less frequently than once every 10 years.
    (3) For inspections to determine if any IFR type B failures are 
present as required by paragraphs (c)(1)(ii), (c)(2)(i), and 
(c)(2)(ii)(B) of this section, the owner or operator shall comply with 
the refilling notification requirements specified in Sec. 
65.48(c)(1).
    (4) After installing the control equipment required to comply with 
Sec. 65.42(b)(1) or (3), 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 regulated material. 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, the owner or operator shall repair the items before filling the 
storage vessel.
    (d) IFR repair requirements. The owner or operator shall repair any 
observed or determined failures according to paragraphs (d)(1) and (2) 
of this section:
    (1) If an IFR type A failure is observed, the owner or operator 
shall repair the items or empty and remove the storage vessel from 
service within 45 calendar days. If the failure cannot be repaired 
within 45 calendar days or if the vessel cannot be emptied within 45 
calendar days, the owner or operator may utilize up to two extensions of 
up

[[Page 47]]

to 30 additional calendar days each and keep the records specified in 
Sec. 65.47(d).
    (2) If an IFR type B failure is determined, the owner or operator 
shall repair the items and comply with the refilling notification 
requirements of Sec. 65.48(c)(1) before refilling the storage 
vessel with regulated material.



Sec. 65.44  External floating roof (EFR).

    (a) EFR design requirements. The owner or operator who elects to 
control storage vessel regulated material emissions by using an external 
floating roof shall comply with the design requirements listed in 
paragraphs (a)(1) through (3) of this section.
    (1) The external floating roof shall be designed to float on the 
stored liquid surface except when the floating roof must be supported by 
the leg supports.
    (2) The external floating roof shall be equipped with a closure 
device between the wall of the storage vessel and the roof edge.
    (i) Except as provided in paragraph (a)(2)(iii) of this section, the 
closure device is to consist of two continuous 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.
    (ii) Except as provided in paragraph (a)(2)(iv) of this section, the 
primary seal shall be either a metallic shoe seal or a liquid-mounted 
seal.
    (iii) If the external floating roof is equipped with a liquid-
mounted or metallic shoe primary seal as of December 31, 1992, the 
requirement for a secondary seal in paragraph (a)(2)(i) of this section 
does not apply until the next time the storage vessel is emptied and 
degassed, or by April 22, 2004, whichever occurs first.
    (iv) If the external floating roof is equipped with a vapor-mounted 
primary seal and a secondary seal as of December 31, 1992, the 
requirement for a liquid-mounted or metallic shoe primary seal in 
paragraph (a)(2)(ii) of this section does not apply until the next time 
the storage vessel is emptied and degassed, or by April 22, 2004, 
whichever occurs first.
    (3) The external floating roof shall meet the following 
specifications:
    (i) Except for automatic bleeder vents (vacuum breaker vents) and 
rim space vents, each opening in the noncontact external floating roof 
shall provide a projection below the stored liquid surface except as 
provided in paragraph (a)(3)(xiii) of this section.
    (ii) Covers on each access hatch and each gauge float well shall be 
designed to be bolted or fastened when they are closed.
    (iii) Except for automatic bleeder vents, rim space vents, roof 
drains, and leg sleeves, each opening shall be equipped with a gasketed 
cover, seal, or lid.
    (iv) Automatic bleeder vents and rim space vents shall be equipped 
with a gasket.
    (v) Each roof drain that empties into the stored liquid shall be 
equipped with a slotted membrane fabric cover that covers at least 90 
percent of the area of the opening.
    (vi) Each unslotted and slotted guide pole well shall be equipped 
with a gasketed sliding cover or a flexible fabric sleeve seal.
    (vii) Except for antirotational devices equipped with a welded cap, 
each unslotted guide pole shall be equipped with a gasketed cap on the 
end of the pole.
    (viii) Each slotted guide pole shall be equipped with a gasketed 
float or other device that closes off the stored liquid surface from the 
atmosphere.
    (ix) Each gauge hatch/sample well shall be equipped with a gasketed 
cover.
    (x) Where a metallic shoe seal is in use as the primary seal, one 
end of the metallic shoe shall be designed to extend into the stored 
liquid and the other end shall extend a minimum vertical distance of 61 
centimeters (24 inches) above the stored liquid surface.
    (xi) The secondary seal shall be designed to be installed above the 
primary seal so that it completely covers the space between the roof 
edge and the vessel wall.
    (xii) For the primary and secondary seals, there shall be no holes, 
tears, or other openings in the shoe, seal fabric, or seal envelope.
    (xiii) If each opening in a noncontact external floating roof except 
for automatic bleeder vents (vacuum breaker vents) and rim space vents 
does not provide a projection below the liquid

[[Page 48]]

surface as of December 31, 1992, the requirement for providing these 
projections below the liquid surface does not apply until the next time 
the storage vessel is emptied and degassed, or by April 22, 2004, 
whichever occurs first.
    (b) EFR operational requirements. The owner or operator using an 
external floating roof shall comply with the following operational 
requirements:
    (1) The external floating roof shall float on the stored liquid 
surface at all times except when the floating roof must be supported by 
the leg supports.
    (2) When the floating roof is resting on the leg supports, the 
process of filling or refilling shall be continuous and shall be 
accomplished as soon as practical, and the owner or operator shall 
maintain the record specified in Sec. 65.47(e).
    (3) Except for automatic bleeder vents, rim space vents, roof 
drains, and leg sleeves, each opening shall be maintained in a closed 
position (i.e., no visible gap) at all times except when the device is 
in actual use.
    (4) Covers on each access hatch and each gauge float well shall be 
bolted or fastened when they are closed.
    (5) Automatic bleeder vents are to be set 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.
    (6) Rim space vents are to be set to open only when the roof is 
being floated off the roof leg supports or when the pressure beneath the 
rim seal exceeds the manufacturer's recommended setting.
    (7) The cap on the end of each unslotted guide pole shall be closed 
at all times except when gauging the stored liquid level or taking 
samples of the stored liquid.
    (8) The cover on each gauge hatch/sample well shall be closed at all 
times except when the hatch or well must be open for access.
    (9) Except during the inspections required by paragraph (c) of this 
section, both the primary seal and 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.
    (c) EFR inspection requirements. To demonstrate compliance for an 
external floating roof vessel, the owner or operator shall use the 
procedures in paragraphs (c)(4) through (9) of this section for seal 
gaps according to the frequency specified in paragraphs (c)(1) through 
(3) of this section and meet the requirements of paragraph (c)(10) of 
this section.
    (1) Measurements of gaps between the vessel wall and the primary 
seal shall be performed no less frequently than once every 5 years and 
at the times specified in paragraphs (c)(1)(i) and (ii) of this section. 
The owner or operator shall maintain records of the EFR seal gap 
measurements as specified in Sec. 65.47(c)(2).
    (i) During the hydrostatic testing of the vessel, by initial 
startup, or within 90 days of the initial fill with regulated material.
    (ii) For an external floating roof vessel equipped with a liquid-
mounted or metallic shoe primary seal and without a secondary seal as 
provided for in paragraph (a)(2)(iii) of this section, measurements of 
gaps between the vessel wall and the primary seal shall be performed at 
least once per year until a secondary seal is installed. When a 
secondary seal is installed above the primary seal, measurements of gaps 
between the vessel wall and both the primary and secondary seals shall 
be performed within 90 calendar days of installation of the secondary 
seal and according to the frequency specified in paragraphs (c)(1) 
through (3) of this section thereafter.
    (2) Measurements of gaps between the vessel wall and the secondary 
seal shall be performed no less frequently than once per year and within 
90 days of the initial fill with regulated material, within 90 days of 
installation of the secondary seal, or by initial startup. The owner or 
operator shall maintain records of the EFR seal gap measurements as 
specified in Sec. 65.47(c)(2).
    (3) If any storage vessel ceases to store regulated material for a 
period of 1 year or more, measurements of gaps between the vessel wall 
and the primary seal, and gaps between the vessel wall and the secondary 
seal shall be performed within 90 days of the vessel being refilled with 
regulated material. The owner or operator shall maintain

[[Page 49]]

records of the EFR seal gap measurements as specified in Sec. 
65.47(c)(2).
    (4) If the tank contains regulated material, all primary seal 
inspections or gap measurements that require the removal or dislodging 
of the secondary seal shall be accomplished as soon as possible, and the 
secondary seal shall be replaced as soon as possible.
    (5) The owner or operator shall notify the Administrator 30 days 
before any EFR seal gap measurement as specified in Sec. 
65.48(c)(2).
    (6) Except as provided in paragraph (d) of this section, the owner 
or operator shall determine gap widths and gap areas in the primary and 
secondary seals (seal gaps) individually by the following procedures:
    (i) Seal gaps, if any, shall be measured at one or more floating 
roof levels when the roof is not resting on the roof leg supports.
    (ii) Seal gaps, if any, shall be measured around the entire 
circumference of the vessel in each place where a 0.32 centimeter (\1/8\ 
inch) diameter uniform probe passes freely (without forcing or binding 
against the seal) between the seal and the wall of the storage vessel. 
The circumferential distance of each such location shall also be 
measured.
    (iii) The total surface area of each gap described in paragraph 
(c)(6)(ii) of this section shall be determined by using probes of 
various widths to measure accurately the actual distance from the vessel 
wall to the seal and multiplying each such width by its respective 
circumferential distance.
    (7) The owner or operator shall add the gap surface area of each gap 
location for the primary seal and divide the sum by the nominal diameter 
of the vessel. The owner or operator shall include the calculations in 
the record of the seal gap measurement as specified in Sec. 
65.47(c)(2). For metallic shoe primary seals or liquid-mounted primary 
seals, the accumulated area of gaps between the vessel wall and the 
primary seal shall not exceed 212 square centimeters per meter of vessel 
diameter (10.0 square inches per foot of vessel diameter) and the width 
of any portion of any gap shall not exceed 3.81 centimeters (1.50 
inches).
    (8) The owner or operator shall add the gap surface area of each gap 
location for the secondary seal and divide the sum by the nominal 
diameter of the vessel. The owner or operator shall include the 
calculations in the record of the seal gap measurement as specified in 
Sec. 65.47(c)(2). The accumulated area of gaps between the 
vessel wall and the secondary seal used in combination with a metallic 
shoe seal or liquid-mounted primary seal shall not exceed 21.2 square 
centimeters per meter of vessel diameter (1.00 square inch per foot of 
vessel diameter) and the width of any portion of any gap shall not 
exceed 1.27 centimeters (0.50 inch). The secondary seal gap requirements 
may be exceeded during the measurement of primary seal gaps as required 
by paragraph (c)(1) of this section.
    (9) If the owner or operator determines that it is unsafe to perform 
the seal gap measurements or to inspect the vessel to determine 
compliance because the floating roof appears to be structurally unsound 
and poses an imminent or potential danger to inspecting personnel, the 
owner or operator shall comply with one of the following requirements:
    (i) The owner or operator shall measure the seal gaps or inspect the 
storage vessel no later than 30 calendar days after the determination 
that the roof is unsafe; or
    (ii) The owner or operator shall empty and remove the storage vessel 
from service no later than 45 calendar days after determining that the 
roof is unsafe. If the vessel cannot be emptied within 45 calendar days, 
the owner or operator may utilize up to two extensions of up to 30 
additional calendar days each and comply with the recordkeeping 
requirements in Sec. 65.47(d).
    (10) The owner or operator shall visually inspect for EFR failures, 
the external floating roof, the primary seal, secondary seal, and 
fittings prior to initial filling and each time the vessel is emptied 
(including initially before the vessel is filled with regulated 
material), shall maintain records of the EFR inspection results as 
specified in Sec. 65.47(c)(1), and shall comply with the 
refilling notification requirements specified in Sec. 
65.48(c)(1).

[[Page 50]]

    (d) EFR repair requirements. (1) The owner or operator shall repair 
conditions that do not meet seal gap specifications listed in paragraphs 
(c)(7) and (8) of this section or any EFR failure observed by the 
inspection required by paragraph (c)(10) of this section no later than 
45 calendar days after identification, or shall empty and remove the 
storage vessel from service no later than 45 calendar days after 
identification. If the vessel cannot be repaired or emptied within 45 
calendar days, the owner or operator may utilize up to two extensions of 
up to 30 additional calendar days each and comply with the recordkeeping 
requirements in Sec. 65.47(d).
    (2) If an EFR failure is observed by the inspection required by 
paragraph (c)(10) of this section, the owner or operator shall repair 
the items as necessary so that none of the conditions specified in 
paragraph (c)(10) of this section exist before filling or refilling the 
storage vessel with regulated material.



Sec. 65.45  External floating roof converted into an internal floating roof.

    The owner or operator who elects to control storage vessel regulated 
material emissions by using an external floating roof converted into an 
internal floating roof shall comply with the internal floating roof 
requirements of Sec. 65.43 except Sec. 65.43(a)(3), 
(b)(2), and (b)(3) and the external floating roof deck fitting 
requirements of Sec. 65.44 except Sec. 65.44(a)(1), 
(a)(2), (b)(1), (b)(8), (b)(9), (c), and (d), including the 
recordkeeping and reporting provisions referenced therein.



Sec. 65.46  Alternative means of emission limitation.

    Any person seeking permission to use an alternative means of 
compliance under this section shall use the procedures of Sec. 
65.8.



Sec. 65.47  Recordkeeping provisions.

    (a) Retention time. Each owner or operator of a storage vessel 
subject to this subpart shall meet the requirements of Sec. 
65.4, except the record specified in paragraph (b) of this section shall 
be kept as long as the storage vessel is in operation.
    (b) Vessel dimensions and capacity. Each owner or operator of a 
storage vessel subject to this subpart shall keep readily accessible 
records showing the dimensions of the storage vessel and an analysis of 
the capacity of the storage vessel.
    (c) Inspection results. The owner or operator shall keep the records 
specified in paragraphs (c)(1) and (2) of this section.
    (1) For each IFR or EFR inspection required by Sec. 
65.43(c)(1) and (2), or Sec. 65.44(c)(10), respectively, a 
record containing the following information, as appropriate:
    (i) In the event that no IFR type A failure, IFR type B failure, or 
EFR failure is observed, a record showing that the inspection was 
performed. The record shall identify the storage vessel on which the 
inspection was performed, the date the storage vessel was inspected, and 
references indicating which items were inspected.
    (ii) In the event that an IFR type A failure, IFR type B failure, or 
EFR failure is observed, a record that identifies the storage vessel on 
which the inspection was performed, the date the storage vessel was 
inspected, a description of the failure and of the repair made, the date 
the vessel was emptied (if applicable), and the date that the repair was 
made. As specified in Sec. 65.48(b)(1), the owner or operator 
shall include this record in the periodic report.
    (2) For each EFR seal gap measurement required by Sec. 
65.44(c)(1), (2), or (3), a record describing the results of the 
measurement. The record shall identify the vessel on which the 
measurement was performed, shall include the date of the measurement, 
the raw data obtained in the measurement, and the calculations described 
in Sec. 65.44(c)(7) and (8), and shall meet the following two 
additional requirements, as appropriate:
    (i) In the event that the seal gap measurements do conform to the 
specifications in Sec. 65.44(c)(7) and (8), the owner or 
operator shall submit the information specified in Sec. 
65.48(b)(2)(i) in the periodic report.
    (ii) In the event that the seal gap measurements do not conform to 
the

[[Page 51]]

specifications in Sec. 65.44(c)(7) and (8), the owner or 
operator shall also keep a description of the repairs that were made, 
the date the repairs were made, and the date the storage vessel was 
emptied and shall include a report of the seal gap measurement results 
in the periodic report as specified in Sec. 65.48(b)(2)(ii).
    (d) Emptying and repairing extension. The owner or operator who 
elects to utilize an extension in emptying a storage vessel for purposes 
of repair shall prepare by the initiation of the extension the following 
documentation, as appropriate, of the decision to utilize an extension:
    (1) For an extension pursuant to Sec. 65.43(d)(1) or 
Sec. 65.44(d)(1), a description of the failure, documentation 
that alternative storage capacity is unavailable, and a schedule of 
actions that will ensure that the control equipment will be repaired or 
the vessel will be emptied as soon as practical. As specified in 
Sec. 65.48(b)(1)(i), the owner or operator shall include this 
information in the periodic report.
    (2) For an extension pursuant to Sec. 65.44(c)(9), an 
explanation of why it was unsafe to perform the inspection or seal gap 
measurement, documentation that alternate storage capacity is 
unavailable, and a schedule of actions that will ensure that the vessel 
will be emptied as soon as practical. As specified in Sec. 
65.48(b)(3), the owner or operator shall include this information in the 
periodic report.
    (e) Floating roof set on its legs. The owner or operator shall 
maintain a record for each storage vessel subject to Sec. 
65.43(b)(2) and Sec. 65.44(b)(2) identifying the date when the 
floating roof was set on its legs and the date when the roof was 
refloated. The record shall also indicate whether this was a continuous 
operation.



Sec. 65.48  Reporting provisions.

    (a) Notification of initial startup. If Sec. 65.5(b) 
requires that a notification of initial startup be filed, then the 
content of the notification of initial startup shall at least include 
the information specified in Sec. 65.5(b) and the 
identification of each storage vessel, its capacity, and the types of 
regulated material stored in the storage vessel.
    (b) Periodic reports. Report the information specified in paragraphs 
(b)(1) through (3) of this section, as applicable, in the periodic 
report specified in Sec. 65.5(e).
    (1) Inspection results. Report the following information for each 
inspection conducted in accordance with Sec. 65.43(c) and 
Sec. 65.44(c) in which an IFR or EFR failure is detected in 
the control equipment:
    (i) If an IFR type A failure or an EFR failure is observed for 
vessels for which inspections are required under Sec. 
65.43(c)(1)(i), Sec. 65.43(c)(2)(ii)(A), or Sec. 
65.44(c)(10), each report shall include the inspection results record 
listed in Sec. 65.47(c)(1)(ii). If an extension is utilized in 
accordance with Sec. 65.43(d)(1) or Sec. 
65.44(d)(1), the report shall include the records listed in 
Sec. 65.47(c)(1)(ii) plus the documentation specified in 
Sec. 65.47(d)(1).
    (ii) If an IFR type B failure is observed for vessels for which 
inspections are required under Sec. 65.43(c)(1)(ii), 
(c)(2)(i), or (c)(2)(ii)(B), each report shall include a copy of the 
records listed in Sec. 65.47(c)(1)(ii).
    (2) Seal gap measurement results. (i) For each vessel whose seal 
gaps are measured during the reporting period, identify each seal gap 
measurement made in accordance with Sec. 65.44(c) in which the 
requirements of Sec. 65.44(c)(7) or (8) are met.
    (ii) For each seal gap measurement made in accordance with 
Sec. 65.44(c) in which the requirements of Sec. 
65.44(c)(7) or (8) are not met, from the records kept pursuant to 
Sec. 65.47(c)(2), report the date of the measurements, results 
of the calculations, and note which seal gap measurements did not 
conform to the specifications in Sec. 65.44(c)(7) and (8).
    (3) Extension documentation. If an extension is utilized in 
accordance with Sec. 65.44(c)(9), the owner or operator shall 
include the documentation specified in Sec. 65.47(d)(2) in the 
next report required by Sec. 65.5(e).
    (c) Special notifications. An owner or operator who elects to comply 
with Sec. 65.43, Sec. 65.44, or Sec. 65.45 
shall submit, as applicable, the reports specified in paragraphs (c)(1) 
and (2) of this section except as specified in paragraph (c)(3) of this 
section. Each written notification or report shall also include the 
information specified in Sec. 65.5(f).

[[Page 52]]

    (1) Refilling notification. In order to afford the Administrator the 
opportunity to have an observer present, notify the Administrator prior 
to refilling of a storage vessel that has been emptied. If the storage 
vessel is equipped with an internal floating roof as specified in 
Sec. 65.43, an external floating roof as specified in 
Sec. 65.44, or an external floating roof converted to an 
internal floating roof as specified in Sec. 65.45, the 
notification shall meet either of the following requirements, as 
applicable.
    (i) Notify the Administrator in writing at least 30 calendar days 
prior to the refilling of each storage vessel; or
    (ii) If the inspection is not planned and the owner or operator 
could not have known about the inspection 30 calendar days in advance of 
refilling the vessel, the owner or operator shall notify the 
Administrator as soon as practical, but no later than 7 calendar days 
prior to the refilling of the storage vessel. Notification may be made 
by telephone and immediately followed by written documentation 
demonstrating why the inspection was unplanned. Alternatively, the 
notification including the written documentation may be made in writing 
and sent so that it is received by the Administrator at least 7 calendar 
days prior to refilling.
    (2) Seal gap measurement notification. In order to afford the 
Administrator the opportunity to have an observer present during seal 
gap measurements, the owner or operator of a storage vessel equipped 
with an external floating roof as specified in Sec. 65.44 
shall meet either of the following notification requirements, as 
applicable:
    (i) Notify the Administrator in writing at least 30 calendar days in 
advance of any seal gap measurements; or
    (ii) If the seal gap measurements are not planned and the owner or 
operator could not have known about the seal gap measurements 30 
calendar days in advance, the owner or operator shall notify the 
Administrator as soon as practical, but no later than 7 calendar days 
prior to the seal gap measurements. Notification may be made by 
telephone and immediately followed by written documentation 
demonstrating why the seal gap measurements were unplanned. 
Alternatively, the notification including the written documentation may 
be made in writing and sent so that it is received by the Administrator 
at least 7 calendar days prior to refilling.
    (3) Notification waiver. Where a notification required by paragraphs 
(c)(1) or (2) of this section is sent to a delegated State or local 
agency, a copy of the notification to the Administrator is not required. 
A delegated State or local agency may waive the requirements for these 
notifications.
    (d) Compliance certification. For sources subject to the compliance 
certification provisions of title V, a recertification of continuous 
compliance with Sec. 65.43(b)(1) and Sec. 
65.44(b)(1) shall be based on the annual inspections required by 
Sec. 65.43(c)(1)(i) and (c)(2)(ii)(A) and any observations 
made at other times when the roof is viewed.



Sec.Sec. 65.49-65.59  [Reserved]



                     Subpart D - Process Vents



Sec. 65.60  Applicability.

    The provisions of this subpart and of subpart A of this part apply 
to regulated material emissions from process vents where a referencing 
subpart references the use of this subpart.



Sec. 65.61  Definitions.

    All terms used in this subpart shall have the meaning given them in 
the Act and in subpart A of this part. If a term is defined in both 
subpart A of this part and in other subparts that reference the use of 
this subpart, the term shall have the meaning given in subpart A of this 
part for purposes of this subpart.



Sec. 65.62  Process vent group determination.

    (a) Group status. The owner or operator of a process vent shall 
determine the group status (i.e., Group 1, Group 2A, or Group 2B) for 
each process vent. Group 1 process vents require control, and Group 2A 
and 2B process vents do not. Group 2A process vents require parameter 
monitoring, and Group 2B process vents do not. The owner or operator 
shall report the group status of

[[Page 53]]

each process vent as specified in Sec. 65.5(c)(2).
    (b) Group 1. A process vent is considered Group 1 if it meets at 
least one of the following specifications:
    (1) The owner or operator designates the process vent as Group 1.
    (2) At representative operating conditions expected to yield the 
lowest TRE index value for the process vent, the TRE index value is less 
than or equal to 1.0, the flow rate is greater than or equal to 0.011 
standard cubic meter per minute (0.40 standard cubic foot per minute), 
and the concentration is greater than or equal to the applicable 
criterion in table 1 of this subpart. Procedures for determining the TRE 
index value, flow rate, and concentration are specified in 
Sec. 65.64.
    (c) Group 2A. A process vent is considered Group 2A if, at 
representative operating conditions expected to yield the lowest TRE 
index value, it has a TRE index value of greater than 1.0 and less than 
or equal to 4.0, a flow rate of greater than or equal to 0.011 standard 
cubic meter per minute (0.40 standard cubic foot per minute), and a 
concentration greater than or equal to the applicable table 1 criterion. 
Procedures for determining the TRE index value, flow rate, and 
concentration are specified in Sec. 65.64.
    (d) Group 2B. A process vent is considered Group 2B if, at 
representative operating conditions expected to yield the lowest TRE 
index value, it has a TRE index value of greater than 4.0; or a flow 
rate of less than 0.011 standard cubic meter per minute (0.40 standard 
cubic foot per minute); or a concentration less than the applicable 
criterion in table 1 of this subpart. Procedures for determining the TRE 
index value, flow rate, and concentration are specified in 
Sec. 65.64.



Sec. 65.63  Performance and group status change requirements.

    (a) Group 1 performance requirements. Except for the additional 
requirement for halogenated vent streams as provided in paragraph (b) of 
this section, the owner or operator of a Group 1 process vent shall 
comply with the requirements of either paragraph (a)(1), (2), or (3) of 
this section.
    (1) Flare. Reduce emissions of regulated material using a flare 
meeting the applicable requirements of Sec. 65.142(b).
    (2) 98 percent or 20 parts per million standard. Reduce emissions of 
regulated material or TOC by at least 98 weight-percent or to a 
concentration of less than 20 parts per million by volume, whichever is 
less stringent. For combustion devices, the emission reduction or 
concentration shall be calculated on a dry basis, and corrected to 3 
percent oxygen. The owner or operator shall meet the requirements in 
Sec. 65.142(b) and paragraphs (a)(2)(i) and/or (a)(2)(ii) of 
this section.
    (i) Compliance with paragraph (a)(2) of this section may be achieved 
by using any combination of recovery and/or control device to meet the 
20 parts per million by volume concentration standard; or by using any 
combination of recovery and/or control device to meet the 98 weight 
percent reduction standard, if the recovery device meets the conditions 
of paragraph (a)(2)(ii) of this section.
    (ii) An owner or operator may use a recovery device alone or in 
combination with one or more control devices to reduce emissions of 
total regulated material by 98 weight-percent if all of the following 
conditions are met:
    (A) For process vents referenced to this part by 40 CFR part 63, 
subpart G, the recovery device (and any control device that operates in 
combination with the recovery device to reduce emissions of total 
regulated material by 98 weight-percent) was installed before December 
31, 1992.
    (B) The recovery device that will be used to reduce emissions of 
total regulated material by 98 weight-percent is the last recovery 
device before emission to the atmosphere.
    (C) The recovery device alone or in combination with one or more 
control devices is capable of reducing emissions of total regulated 
material by 98 weight-percent but is not capable of reliably reducing 
emissions of total regulated material to a concentration of 20 parts per 
million by volume.
    (D) If the owner or operator disposed of the recovered material, the 
recovery device would be considered a control

[[Page 54]]

device and comply with the requirements of this subpart and 
Sec. 65.142(b) for control devices.
    (3) TRE index value. Achieve and maintain a TRE index value greater 
than 1.0 at the outlet of the final recovery device, or prior to release 
from the process vent to the atmosphere if no recovery device is 
present. If the TRE index value is greater than 1.0, the process vent 
shall meet the provisions for a Group 2A or 2B process vent specified in 
either paragraph (c), (d), (e), or (f) of this section, whichever is 
applicable.
    (b) Halogenated Group 1 performance requirement. Halogenated Group 1 
process vents that are combusted shall be controlled according to 
paragraph (b)(1) or (2) of this section. The owner or operator shall 
either designate the Group 1 process vent as a halogenated Group 1 
process vent or shall determine whether the process vent is halogenated 
using the procedures specified in Sec. 65.64(g). If 
determined, the halogen concentration in the vent stream shall be 
recorded and reported in the Initial Compliance Status Report as 
specified in Sec. 65.160(d). If the owner or operator 
designates the process vent as a halogenated Group 1 process vent, then 
this shall also be recorded and reported in the Initial Compliance 
Status Report.
    (1) Halogen reduction device following combustion. If a combustion 
device is used to comply with paragraph (a)(2) of this section for a 
halogenated process vent, then the process vent exiting the combustion 
device shall be ducted to a halogen reduction device including, but not 
limited to, a scrubber before it is discharged to the atmosphere, and 
the halogen reduction device shall meet the requirements of paragraph 
(b)(1)(i) or (ii) of this section, as applicable. The halogenated 
process vent shall not be combusted using a flare.
    (i) Except as provided in paragraph (b)(1)(ii) of this section, the 
halogen reduction device shall reduce overall emissions of hydrogen 
halides and halogens by 99 percent or shall reduce the outlet mass of 
total hydrogen halides and halogens to less than 0.45 kilogram per hour 
(0.99 pound per hour), whichever is less stringent. The owner or 
operator shall meet the requirements in Sec. 65.142(b).
    (ii) If a scrubber or other halogen reduction device was installed 
prior to December 31, 1992, the device shall reduce overall emissions of 
hydrogen halides and halogens by 95 percent or shall reduce the outlet 
mass of total hydrogen halides and halogens to less than 0.45 kilogram 
per hour (0.99 pound per hour), whichever is less stringent. The owner 
or operator shall meet the requirements in Sec. 65.142(b).
    (2) Halogen reduction device prior to combustion. A halogen 
reduction device, such as a scrubber, or other technique may be used to 
reduce the process vent halogen atom mass emission rate to less than 
0.45 kilogram per hour (0.99 pound per hour) prior to any combustion 
control device and thus make the process vent nonhalogenated; the 
process vent must comply with the requirements of paragraph (a)(1) or 
(2) of this section. The mass emission rate of halogen atoms contained 
in organic compounds prior to the combustor shall be determined 
according to the procedures in Sec. 65.64(g). The owner or 
operator shall maintain the record specified in Sec. 65.160(d) 
and submit the report specified in Sec. 65.165(d).
    (c) Performance requirements for Group 2A process vents with 
recovery devices. For Group 2A process vents, where the owner or 
operator is using a recovery device to maintain a TRE index value 
greater than 1.0, the owner or operator shall maintain a TRE index value 
greater than 1.0 and comply with the requirements for recovery devices 
in Sec. 65.142(b).
    (d) Performance requirements for Group 2A process vents without 
recovery devices. For Group 2A process vents where the owner or operator 
is not using a recovery device to maintain a TRE index value greater 
than 1.0, determine the appropriate parameters to be monitored and 
submit the information as specified in paragraphs (d)(1), (2), and (3) 
of this section. Such information shall be submitted for approval to the 
Administrator as part of a title V permit application or by separate 
notice. The owner or operator shall monitor as specified in 
Sec. 65.65(a), maintain the record specified in Sec. 
65.66(e), and submit reports as specified in Sec. 65.67(c).

[[Page 55]]

    (1) Parameter monitoring. A description of the parameter(s) to be 
monitored to ensure the owner or operator of a process vent achieves and 
maintains the TRE above 1.0. and an explanation of the criteria used to 
select the parameter(s).
    (2) Demonstration methods and procedures. A description of the 
methods and procedures that will be used to demonstrate that the 
parameter indicates proper operation of the process, the schedule for 
this demonstration, and a statement that the owner or operator will 
establish a range for the monitored parameter as part of the Initial 
Compliance Status Report required in Sec. 65.5(d), unless this 
information has already been included in the operating permit 
application.
    (3) Monitoring, recordkeeping, and reporting frequency. The 
frequency and content of monitoring, recording, and reporting if 
monitoring and recordkeeping are not continuous, or if reports of daily 
average values when the monitored parameter value is outside the range 
established in the operating permit or Initial Compliance Status Report 
will not be included in periodic reports required under Sec. 
65.5(e). The rationale for the proposed monitoring, recording, and 
reporting system shall be included.
    (e) Group 2B performance requirements. For Group 2B process vents, 
the owner or operator shall maintain a TRE index greater than 4.0, a 
flow rate less than 0.011 scmm, or a concentration less than the 
applicable criteria in table 1 to this subpart.
    (f) Group 2A or 2B process change requirements. Whenever process 
changes are made that could reasonably be expected to change a Group 2A 
or 2B process vent to a Group 1 vent, the owner or operator shall 
recalculate the TRE index value, flow, or TOC or organic hazardous air 
pollutant (HAP) concentration according to paragraph (f)(1), (2), or (3) 
of this section as specified for each process vent as necessary to 
determine whether the process vent is Group 1, Group 2A, or Group 2B and 
shall maintain the applicable records specified in Sec. 
65.66(d) and submit the applicable reports specified in Sec. 
65.67(b). The owner or operator shall perform the group status 
determination as soon as practical after the process change and within 
180 days after the process change. Examples of process changes include, 
but are not limited to, changes in production capacity, production rate, 
feedstock type, or catalyst type, or whenever there is replacement, 
removal, or addition of recovery equipment. For purposes of paragraph 
(f) of this section, process changes do not include process upsets; 
unintentional, temporary process changes; and changes that are within 
the range on which the original TRE index value calculation was based.
    (1) Flow rate. The flow rate shall be determined as specified in the 
sampling site and flow rate determination procedures in Sec. 
65.64(b) and (d) or by using best engineering assessment of the effects 
of the change. Engineering assessments shall meet the specifications in 
Sec. 65.64(i).
    (2) Concentration. The TOC or organic HAP concentration shall be 
determined as specified in Sec. 65.64(b) and (c) or by using 
best engineering assessment of the effects of the change. Engineering 
assessments shall meet the specifications in Sec. 65.64(i).
    (3) TRE index value. The TRE index value shall be recalculated based 
on measurements of process vent flow rate, TOC, and/or organic HAP 
concentrations, and heating values as specified in Sec. 
65.64(b), (c), (d), (e), (f), (g), and (h) as applicable, or based on 
best engineering assessment of the effects of the change. Engineering 
assessments shall meet the specifications in Sec. 65.64(i).
    (4) Group status change to Group 1. Where the process change causes 
the group status to change to Group 1, the owner or operator shall 
comply with the Group 1 process vent provisions in paragraph (a) of this 
section and, if they apply, the halogenated Group 1 process vent 
provisions in paragraph (b) of this section upon initial startup after 
the change and thereafter unless the owner or operator demonstrates to 
the Administrator that achieving compliance will take longer than making 
the process change. If this demonstration is made to the Administrator's 
satisfaction, the owner or operator shall comply as expeditiously as 
practical, but in no event later than 3 years

[[Page 56]]

after the emission point becomes Group 1, and shall comply with the 
following procedures to establish a compliance date:
    (i) The owner or operator shall submit to the Administrator for 
approval a compliance schedule, along with a justification for the 
schedule.
    (ii) The compliance schedule shall be submitted with the operating 
permit application or amendment or by other appropriate means.
    (iii) The Administrator shall approve the compliance schedule or 
request changes within 120 calendar days of receipt of the compliance 
schedule and justification.
    (5) Group status change to Group 2A. Whenever a process change 
causes the process vent group status to change to Group 2A, the owner or 
operator shall comply with the provisions of paragraph (c) or (d) of 
this section upon completion of the group status determination of the 
process vent.
    (6) Group status change to Group 2B. Whenever a process change 
causes the process vent group status to change to Group 2B, the owner or 
operator shall comply with the provisions of paragraph (e) of this 
section as soon as practical after the process change.



Sec. 65.64  Group determination procedures.

    (a) General. The provisions of this section provide calculation and 
measurement methods for parameters that are used to determine group 
status.
    (b)(1) Sampling site. For purposes of determining TOC or HAP 
concentration, process vent volumetric flow rate, heating value, or TRE 
index value as specified under paragraph (c), (d), (e), (f), or (h) of 
this section, the sampling site shall be located after the last recovery 
device (if any recovery devices are present) but prior to the inlet of 
any control device that is present, and prior to release to the 
atmosphere.
    (2) Sampling site when a halogen reduction device is used prior to a 
combustion device. An owner or operator using a scrubber or other 
halogen reduction device to reduce the process vent halogen atom mass 
emission rate to less than 0.45 kilogram per hour (0.99 pound per hour) 
prior to a combustion control device in compliance with Sec. 
65.63(b)(2) shall determine the halogen atom mass emission rate prior to 
the combustor and after the scrubber or other halogen reduction device 
according to the procedures in paragraph (g) of this section.
    (3) Sampling site selection method. Method 1 or 1A of appendix A of 
40 CFR part 60, as appropriate, shall be used for selection of the 
sampling site. No traverse site selection method is needed for process 
vents smaller than 0.10 meter (4 inches) in nominal inside diameter.
    (c) TOC or HAP concentration. The TOC or HAP concentrations used for 
TRE index value calculations in paragraph (h) of this section shall be 
determined based on paragraph (c)(1) or (i) of this section, or any 
other method or data that have been validated according to the protocol 
in Method 301 of appendix A of 40 CFR part 63. For concentrations needed 
for comparison with the appropriate concentration in table 1 of this 
subpart, TOC or HAP concentration shall be determined based on paragraph 
(c)(1), (c)(2), or (i) of this section or any other method or data that 
have been validated according to the protocol in Method 301 of appendix 
A of 40 CFR part 63. The owner or operator shall record the TOC or HAP 
concentration as specified in Sec. 65.66(c).
    (1) Method 18. The procedures specified in paragraph (c)(1)(i) and 
(ii) of this section shall be used to calculate parts per million by 
volume concentration using Method 18 of appendix A of 40 CFR part 60.
    (i) The minimum sampling time for each run shall be 1 hour in which 
either an integrated sample or four grab samples shall be taken. If grab 
sampling is used, then the samples shall be taken at approximately equal 
intervals in time, such as 15-minute intervals during the run.
    (ii) The concentration of either TOC (minus methane and ethane) or 
organic HAP emissions shall be calculated using the following two 
procedures, as applicable.
    (A) The TOC concentration (CTOC) is the sum of the 
concentrations of the individual components and shall be computed for 
each run using Equation 64-1 of this section:

[[Page 57]]

[GRAPHIC] [TIFF OMITTED] TR14DE00.000

Where:

CTOC = Concentration of TOC (minus methane and ethane), dry 
basis, parts per million by volume.
x = Number of samples in the sample run.
n = Number of components in the sample.
Cji = Concentration of sample component j of the sample i, 
dry basis, parts per million by volume.

    (B) The total organic HAP concentration (CHAP) shall be 
computed according to the equation in paragraph (c)(1)(ii)(A) of this 
section except that only the organic HAP species shall be summed.
    (2) Method 25A. The following procedures shall be used to calculate 
parts per million by volume concentration using Method 25A of appendix A 
of 40 CFR part 60:
    (i) Method 25A of appendix A of 40 CFR part 60 shall be used only if 
a single organic compound of regulated material is greater than 50 
percent of total organic HAP or TOC, by volume, in the process vent.
    (ii) The process vent composition may be determined by either 
process knowledge, test data collected using an appropriate EPA method, 
or a method or data validated according to the protocol in Method 301 of 
appendix A of 40 CFR part 63. Examples of information that could 
constitute process knowledge include calculations based on material 
balances, process stoichiometry, or previous test results provided the 
results are still relevant to the current process vent conditions.
    (iii) The organic compound used as the calibration gas for Method 
25A of appendix A of 40 CFR part 60 shall be the single organic compound 
of regulated material present at greater than 50 percent of the total 
organic HAP or TOC by volume.
    (iv) The span value for Method 25A of appendix A of 40 CFR part 60 
shall be equal to the appropriate concentration value in table 1 to this 
subpart.
    (v) Use of Method 25A of appendix A of 40 CFR part 60 is acceptable 
if the response from the high-level calibration gas is at least 20 times 
the standard deviation of the response from the zero calibration gas 
when the instrument is zeroed on the most sensitive scale.
    (vi) The owner or operator shall demonstrate that the concentration 
of TOC including methane and ethane measured by Method 25A of appendix A 
of 40 CFR part 60 is below one-half the appropriate value in table 1 to 
this subpart to be considered a Group 2B vent with an organic HAP or TOC 
concentration below the appropriate value in table 1 to this subpart.
    (d) Volumetric flow rate. The process vent volumetric flow rate 
(QS) in standard cubic meters per minute at 20 
C (68 F) shall be determined as specified in 
paragraphs (d)(1) and (2) of this section and shall be recorded as 
specified in Sec. 65.66(b):
    (1) Use Method 2, 2A, 2C, or 2D of appendix A of 40 CFR part 60, as 
appropriate. If the process vent tested passes through a final steam jet 
ejector and is not condensed, the stream volumetric flow shall be 
corrected to 2.3 percent moisture; or
    (2) The engineering assessment procedures in paragraph (i) of this 
section can be used for determining volumetric flow rates.
    (e) Heating value. The net heating value shall be determined as 
specified in paragraphs (e)(1) and (2) of this section or by using the 
engineering assessment procedures in paragraph (i) of this section.
    (1) The net heating value of the process vent shall be calculated 
using Equation 64-2 of this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.001

Where:

HT = Net heating value of the sample, megajoule per standard 
cubic meter, where the net enthalpy per mole of process vent is based on 
combustion at 25 C and 760 millimeters of mercury, but the 
standard temperature for determining the volume corresponding to 1 mole 
is 20 C as in the definition of QS (process 
vent volumetric flow rate).
K1 = Constant, 1.740 x 10-7 (parts per 
million)-1 (gram-mole per standard cubic meter) (megajoule 
per kilocalorie), where standard temperature for (gram-mole per standard 
cubic meter) is 20 C.

[[Page 58]]

n = Number of components in the sample.
Dj = Concentration on a wet basis of compound j in parts per 
million as measured by procedures indicated in paragraph (e)(2) of this 
section. For process vents that pass through a final steam jet and are 
not condensed, the moisture is assumed to be 2.3 percent by volume.
Hj = Net heat of combustion of compound j, kilocalorie per 
gram-mole, based on combustion at 25 C and 760 millimeters 
of mercury. The heat of combustion of process vent components shall be 
determined using American Society for Testing and Materials (ASTM) 
D2382-76 (incorporated by reference as specified in Sec. 
65.13) if published values are not available or cannot be calculated.

    (2) The molar composition of the process vent (Dj) shall 
be determined using the following methods:
    (i) Method 18 of appendix A of 40 CFR part 60 to measure the 
concentration of each organic compound.
    (ii) American Society for Testing and Materials (ASTM) D1946-77 
(incorporated by reference as specified in Sec. 65.13) to 
measure the concentration of carbon monoxide and hydrogen.
    (iii) Method 4 of appendix A of 40 CFR part 60 to measure the 
moisture content of the stack gas.
    (f) TOC or HAP emission rate. The emission rate of TOC (minus 
methane and ethane) (ETOC) and/or the emission rate of total 
organic HAP (EHAP) in the process vent as required by the TRE 
index value equation specified in paragraph (h) of this section, shall 
be calculated using Equation 64.3 of this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.002

Where:

E = Emission rate of TOC (minus methane and ethane) (ETOC) or 
emission rate of total organic HAP (EHAP) in the sample, 
kilograms per hour.
K2 = Constant, 2.494 x 10-6 (parts per million) 
(gram-mole per standard cubic meter) (kilogram per gram) (minutes per 
hour), where standard temperature for (gram-mole per standard cubic 
meter) is 20 C.
n = Number of components in the sample.
Cj = Concentration on a dry basis of organic compound j in 
parts per million as measured by Method 18 of appendix A of 40 CFR part 
60 as indicated in paragraph (c) of this section. If the TOC emission 
rate is being calculated, Cj includes all organic compounds 
measured minus methane and ethane; if the total organic HAP emission 
rate is being calculated, only organic HAP compounds are included.
Mj = Molecular weight of organic compound j, gram/gram-mole.
Qs = Process vent flow rate, dry standard cubic meter per 
minute, at a temperature of 20 C.

    (g) Halogenated vent determination. In order to determine whether a 
process vent is halogenated, the mass emission rate of halogen atoms 
contained in organic compounds shall be calculated according to the 
procedures specified in paragraphs (g)(1) and (2) of this section. A 
process vent is considered halogenated if the mass emission rate of 
halogen atoms contained in the organic compounds is equal to or greater 
than 0.45 kilogram per hour (0.99 pound per hour).
    (1) The process vent concentration of each organic compound 
containing halogen atoms (parts per million by volume, by compound) 
shall be determined based on one of the following procedures:
    (i) Process knowledge that no halogen or hydrogen halides are 
present in the process vent; or
    (ii) Applicable engineering assessment as discussed in paragraph 
(i)(3) of this section; or
    (iii) Concentration of organic compounds containing halogens 
measured by Method 18 of appendix A of 40 CFR part 60; or
    (iv) Any other method or data that have been validated according to 
the applicable procedures in Method 301 of appendix A of 40 CFR part 63.
    (2) Equation 64-4 of this section shall be used to calculate the 
mass emission rate of halogen atoms:
[GRAPHIC] [TIFF OMITTED] TR14DE00.003

Where:

E = Mass of halogen atoms, dry basis, kilogram per hour.
K2 = Constant, 2.494 x 10- 6 (parts per 
million)-1 (kilogram-mole per standard cubic meter) (minute 
per hour), where standard temperature is 20 C.
Q = Flow rate of gas stream, dry standard cubic meters per minute, 
determined according to paragraph (d) or (i) of this section.

[[Page 59]]

n = Number of halogenated compounds j in the gas stream.
j = Halogenated compound j in the gas stream.
m = Number of different halogens i in each compound j of the gas stream.
i = Halogen atom i in compound j of the gas stream.
Cj = Concentration of halogenated compound j in the gas 
stream, dry basis, parts per million by volume.
Lji = Number of atoms of halogen i in compound j of the gas 
stream.
Mji = Molecular weight of halogen atom i in compound j of the 
gas stream, kilogram per kilogram-mole.

    (h) TRE index value. The owner or operator shall calculate the TRE 
index value of the process vent using the equations and procedures 
specified in paragraphs (h)(1) through (3) of this section, as 
applicable, and shall maintain the records specified in Sec. 
65.66(a) or Sec. 65.66(d)(4), as applicable.
    (1) TRE index value equation. Equation 64-5 of this section shall be 
used to calculate the TRE index:
[GRAPHIC] [TIFF OMITTED] TR14DE00.022

Where:

TRE = TRE index value.
A, B, C, D, E, and F = Parameters presented in tables 2 and 3 of this 
subpart that include the following variables:
Q = Process vent flow rate, standard cubic meters per minute, at a 
standard temperature of 20 C, as calculated according to 
paragraph (d) or (i) of this section.
H = Process vent net heating value, megajoules per standard cubic meter, 
as calculated according to paragraph (e) or (i) of this section.
ETOC = Emission rate of TOC (minus methane and ethane), 
kilograms per hour, as calculated according to paragraph (f) or (i) of 
this section.
EHAP = Emission rate of total organic HAP, kilograms per 
hour, as calculated according to paragraph (f) or (i) of this section.

    (2) Nonhalogenated process vents. The owner or operator of a 
nonhalogenated process vent shall calculate the TRE index value using 
either one of the following procedures, as applicable:
    (i) TRE calculations: Part 60 regulated sources. Use the parameters 
in table 2 to this subpart and calculate the TRE index value twice, once 
using the appropriate equation (depending on the heating value and flow 
rate of the process vent) in equations 15 through 30 and once using the 
appropriate equation (depending on the heating value of the process 
vent) in equations 31 and 32. Select the lowest TRE index value.
    (ii) TRE calculations: Part 63 regulated sources. Use the equation 
and parameters in table 3 to this subpart and calculate the TRE index 
value using equations 34, 35, and 36 for process vents at existing 
sources; or equations 38, 39, and 40 for process vents at new sources. 
Select the lowest TRE index value.
    (3) Halogenated process vents. The owner or operator of a 
halogenated process vent stream as determined according to procedures 
specified in paragraph (g) of this section shall calculate the TRE index 
value using either one of the following procedures, as applicable:
    (i) TRE Calculations: Part 60 regulated sources. Use the parameters 
in table 2 to this subpart and calculate the TRE index value using the 
appropriate equation chosen from equations 1 through 14 depending on the 
heating value and flow rate of the process vent.
    (ii) TRE calculations: Part 63 regulated sources. Use the 
appropriate parameters in table 3 to this subpart and calculate the TRE 
index value using equation 33 or 37 depending on whether the process 
vent is at a new or existing source.
    (i) Engineering assessment. For purposes of TRE index value 
determination, engineering assessment may be used to determine process 
vent flow rate, net heating value, TOC emission rate, and total organic 
HAP emission rate for the representative operating condition expected to 
yield the lowest TRE index value. Engineering assessments shall meet the 
requirements of paragraphs (i)(1) through (4) of this section. If 
process vent flow rate or process vent organic HAP or TOC concentration 
is being determined for comparison with the 0.011 scmm (0.40

[[Page 60]]

standard cubic foot) flow rate or the applicable concentration value in 
table 1 to this subpart, engineering assessment may be used to determine 
the flow rate or concentration for the representative operating 
condition expected to yield the highest flow rate or concentration.
    (1) If the TRE index value calculated using such engineering 
assessment and the TRE index value equation in paragraph (h) of this 
section is greater than 4.0, then the owner or operator is not required 
to perform the measurements specified in paragraphs (c) through (g) of 
this section.
    (2) If the TRE index value calculated using such engineering 
assessment and the TRE index value equation in paragraph (h) of this 
section is less than or equal to 4.0, then the owner or operator is 
required either to perform the measurements specified in paragraphs (c) 
through (g) of this section for group determination or to consider the 
process vent a Group 1 process vent and comply with the requirement (or 
standard) specified in Sec. 65.63(a) and, if applicable, 
Sec. 65.63(b).
    (3) Engineering assessment includes, but is not limited to, the 
examples specified in paragraphs (i)(3)(i) through (iv) of this section.
    (i) Previous test results provided the tests are representative of 
current operating practices at the process unit.
    (ii) Bench-scale or pilot-scale test data representative of the 
process under representative operating conditions.
    (iii) Maximum flow rate, TOC emission rate, organic HAP emission 
rate, organic HAP or TOC concentration, or net heating value limit 
specified or implied within a permit limit applicable to the process 
vent.
    (iv) Design analysis based on accepted chemical engineering 
principles, measurable process parameters, or physical or chemical laws 
or properties. Examples of analytical methods include, but are not 
limited to, the following examples:
    (A) Use of material balances based on process stoichiometry to 
estimate maximum TOC or organic HAP concentrations;
    (B) Estimation of maximum flow rate based on physical equipment 
design such as pump or blower capacities;
    (C) Estimation of TOC or organic HAP concentrations based on 
saturation conditions; and
    (D) Estimation of maximum expected net heating value based on the 
stream concentration of each organic compound or, alternatively, as if 
all TOC in the stream were the compound with the highest heating value.
    (4) All data, assumptions, and procedures used in the engineering 
assessment shall be documented. The owner or operator shall maintain the 
records specified in Sec. 65.66(a), (b), (c), or (d), as 
applicable.



Sec. 65.65  Monitoring.

    (a) An owner or operator of a Group 2A process vent maintaining a 
TRE index value greater than 1.0 without a recovery device shall monitor 
based on the approved plan as specified in Sec. 65.63(d).
    (b) As required in Sec. 65.63(a) and (c), an owner or 
operator of a Group 2A process vent maintaining a TRE index value 
greater than 1.0 with a recovery device or a Group 1 process vent shall 
comply with Sec. 65.142(b).



Sec. 65.66  Recordkeeping provisions.

    (a) TRE index value records. The owner or operator shall maintain 
records of measurements, engineering assessments, and calculations 
performed to determine the TRE index value of the process vent according 
to the procedures of Sec. 65.64(h), including those records 
associated with halogen vent stream determination. Documentation of 
engineering assessments shall include all data, assumptions, and 
procedures used for the engineering assessments, as specified in 
Sec. 65.64(i). As specified in Sec. 65.67(a), the 
owner or operator shall include this information in the Initial 
Compliance Status Report.
    (b) Flow rate records. Each owner or operator who elects to 
demonstrate that a process vent is Group 2B based on a flow rate less 
than 0.011 standard cubic meter per minute (0.40 standard cubic foot per 
minute) shall record the flow rate as measured using the sampling site 
and flow rate determination procedures specified in Sec. 
65.64(b) and (d)

[[Page 61]]

or determined through engineering assessment as specified in 
Sec. 65.64(i). As specified in Sec. 65.67(a), the 
owner or operator shall include this information in the Initial 
Compliance Status Report.
    (c) Concentration records. Each owner or operator who elects to 
demonstrate that a process vent is Group 2B based on a concentration 
less than the applicable criteria in table 1 to this subpart shall 
record the organic HAP or TOC concentration as measurement using the 
sampling site and HAP or TOC concentration determination procedures 
specified in Sec. 65.64(b) and (c) or determined through 
engineering assessment as specified in Sec. 65.64(i). As 
specified in Sec. 65.67(a), the owner or operator shall 
include this information in the Initial Compliance Status Report.
    (d) Process change records. The owner or operator shall keep up-to-
date, readily accessible records as specified in the following and shall 
report this information as specified in Sec. 65.67(b):
    (1) If the process vent is Group 2B on the basis of flow rate being 
less than 0.011 scmm (0.40 standard cubic foot), then the owner or 
operator shall keep records of any process changes as defined in 
Sec. 65.63(f) that increase the process vent flow rate and any 
recalculation or measurement of the flow rate pursuant to Sec. 
65.63(f).
    (2) If the process vent is Group 2B on the basis of organic HAP or 
TOC concentration being less than the applicable value in table 1 to 
this subpart, then the owner or operator shall keep records of any 
process changes as defined in Sec. 65.63(f) that increase the 
organic HAP or TOC concentration of the process vent and any 
recalculation or measurement of the concentration pursuant to 
Sec. 65.63(f).
    (3) If the process vent is Group 2A or Group 2B on the basis of the 
TRE index value being greater than 1.0, then the owner or operator shall 
keep records of any process changes as defined in Sec. 
65.63(f) and any recalculation of the TRE index value pursuant to 
Sec. 65.63(f).
    (4) As a result of a process change, if a process vent that was 
Group 2B on any basis becomes a Group 2B process vent only on the basis 
of having a TRE greater than 4.0, then the owner or operator shall keep 
records of the TRE index value determination performed according to the 
sample site and TRE index value determination procedures of 
Sec. 65.64(b)(1) and (h) or determined through engineering 
assessment as specified in Sec. 65.64(i).
    (e) Other Group 2A records. An owner or operator of a Group 2A 
process vent maintaining a TRE index value greater than 1.0 without a 
recovery device shall record the parameters monitored based on the 
approved plan as specified in Sec. 65.63(d).



Sec. 65.67  Reporting provisions.

    (a) Initial compliance status report. The owner or operator shall 
submit as part of the Initial Compliance Status Report specified in 
Sec. 65.5(d) the information recorded in Sec. 
65.66(a), (b), and (c), as applicable.
    (b) Process change. (1) Whenever a process change, as described in 
Sec. 65.63(f), is made that causes a Group 2A or 2B process 
vent to become a Group 1 process vent or a Group 2B process vent to 
become a Group 2A process vent, the owner or operator shall either 
submit a report within 60 days after the performance test or group 
determination or submit a report included as part of the next periodic 
report. The report shall include the following information:
    (i) A description of the process change;
    (ii) The results of the recalculation of the flow rate, organic HAP 
or TOC concentration, and/or TRE index value required under 
Sec. 65.63(f) and recorded under Sec. 65.66(d); and
    (iii) A statement that the owner or operator will comply with the 
provisions of Sec. 65.63 by the schedules specified in 
Sec. 65.63(f)(4) through (6).
    (2) For process vents that become Group 1 process vents after a 
process change requiring a performance test to be conducted for the 
control device being used as specified in subpart G of this part, the 
owner or operator shall specify that the performance test has become 
necessary due to a process change. This specification shall be made in 
the notification to the Administrator of the intent to conduct a 
performance test as provided in Sec. 65.164(b)(1).
    (3) Whenever a process change as described in Sec. 
65.63(f) is made that

[[Page 62]]

changes the group status of a process vent from Group 1 to Group 2A, or 
from Group 1 to Group 2B, or from Group 2A to Group 2B, the owner or 
operator shall include a statement in the next periodic report after the 
process change that a process change has been made and the new group 
status of the process vents.
    (4) The owner or operator is not required to submit a report of a 
process change if one of the following conditions is met:
    (i) The change does not meet the definition of a process change in 
Sec. 65.63(f); or
    (ii) For a Group 2B process vent, the vent stream flow rate is 
recalculated according to Sec. 65.63(f) and the recalculated 
value is less than 0.011 standard cubic meter per minute (0.40 standard 
cubic foot per minute); or
    (iii) For a Group 2B process vent, the organic HAP or TOC 
concentration of the vent stream is recalculated according to 
Sec. 65.63(f), and the recalculated value is less than the 
applicable value in table 1 to this subpart; or
    (iv) For a Group 2B process vent, the TRE index value is 
recalculated according to Sec. 65.63(f) and the recalculated 
value is greater than 4.0.
    (c) Parameters for Group 2A without a recovery device. An owner or 
operator of a Group 2A process vent maintaining a TRE index value 
greater than 1.0 without using a recovery device shall report the 
information specified in the approved plan under Sec. 
65.63(d).



Sec.Sec. 65.68-65.79  [Reserved]

Table 1 to Subpart D of Part 65 - Concentration for Group 
                              Determination

------------------------------------------------------------------------
            Referencing subpart                   Concentration \1\
------------------------------------------------------------------------
Subpart III of Part 60....................  NA.
Subpart NNN of Part 60....................  300 ppmv of TOC.
Subpart RRR of Part 60....................  300 ppmv of TOC.
Subpart G of Part 63......................  50 ppmv of HAP \2\.
------------------------------------------------------------------------
\1\ The 50 ppm HAP concentration cutoff only applies to 40 CFR part 63,
  subpart G sources. Process vents subject to only 40 CFR part 60,
  subparts RRR or NNN are eligible for the 300 ppm TOC cutoff. There is
  no concentration cutoff for subpart III sources. The process vent
  provisions of subpart DDD are not consolidated under this subpart.
\2\ For process vents subject to subpart G of 40 CFR part 63, the owner
  or operator may measure HAP or TOC concentration with regard to the
  low concentration exemption provisions of this part.


[[Page 63]]

Table 2 to Subpart D of Part 65 - TRE Parameters for NSPS 
                         Referencing Subparts\a\

------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
                                    Net heating                                                  Values of terms for TRE equation: TRE=A * [ B + C + D + E + F ]
    Halogenated vent stream?        value  (MJ/     Vent stream flow rate ------------------------------------------------------------------------------------------------------------  Equation
                                      scm)\b\           (scm/min)\c\              A             B             C                   D                     E                   F            number
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
Yes............................  0[le] H [le]3.5   Q <14.2              1/ETOC            30.96334  0                0                      -0.13064QH          0                           1
                                                   14.2[le] Q [le]18.8     1/ETOC            19.18370  0.27580Q         0.757620Q0.88          -0.13064QH          0.01025Q0.5                 2
                                                   18.8< Q [le]699      1/ETOC            20.00563  0.27580Q         0.303870Q0.88          -0.13064QH          0.01025Q0.5                 3
                                                   699< Q [le]1400      1/ETOC            39.87022  0.29973Q         0.303870Q0.88          -0.13064QH          0.01449Q0.5                 4
                                                   1400< Q [le]2100     1/ETOC            59.73481  0.31467Q         0.303870Q0.88          -0.13064QH          0.01775Q0.5                 5
                                                   2100< Q [le]2800     1/ETOC            79.59941  0.32572Q         0.303870Q0.88          -0.13064QH          0.02049Q0.5                 6
                                                   2800< Q [le]3500     1/ETOC            99.46400  0.33456Q         0.303870Q0.88          -0.13064QH          0.02291Q0.5                 7
                                 H >3.5         Q <14.2              1/ETOC            20.61052  0                0                      0                   0                           8
                                                   14.2[le] Q [le]18.8     1/ETOC            18.84466  0.26742Q         -0.200440Q0.88         0                   0.01025Q0.5                 9
                                                   18.8< Q [le]699      1/ETOC            19.66658  0.26742Q         -0.253320Q0.88         0                   0.01025Q0.5                10
                                                   699< Q [le]1400      1/ETOC            39.19213  0.29062Q         -0.253320Q0.88         0                   0.01449Q0.5                11
                                                   1400< Q [le]2100     1/ETOC            58.71768  0.30511Q         -0.253320Q0.88         0                   0.01775Q0.5                12
                                                   2100< Q [le]2800     1/ETOC            78.24323  0.31582Q         -0.253320Q0.88         0                   0.02049Q0.5                13
                                                   2800< Q [le]3500     1/ETOC            97.76879  0.32439Q         -0.253320Q0.88         0                   0.02291Q0.5                14
 No............................  0[le] H [le]0.48  Q <14.2              1/ETOC            11.01250  0                0                      -0.17109QH          0                          15
                                                   14.2[le] Q [le]1340     1/ETOC             8.54245  0.10555Q         0.090300Q0.88          -0.17109QH          0.01025Q0.5                16
                                                   1340< Q [le]2690     1/ETOC            16.94386  0.11470Q         0.090300Q0.88          -0.17109QH          0.01449Q0.5                17
                                                   2690< Q [le]4040     1/ETOC            25.34528  0.12042Q         0.090300Q0.88          -0.17109QH          0.01775Q0.5                18
                                 0.48< H        Q <14.2              1/ETOC            13.45630  0                0                      -0.16181QH          0                          19
                                  [le]1.9
                                                   14.2[le] Q [le]1340     1/ETOC             9.25233  0.06105Q         0.319370Q0.88          -0.16181QH1         0.01025Q0.5                20
                                                   1340< Q [le]2690     1/ETOC            18.36363  0.06635Q         0.319370Q0.88          -0.16181QH          0.01449Q0.5                21
                                                   2690< Q [le]4040     1/ETOC            27.47492  0.06965Q         0.319370Q0.88          -0.16181QH          0.01775Q0.5                22
                                 1.9< H         Q <14.2              1/ETOC             7.96988  0                0                      0                   0                          23
                                  [le]3.6
                                                   14.2[le] Q [le]1180     1/ETOC             6.67868  0.06943Q         0.025820Q0.88          0                   0.01025Q0.5                24
                                                   1180< Q [le]2370     1/ETOC            13.21633  0.07546Q         0.025820Q0.88          0                   0.01449Q0.5                25
                                                   2370< Q [le]3550     1/ETOC            19.75398  0.07922Q         0.025820Q0.88          0                   0.01775Q0.5                26
                                 H >3.6         Q <14.2              1/ETOC             6.67868  0                0.02220Q0.88H0.88      -0.00707QH          0.02036H0.5                27
                                                   Q =14.2 and  1/ETOC             6.67868  0                0.02220Q0.88H0.88      -0.00707QH          0.00540Q0.5H0.5            28
                                                   14.2[le] Q*(H/3.6)
                                                    [le]1180
                                                   Q =14.2 and  1/ETOC            13.21633  0                0.02412Q0.88H0.88      -0.00707QH          0.00764Q0.5H0.5            29
                                                   1180< Q*(H/3.6)
                                                    [le]2370
                                                   Q =14.2 and  1/ETOC            19.75398  0                0.02533Q0.88H0.88      -0.00707QH          0.00936Q0.5H0.5            30
                                                   2370< Q*(H/3.6)
                                                    [le]3550
--------------------------------

[[Page 64]]

 
 No............................  0[le] H <11.2  All                     1/ETOC                2.08  2.25Q            0.288Q0.8              -0.193QH            -0.0051ETOC                31
                                 H TOC                2.08  0.309Q           0.0619Q0.8             -0.0043QH           -0.0043ETOC               32
                                  eq>=11.2
------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
 \a\ Use according to procedures outlined in Sec. 65.64(h).
 \b\ MJ/scm = mega Joules per standard cubic meter.
\c\ scm/min = standard cubic meters per minute.

 Table 3 to Subpart D of Part 65 - TRE Parameters for HON 
                    Referencing Subpartsa

--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                                    Values of terms for TRE equation: TRE = A * [ B + C + D + E + F ]
                                 Halogenated   ---------------------------------------------------------------------------------------------------------
       Existing or new?          vent stream?                                                                                                   Equation
                                                      A            B            C             D              E                    F              number
--------------------------------------------------------------------------------------------------------------------------------------------------------
Existing.....................  Yes............  1/EHAP             3.995  0.05200Q                0  -0.001769H         0.0009700ETOC                 33
                               No.............  1/EHAP             1.935  0.3660Q                 0  -0.007687H         -0.000733ETOC                 34
                                                1/EHAP             1.492  0.06267Q                0  0.03177H           -0.001159ETOC                 35
                                                1/EHAP             2.519  0.01183Q                0  0.01300H           0.04790ETOC                   36
New..........................  Yes............  1/EHAP            1.0895  0.01417Q                0  -0.000482H         0.0002645ETOC                 37
                               No.............  1/EHAP            0.5276  0.0998Q                 0  -0.002096H         -0.0002000ETOC                38
                                                1/EHAP            0.4068  0.0171Q                 0  0.008664H          -0.000316ETOC                 39
                                                1/EHAP            0.6868  0.00321Q                0  0.003546H          0.01306ETOC                  40
--------------------------------------------------------------------------------------------------------------------------------------------------------
a Use according to procedures outlined in Sec. 65.64(h).


[[Page 65]]



                     Subpart E - Transfer Racks



Sec. 65.80  Applicability.

    (a) The provisions of this subpart and of subpart A of this part 
apply to control of regulated material emissions from transfer racks 
where a referencing subpart references the use of this subpart for such 
emissions control.
    (b) If a physical or process change is made that causes a transfer 
rack to fall outside the criteria in the referencing subpart that 
required the transfer rack to control emission of regulated material, 
the owner or operator may elect to comply with the provisions for 
transfer racks not subject to control contained in the referencing 
subpart instead of the provisions of this subpart.



Sec. 65.81  Definitions.

    All terms used in this subpart shall have the meaning given them in 
the Act and in subpart A of this part. If a term is defined in both 
subpart A of this part and in other subparts that reference the use of 
this subpart, the term shall have the meaning given in subpart A of this 
part for purposes of this subpart.



Sec. 65.82  Design requirements.

    (a) The owner or operator shall equip each transfer rack with either 
one of the following equipment:
    (1) A closed vent system which routes the regulated material vapors 
to a control device as provided in Sec. 65.83(a)(1) and (2).
    (2) Process piping which routes the regulated material vapors to a 
process or a fuel gas system as provided in Sec. 65.83(a)(4), 
or to a vapor balance system as provided in Sec. 65.83(a)(3).
    (b) Each closed vent system shall be designed to collect the 
regulated material displaced from tank trucks or railcars during loading 
and to route the collected regulated material to a control device as 
provided in Sec. 65.83(a)(1) and (2).
    (c) Process piping shall be designed to collect the regulated 
material displaced from tank trucks or railcars during loading and to 
route the collected regulated material vapors to a process or a fuel gas 
system as provided in Sec. 65.83(a)(4), or to a vapor balance 
system as provided in Sec. 65.83(a)(3).
    (d) Each closed vent system shall meet the applicable requirements 
of Sec. 65.143.
    (e) If the collected regulated material vapors are routed to a 
process or a fuel gas system as provided in Sec. 65.83(a)(4), 
then each owner or operator shall meet the applicable requirements of 
Sec. 65.142(c).



Sec. 65.83  Performance requirements.

    (a) The owner or operator of the transfer rack shall comply with 
paragraph (a)(1), (2), (3), or (4) of this section.
    (1) 98 Percent or 20 parts per million by volume standard. Use a 
control device to reduce emissions of regulated material by 98 weight-
percent or to an exit concentration of 20 parts per million by volume, 
whichever is less stringent. For combustion devices, the emission 
reduction or concentration shall be calculated on a dry basis, corrected 
to 3 percent oxygen. The owner or operator shall meet the applicable 
requirements of Sec. 65.142(c). Compliance may be achieved by 
using any combination of control devices.
    (2) Flare. Reduce emissions of regulated material using a flare 
meeting the applicable requirements of Sec. 65.142(c).
    (3) Vapor balancing. Reduce emissions of regulated material using a 
vapor balancing system designed and operated to collect regulated 
material vapors displaced from tank trucks or railcars during loading; 
and to route the collected regulated material vapors to the storage 
vessel from which the liquid being loaded originated, or to another 
storage vessel connected to a common header, or to compress and route 
collected regulated material vapors to a process. Transfer racks for 
which the owner or operator is using a vapor balancing system are exempt 
from the closed vent system design requirements of Sec. 
65.82(b) and (d), the halogenated vent stream control requirements of 
paragraph (b) of this section, the control device operation requirements 
of Sec. 65.84(b), the monitoring requirements of 
Sec. 65.86, and the requirements of subpart G of this part.

[[Page 66]]

    (4) Route to a process or fuel gas system. Route emissions of 
regulated material to a process or fuel gas system. The owner or 
operator shall meet the applicable requirements of Sec. 
65.142(c) and is exempt from the closed vent system design requirements 
of paragraphs Sec. 65.82(b) and (d), the halogenated vent 
stream control requirements of paragraph (b) of this section, the 
control device operation requirements of Sec. 65.84(b), and 
the monitoring requirements of Sec. 65.86. If the emissions 
are routed to a process, the regulated material in the emissions shall 
predominantly meet one of, or a combination of, the ends specified in 
the following:
    (i) Recycled and/or consumed in the same manner as a material that 
fulfills the same function in that process;
    (ii) Transformed by chemical reaction into materials that are not 
regulated materials;
    (iii) Incorporated into a product; and/or
    (iv) Recovered.
    (b) Additional control requirements for halogenated vent streams. 
Halogenated vent streams from transfer racks that are combusted shall be 
controlled according to paragraph (b)(1) or (2) of this section. The 
owner or operator shall either designate the transfer rack vent stream 
as a halogenated vent stream or shall determine whether the vent stream 
is halogenated using the procedures specified in Sec. 
65.85(c). If determined, the halogen concentration in the vent stream 
shall be recorded and reported in the Initial Compliance Status Report 
as specified in Sec. 65.160(d). If the owner or operator 
designates the vent stream as a halogenated vent stream, then this shall 
also be recorded and reported in the Initial Compliance Status Report.
    (1) Halogen reduction device following combustion. If a combustion 
device is used to comply with paragraph (a)(1) of this section for a 
halogenated vent stream, then the vent stream exiting the combustion 
device shall be ducted to a halogen reduction device including, but not 
limited to, a scrubber before it is discharged to the atmosphere, and 
the halogen reduction device shall meet the requirements of paragraph 
(b)(1)(i) or (ii) of this section, as applicable. The halogenated vent 
stream shall not be combusted using a flare.
    (i) Except as provided in paragraph (b)(1)(ii) of this section, the 
halogen reduction device shall reduce overall emissions of hydrogen 
halides and halogens by 99 percent or shall reduce the outlet mass 
emission rate of total hydrogen halides and halogens to 0.45 kilogram 
per hour (0.99 pound per hour) or less, whichever is less stringent. The 
owner or operator shall meet the applicable requirements of 
Sec. 65.142(c).
    (ii) If a scrubber or other halogen reduction device was installed 
prior to December 31, 1992, the halogen reduction device shall reduce 
overall emissions of hydrogen halides and halogens by 95 percent or 
shall reduce the outlet mass of total hydrogen halides and halogens to 
less than 0.45 kilogram per hour (0.99 pound per hour), whichever is 
less stringent. The owner or operator shall meet the applicable 
requirements of Sec. 65.142(c).
    (2) Halogen reduction device prior to combustion. A halogen 
reduction device, such as a scrubber, or other technique may be used to 
make the vent stream nonhalogenated by reducing the vent stream halogen 
atom mass emission rate to less than 0.45 kilogram per hour (0.99 pound 
per hour) prior to any combustion control device used to comply with the 
requirements of paragraph (a)(1) or (2) of this section. The mass 
emission rate of halogen atoms contained in organic compounds prior to 
the combustor shall be determined according to the procedures in 
Sec. 65.85(c). The owner or operator shall maintain the record 
specified in Sec. 65.160(d) and submit the report specified in 
Sec. 65.165(d).



Sec. 65.84  Operating requirements.

    (a) Closed vent systems or process piping. An owner or operator of a 
transfer rack shall operate it in such a manner that emissions are 
routed through the equipment specified in either paragraph (a)(1) or (2) 
of this section.
    (1) A closed vent system which routes the regulated material vapors 
to a control device as provided in Sec. 65.83(a)(1) and (2).
    (2) Process piping which routes the regulated material vapors to a 
process or a fuel gas system as provided in

[[Page 67]]

Sec. 65.83(a)(4) or to a vapor balance system as provided in 
Sec. 65.83(a)(3).
    (b) Control device operation. Whenever regulated material emissions 
are vented to a control device used to comply with the provisions of 
this subpart, such control device shall be operating.
    (c) Tank trucks and railcars. The owner or operator shall load 
regulated material only into tank trucks and railcars that meet one of 
the following two requirements and shall maintain the records specified 
in Sec. 65.87:
    (1) Have a current certification in accordance with the U.S. 
Department of Transportation (DOT) pressure test requirements of 49 CFR 
part 180 for tank trucks and 49 CFR 173.31 for railcars; or
    (2) Have been demonstrated to be vapor-tight within the preceding 12 
months as determined by the procedures in Sec. 65.85(a). 
Vapor-tight means that the pressure in a truck or railcar tank will not 
drop more than 750 pascals (0.11 pound per square inch) within 5 minutes 
after it is pressurized to a minimum of 4,500 pascals (0.65 pound per 
square inch).
    (d) Pressure relief device. The owner or operator of a transfer rack 
subject to the provisions of this subpart shall ensure that no pressure 
relief device in the loading equipment of each tank truck or railcar 
shall begin to open to the atmosphere during loading. Pressure relief 
devices needed for safety purposes are not subject to paragraph (d) of 
this section.
    (e) Compatible system. The owner or operator of a transfer rack 
subject to the provisions of this subpart shall load regulated material 
only to tank trucks or railcars equipped with a vapor collection system 
that is compatible with the transfer rack's closed vent system or 
process piping.
    (f) Loading while systems connected. The owner or operator of a 
transfer rack subject to this subpart shall load regulated material only 
to tank trucks or railcars whose collection systems are connected to the 
transfer rack's closed vent systems or process piping.



Sec. 65.85  Procedures.

    (a) Vapor tightness. For the purposes of demonstrating vapor 
tightness to determine compliance with Sec. 65.84(c)(2), the 
following procedures and equipment shall be used:
    (1) The pressure test procedures specified in Method 27 of appendix 
A of 40 CFR part 60; and
    (2) A pressure measurement device that has a precision of 
�2.5 millimeters of mercury (0.10 inch) or better and that 
is capable of measuring above the pressure at which the tank truck or 
railcar is to be tested for vapor tightness.
    (b) Engineering assessment. Engineering assessment to determine if a 
vent stream is halogenated or flow rate of a gas stream includes, but is 
not limited to, the following examples:
    (1) Previous test results, provided the tests are representative of 
current operating practices at the process unit.
    (2) Bench-scale or pilot-scale test data representative of the 
process under representative operating conditions.
    (3) Maximum flow rate or halogen emission rate specified or implied 
within a permit limit applicable to the process vent.
    (4) Design analysis based on accepted chemical engineering 
principles, measurable process parameters, or physical or chemical laws 
or properties.
    (5) All data, assumptions, and procedures used in the engineering 
assessment shall be documented.
    (c) Halogenated vent stream determination. In order to determine 
whether a vent stream is halogenated, the mass emission rate of halogen 
atoms contained in organic compounds shall be calculated as specified in 
paragraphs (c)(1) and (2) of this section.
    (1) The vent stream concentration of each organic compound 
containing halogen atoms (parts per million by volume by compound) shall 
be determined based on any of the following procedures:
    (i) Process knowledge that no halogen or hydrogen halides are 
present in the vent stream; or
    (ii) Applicable engineering assessment as specified in paragraph (b) 
of this section; or
    (iii) Concentration of organic compounds containing halogens 
measured by Method 18 of appendix A of 40 CFR part 60; or

[[Page 68]]

    (iv) Any other method or data that have been validated according to 
the applicable procedures in Method 301 of appendix A of 40 CFR part 63.
    (2) Equation 85-1 of this section shall be used to calculate the 
mass emission rate of halogen atoms:
[GRAPHIC] [TIFF OMITTED] TR14DE00.004

Where:

E = Mass of halogen atoms, dry basis, kilograms per hour.
K2 = Constant, 2.494 x 10-6 (parts per 
million)-1 (kilogram-mole per standard cubic meter) (minute/
hour), where standard temperature is 20 C.
Vs = Flow rate of gas stream, dry standard cubic meters per 
minute, determined according to Method 2, 2A, 2C, or 2D of appendix A of 
40 CFR part 60, as appropriate, or determined using engineering 
assessment as specified in paragraph (b) of this section.
n = Number of halogenated compounds j in the gas stream.
j = Halogenated compound j in the gas stream.
m = Number of different halogens i in each compound j of the gas stream.
i = Halogen atom i in compound j of the gas stream.
Cj = Concentration of halogenated compound j in the gas 
stream, dry basis, parts per million by volume.
Lji = Number of atoms of halogen i in compound j of the gas 
stream.
Mji = Molecular weight of halogen atom i in compound j of the 
gas stream, kilogram per kilogram-mole.



Sec. 65.86  Monitoring.

    The owner or operator of a transfer rack equipped with a closed vent 
system and control device pursuant to Sec. 65.83(a)(1) or (2) 
shall monitor the closed vent system and control device as required 
under the applicable paragraphs specified in Sec. 65.142(c).



Sec. 65.87  Recordkeeping provisions.

    The owner or operator of a transfer rack shall record that either 
the verification of U.S. Department of Transportation (DOT) tank 
certification or Method 27 of appendix A of 40 CFR part 60 testing 
required in Sec. 65.84(c) has been performed. Various methods 
for the record of verification can be used, such as a check off on a log 
sheet, a list of DOT serial numbers or Method 27 data, or a position 
description for gate security showing that the security guard will not 
allow any trucks on-site that do not have the appropriate documentation.



Sec.Sec. 65.88-65.99  [Reserved]



                    Subpart F - Equipment Leaks



Sec. 65.100  Applicability.

    (a) Equipment subject to this subpart. The provisions of this 
subpart and subpart A of this part apply to equipment that contains or 
contacts regulated material. Compliance with this subpart instead of the 
referencing subpart does not alter the applicability of the referencing 
subpart. This subpart applies only to the equipment to which the 
referencing subpart applies. This part does not extend applicability to 
equipment that is not regulated by the referencing subpart.
    (b) Equipment in vacuum service. Equipment in vacuum service is 
excluded from the requirements of this subpart.
    (c) Equipment in service less than 300 hours per calendar year. 
Equipment intended to be in regulated material service less than 300 
hours per calendar year is excluded from the requirements of 
Sec.Sec. 65.106 through 65.115 and Sec. 
65.117 if it is identified as required in Sec. 65.103(b)(6).
    (d) Lines and equipment not containing process fluids. Lines and 
equipment not containing process fluids are not subject to the 
provisions of this subpart. Utilities and other nonprocess lines, such 
as heating and cooling systems that do not combine their materials with 
those in the processes they serve, are not considered to be part of a 
process unit.

[[Page 69]]



Sec. 65.101  Definitions.

    All terms used in this subpart shall have the meaning given them in 
the Act and in subpart A of this part. If a term is defined in both 
subpart A of this part and in other subparts that reference the use of 
this subpart, the term shall have the meaning given in subpart A of this 
part for purposes of this subpart.



Sec. 65.102  Alternative means of emission limitation.

    (a) Performance standard exemption. The provisions of paragraph (b) 
of this section do not apply to the performance standards of 
Sec. 65.111(b) for pressure relief devices or Sec. 
65.112(f) for compressors operating under the alternative compressor 
standard.
    (b) Requests by owners or operators. An owner or operator may 
request a determination of alternative means of emission limitation to 
the requirements of Sec.Sec. 65.106 through 65.115 
as provided in paragraph (d) of this section. If the Administrator makes 
a determination that a means of emission limitation is a permissible 
alternative, the owner or operator shall either comply with the 
alternative or comply with the requirements of 
Sec.Sec. 65.106 through 65.115.
    (c) Requests by manufacturers of equipment. (1) Manufacturers of 
equipment used to control equipment leaks of a regulated material may 
apply to the Administrator for approval of an alternative means of 
emission limitation that achieves a reduction in emissions of the 
regulated material equivalent to the reduction achieved by the 
equipment, design, and operational requirements of this subpart.
    (2) The Administrator will grant permission according to the 
provisions of paragraph (d) of this section.
    (d) Permission to use an alternative means of emission limitation. 
Permission to use an alternative means of emission limitation shall be 
governed by the procedures in paragraph (d)(1) through (4) of this 
section.
    (1) Where the standard is an equipment, design, or operational 
requirement, the following requirements apply:
    (i) Each owner or operator applying for permission to use an 
alternative means of emission limitation shall be responsible for 
collecting and verifying emission performance test data for an 
alternative means of emission limitation.
    (ii) The Administrator will compare test data for the means of 
emission limitation to test data for the equipment, design, and 
operational requirements.
    (iii) The Administrator may condition the permission on requirements 
that may be necessary to ensure operation and maintenance to achieve at 
least the same emission reduction as the equipment, design, and 
operational requirements of this subpart.
    (2) Where the standard is a work practice, the following 
requirements apply:
    (i) Each owner or operator applying for permission to use an 
alternative means of emission limitation shall be responsible for 
collecting and verifying test data for the alternative.
    (ii) The owner or operator shall demonstrate the emission reduction 
achieved by the required work practice and the proposed alternative 
means of emission limitation.
    (iii) The Administrator will compare the demonstrated emission 
reduction for the alternative means of emission limitation to the 
demonstrated emission reduction for the required work practices and will 
consider the commitment in paragraph (d)(2)(iv) of this section.
    (iv) The Administrator may condition the permission on requirements 
that may be necessary to ensure operation and maintenance to achieve the 
same or greater emission reduction as the required work practices of 
this subpart.
    (3) An owner or operator may offer a unique approach to demonstrate 
the alternative means of emission limitation.
    (4) If in the judgment of the Administrator an alternative means of 
emission limitation will be approved, the Administrator will publish a 
notice of the determination in the Federal Register using the procedures 
pursuant to Sec. 65.8(a).



Sec. 65.103  Equipment identification.

    (a) General equipment identification. Equipment subject to this 
subpart

[[Page 70]]

shall be identified. Identification of the equipment does not require 
physical tagging of the equipment. For example, the equipment may be 
identified on a plant site plan, in log entries, by designation of 
process unit boundaries, by some form of weatherproof identification, or 
by other appropriate methods.
    (b) Additional equipment identification. In addition to the general 
identification required by paragraph (a) of this section, equipment 
subject to any of the provisions in Sec.Sec. 65.106 
through 65.115 shall be specifically identified as required in 
paragraphs (b)(1) through (6) of this section, as applicable. Paragraph 
(b) of this section does not apply to an owner or operator of a batch 
product-process who elects to pressure test the batch product-process 
equipment train pursuant to Sec. 65.117.
    (1) Connectors. Except for inaccessible, ceramic, or ceramic-lined 
connectors meeting the provisions of Sec. 65.108(e)(2), and 
instrumentation systems identified pursuant to paragraph (b)(5) of this 
section, identify the connectors subject to the requirements of this 
subpart. Connectors subject to Sec. 65.108(e)(3) shall be 
distinguished from other connectors. Connectors need not be individually 
identified if all connectors in a designated area or length of pipe 
subject to the provisions of this subpart are identified as a group, and 
the number of connectors subject is indicated. With respect to 
connectors, the identification shall be complete no later than the 
completion of the initial survey required by Sec. 65.108(a).
    (2) [Reserved]
    (3) Routed to a process or fuel gas system or equipped with a closed 
vent system and control device. Identify the equipment that the owner or 
operator elects to route to a process or fuel gas system or equip with a 
closed vent system and control device under the provisions of 
Sec. 65.107(e)(3) (pumps in light liquid service), 
Sec. 65.109(e)(3) (agitators), Sec. 65.111(d) 
(pressure relief devices in gas/vapor service), Sec. 65.112(e) 
(compressors), or Sec. 65.118 (alternative means of emission 
limitation for enclosed-vented process units).
    (4) Pressure relief devices. Identify the pressure relief devices 
equipped with rupture disks under the provisions of Sec. 
65.111(e).
    (5) Instrumentation systems. Identify instrumentation systems 
subject to the provisions of this subpart. Individual components in an 
instrumentation system need not be identified.
    (6) Equipment in service less than 300 hours per calendar year. 
Identify either by list, location (area or group), or other method, 
equipment in regulated material service less than 300 hours per calendar 
year within a process unit subject to the provisions of this subpart.
    (c) Special equipment designations: Equipment that is unsafe or 
difficult-to-monitor. (1) Designation and criteria for unsafe-to-
monitor. Valves meeting the provisions of Sec. 65.106(e)(1), 
pumps meeting the provisions of Sec. 65.107(e)(6), connectors 
meeting the provisions of Sec. 65.108(e)(1), and agitators 
meeting the provisions of Sec. 65.109(e)(7) may be designated 
unsafe-to-monitor if the owner or operator determines that monitoring 
personnel would be exposed to an immediate danger as a consequence of 
complying with the monitoring requirements of this subpart.
    (2) Designation and criteria for difficult-to-monitor. Valves 
meeting the provisions of Sec. 65.106(e)(2) may be designated 
difficult-to-monitor if the provisions of paragraph (c)(2)(i) of this 
section apply. Agitators meeting the provisions of Sec. 
65.109(e)(5) may be designated difficult-to-monitor if the provisions of 
paragraph (c)(2)(ii) of this section apply.
    (i) Valves. The owner or operator of the valve: (A) Determines that 
the valve cannot be monitored without elevating the monitoring personnel 
more than 2 meters (7 feet) above a support surface, or it is not 
accessible in a safe manner when it is in regulated material service, 
and the process unit within which the valve is located is a regulated 
source for which the owner or operator commenced construction, 
reconstruction, or modification prior to the compliance date of the 
referencing subpart; or
    (B) Designates less than 3 percent of the total number of valves 
within the process unit as difficult-to-monitor.
    (ii) Agitators. The owner or operator determines that the agitator 
cannot be monitored without elevating the monitoring personnel more than 
2 meters (7

[[Page 71]]

feet) above a support surface, or it is not accessible in a safe manner 
when it is in regulated material service.
    (3) Identification of unsafe or difficult-to-monitor equipment. The 
owner or operator shall record the identity of equipment designated as 
unsafe-to-monitor according to the provisions of paragraph (c)(1) of 
this section and the planned schedule for monitoring this equipment. The 
owner or operator shall record the identity of equipment designated as 
difficult-to-monitor according to the provisions of paragraph (c)(2) of 
this section, the planned schedule for monitoring this equipment, and an 
explanation why the equipment is difficult-to-monitor.
    (4) Written plan requirements. (i) The owner or operator of 
equipment designated as unsafe-to-monitor according to the provisions of 
paragraph (c)(1) of this section shall have a written plan that requires 
monitoring of the equipment as frequently as practical during safe-to-
monitor times, but not more frequently than the periodic monitoring 
schedule otherwise applicable, and repair of the equipment according to 
the procedures in Sec. 65.105 if a leak is detected.
    (ii) The owner or operator of equipment designated as difficult-to-
monitor according to the provisions of paragraph (c)(2) of this section 
shall have a written plan that requires monitoring of the equipment at 
least once per calendar year and repair of the equipment according to 
the procedures in Sec. 65.105 if a leak is detected.
    (d) Special equipment designations: Equipment that is unsafe to 
repair. - (1) Designation and criteria. Connectors subject 
to the provisions of Sec. 65.105(e) may be designated unsafe 
to repair if the owner or operator determines that repair personnel 
would be exposed to an immediate danger as a consequence of complying 
with the repair requirements of this subpart, and if the connector will 
be repaired before the end of the next process unit shutdown as 
specified in Sec. 63.105(e).
    (2) Identification of equipment. The identity of connectors 
designated as unsafe to repair and an explanation why the connector is 
unsafe to repair shall be recorded.
    (e) Special equipment designations: Compressors operating with an 
instrument reading of less than 500 parts per million. Identify the 
compressors that the owner or operator elects to designate as operating 
with an instrument reading of less than 500 parts per million under the 
provisions of Sec. 65.112(f).
    (f) Special equipment designations: Equipment in heavy liquid 
service. The owner or operator of equipment in heavy liquid service 
shall comply with the requirements of either paragraph (f)(1) or (2) of 
this section as provided in paragraph (f)(3) of this section.
    (1) Retain information, data, and analyses used to determine that a 
piece of equipment is in heavy liquid service.
    (2) When requested by the Administrator, demonstrate that the piece 
of equipment or process is in heavy liquid service.
    (3) A determination or demonstration that a piece of equipment or 
process is in heavy liquid service shall include an analysis or 
demonstration that the process fluids do not meet the definition of 
``in light liquid service.'' Examples of 
information that could document this include, but are not limited to, 
records of chemicals purchased for the process, analyses of process 
stream composition, engineering calculations, or process knowledge.



Sec. 65.104  Instrument and sensory monitoring for leaks.

    (a) Monitoring for leaks. The owner or operator of a regulated 
source subject to this subpart shall monitor regulated equipment as 
specified in paragraph (a)(1) of this section for instrument monitoring 
and paragraph (a)(2) of this section for sensory monitoring.
    (1) Instrument monitoring for leaks. (i) Valves in gas/vapor service 
and in light liquid service shall be monitored pursuant to 
Sec. 65.106(b).
    (ii) Pumps in light liquid service shall be monitored pursuant to 
Sec. 65.107(b).
    (iii) Connectors in gas/vapor service and in light liquid service 
shall be monitored pursuant to Sec. 65.108(b).
    (iv) Agitators in gas/vapor service and in light liquid service 
shall be monitored pursuant to Sec. 65.109(b).

[[Page 72]]

    (v) Pressure relief devices in gas/vapor service shall be monitored 
pursuant to Sec. 65.111(b) and (c).
    (vi) Compressors designated to operate with an instrument reading 
less than 500 parts per million as described in Sec. 65.103(e) 
shall be monitored pursuant to Sec. 65.112(f).
    (2) Sensory monitoring for leaks. (i) Pumps in light liquid service 
shall be observed pursuant to Sec. 65.107(b)(4) and (e)(1)(v).
    (ii) Agitators in gas/vapor service and in light liquid service 
shall be observed pursuant to Sec. 65.109(b)(3) or (e)(1)(v).
    (b) Instrument monitoring methods. Instrument monitoring as required 
under this subpart shall comply with the requirements specified in 
paragraphs (b)(1) through (6) of this section.
    (1) Monitoring method. Monitoring shall comply with Method 21 of 
appendix A of 40 CFR part 60, except as otherwise provided in this 
section.
    (2) Detection instrument performance criteria. (i) Except as 
provided for in paragraph (b)(2)(ii) of this section, the detection 
instrument shall meet the performance criteria of Method 21 of appendix 
A of 40 CFR part 60, except the instrument response factor criteria in 
section 3.1.2(a) of Method 21 shall be for the representative 
composition of the process fluid not each individual organic compound in 
the stream. For process streams that contain nitrogen, air, water, or 
other inerts that are not organic hazardous air pollutants or volatile 
organic compounds, the response factor shall be determined on an inert-
free basis. The response factor may be determined at any concentration 
for which monitoring for leaks will be conducted. Maintain the record 
specified by Sec. 65.119(b)(8).
    (ii) If no instrument is available at the plant site that will meet 
the performance criteria specified in paragraph (b)(2)(i) of this 
section, the instrument readings may be adjusted by multiplying by the 
representative response factor of the process fluid calculated on an 
inert-free basis as described in paragraph (b)(2)(i) of this section.
    (3) Detection instrument calibration procedure. The detection 
instrument shall be calibrated before use on each day of its use by the 
procedures specified in Method 21 of appendix A of 40 CFR part 60.
    (4) Detection instrument calibration gas. Calibration gases shall be 
zero air (less than 10 parts per million of hydrocarbon in air) and the 
gases specified in paragraph (b)(4)(i) of this section except as 
provided in paragraph (b)(4)(ii) of this section.
    (i) Mixtures of methane in air at a concentration no more than 2,000 
parts per million greater than the leak definition concentration of the 
equipment monitored. If the monitoring instrument's design allows for 
multiple calibration scales, then the lower scale shall be calibrated 
with a calibration gas that is no higher than 2,000 parts per million 
above the concentration specified as a leak, and the highest scale shall 
be calibrated with a calibration gas that is approximately equal to 
10,000 parts per million. If only one scale on an instrument will be 
used during monitoring, the owner or operator need not calibrate the 
scales that will not be used during that day's monitoring.
    (ii) A calibration gas other than methane in air may be used if the 
instrument does not respond to methane or if the instrument does not 
meet the performance criteria specified in paragraph (b)(2)(i) of this 
section. In such cases, the calibration gas may be a mixture of one or 
more of the compounds to be measured in air.
    (5) Monitoring performance. Monitoring shall be performed when the 
equipment is in regulated material service or is in use with any other 
detectable material.
    (6) Monitoring data. Monitoring data obtained prior to the regulated 
source becoming subject to the referencing subpart that do not meet the 
criteria specified in paragraphs (b)(1) through (5) of this section may 
still be used to qualify initially for less frequent monitoring under 
the provisions in Sec. 65.106(a)(2), (b)(3), or (b)(4) for 
valves or Sec. 65.108(b)(3) for connectors, provided the 
departures from the criteria or from the specified monitoring frequency 
of Sec. 65.106(b)(3) or (4) are minor and do not significantly 
affect the quality of the data. Examples of minor departures are 
monitoring at a slightly different frequency (such as every 6

[[Page 73]]

weeks instead of monthly or quarterly), following the performance 
criteria of section 3.1.2(a) of Method 21 of appendix A of 40 CFR part 
60 instead of paragraph (b)(2) of this section, or monitoring using a 
different leak definition if the data would indicate the presence or 
absence of a leak at the concentration specified in this subpart. 
Failure to use a calibrated instrument is not considered a minor 
departure.
    (c) Instrument monitoring readings and background adjustments. The 
owner or operator may elect to adjust or not to adjust the instrument 
readings for background. If an owner or operator elects not to adjust 
instrument readings for background, the owner or operator shall monitor 
the equipment according to the procedures specified in paragraphs (b)(1) 
through (5) of this section. In such cases, all instrument readings 
shall be compared directly to the applicable leak definition for the 
monitored equipment to determine whether there is a leak or to determine 
compliance with Sec. 65.111(b) (pressure relief devices) or 
Sec. 65.112(f) (alternative compressor standard). If an owner 
or operator elects to adjust instrument readings for background, the 
owner or operator shall monitor the equipment according to the following 
procedures:
    (1) The requirements of paragraphs (b)(1) through (5) of this 
section shall apply.
    (2) The background level shall be determined using the procedures in 
Method 21 of appendix A of 40 CFR part 60.
    (3) The instrument probe shall be traversed around all potential 
leak interfaces as close to the interface as possible as described in 
Method 21 of appendix A of 40 CFR part 60.
    (4) The arithmetic difference between the maximum concentration 
indicated by the instrument and the background level shall be compared 
to the applicable leak definition for the monitored equipment to 
determine whether there is a leak or to determine compliance with 
Sec. 65.111(b) (pressure relief devices) or Sec. 
65.112(f) (alternative compressor standard).
    (d) Sensory monitoring methods. Sensory monitoring consists of 
visual, audible, olfactory, or any other detection method used to 
determine a potential leak to the atmosphere.
    (e) Leaking equipment identification and records. (1) When each leak 
is detected, a weatherproof and readily visible identification shall be 
attached to the leaking equipment.
    (2) When each leak is detected, the information specified in 
paragraphs (e)(2)(i) and (ii) of this section shall be recorded and kept 
pursuant to Sec. 65.4(a), except the information for valves 
complying with the 2-year monitoring period allowed under Sec. 
65.106(b)(3)(v), and connectors complying with the 8-year monitoring 
period allowed under Sec. 65.108(b)(3)(iii) shall be kept 5 
years beyond the date of the last use of the information to set a 
monitoring period.
    (i) The instrument, the equipment identification, and the instrument 
operator's name, initials, or identification number if a leak is 
detected or confirmed by instrument monitoring.
    (ii) The date the leak was detected.



Sec. 65.105  Leak repair.

    (a) Leak repair schedule. The owner or operator shall repair each 
leak detected as soon as practical but not later than 15 calendar days 
after it is detected except as provided in paragraph (d) or (e) of this 
section. A first attempt at repair as defined in subpart A of this part 
shall be made no later than 5 calendar days after the leak is detected. 
First attempt at repair for pumps includes, but is not limited to, 
tightening the packing gland nuts and/or ensuring that the seal flush is 
operating at design pressure and temperature. First attempt at repair 
for valves includes, but is not limited to, tightening the bonnet bolts, 
and/or replacing the bonnet bolts, and/or tightening the packing gland 
nuts, and/or injecting lubricant into the lubricated packing.
    (b) [Reserved]
    (c) Leak identification removal. (1) Valves and connectors. The leak 
identification on a valve in gas/vapor or light liquid service may be 
removed after it has been monitored as specified in Sec. 
65.106(d)(2) and no leak has been detected during that monitoring. The 
leak identification on a connector in gas/vapor or light liquid service 
may be removed after it has been monitored as specified in 
Sec. 65.108(b)(3)(iv) and no leak

[[Page 74]]

has been detected during that monitoring.
    (2) Other equipment. The identification that has been placed 
pursuant to Sec. 65.104(e)(1) on equipment determined to have 
a leak, except for a valve or for a connector that is subject to the 
provisions of Sec. 65.108(b)(3)(iv), may be removed after it 
is repaired.
    (d) Delay of repair. Delay of repair is allowed for any of the 
conditions specified in paragraphs (d)(1) through (5) of this section. 
The owner or operator shall maintain a record of the facts that explain 
any delay of repairs and, where appropriate, why repair within 15 days 
was technically infeasible without a process unit shutdown.
    (1) Delay of repair of equipment for which leaks have been detected 
is allowed if repair within 15 days after a leak is detected is 
technically infeasible without a process unit shutdown. Repair of this 
equipment shall occur as soon as practical, but no later than the end of 
the next process unit shutdown, except as provided in paragraph (d)(5) 
of this section.
    (2) Delay of repair of equipment for which leaks have been detected 
is allowed for equipment that is isolated from the process and that does 
not remain in regulated material service.
    (3) Delay of repair for valves, connectors, and agitators is also 
allowed if the following provisions are met:
    (i) The owner or operator determines that emissions of purged 
material resulting from immediate repair would be greater than the 
fugitive emissions likely to result from delay of repair; and
    (ii) When repair procedures are effected, the purged material is 
collected and routed to a process or fuel gas system or is collected and 
destroyed or recovered in a control device complying with Sec. 
65.115.
    (4) Delay of repair for pumps is also allowed if the provisions of 
paragraphs (d)(4)(i) and (ii) of this section are met.
    (i) Repair requires replacing the existing seal design with a new 
system that the owner or operator has determined under the provisions of 
Sec. 65.116(d) will provide better performance or one of the 
following specifications are met:
    (A) A dual mechanical seal system that meets the requirements of 
Sec. 65.107(e)(1) will be installed;
    (B) A pump that meets the requirements of Sec. 
65.107(e)(2) will be installed; or
    (C) A system that routes emissions to a process or a fuel gas system 
or a closed vent system and control device that meets the requirements 
of Sec. 65.107(e)(3) will be installed.
    (ii) Repair is completed as soon as practical but not later than 6 
months after the leak was detected.
    (5) Delay of repair beyond a process unit shutdown will be allowed 
for a valve if valve assembly replacement is necessary during the 
process unit shutdown, and valve assembly supplies have been depleted, 
and valve assembly supplies had been sufficiently stocked before the 
supplies were depleted. Delay of repair beyond the second process unit 
shutdown will not be allowed unless the third process unit shutdown 
occurs sooner than 6 months after the first process unit shutdown.
    (e) Unsafe-to-repair: Connectors. Any connector that is designated 
as described in Sec. 65.103(d) as an unsafe-to-repair 
connector is exempt from the requirements of Sec. 65.108(d) 
and paragraph (a) of this section if the provisions of Sec. 
65.103(d) are met.
    (f) Leak repair records. For each leak detected, the information 
specified in paragraphs (f)(1) through (5) of this section shall be 
recorded and kept pursuant to Sec. 65.4(a).
    (1) The date of first attempt to repair the leak.
    (2) The date of successful repair of the leak.
    (3) Maximum instrument reading measured by Method 21 of appendix A 
of 40 CFR part 60 at the time the leak is successfully repaired or 
determined to be nonrepairable.
    (4) ``Repair delayed'' and the reason 
for the delay if a leak is not repaired within 15 calendar days after 
discovery of the leak as specified in the paragraphs (f)(4)(i) and (ii) 
of this section.
    (i) The owner or operator may develop a written procedure that 
identifies the conditions that justify a delay of repair. The written 
procedures may be included as part of the startup/shutdown/malfunction 
plan required by

[[Page 75]]

Sec. 65.6 for the source or may be part of a separate document 
that is maintained at the plant site. In such cases, reasons for delay 
of repair may be documented by citing the relevant sections of the 
written procedure.
    (ii) If delay of repair was caused by depletion of stocked parts, 
there must be documentation that the spare parts were sufficiently 
stocked onsite before depletion and the reason for depletion.
    (5) Dates of process unit shutdowns that occur while the equipment 
is unrepaired.



Sec. 65.106  Standards: Valves in gas/vapor service and in light liquid service.

    (a) Compliance schedule. (1) The owner or operator shall comply with 
this section no later than the implementation date specified in 
Sec. 65.1(f).
    (2) The use of monitoring data generated before the regulated source 
became subject to the referencing subpart to qualify initially for less 
frequent monitoring is governed by the provisions of Sec. 
65.104(b)(6).
    (b) Leak detection. Unless otherwise specified in Sec. 
65.102(b) or paragraph (e) of this section, the owner or operator shall 
monitor all valves at the intervals specified in paragraphs (b)(3) and/
or (b)(4) of this section and shall comply with all other provisions of 
this section.
    (1) Monitoring method. The valves shall be monitored to detect leaks 
by the method specified in Sec. 65.104(b) and (c).
    (2) Instrument reading that defines a leak. The instrument reading 
that defines a leak is 500 parts per million or greater.
    (3) Monitoring frequency. The owner or operator shall monitor valves 
for leaks at the intervals specified in paragraphs (b)(3)(i) through (v) 
of this section and shall keep the record specified in paragraph 
(b)(3)(vi) of this section.
    (i) If at least the greater of two valves or 2 percent of the valves 
in a process unit leak, as calculated according to paragraph (c) of this 
section, the owner or operator shall monitor each valve once per month.
    (ii) At process units with less than the greater of two leaking 
valves or 2 percent leaking valves, the owner or operator shall monitor 
each valve once each quarter except as provided in paragraphs 
(b)(3)(iii) through (v) of this section. Monitoring data generated 
before the regulated source became subject to the referencing subpart 
and meeting the criteria of either Sec. 65.104(b)(1) through 
(5) or Sec. 65.104(b)(6) may be used to qualify initially for 
less frequent monitoring under paragraphs (b)(3)(iii) through (v) of 
this section.
    (iii) At process units with less than 1 percent leaking valves, the 
owner or operator may elect to monitor each valve once every 2 quarters.
    (iv) At process units with less than 0.5 percent leaking valves, the 
owner or operator may elect to monitor each valve once every 4 quarters.
    (v) At process units with less than 0.25 percent leaking valves, the 
owner or operator may elect to monitor each valve once every 2 years.
    (vi) The owner or operator shall keep a record of the monitoring 
schedule for each process unit.
    (4) Valve subgrouping. For a process unit or a group of process 
units to which this subpart applies, an owner or operator may choose to 
subdivide the valves in the applicable process unit or group of process 
units and apply the provisions of paragraph (b)(3) of this section to 
each subgroup. If the owner or operator elects to subdivide the valves 
in the applicable process unit or group of process units, then the 
provisions of paragraphs (b)(4)(i) through (viii) of this section apply.
    (i) The overall performance of total valves in the applicable 
process unit or group of process units to be subdivided shall be less 
than 2 percent leaking valves, as detected according to paragraphs 
(b)(1) and (2) of this section and as calculated according to paragraphs 
(c)(1)(ii) and (c)(2) of this section.
    (ii) The initial assignment or subsequent reassignment of valves to 
subgroups shall be governed by the following provisions:
    (A) The owner or operator shall determine which valves are assigned 
to each subgroup. Valves with less than 1 year of monitoring data or 
valves not monitored within the last 12 months must be placed initially 
into the most frequently monitored subgroup until at least 1 year of 
monitoring data have been obtained.

[[Page 76]]

    (B) Any valve or group of valves can be reassigned from a less 
frequently monitored subgroup to a more frequently monitored subgroup 
provided that the valves to be reassigned were monitored during the most 
recent monitoring period for the less frequently monitored subgroup. The 
monitoring results must be included with that less frequently monitored 
subgroup's associated percent leaking valves calculation for that 
monitoring event.
    (C) Any valve or group of valves can be reassigned from a more 
frequently monitored subgroup to a less frequently monitored subgroup 
provided that the valves to be reassigned have not leaked for the period 
of the less frequently monitored subgroup (for example, for the last 12 
months, if the valve or group of valves is to be reassigned to a 
subgroup being monitored annually). Nonrepairable valves may not be 
reassigned to a less frequently monitored subgroup.
    (iii) The owner or operator shall determine every 6 months if the 
overall performance of total valves in the applicable process unit or 
group of process units is less than 2 percent leaking valves and so 
indicate the performance in the next periodic report. If the overall 
performance of total valves in the applicable process unit or group of 
process units is 2 percent leaking valves or greater, the owner or 
operator shall no longer subgroup and shall revert to the program 
required in paragraphs (b)(1) through (3) of this section for that 
applicable process unit or group of process units. An owner or operator 
can again elect to comply with the valve subgrouping procedures of 
paragraph (b)(4) of this section if future overall performance of total 
valves in the process unit or group of process units is again less than 
2 percent. The overall performance of total valves in the applicable 
process unit or group of process units shall be calculated as a weighted 
average of the percent leaking valves of each subgroup according to 
Equation 106-1 of this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.005

Where:

%VLO = Overall performance of total valves in the applicable 
process unit or group of process units.
%VLi = Percent leaking valves in subgroup i, most recent 
value calculated according to the procedures in paragraphs (c)(1)(ii) 
and (c)(2) of this section.
Vi = Number of valves in subgroup i.
n = Number of subgroups.

    (iv) The owner or operator shall maintain the following records:
    (A) Which valves are assigned to each subgroup;
    (B) Monitoring results and calculations made for each subgroup for 
each monitoring period;
    (C) Which valves are reassigned, the last monitoring result prior to 
reassignment, and when they were reassigned; and
    (D) The results of the semiannual overall performance calculation 
required in paragraph (b)(4)(iii) of this section.
    (v) The owner or operator shall notify the Administrator no later 
than 30 days prior to the beginning of the next monitoring period of the 
decision to begin or end subgrouping valves. The notification shall 
identify the participating process units and the number of valves 
assigned to each subgroup, if applicable. The notification may be 
included in a periodic report if the periodic report is submitted no 
later than 30 days prior to the beginning of the next monitoring period.
    (vi) The owner or operator shall submit in the periodic reports the 
following information:
    (A) Total number of valves in each subgroup; and
    (B) Results of the semiannual overall performance calculation 
required by paragraph (b)(4)(iii) of this section.

[[Page 77]]

    (vii) To determine the monitoring frequency for each subgroup, the 
calculation procedures of paragraph (c)(2) of this section shall be 
used.
    (viii) Except for the overall performance calculations required by 
paragraphs (b)(4)(i) and (iii) of this section, each subgroup shall be 
treated as if it were a separate process unit for the purposes of 
applying the provisions of this section.
    (c) Percent leaking valves calculation - (1) 
Calculation basis and procedures. (i) The owner or operator shall decide 
no later than the implementation date of this part or upon revision of 
an operating permit whether to calculate percent leaking valves on a 
process unit or group of process units basis. Once the owner or operator 
has decided, all subsequent percentage calculations shall be made on the 
same basis, and this shall be the basis used for comparison with the 
subgrouping criteria specified in paragraph (b)(4)(i) of this section.
    (ii) The percent leaking valves for each monitoring period for each 
process unit or valve subgroup, as provided in paragraph (b)(4) of this 
section, shall be calculated using Equation 106-2 of this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.020

Where:

%VL = Percent leaking valves.
VL = Number of valves found leaking, including those valves 
found leaking pursuant to paragraphs (d)(2)(iii)(A) and (d)(2)(iii)(B) 
of this section and excluding nonrepairable valves as provided in 
paragraph (c)(3) of this section.
VT = The sum of the total number of valves monitored.

    (2) Calculation for monitoring frequency. When determining 
monitoring frequency for each process unit or valve subgroup subject to 
monthly, quarterly, or semiannual monitoring frequencies, the percent 
leaking valves shall be the arithmetic average of the percent leaking 
valves from the last two monitoring periods. When determining monitoring 
frequency for each process unit or valve subgroup subject to annual or 
biennial (once every 2 years) monitoring frequencies, the percent 
leaking valves shall be the arithmetic average of the percent leaking 
valves from the last three monitoring periods.
    (3) Nonrepairable valves. (i) Nonrepairable valves shall be included 
in the calculation of percent leaking valves the first time the valve is 
identified as leaking and nonrepairable and as required to comply with 
paragraph (c)(3)(ii) of this section. Otherwise, a number of 
nonrepairable valves (identified and included in the percent leaking 
valves calculation in a previous period) up to a maximum of 1 percent of 
the total number of valves in regulated material service at a process 
unit may be excluded from calculation of percent leaking valves for 
subsequent monitoring periods.
    (ii) If the number of nonrepairable valves exceeds 1 percent of the 
total number of valves in regulated material service at a process unit, 
the number of nonrepairable valves exceeding 1 percent of the total 
number of valves in regulated material service shall be included in the 
calculation of percent leaking valves.
    (d) Leak repair. (1) If a leak is determined pursuant to paragraph 
(b), (e)(1), or (e)(2) of this section, then the leak shall be repaired 
using the procedures in Sec. 65.105, as applicable.
    (2) After a leak determined under paragraph (b) or (e)(2) of this 
section has been repaired, the valve shall be monitored at least once 
within the first 3 months after its repair. The monitoring required by 
paragraph (d) of this section is in addition to the monitoring required 
to satisfy the definition of repair.
    (i) The monitoring shall be conducted as specified in Sec. 
65.104(b) and (c), as appropriate, to determine whether the valve has 
resumed leaking.
    (ii) Periodic monitoring required by paragraph (b) of this section 
may be used to satisfy the requirements of paragraph (d) of this section 
if the timing of the monitoring period coincides with the time specified 
in paragraph (d) of this section. Alternatively, other monitoring may be 
performed to satisfy the requirements of paragraph (d) of this section 
regardless of whether the timing of the monitoring period for periodic 
monitoring coincides with the time specified in paragraph (d) of this 
section.

[[Page 78]]

    (iii) If a leak is detected by monitoring that is conducted under 
paragraph (d)(2) of this section, the owner or operator shall comply 
with the following provisions to determine whether that valve must be 
counted as a leaking valve for purposes of paragraph (c)(1)(ii) of this 
section:
    (A) If the owner or operator elected to use periodic monitoring 
required by paragraph (b) of this section to satisfy the requirements of 
paragraph (d)(2) of this section, then the valve shall be counted as a 
leaking valve.
    (B) If the owner or operator elected to use other monitoring, prior 
to the periodic monitoring required by paragraph (b) of this section, to 
satisfy the requirements of paragraph (d)(2) of this section, then the 
valve shall be counted as a leaking valve unless it is repaired and 
shown by periodic monitoring not to be leaking.
    (e) Special provisions for valves - (1) Unsafe-to-
monitor valves. Any valve that is designated as described in 
Sec. 65.103(c)(1) as an unsafe-to-monitor valve is exempt from 
the requirements of paragraph (b) and (d)(2) of this section, and the 
owner or operator shall monitor the valve according to the written plan 
specified in Sec. 65.103(c)(4).
    (2) Difficult-to-monitor valves. Any valve that is designated as 
described in Sec. 65.103(c)(2) as a difficult-to-monitor valve 
is exempt from the requirements of paragraph (b) of this section, and 
the owner or operator shall monitor the valve according to the written 
plan specified in Sec. 65.103(c)(4).
    (3) Less than 250 valves. Any equipment located at a plant site with 
fewer than 250 valves in regulated material service is exempt from the 
requirements for monthly monitoring specified in paragraph (b)(3)(i) of 
this section. Instead, the owner or operator shall monitor each valve in 
regulated material service for leaks once each quarter or comply with 
paragraph (b)(3)(iii), (iv), or (v) of this section except as provided 
in paragraphs (e)(1) and (2) of this section.



Sec. 65.107  Standards: Pumps in light liquid service.

    (a) Compliance schedule. The owner or operator shall comply with 
this section no later than the implementation date specified in 
Sec. 65.1(f).
    (b) Leak detection. Unless otherwise specified in Sec. 
65.102(b) or paragraph (e) of this section, the owner or operator shall 
monitor each pump to detect leaks and shall comply with all other 
provisions of this section.
    (1) Monitoring method. The pumps shall be monitored monthly to 
detect leaks by the method specified in Sec. 65.104(b) and 
(c).
    (2) Instrument reading that defines a leak. The following leak 
definitions determined through instrument readings apply:
    (i) 5,000 parts per million or greater for pumps handling 
polymerizing monomers;
    (ii) 2,000 parts per million or greater for pumps in food/medical 
service; and
    (iii) 1,000 parts per million or greater for all other pumps.
    (3) Leak repair exception. For pumps to which a 1,000 parts per 
million leak definition applies, repair is not required unless an 
instrument reading of 2,000 parts per million or greater is detected.
    (4) Visual inspection. Each pump shall be checked by visual 
inspection each calendar week for indications of liquids dripping from 
the pump seal. The owner or operator shall document that the inspection 
was conducted and the date of the inspection. If there are indications 
of liquids dripping from the pump seal at the time of the weekly 
inspection, the owner or operator shall comply with either of the 
following procedures:
    (i) The owner or operator shall monitor the pump as specified in 
Sec. 65.104(b) and (c) unless the pump has already been 
monitored since the last routine monthly monitoring required by 
paragraph (b)(1) of this section. If monitoring is performed and the 
instrument reading indicates a leak as specified in paragraph (b)(2) of 
this section, a leak is detected and the leak shall be repaired using 
the procedures in Sec. 65.105, except as specified in 
paragraph (b)(3) of this section; or
    (ii) The owner or operator shall eliminate the visual indications of 
liquids dripping.
    (c) Percent leaking pumps calculation. (1) The owner or operator 
shall decide

[[Page 79]]

no later than the implementation date of this part or upon revision of 
an operating permit whether to calculate percent leaking pumps on a 
process unit basis or group of process units basis. Once the owner or 
operator has decided, all subsequent percentage calculations shall be 
made on the same basis.
    (2) If, when calculated on a 6-month rolling average, at least the 
greater of either 10 percent of the pumps in a process unit or three 
pumps in a process unit leak, the owner or operator shall implement a 
quality improvement program for pumps that complies with the 
requirements of Sec. 65.116.
    (3) The number of pumps at a process unit shall be the sum of all 
the pumps in regulated material service, except that pumps found leaking 
in a continuous process unit within 1 month after startup of the pump 
shall not count in the percent leaking pumps calculation for that one 
monitoring period only.
    (4) Percent leaking pumps shall be determined by Equation 107-1 of 
this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.021

Where:

%PL = Percent leaking pumps.
PL = Number of pumps found leaking as determined through 
monthly monitoring as required in paragraph (b)(1) of this section.
PS = Number of pumps leaking within 1 month of startup during 
the current monitoring period.
PT = Total pumps in regulated material service, including 
those meeting the criteria in paragraphs (e)(1), (e)(2), (e)(3), and 
(e)(6) of this section.

    (d) Leak repair. If a leak is detected pursuant to paragraph (b) of 
this section, then the leak shall be repaired using the procedures in 
Sec. 65.105, as applicable.
    (e) Special provisions for pumps. - (1) Dual mechanical 
seal pumps. Each pump equipped with a dual mechanical seal system that 
includes a barrier fluid system is exempt from the requirements of 
paragraph (b) of this section, provided the requirements specified in 
paragraphs (e)(1)(i) through (viii) of this section are met.
    (i) The owner or operator determines, based on design considerations 
and operating experience, criteria applicable to the presence and 
frequency of drips and to the sensor that indicates failure of the seal 
system, the barrier fluid system, or both. The owner or operator shall 
keep records of the design criteria and an explanation of the design 
criteria, and any changes to these criteria and the reasons for the 
changes.
    (ii) Each dual mechanical seal system shall meet the following three 
requirements:
    (A) Operated with the barrier fluid at a pressure that is at all 
times (except periods of start-up, shutdown, or malfunction) greater 
than the pump stuffing box pressure; or
    (B) Equipped with a barrier fluid degassing reservoir that is routed 
to a process or fuel gas system or connected by a closed vent system to 
a control device that complies with the requirements of Sec. 
65.115; or
    (C) Equipped with a closed-loop system that purges the barrier fluid 
into a process stream.
    (iii) The barrier fluid is not in light liquid service.
    (iv) Each barrier fluid system is equipped with a sensor that will 
detect failure of the seal system, the barrier fluid system, or both.
    (v) Each pump is checked by visual inspection each calendar week for 
indications of liquids dripping from the pump seal. The owner or 
operator shall document that the inspection was conducted and the date 
of the inspection. If there are indications of liquids dripping from the 
pump seal at the time of the weekly inspection, the owner or operator 
shall follow either one of the following procedures prior to the next 
required inspection:
    (A) The owner or operator shall monitor the pump as specified in 
Sec. 65.104(b) and (c) to determine if there is a leak of 
regulated material in the barrier

[[Page 80]]

fluid. If an instrument reading of 1,000 parts per million or greater is 
measured, a leak is detected and it shall be repaired using the 
procedures in Sec. 65.105; or
    (B) The owner or operator shall eliminate the visual indications of 
liquids dripping.
    (vi) If indications of liquids dripping from the pump seal exceed 
the criteria established in paragraph (e)(1)(i) of this section, or if 
based on the criteria established in paragraph (e)(1)(i) of this section 
the sensor indicates failure of the seal system, the barrier fluid 
system, or both, a leak is detected.
    (vii) Each sensor as described in paragraph (e)(1)(iv) of this 
section is observed daily or is equipped with an alarm unless the pump 
is located within the boundary of an unmanned plant site.
    (viii) When a leak is detected pursuant to paragraph (e)(1)(vi) of 
this section, it shall be repaired as specified in Sec. 
65.105.
    (2) No external shaft. Any pump that is designed with no externally 
actuated shaft penetrating the pump housing is exempt from the 
requirements of paragraph (b) of this section.
    (3) Routed to a process or fuel gas system or equipped with a closed 
vent system. Any pump that is routed to a process or fuel gas system or 
equipped with a closed vent system that captures and transports leakage 
from the pump to a control device meeting the requirements of 
Sec. 65.115 is exempt from the requirements of paragraph (b) 
of this section.
    (4) Unmanned plant site. Any pump that is located within the 
boundary of an unmanned plant site is exempt from the weekly visual 
inspection requirement of paragraphs (b)(4) and (e)(1)(v) of this 
section and the daily requirements of paragraph (e)(1)(vii) of this 
section provided that each pump is visually inspected as often as 
practical and at least monthly.
    (5) Ninety percent exemption. If more than 90 percent of the pumps 
at a process unit meet the criteria in either paragraph (e)(1) or (2) of 
this section, the process unit is exempt from the percent leaking 
calculation in paragraph (c) of this section.
    (6) Unsafe-to-monitor pumps. Any pump that is designated as 
described in Sec. 65.103(c)(1) as an unsafe-to-monitor pump is 
exempt from the requirements of paragraph (b) of this section, the 
monitoring and inspection requirements of paragraphs (e)(1)(v) through 
(viii) of this section, and the owner or operator shall monitor and 
repair the pump according to the written plan specified in 
Sec. 65.103(c)(4).



Sec. 65.108  Standards: Connectors in gas/vapor service and in light liquid service.

    (a) Compliance schedule. Except as allowed in Sec. 
65.102(b) or as specified in paragraph (e) of this section, the owner or 
operator shall monitor all connectors in each process unit initially for 
leaks by either 12 months after the implementation date as specified in 
Sec. 65.1(f) or 12 months after initial startup, whichever is 
later. If all connectors in each process unit have been monitored for 
leaks prior to the implementation date specified in Sec. 
65.1(f), no initial monitoring is required provided either no process 
changes have been made since the monitoring or the owner or operator can 
determine that the results of the monitoring, with or without 
adjustments, reliably demonstrate compliance despite process changes. If 
required to monitor because of a process change, the owner or operator 
is required to monitor only those connectors involved in the process 
change.
    (b) Leak detection. Except as allowed in Sec. 65.102(b) or 
as specified in paragraph (e) of this section, the owner or operator 
shall monitor all connectors in gas/vapor and light liquid service as 
specified in paragraphs (a) and (b)(3) of this section.
    (1) Monitoring method. The connectors shall be monitored to detect 
leaks by the method specified in Sec. 65.104(b) and (c).
    (2) Instrument reading that defines a leak. If an instrument reading 
greater than or equal to 500 parts per million is measured, a leak is 
detected.
    (3) Monitoring periods. The owner or operator shall perform 
monitoring, subsequent to the initial monitoring required in paragraph 
(a) of this section, as specified in paragraphs (b)(3)(i)

[[Page 81]]

through (iii) of this section, and shall comply with the requirements of 
paragraphs (b)(3)(iv) and (v) of this section. The required period in 
which monitoring must be conducted shall be determined from paragraphs 
(b)(3)(i) through (iii) of this section using the monitoring results 
from the preceding monitoring period. The percent leaking connectors 
shall be calculated as specified in paragraph (c) of this subpart.
    (i) If the percent leaking connectors in the process unit was 
greater than or equal to 0.5 percent, then monitor within 12 months (1 
year).
    (ii) If the percent leaking connectors in the process unit was 
greater than or equal to 0.25 percent but less than 0.5 percent, then 
monitor within 4 years. An owner or operator may comply with the 
requirements of paragraph (b)(3)(ii) of this section by monitoring at 
least 40 percent of the connectors within 2 years of the start of the 
monitoring period, provided all connectors have been monitored by the 
end of the 4-year monitoring period.
    (iii) If the percent leaking connectors in the process unit was less 
than 0.25 percent, then monitor as provided in paragraph (b)(3)(iii)(A) 
of this section and either paragraph (b)(3)(iii)(B) or (C) of this 
section, as appropriate.
    (A) An owner or operator shall monitor at least 50 percent of the 
connectors within 4 years of the start of the monitoring period.
    (B) If the percent leaking connectors calculated from the monitoring 
results in paragraph (b)(3)(iii)(A) of this section is greater than or 
equal to 0.35 percent of the monitored connectors, the owner or operator 
shall monitor as soon as practical, but within the next 6 months, all 
connectors that have not yet been monitored during the monitoring 
period. At the conclusion of monitoring, a new monitoring period shall 
be started pursuant to paragraph (b)(3) of this section, based on the 
percent leaking connectors of the total monitored connectors.
    (C) If the percent leaking connectors calculated from the monitoring 
results in paragraph (b)(3)(iii)(A) of this section is less than 0.35 
percent of the monitored connectors, the owner or operator shall monitor 
all connectors that have not yet been monitored within 8 years of the 
start of the monitoring period.
    (iv) If, during the monitoring conducted pursuant to paragraphs 
(b)(3)(i) through (iii) of this section, a connector is found to be 
leaking, it shall be re-monitored once within 90 days after repair to 
confirm that it is not leaking.
    (v) The owner or operator shall keep a record of the start date and 
end date of each monitoring period under this section for each process 
unit.
    (c) Percent leaking connectors calculation. For use in determining 
the monitoring frequency as specified in paragraphs (a) and (b)(3) of 
this section, the percent leaking connectors as used in paragraphs (a) 
and (b)(3) of this section shall be calculated by using Equation 108-1 
of this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.006

Where:

%CL = Percent leaking connectors as determined through 
periodic monitoring required in paragraphs (a) and (b)(3)(i) through 
(b)(3)(iii) of this section.
CL = Number of connectors measured at 500 parts per million 
or greater by the method specified in Sec. 65.104(b).
Ct = Total number of monitored connectors in the process 
unit.

    (d) Leak repair. If a leak is detected pursuant to paragraphs (a) 
and (b) of this section, then the leak shall be repaired using the 
procedures in Sec. 65.105, as applicable.
    (e) Special provisions for connectors. - (1) Unsafe-to-monitor 
connectors. Any connector that is designated, as described in 
Sec. 65.103(c)(1), as an unsafe-to-monitor connector is exempt 
from the requirements of paragraphs (a) and (b) of this section and the 
owner or operator shall monitor according to the written plan specified 
in Sec. 65.103(c)(4).
    (2) Inaccessible, ceramic, or ceramic-lined connectors. (i) Any 
connector that is inaccessible or that is ceramic or ceramic-lined (for 
example, porcelain, glass, or glass-lined), is exempt from the 
monitoring requirements of paragraphs (a) and (b) of this section and 
from the recordkeeping and reporting requirements of 
Sec.Sec. 65.119 and 65.120. An inaccessible 
connector is one that meets any of the following provisions, as 
applicable:

[[Page 82]]

    (A) Buried;
    (B) Insulated in a manner that prevents access to the connector by a 
monitor probe;
    (C) Obstructed by equipment or piping that prevents access to the 
connector by a monitor probe;
    (D) Unable to be reached from a wheeled scissor-lift or hydraulic-
type scaffold that would allow access to connectors up to 7.6 meters (25 
feet) above the ground;
    (E) Inaccessible because it would require elevating the monitoring 
personnel more than 2 meters (7 feet) above a permanent support surface 
or would require the erection of scaffold;
    (F) Not able to be accessed at any time in a safe manner to perform 
monitoring. Unsafe access includes, but is not limited to, the use of a 
wheeled scissor-lift on unstable or uneven terrain, the use of a 
motorized man-lift basket in areas where an ignition potential exists, 
or access would require near proximity to hazards such as electrical 
lines or would risk damage to equipment.
    (ii) If any inaccessible, ceramic, or ceramic-lined connector is 
observed by visual, audible, olfactory, or other means to be leaking, 
the visual, audible, olfactory, or other indications of a leak to the 
atmosphere shall be eliminated as soon as practical.
    (3) Connectors referenced from 40 CFR part 60, subpart VV or 40 CFR 
part 61, subpart V. For sources referenced to this part from 40 CFR part 
61, subpart VV, or from 40 CFR part 61, subpart V, connectors are exempt 
from the requirements of paragraphs (a) through (d) of this section and 
the owner or operator shall comply with the following paragraphs:
    (i) Connectors shall be monitored within 5 days by the method 
specified in Sec. 65.104(b) and (c) if evidence of a potential 
leak is found by visual, audible, olfactory, or any other detection 
method.
    (ii) If an instrument reading of 500 parts per million or greater is 
measured, a leak is detected.
    (iii) When a leak is detected, it shall be repaired using the 
procedures in Sec. 65.105, as applicable.



Sec. 65.109  Standards: Agitators in gas/vapor service and in light liquid service.

    (a) Compliance schedule. The owner or operator shall comply with 
this section no later than the implementation date specified in 
Sec. 65.1(f).
    (b) Leak detection. (1) Monitoring method. Each agitator seal shall 
be monitored monthly to detect leaks by the methods specified in 
Sec. 65.104(b) and (c), except as provided in Sec. 
65.102(b) or paragraph (e) of this section.
    (2) Instrument reading that defines a leak. If an instrument reading 
of 10,000 parts per million or greater is measured, a leak is detected.
    (3) Visual inspection. Each agitator seal shall be checked by visual 
inspection each calendar week for indications of liquids dripping from 
the agitator seal. The owner or operator shall document that the 
inspection was conducted and the date of the inspection. If there are 
indications of liquids dripping from the agitator seal, the owner or 
operator shall comply with either of the following procedures prior to 
the next required inspection:
    (i) The owner or operator shall monitor the agitator seal as 
specified in Sec. 65.104(b) and (c) to determine if there is a 
leak of regulated material. If an instrument reading of 10,000 parts per 
million or greater is measured, a leak is detected, and it shall be 
repaired according to paragraph (d) of this section.
    (ii) The owner or operator shall eliminate the indications of 
liquids dripping from the agitator seal.
    (c) [Reserved]
    (d) Leak repair. If a leak is detected, then the leak shall be 
repaired using the procedures in Sec. 65.105(a).
    (e) Special provisions for agitators. (1) Dual mechanical seal. Each 
agitator equipped with a dual mechanical seal system that includes a 
barrier fluid system is exempt from the requirements of paragraph (b) of 
this section provided the requirements specified in paragraphs (e)(1)(i) 
through (vi) of this section are met.
    (i) Each dual mechanical seal system shall meet any one of the 
following requirements:
    (A) Operated with the barrier fluid at a pressure that is at all 
times (except

[[Page 83]]

during periods of startup, shutdown, or malfunction) greater than the 
agitator stuffing box pressure; or
    (B) Equipped with a barrier fluid degassing reservoir that is routed 
to a process or fuel gas system, or connected by a closed vent system to 
a control device that meets the requirements of Sec. 65.115; 
or
    (C) Equipped with a closed-loop system that purges the barrier fluid 
into a process stream.
    (ii) The barrier fluid is not in light liquid service.
    (iii) Each barrier fluid system is equipped with a sensor that will 
detect failure of the seal system, the barrier fluid system, or both.
    (iv) Each agitator seal is checked by visual inspection each 
calendar week for indications of liquids dripping from the agitator 
seal. If there are indications of liquids dripping from the agitator 
seal at the time of the weekly inspection, the owner or operator shall 
follow either of the following procedures prior to the next required 
inspection:
    (A) The owner or operator shall monitor the agitator seal as 
specified in Sec. 65.104(b) and (c) to determine the presence 
of regulated material in the barrier fluid. If an instrument reading of 
10,000 parts per million or greater is measured, a leak is detected and 
it shall be repaired using the procedures in Sec. 65.105; or
    (B) The owner or operator shall eliminate the visual indications of 
liquids dripping.
    (v) Each sensor as described in paragraph (e)(1)(iii) of this 
section is observed daily or is equipped with an alarm unless the 
agitator seal is located within the boundary of an unmanned plant site.
    (vi) The owner or operator of each dual mechanical seal system shall 
meet the following requirements:
    (A) The owner or operator shall determine based on design 
considerations and operating experience criteria that indicates failure 
of the seal system, the barrier fluid system, or both and that are 
applicable to the presence and frequency of drips. If indications of 
liquids dripping from the agitator seal exceed the criteria, or if based 
on the criteria the sensor indicates failure of the seal system, the 
barrier fluid system, or both, a leak is detected and shall be repaired 
pursuant to Sec. 65.105, as applicable.
    (B) The owner or operator shall keep records of the design criteria 
and an explanation of the design criteria, and any changes to these 
criteria and the reasons for the changes.
    (2) No external shaft. Any agitator that is designed with no 
externally actuated shaft penetrating the agitator housing is exempt 
from paragraph (b) of this section.
    (3) Routed to a process or fuel gas system or equipped with a closed 
vent system. Any agitator that is routed to a process or fuel gas system 
or equipped with a closed vent system that captures and transports 
leakage from the agitator to a control device meeting the requirements 
of Sec. 65.115 is exempt from the requirements of paragraph 
(b) of this section.
    (4) Unmanned plant site. Any agitator that is located within the 
boundary of an unmanned plant site is exempt from the weekly visual 
inspection requirement of paragraphs (b)(3) and (e)(1)(iv) of this 
section, and the daily requirements of paragraph (e)(1)(v) of this 
section provided that each agitator is visually inspected as often as 
practical and at least monthly.
    (5) Difficult-to-monitor agitator seals. Any agitator seal that is 
designated as described in Sec. 65.103(c)(2) as a difficult-
to-monitor agitator seal is exempt from the requirements of paragraph 
(b) of this section and the owner or operator shall monitor the agitator 
seal according to the written plan specified in Sec. 
65.103(c)(4).
    (6) Equipment obstructions. Any agitator seal that is obstructed by 
equipment or piping that prevents access to the agitator by a monitor 
probe is exempt from the monitoring requirements of paragraph (b) of 
this section.
    (7) Unsafe-to-monitor agitator seals. Any agitator seal that is 
designated as described in Sec. 65.103(c)(1) as an unsafe-to-
monitor agitator seal is exempt from the requirements of paragraph (b) 
of this section and the owner or operator of the agitator seal monitors 
the agitator seal according to the written plan specified in 
Sec. 65.103(c)(4).

[[Page 84]]



Sec. 65.110  Standards: Pumps, valves, connectors, and agitators in heavy liquid service; pressure relief devices in liquid service; and instrumentation 
          systems.

    (a) Compliance schedule. The owner or operator shall comply with 
this section no later than the implementation date specified in 
Sec. 65.1(f).
    (b) Leak detection. Unless otherwise specified in Sec. 
65.102(b), the owner or operator shall comply with the following:
    (1) Monitoring method. Pumps, valves, connectors, and agitators in 
heavy liquid service; pressure relief devices in light liquid or heavy 
liquid service; and instrumentation systems shall be monitored within 5 
calendar days by the method specified in Sec. 65.104(b) and 
(c) if evidence of a potential leak to the atmosphere is found by 
visual, audible, olfactory, or any other detection method, unless the 
potential leak is repaired as required in paragraph (c) of this section.
    (2) Instrument reading that defines a leak. If an instrument reading 
of 10,000 parts per million or greater for agitators, 5,000 parts per 
million or greater for pumps handling polymerizing monomers, 2,000 parts 
per million or greater for all other pumps (including pumps in food/
medical service), or 500 parts per million or greater for valves, 
connectors, instrumentation systems, and pressure relief devices is 
measured pursuant to paragraph (b)(1) of this section, a leak is 
detected and it shall be repaired pursuant to Sec. 65.105, as 
applicable.
    (c) Leak repair. For equipment identified in paragraph (b) of this 
section that is not monitored by the method specified in Sec. 
65.104(b), repaired shall mean that the visual, audible, olfactory, or 
other indications of a leak to the atmosphere have been eliminated; that 
no bubbles are observed at potential leak sites during a leak check 
using soap solution; or that the system will hold a test pressure.



Sec. 65.111  Standards: Pressure relief devices in gas/vapor service.

    (a) Compliance schedule. The owner or operator shall comply with 
this section no later than the implementation date specified in 
Sec. 65.1(f).
    (b) Compliance standard. Except during pressure releases as provided 
for in paragraph (c) of this section, each pressure relief device in 
gas/vapor service shall be operated with an instrument reading of less 
than 500 parts per million as measured by the method specified in 
Sec. 65.104(b) and (c).
    (c) Pressure relief requirements. (1) After each pressure release, 
the pressure relief device shall be returned to a condition indicated by 
an instrument reading of less than 500 parts per million, as soon as 
practical, but no later than 5 calendar days after each pressure release 
except as provided in Sec. 65.105(d).
    (2) The pressure relief device shall be monitored no later than 5 
calendar days after the pressure release and being returned to regulated 
material service to confirm the condition indicated by an instrument 
reading of less than 500 parts per million as measured by the method 
specified in Sec. 65.104(b) and (c).
    (3) The owner or operator shall record the dates and results of the 
monitoring required by paragraph (c)(2) of this section following a 
pressure release including maximum instrument reading measured during 
the monitoring and the background level measured if the instrument 
reading is adjusted for background.
    (d) Pressure relief devices routed to a process or fuel gas system 
or equipped with a closed vent system and control device. Any pressure 
relief device that is routed to a process or fuel gas system or equipped 
with a closed vent system capable of capturing and transporting leakage 
from the pressure relief device to a control device meeting the 
requirements of Sec. 65.115 is exempt from the requirements of 
paragraphs (b) and (c) of this section.
    (e) Rupture disk exemption. Any pressure relief device that is 
equipped with a rupture disk upstream of the pressure relief device is 
exempt from the requirements of paragraphs (b) and (c) of this section 
provided the owner or operator installs a new rupture disk upstream of 
the pressure relief device as soon as practical after each pressure 
release, but no later than 5 calendar days after each pressure release 
except as provided in Sec. 65.105(d).

[[Page 85]]



Sec. 65.112  Standards: Compressors.

    (a) Compliance schedule. The owner or operator shall comply with 
this section no later than the implementation date specified in 
Sec. 65.1(f).
    (b) Seal system standard. Each compressor shall be equipped with a 
seal system that includes a barrier fluid system and that prevents 
leakage of process fluid to the atmosphere except as provided in 
Sec. 65.102(b) and paragraphs (e) and (f) of this section. 
Each compressor seal system shall meet any one of the following 
requirements:
    (1) Operated with the barrier fluid at a pressure that is greater 
than the compressor stuffing box pressure at all times (except during 
periods of start-up, shutdown, or malfunction); or
    (2) Equipped with a barrier fluid system degassing reservoir that is 
routed to a process or fuel gas system, or connected by a closed vent 
system to a control device that meets the requirements of Sec. 
65.115; or
    (3) Equipped with a closed-loop system that purges the barrier fluid 
directly into a process stream.
    (c) Barrier fluid system. The barrier fluid shall not be in light 
liquid service. Each barrier fluid system shall be equipped with a 
sensor that will detect failure of the seal system, barrier fluid 
system, or both. Each sensor shall be observed daily or shall be 
equipped with an alarm unless the compressor is located within the 
boundary of an unmanned plant site.
    (d) Failure criterion and leak detection. (1) The owner or operator 
shall determine, based on design considerations and operating 
experience, a criterion that indicates failure of the seal system, the 
barrier fluid system, or both. If the sensor indicates failure of the 
seal system, the barrier fluid system, or both based on the criterion, a 
leak is detected and shall be repaired pursuant to Sec. 
65.105, as applicable.
    (2) The owner or operator shall keep records of the design criteria 
and an explanation of the design criteria, and any changes to these 
criteria and the reasons for the changes.
    (e) Routed to a process or fuel gas system or equipped with a closed 
vent system. A compressor is exempt from the requirements of paragraphs 
(b) through (d) of this section if it is equipped with a system to 
capture and transport leakage from the compressor drive shaft seal to a 
process or a fuel gas system or to a closed vent system that captures 
and transports leakage from the compressor to a control device meeting 
the requirements of Sec. 65.115.
    (f) Alternative compressor standard. (1) Any compressor that is 
designated as described in Sec. 65.103(e) shall operate at all 
times with an instrument reading of less than 500 parts per million. A 
compressor so designated is exempt from the requirements of paragraphs 
(b) through (d) of this section if the compressor is demonstrated 
initially upon designation, annually, and at other times requested by 
the Administrator to be operating with an instrument reading of less 
than 500 parts per million as measured by the method specified in 
Sec. 65.104(b) and (c).
    (2) The owner or operator shall record the dates and results of each 
compliance test including the background level measured and the maximum 
instrument reading measured during each compliance test.



Sec. 65.113  Standards: Sampling connection systems.

    (a) Compliance schedule. The owner or operator shall comply with 
this section no later than the implementation date specified in 
Sec. 65.1(f).
    (b) Equipment requirement. Each sampling connection system shall be 
equipped with a closed-purge, closed-loop, or closed vent system except 
as provided in paragraph (d) of this section or Sec. 
65.102(b). Gases displaced during filling of the sample container are 
not required to be collected or captured.
    (c) Equipment design and operation. Each closed-purge, closed-loop, 
or closed vent system as required in paragraph (b) of this section shall 
meet the following applicable requirements:
    (1) The system shall return the purged process fluid directly to a 
process line or to a fuel gas system; or
    (2) Collect and recycle the purged process fluid to a process; or
    (3) Be designed and operated to capture and transport all the purged 
process fluid to a control device that meets the requirements of 
Sec. 65.115; or

[[Page 86]]

    (4) Collect, store, and transport the purged process fluid to any of 
the following systems or facilities:
    (i) A waste management unit as defined in 40 CFR 63.111, if the 
waste management unit is complying with the provisions of 40 CFR part 
63, subpart G, applicable to Group 1 wastewater streams. For sources 
referenced to this part from 40 CFR part 63, subpart H, and if the 
purged process fluid does not contain any organic HAP listed in table 9 
of 40 CFR part 63, subpart G, the waste management unit need not be 
subject to and operated in compliance with the requirements of 40 CFR 
part 63, subpart G, applicable to Group 1 wastewater steams provided the 
facility has a National Pollution Discharge Elimination System (NPDES) 
permit or sends the wastewater to an NPDES-permitted facility; or
    (ii) A treatment, storage, or disposal facility subject to 
regulation under 40 CFR part 262, 264, 265, or 266; or
    (iii) A facility permitted, licensed, or registered by a State to 
manage municipal or industrial solid waste, if the process fluids are 
not hazardous waste as defined in 40 CFR part 261; and
    (5) Containers that are part of a closed-purge system must be 
covered or closed when not being filled or emptied.
    (d) In-situ sampling systems. In-situ sampling systems and sampling 
systems without purges are exempt from the requirements of paragraphs 
(b) and (c) of this section.



Sec. 65.114  Standards: Open-ended valves or lines.

    (a) Compliance schedule. The owner or operator shall comply with 
this section no later than the implementation date specified in 
Sec. 65.1(f).
    (b) Equipment and operational requirements. (1) Each open-ended 
valve or line shall be equipped with a cap, blind flange, plug, or a 
second valve except as provided in Sec. 65.102(b) and 
paragraphs (c) and (d) of this section. The cap, blind flange, plug, or 
second valve shall seal the open end at all times except during 
operations requiring process fluid flow through the open-ended valve or 
line, or during maintenance. The operational provisions of paragraphs 
(b)(2) and (3) of this section also apply.
    (2) Each open-ended valve or line equipped with a second valve shall 
be operated in a manner such that the valve on the process fluid end is 
closed before the second valve is closed.
    (3) When a double block and bleed system is being used, the bleed 
valve or line may remain open during operations that require venting the 
line between the block valves but shall comply with paragraph (b)(1) of 
this section at all other times.
    (c) Emergency shutdown exemption. Open-ended valves or lines in an 
emergency shutdown system that are designed to open automatically in the 
event of a process upset are exempt from the requirements of paragraph 
(b) of this section.
    (d) Polymerizing materials exemption. Open-ended valves or lines 
containing materials that would autocatalytically polymerize or would 
present an explosion, serious overpressure, or other safety hazard if 
capped or equipped with a double block and bleed system as specified in 
paragraph (b) of this section are exempt from the requirements of 
paragraph (b) of this section.



Sec. 65.115  Standards: Closed vent systems and control devices; or emissions routed to a fuel gas system or process.

    (a) Compliance schedule. The owner or operator shall comply with 
this section no later than the implementation date specified in 
Sec. 65.1(f).
    (b) Compliance standard. (1) Owners or operators of closed vent 
systems and nonflare control devices used to comply with provisions of 
this subpart shall design and operate the closed vent systems and 
nonflare control devices to reduce emissions of regulated material with 
an efficiency of 95 percent or greater, or to reduce emissions of 
regulated material to a concentration of 20 parts per million by volume 
or, for an enclosed combustion device, to provide a minimum residence 
time of 0.50 second at a minimum of 760 C (1400 
F). Owners and operators of closed vent systems and 
nonflare control devices used to comply with this part shall comply with 
the provisions of Sec. 65.142(d), except as provided in

[[Page 87]]

Sec. 65.102(b). Note that this includes the startup, shutdown, 
and malfunction plan specified in Sec. 65.6.
    (2) Owners or operators of closed vent systems and flares used to 
comply with the provisions of this subpart shall design and operate the 
flare as specified in Sec. 65.142(d), except as provided in 
Sec. 65.102(b). Note that this includes the startup, shutdown, 
and malfunction plan specified in Sec. 65.6.
    (3) Owners or operators routing emissions from equipment leaks to a 
fuel gas system or process shall comply with the provisions of 
Sec. 65.142(d), except as provided in Sec. 
65.102(b).



Sec. 65.116  Quality improvement program for pumps.

    (a) Criteria. If, on a 6-month rolling average, at least the greater 
of either 10 percent of the pumps in a process unit (or plant site) or 
three pumps in a process unit (or plant site) leak, the owner or 
operator shall comply with the following requirements:
    (1) Pumps that are in food/medical service or in polymerizing 
monomer service shall comply with all requirements except for those 
specified in paragraph (d)(8) of this section.
    (2) Pumps that are not in food/medical or polymerizing monomer 
service shall comply with all requirements of this section.
    (b) Exiting the QIP. The owner or operator shall comply with the 
requirements of this section until the number of leaking pumps is less 
than the greater of either 10 percent of the pumps or three pumps 
calculated as a 6-month rolling average in the process unit (or plant 
site). Once the performance level is achieved, the owner or operator 
shall comply with the requirements in Sec. 65.107.
    (c) Resumption of QIP. If in a subsequent monitoring period, the 
process unit (or plant site) has the greater of either 10 percent of the 
pumps leaking or three pumps leaking (calculated as a 6-month rolling 
average), the owner or operator shall resume the quality improvement 
program starting at performance trials.
    (d) QIP requirements. The quality improvement program shall meet the 
requirements specified in paragraphs (d)(1) through (8) of this section.
    (1) The owner or operator shall comply with the requirements in 
Sec. 65.107.
    (2) Data collection. The owner or operator shall collect the data 
specified in paragraphs (d)(2)(i) through (v) of this section and 
maintain records for each pump in each process unit (or plant site) 
subject to the quality improvement program. The data may be collected 
and the records may be maintained on a process unit or plant site basis.
    (i) Pump type (for example, piston, horizontal or vertical 
centrifugal, gear, bellows); pump manufacturer; seal type and 
manufacturer; pump design (for example, external shaft, flanged body); 
materials of construction; if applicable, barrier fluid or packing 
material; and year installed.
    (ii) Service characteristics of the stream such as discharge 
pressure, temperature, flow rate, corrosivity, and annual operating 
hours.
    (iii) The maximum instrument readings observed in each monitoring 
observation before repair, response factor for the stream if 
appropriate, instrument model number, and date of the observation.
    (iv) If a leak is detected, the repair methods used and the 
instrument readings after repair.
    (v) If the data will be analyzed as part of a larger analysis 
program involving data from other plants or other types of process 
units, a description of any maintenance or quality assurance programs 
used in the process unit that are intended to improve emission 
performance.
    (3) The owner or operator shall continue to collect data on the 
pumps as long as the process unit (or plant site) remains in the quality 
improvement program.
    (4) Pump or pump seal inspection. The owner or operator shall 
inspect all pumps or pump seals that exhibited frequent seal failures 
and were removed from the process unit due to leaks. The inspection 
shall determine the probable cause of the pump seal failure or of the 
pump leak and shall include recommendations, as appropriate, for design 
changes or changes in specifications to reduce leak potential.
    (5) Data analysis. (i) The owner or operator shall analyze the data 
collected

[[Page 88]]

to comply with the requirements of paragraph (d)(2) of this section to 
determine the services, operating or maintenance practices, and pump or 
pump seal designs or technologies that have poorer than average emission 
performance and those that have better than average emission 
performance. The analysis shall determine if specific trouble areas can 
be identified on the basis of service, operating conditions or 
maintenance practices, equipment design, or other process-specific 
factors.
    (ii) The analysis shall also be used to determine if there are 
superior performing pump or pump seal technologies that are applicable 
to the service(s), operating conditions, or pump or pump seal designs 
associated with poorer than average emission performance. A superior 
performing pump or pump seal technology is one with a leak frequency of 
less than 10 percent for specific applications in the process unit or 
plant site. A candidate superior performing pump or pump seal technology 
is one demonstrated or reported in the available literature or through a 
group study as having low emission performance and as being capable of 
achieving less than 10 percent leaking pumps in the process unit (or 
plant site).
    (iii) The analysis shall include consideration of the following 
information:
    (A) The data obtained from the inspections of pumps and pump seals 
removed from the process unit due to leaks;
    (B) Information from the available literature and from the 
experience of other plant sites that will identify pump designs or 
technologies and operating conditions associated with low emission 
performance for specific services; and
    (C) Information on limitations on the service conditions for the 
pump seal technology operating conditions as well as information on 
maintenance procedures to ensure continued low emission performance.
    (iv) The data analysis may be conducted through an inter- or 
intracompany program (or through some combination of the two approaches) 
and may be for a single process unit, a plant site, a company, or a 
group of process units.
    (v) The first analysis of the data shall be completed no later than 
18 months after the start of the quality improvement program. The first 
analysis shall be performed using data collected for a minimum of 6 
months. An analysis of the data shall be done each year the process unit 
is in the quality improvement program.
    (6) Trial evaluation program. A trial evaluation program shall be 
conducted at each plant site for which the data analysis does not 
identify use of superior performing pump seal technology or pumps that 
can be applied to the areas identified as having poorer than average 
performance except as provided in paragraph (d)(6)(v) of this section. 
The trial program shall be used to evaluate the feasibility of using in 
the process unit (or plant site) the pump designs or seal technologies, 
and operating and maintenance practices that have been identified by 
others as having low emission performance.
    (i) The trial evaluation program shall include on-line trials of 
pump seal technologies or pump designs and operating and maintenance 
practices that have been identified in the available literature or in 
analysis by others as having the ability to perform with leak rates 
below 10 percent in similar services, as having low probability of 
failure, or as having no external actuating mechanism in contact with 
the process fluid. If any of the candidate superior performing pump seal 
technologies or pumps is not included in the performance trials, the 
reasons for rejecting specific technologies from consideration shall be 
documented as required in paragraph (e)(3)(ii) of this section.
    (ii) The number of pump seal technologies or pumps in the trial 
evaluation program shall be the lesser of 1 percent or two pumps for 
programs involving single process units, and the lesser of 1 percent or 
five pumps for programs involving a plant site or groups of process 
units. The minimum number of pumps or pump seal technologies in a trial 
program shall be one.
    (iii) The trial evaluation program shall specify and include 
documentation of the following information:

[[Page 89]]

    (A) The candidate superior performing pump seal designs or 
technologies to be evaluated, the stages for evaluating the identified 
candidate pump designs or pump seal technologies, including the time 
period necessary to test the applicability;
    (B) The frequency of monitoring or inspection of the equipment;
    (C) The range of operating conditions over which the component will 
be evaluated; and
    (D) Conclusions regarding the emission performance and the 
appropriate operating conditions and services for the trial pump seal 
technologies or pumps.
    (iv) The performance trials shall initially be conducted at least 
for a 6-month period beginning not later than 18 months after the start 
of the quality improvement program. No later than 24 months after the 
start of the quality improvement program, the owner or operator shall 
have identified pump seal technologies or pump designs that, combined 
with appropriate process, operating, and maintenance practices, operate 
with low emission performance for specific applications in the process 
unit. The owner or operator shall continue to conduct performance trials 
as long as no superior performing design or technology has been 
identified, except as provided in paragraph (d)(6)(vi) of this section. 
The initial list of superior emission performance pump designs or pump 
seal technologies shall be amended in the future, as appropriate, as 
additional information and experience are obtained.
    (v) Any plant site with fewer than 400 valves and owned by a 
corporation with fewer than 100 employees shall be exempt from trial 
evaluations of pump seals or pump designs. Plant sites exempt from the 
trial evaluations of pumps shall begin the pump seal or pump replacement 
program at the start of the fourth year of the quality improvement 
program.
    (vi) An owner or operator who has conducted performance trials on 
all alternative superior emission performance technologies suitable for 
the required applications in the process unit may stop conducting 
performance trials provided that a superior performing design or 
technology has been demonstrated, or there are no technically feasible 
alternative superior technologies remaining. The owner or operator shall 
prepare an engineering evaluation documenting the physical, chemical, or 
engineering basis for the judgment that the superior emission 
performance technology is technically infeasible or demonstrating that 
it would not reduce emissions.
    (7) Quality assurance program. Each owner or operator shall prepare 
and implement a pump quality assurance program that details purchasing 
specifications and maintenance procedures for all pumps and pump seals 
in the process unit. The quality assurance program may establish any 
number of categories, or classes, of pumps as needed to distinguish 
among operating conditions and services associated with poorer than 
average emission performance, as well as those associated with better 
than average emission performance. The quality assurance program shall 
be developed considering the findings of the data analysis required 
under paragraph (d)(5) of this section, if applicable; the findings of 
the trial evaluation required in paragraph (d)(6) of this section; and 
the operating conditions in the process unit. The quality assurance 
program shall be updated each year as long as the process unit has the 
greater of either 10 percent or more leaking pumps or has three leaking 
pumps.
    (i) The quality assurance program shall meet the following 
requirements:
    (A) Establish minimum design standards for each category of pumps or 
pump seal technology. The design standards shall specify known critical 
parameters such as tolerance, manufacturer, materials of construction, 
previous usage, or other applicable identified critical parameters;
    (B) Require that all equipment orders specify the design standard 
(or minimum tolerances) for the pump or the pump seal;
    (C) Provide for an audit procedure for quality control of purchased 
equipment to ensure conformance with purchase specifications. The audit 
program may be conducted by the owner or operator of the plant site or 
process unit or by a designated representative; and

[[Page 90]]

    (D) Detail off-line pump maintenance and repair procedures. These 
procedures shall include provisions to ensure that rebuilt or 
refurbished pumps and pump seals will meet the design specifications for 
the pump category and will operate so that emissions are minimized.
    (ii) The quality assurance program shall be established no later 
than the start of the third year of the quality improvement program for 
plant sites with 400 or more valves or 100 or more employees, and no 
later than the start of the fourth year of the quality improvement 
program for plant sites with less than 400 valves and less than 100 
employees.
    (8) Pump or pump seal replacement. Beginning at the start of the 
third year of the quality improvement program for plant sites with 400 
or more valves or 100 or more employees and at the start of the fourth 
year of the quality improvement program for plant sites with less than 
400 valves and less than 100 employees, the owner or operator shall 
replace as described in paragraphs (d)(8)(i) and (ii) of this section 
the pumps or pump seals that are not superior emission performance 
technology with pumps or pump seals that have been identified as 
superior emission performance technology and that comply with the 
quality assurance standards for the pump category. Superior emission 
performance technology is that category or design of pumps or pump seals 
with emission performance that, when combined with appropriate process, 
operating, and maintenance practices, will result in less than 10 
percent leaking pumps for specific applications in the process unit or 
plant site. Superior emission performance technology includes material 
or design changes to the existing pump, pump seal, seal support system, 
installation of multiple mechanical seals or equivalent, or pump 
replacement.
    (i) Pumps or pump seals shall be replaced at the rate of 20 percent 
per year based on the total number of pumps in light liquid service. The 
calculated value shall be rounded to the nearest nonzero integer value. 
The minimum number of pumps or pump seals shall be one. Pump replacement 
shall continue until all pumps subject to the requirements of 
Sec. 65.107 are pumps determined to be superior performance 
technology.
    (ii) The owner or operator may delay replacement of pump seals or 
pumps with superior technology until the next planned process unit 
shutdown provided the number of pump seals and pumps replaced is 
equivalent to the 20 percent or greater annual replacement rate.
    (iii) The pumps shall be maintained as specified in the quality 
assurance program.
    (e) QIP recordkeeping. In addition to the records required by 
paragraph (d)(2) of this section, the owner or operator shall maintain 
records for the period of the quality improvement program for the 
process unit as specified in paragraphs (e)(1) through (6) of this 
section.
    (1) When using a pump quality improvement program as specified in 
this section, record the following information:
    (i) The rolling average percent leaking pumps.
    (ii) Documentation of all inspections conducted under the 
requirements of paragraph (d)(4) of this section and any recommendations 
for design or specification changes to reduce leak frequency.
    (iii) The beginning and ending dates while meeting the requirements 
of paragraph (d) of this section.
    (2) If a leak is not repaired within 15 calendar days after 
discovery of the leak, the reason for the delay and the expected date of 
successful repair.
    (3) Records of all analyses required in paragraph (d) of this 
section. The records will include the following information:
    (i) A list identifying areas associated with poorer than average 
performance and the associated service characteristics of the stream, 
the operating conditions, and the maintenance practices.
    (ii) The reasons for rejecting specific candidate superior emission 
performing pump technology from performance trials.
    (iii) The list of candidate superior emission performing valve or 
pump technologies and documentation of the performance trial program 
items required under paragraph (d)(6)(iii) of this section.

[[Page 91]]

    (iv) The beginning date and duration of performance trials of each 
candidate superior emission performing technology.
    (4) All records documenting the quality assurance program for pumps 
as specified in paragraph (d)(7) of this section, including records 
indicating that all pumps replaced or modified during the period of the 
quality improvement program are in compliance with the quality 
assurance.
    (5) Records documenting compliance with the 20 percent or greater 
annual replacement rate for pumps as specified in paragraph (d)(8) of 
this section.
    (6) Information and data to show the corporation has fewer than 100 
employees, including employees providing professional and technical 
contracted services.



Sec. 65.117  Alternative means of emission limitation: Batch processes.

    (a) General requirement. As an alternative to complying with the 
requirements of Sec.Sec. 65.106 through 65.114 and 
Sec. 65.116, an owner or operator of a batch process that 
operates in regulated material service during the calendar year may 
comply with one of the standards specified in paragraphs (b) and (c) of 
this section, or the owner or operator may petition for approval of an 
alternative standard under the provisions of Sec. 65.102(b). 
The alternative standards of this section provide the options of 
pressure testing or monitoring the equipment for leaks. The owner or 
operator may switch among the alternatives provided the change is 
documented as specified in paragraph (b)(7) of this section.
    (b) Pressure testing of the batch equipment. The following 
requirements shall be met if an owner or operator elects to use pressure 
testing of batch product-process equipment to demonstrate compliance 
with this subpart:
    (1) Reconfiguration. Each time equipment is reconfigured for 
production of a different product or intermediate, the batch product-
process equipment train shall be pressure-tested for leaks before 
regulated material is first fed to the equipment and the equipment is 
placed in regulated material service.
    (i) When the batch product-process equipment train is reconfigured 
to produce a different product, pressure testing is required only for 
the new or disturbed equipment.
    (ii) Each batch product-process that operates in regulated material 
service during a calendar year shall be pressure-tested at least once 
during that calendar year.
    (iii) Pressure testing is not required for routine seal breaks, such 
as changing hoses or filters, that are not part of the reconfiguration 
to produce a different product or intermediate.
    (2) Testing procedures. The batch product-process equipment shall be 
tested either using the procedures specified in paragraph (b)(5) of this 
section for pressure vacuum loss or with a liquid using the procedures 
specified in paragraph (b)(6) of this section.
    (3) Leak detection. (i) For pressure or vacuum tests using a gas, a 
leak is detected if the rate of change in pressure is greater than 6.9 
kilopascals (1 pound per square inch gauge) in 1 hour or if there is 
visible, audible, or olfactory evidence of fluid loss.
    (ii) For pressure tests using a liquid, a leak is detected if there 
are indications of liquids dripping or if there is other evidence of 
fluid loss.
    (4) Leak repair. (i) If a leak is detected, it shall be repaired and 
the batch product-process equipment shall be retested before startup of 
the process.
    (ii) If a batch product-process fails the retest (the second of two 
consecutive pressure tests), it shall be repaired as soon as practical 
but not later than 30 calendar days after the second pressure test, 
except as specified in paragraph (e) of this section.
    (5) Gas pressure test procedure for pressure or vacuum loss. The 
following procedures shall be used to pressure test batch product-
process equipment for pressure or vacuum loss to demonstrate compliance 
with the requirements of paragraph (b)(3)(i) of this section:
    (i) The batch product-process equipment train shall be pressurized 
with a gas to a pressure less than the set pressure of any safety relief 
devices or valves or to a pressure slightly above the operating pressure 
of the equipment, or alternatively the equipment shall be placed under a 
vacuum.

[[Page 92]]

    (ii) Once the test pressure is obtained, the gas source or vacuum 
source shall be shut off.
    (iii) The test shall continue for not less than 15 minutes unless it 
can be determined in a shorter period of time that the allowable rate of 
pressure drop or of pressure rise was exceeded. The pressure in the 
batch product-process equipment shall be measured after the gas or 
vacuum source is shut off and at the end of the test period. The rate of 
change in pressure in the batch product-process equipment shall be 
calculated using Equation 117-1 of this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.007

Where:

[Delta](P/t) = Change in pressure, pounds per square inch gauge/hr.
Pf = Final pressure, pounds per square inch gauge.
Pi = Initial pressure, pounds per square inch gauge.
tf - ti = Elapsed time, hours.

    (iv) The pressure shall be measured using a pressure measurement 
device (gauge, manometer, or equivalent) that has a precision of 
�2.5 millimeters mercury (0.10 inch of mercury) in the 
range of test pressure and is capable of measuring pressures up to the 
relief set pressure of the pressure relief device. If such a pressure 
measurement device is not reasonably available, the owner or operator 
shall use a pressure measurement device with a precision of at least 
�10 percent of the test pressure of the equipment and shall 
extend the duration of the test for the time necessary to detect a 
pressure loss or rise that equals a rate of 1 pound per square inch 
gauge per hour (7 kilopascals per hour).
    (v) An alternative procedure may be used for leak testing the 
equipment if the owner or operator demonstrates the alternative 
procedure is capable of detecting a pressure loss or rise.
    (6) Pressure test procedure using test liquid. The following 
procedures shall be used to pressure test batch product-process 
equipment using a liquid to demonstrate compliance with the requirements 
of paragraph (b)(3)(ii) of this section:
    (i) The batch product-process equipment train or section of the 
equipment train shall be filled with the test liquid (for example, 
water, alcohol) until normal operating pressure is obtained. Once the 
equipment is filled, the liquid source shall be shut off.
    (ii) The test shall be conducted for a period of at least 60 minutes 
unless it can be determined in a shorter period of time that the test is 
a failure.
    (iii) Each seal in the equipment being tested shall be inspected for 
indications of liquid dripping or other indications of fluid loss. If 
there are any indications of liquids dripping or of fluid loss, a leak 
is detected.
    (iv) An alternative procedure may be used for leak testing the 
equipment if the owner or operator demonstrates the alternative 
procedure is capable of detecting losses of fluid.
    (7) Pressure testing recordkeeping. The owner or operator of a batch 
product-process who elects to pressure test the batch product-process 
equipment train to demonstrate compliance with this subpart shall 
maintain records of the information specified in paragraphs (b)(7)(i) 
through (v) of this section.
    (i) The identification of each product or product code produced 
during the calendar year. It is not necessary to identify individual 
items of equipment in a batch product-process equipment train.
    (ii) Physical tagging of the equipment to identify that it is in 
regulated material service and subject to the provisions of this subpart 
is not required. Equipment in a batch product-process subject to the 
provisions of this subpart may be identified on a plant site plan, in 
log entries, or by other appropriate methods.
    (iii) The dates of each pressure test required in paragraph (b) of 
this section, the test pressure, and the pressure drop observed during 
the test.
    (iv) Records of any visible, audible, or olfactory evidence of fluid 
loss.

[[Page 93]]

    (v) When a batch product-process equipment train does not pass two 
consecutive pressure tests, as specified in paragraph (b)(4)(ii) of this 
section, the following information shall be recorded in a log and kept 
for 2 years:
    (A) The date of each pressure test and the date of each leak repair 
attempt;
    (B) Repair methods applied in each attempt to repair the leak;
    (C) The reason for the delay of repair;
    (D) The expected date for delivery of the replacement equipment and 
the actual date of delivery of the replacement equipment; and
    (E) The date of successful repair.
    (c) Equipment monitoring. The following requirements shall be met if 
an owner or operator elects to monitor the equipment in a batch process 
to detect leaks by the method specified in Sec. 65.104(b) and 
(c) to demonstrate compliance with this subpart:
    (1) The owner or operator shall comply with the requirements of 
Sec.Sec. 65.106 through 65.116 as modified by 
paragraphs (c)(2) through (4) of this section.
    (2) The equipment shall be monitored for leaks by the method 
specified in Sec. 65.104(b) and (c) when the equipment is in 
regulated material service or is in use with any other detectable 
material.
    (3) The equipment shall be monitored for leaks as specified in the 
following:
    (i) Each time the equipment is reconfigured for the production of a 
new product, the reconfigured equipment shall be monitored for leaks 
within 30 days of startup of the process. This initial monitoring of 
reconfigured equipment shall not be included in determining percent 
leaking equipment in the process unit.
    (ii) Connectors shall be monitored in accordance with the 
requirements in Sec. 65.108.
    (iii) Equipment other than connectors shall be monitored at the 
frequencies specified in table 1 to this subpart. The operating time 
shall be determined as the proportion of the year the batch product-
process that is subject to the provisions of this subpart is operating.
    (iv) The monitoring frequencies specified in paragraph (c)(3)(iii) 
of this section are not requirements for monitoring at specific 
intervals and can be adjusted to accommodate process operations. An 
owner or operator may monitor anytime during the specified monitoring 
period (for example, month, quarter, year), provided the monitoring is 
conducted at a reasonable interval after completion of the last 
monitoring campaign. For example, if the equipment is not operating 
during the scheduled monitoring period, the monitoring can be done 
during the next period when the process is operating.
    (4) If a leak is detected, it shall be repaired as soon as practical 
but not later than 15 calendar days after it is detected except as 
provided in paragraph (e) of this section.
    (d) Added equipment recordkeeping. (1) For batch product-process 
units that the owner or operator elects to monitor as provided under 
paragraph (c) of this section, the owner or operator shall prepare a 
list of equipment added to batch product-process units since the last 
monitoring period required in paragraphs (c)(3)(ii) and (iii) of this 
section.
    (2) Maintain records demonstrating the proportion of the time during 
the calendar year the equipment is in use in a batch process that is 
subject to the provisions of this subpart. Examples of suitable 
documentation are records of time in use for individual pieces of 
equipment or average time in use for the process unit. These records are 
not required if the owner or operator does not adjust monitoring 
frequency by the time in use, as provided in paragraph (c)(3)(iii) of 
this section.
    (3) Record and keep pursuant to Sec. 65.4 the date and 
results of the monitoring required in paragraph (c)(3)(i) of this 
section for equipment added to a batch product-process unit since the 
last monitoring period required in paragraphs (c)(3)(ii) and (iii) of 
this section. If no leaking equipment is found during this monitoring, 
the owner or operator shall record that the inspection was performed. 
Records of the actual monitoring results are not required.
    (e) Delay of repair. Delay of repair of equipment for which leaks 
have been detected is allowed if the replacement equipment is not 
available provided the following conditions are met:

[[Page 94]]

    (1) Equipment supplies have been depleted and supplies had been 
sufficiently stocked before the supplies were depleted.
    (2) The repair is made no later than 10 calendar days after delivery 
of the replacement equipment.
    (f) Periodic report contents. For owners or operators electing to 
meet the requirements of paragraph (b) of this section, the following 
periodic report to be filed pursuant to Sec. 65.120(b) shall 
include the following information for each process unit:
    (1) Batch product-process equipment train identification;
    (2) The number of pressure tests conducted;
    (3) The number of pressure tests where the equipment train failed 
the pressure test; and
    (4) The facts that explain any delay of repairs.



Sec. 65.118  Alternative means of emission limitation: Enclosed-vented process units.

    (a) Use of closed vent system and control device. Process units that 
are enclosed in such a manner that all emissions from equipment leaks 
are routed to a process or fuel gas system or collected and vented 
through a closed vent system to a control device meeting the 
requirements of Sec. 65.115 are exempt from the requirements 
of Sec.Sec. 65.106 through 65.114 and Sec. 
65.116. The enclosure shall be maintained under a negative pressure at 
all times while the process unit is in operation to ensure that all 
emissions are routed to a control device.
    (b) Recordkeeping. Owners and operators choosing to comply with the 
requirements of this section shall maintain the following records:
    (1) Identification of the process unit(s) and the regulated 
materials they handle.
    (2) A schematic of the process unit, enclosure, and closed vent 
system.
    (3) A description of the system used to create a negative pressure 
in the enclosure to ensure that all emissions are routed to the control 
device.



Sec. 65.119  Recordkeeping provisions.

    (a) Recordkeeping system. An owner or operator of more than one 
regulated source subject to the provisions of this subpart may comply 
with the recordkeeping requirements for these regulated sources in one 
recordkeeping system. The recordkeeping system shall identify each 
record by regulated source and the type of program being implemented 
(for example, quarterly monitoring, quality improvement) for each type 
of equipment. The records required by this subpart are summarized in 
paragraphs (b) and (c) of this section.
    (b) General equipment leak records. (1) As specified in 
Sec. 65.103(a) through (c), the owner or operator shall keep 
general and specific equipment identification if the equipment is not 
physically tagged and the owner or operator is electing to identify the 
equipment subject to subpart F of this part through written 
documentation such as a log or other designation.
    (2) The owner or operator shall keep a written plan as specified in 
Sec. 65.103(c)(4) for any equipment that is designated as 
unsafe- or difficult-to-monitor.
    (3) The owner or operator shall maintain a record of the identity 
and an explanation as specified in Sec. 65.103(d)(2) for any 
equipment that is designated as unsafe to repair.
    (4) As specified in Sec. 65.103(e), the owner or operator 
shall maintain a record of the identity of compressors operating with an 
instrument reading of less than 500 parts per million.
    (5) The owner or operator shall keep records associated with the 
determination that equipment is in heavy liquid service as specified in 
Sec. 65.103(f).
    (6) The owner or operator shall keep records for leaking equipment 
as specified in Sec. 65.104(e)(2).
    (7) The owner or operator shall keep records for leak repair as 
specified in Sec. 65.105(f) and records for delay of repair as 
specified in Sec. 65.105(d).
    (8) For instrument response factor criteria determinations performed 
pursuant to Sec. 65.104(b)(2)(i), the owner or operator shall 
maintain a record of an engineering assessment that identifies the 
representative composition of the process fluid. The assessment shall be 
based on knowledge of the compounds present in the process, similarity 
of response factors for the materials

[[Page 95]]

present, the range of compositions encountered during monitoring, or 
other information available to the owner or operator.
    (9) The owner or operator shall keep records of the detection limit 
calibration as specified in Sec. 65.104(b)(3).
    (c) Specific equipment leak records. (1) For valves, the owner or 
operator shall maintain the following records:
    (i) The monitoring schedule for each process unit as specified in 
Sec. 65.106(b)(3)(v).
    (ii) The valve subgrouping records specified in Sec. 
65.106(b)(4)(iv), if applicable.
    (2) For pumps, the owner or operator shall maintain the following 
records:
    (i) Documentation of pump visual inspections as specified in 
Sec. 65.107(b)(4).
    (ii) Documentation of dual mechanical seal pump visual inspections 
as specified in Sec. 65.107(e)(1)(v).
    (iii) For the criteria as to the presence and frequency of drips for 
dual mechanical seal pumps, records of the design criteria and 
explanations and any changes and the reason for the changes, as 
specified in Sec. 65.107(e)(1)(i).
    (3) For connectors, the owner or operator shall maintain the records 
specified in Sec. 65.108(b)(3)(v) which identify a monitoring 
schedule for each process unit.
    (4) For agitators, the owner or operator shall maintain the 
following records:
    (i) Documentation of agitator seal visual inspections as specified 
in Sec. 65.109(b)(3).
    (ii) For agitators equipped with a dual mechanical seal system that 
includes barrier fluid system, the owner or operator shall keep records 
as specified in Sec. 65.109(e)(1)(vi)(B).
    (iii) Documentation of the dual mechanical seal agitator seal visual 
inspections as specified in Sec. 65.109(e)(1)(iv).
    (5) For pressure relief devices in gas/vapor or light liquid 
service, the owner or operator shall keep records of the dates and 
results of monitoring following a pressure release, as specified in 
Sec. 65.111(c)(3), or the date the rupture disk is replaced as 
specified in Sec. 65.111(e).
    (6) For compressors, the owner or operator shall maintain the 
following records:
    (i) For criteria as to failure of the seal system and/or the barrier 
fluid system, record the design criteria and explanations and any 
changes and the reason for the changes, as specified in Sec. 
65.112(d)(2).
    (ii) For compressors operating under the alternative compressor 
standard, record the dates and results of each compliance test as 
specified in Sec. 65.112(f)(2).
    (7) For a pump QIP program, the owner or operator shall maintain the 
following records:
    (i) Individual pump records as specified in Sec. 
65.116(d)(2).
    (ii) Trial evaluation program documentation as specified in 
Sec. 65.116(d)(6)(iii).
    (iii) Engineering evaluation documenting the basis for judgement 
that superior emission performance technology is not applicable as 
specified in Sec. 65.116(d)(6)(vi).
    (iv) Quality assurance program documentation as specified in 
Sec. 65.116(d)(7).
    (v) QIP records as specified in Sec. 65.116(e).
    (8) For process units complying with the batch process unit 
alternative, the owner or operator shall maintain the following records:
    (i) Pressure test records as specified in Sec. 
65.117(b)(7).
    (ii) Records for equipment added to the process unit as specified in 
Sec. 65.117(d).
    (9) For process units complying with the enclosed-vented process 
unit alternative, the owner or operator shall maintain the records for 
enclosed-vented process units as specified in Sec. 65.118(b).



Sec. 65.120  Reporting provisions.

    (a) Initial Compliance Status Report. Unless the information 
specified in paragraphs (a)(1) through (3) of this section has 
previously been submitted under the referencing subpart, each owner or 
operator shall submit an Initial Compliance Status Report according to 
the procedures in Sec. 65.5(d). The notification shall include 
the information listed in paragraphs (a)(1) through (3) of this section, 
as applicable.

[[Page 96]]

    (1) The notification shall provide the following information for 
each process unit subject to the requirements of this subpart:
    (i) Process unit identification;
    (ii) Number of each equipment type (for example, valves, pumps) 
excluding equipment in vacuum service; and
    (iii) Method of compliance with the standard (for example, 
``monthly leak detection and repair'' or 
``equipped with dual mechanical seals'').
    (2) The notification shall provide the following information for 
each process unit subject to the requirements of Sec. 
65.117(b):
    (i) Batch products or product codes subject to the provisions of 
this subpart; and
    (ii) Planned schedule for pressure testing when equipment is 
configured for production of products subject to the provisions of this 
subpart.
    (3) The notification shall provide the following information for 
each process unit subject to the requirements in Sec. 65.118:
    (i) Process unit identification;
    (ii) A description of the system used to create a negative pressure 
in the enclosure, and the control device used to comply with the 
requirements of subpart G of this part.
    (b) Periodic reports. The owner or operator shall report the 
information specified in paragraphs (b)(1) through (9) of this section, 
as applicable, in the periodic report specified in Sec. 
65.5(e).
    (1) For the equipment specified in paragraphs (b)(1)(i) through (v) 
of this section, report in a summary format by equipment type the number 
of components for which leaks were detected, and for valves, pumps, and 
connectors show the percent leakers and the total number of components 
monitored. Also include the number of leaking components that were not 
repaired as required by Sec. 65.105(a), and for valves 
identify the number of components that are determined by Sec. 
65.106(c)(3) to be nonrepairable.
    (i) Valves in gas/vapor service and in light liquid service pursuant 
to Sec. 65.106(b) and (c).
    (ii) Pumps in light liquid service pursuant to Sec. 
65.107(b) and (c).
    (iii) Connectors in gas/vapor service and in light liquid service 
pursuant to Sec. 65.108(b) and (c).
    (iv) Agitators in gas/vapor service and in light liquid service 
pursuant to Sec. 65.109(b).
    (v) Compressors pursuant to Sec. 65.112(d).
    (2) Where any delay of repair is utilized pursuant to Sec. 
65.105(d), report that delay of repair has occurred and report the 
number of instances of delay of repair.
    (3) If applicable, report the valve subgrouping information 
specified in Sec. 65.106(b)(4)(iv).
    (4) For pressure relief devices in gas/vapor service pursuant to 
Sec. 65.111(b) and for compressors pursuant to Sec. 
65.112(f) that are to be operated at a leak detection instrument reading 
of less than 500 parts per million, report the results of all monitoring 
to show compliance conducted within the semiannual reporting period.
    (5) Report, if applicable, the initiation of a monthly monitoring 
program for valves pursuant to Sec. 65.106(b)(3)(i).
    (6) Report, if applicable, the initiation of a quality improvement 
program for pumps pursuant to Sec. 65.116.
    (7) [Reserved]
    (8) Where the alternative means of emissions limitation for batch 
processes is utilized, report the information listed in Sec. 
65.117(f).
    (9) Report the information listed in paragraph (a) of this section 
for the Initial Compliance Status Report for process units with later 
compliance dates. Report any revisions to items reported in an earlier 
Initial Compliance Status Report if the method of compliance has changed 
since the last report.



Sec.Sec. 65.121-65.139  [Reserved]

[[Page 97]]

    Table 1 to Subpart F of Part 65 - Batch Processes 
        Monitoring Frequency for Equipment Other Than Connectors

----------------------------------------------------------------------------------------------------------------
                                             Equivalent continuous process monitoring frequency time in use
  Operating time  (percent of year)   --------------------------------------------------------------------------
                                               Monthly                 Quarterly               Semiannually
----------------------------------------------------------------------------------------------------------------
0 to <25..........................  Quarterly..............  Annually...............  Annually.
25 to <50.........................  Quarterly..............  Semiannually...........  Annually.
50 to <75.........................  Bimonthly..............  Three times............  Semiannually.
75 to 100............................  Monthly................  Quarterly..............  Semiannually.
----------------------------------------------------------------------------------------------------------------


Subpart G - Closed Vent Systems, Control Devices, and Routing to a 
                      Fuel Gas System or a Process



Sec. 65.140  Applicability.

    The provisions of this subpart and of subpart A of this part 
(including the startup, shutdown, and malfunction provisions in 
Sec. 65.6) apply to routing emissions to processes, fuel gas 
systems, closed vent systems, control devices, and recovery devices 
where another subpart expressly references the use of this subpart.


Sec. 65.141  Definitions.

    All terms used in this subpart shall have the meaning given them in 
the Act and in subpart A of this part. If a term is defined in both 
subpart A of this part and in other subparts that reference the use of 
this subpart, the term shall have the meaning given in subpart A of this 
part for purposes of this subpart.


Sec. 65.142  Standards.

    (a) Storage vessel requirements. The owner or operator expressly 
referenced to this subpart from subpart C of this part shall comply with 
the following requirements, as applicable:
    (1) Closed vent system and flare. Owners or operators subject to 
Sec. 65.42(b)(4) who route storage vessel emissions through a 
closed vent system to a flare shall meet the requirements in 
Sec. 65.143 for closed vent systems; Sec. 65.147 for 
flares; and Sec. 65.157(a), (b), and (c) for provisions 
regarding flare compliance determinations; and the monitoring, 
recordkeeping, and reporting requirements referenced therein. No other 
provisions of this subpart apply to storage vessel emissions routed 
through a closed vent system to a flare.
    (2) Closed vent system and nonflare control device. Owners or 
operators subject to Sec. 65.42(b)(5) who route storage vessel 
emissions through a closed vent system to a nonflare control device 
shall meet the requirements in Sec. 65.143 for closed vent 
systems and Sec. 65.145 for nonflare control devices and the 
monitoring, recordkeeping, and reporting requirements referenced 
therein. No other provisions of this subpart apply to storage vessel 
emissions routed through a closed vent system to a nonflare control 
device unless specifically required in the monitoring plan submitted 
under Sec. 65.145(c).
    (3) Route to a fuel gas system or process. Owners or operators 
subject to Sec. 65.42(b)(6) who route storage vessel emissions 
to a fuel gas system or to a process shall meet the requirements in 
Sec. 65.144 and the monitoring, recordkeeping, and reporting 
requirements referenced therein. No other provisions of this subpart 
apply to storage vessel emissions being routed to a fuel gas system or 
to a process.
    (b) Process vent requirements. The owner or operator expressly 
referenced to this subpart from subpart D of this part or 40 CFR part 
60, subpart DDD, shall comply with the following requirements, as 
applicable:
    (1) Flare. Owners or operators subject to Sec. 65.63(a)(1) 
or 40 CFR 60.562-1(a)(1)(i)(C) who route process vent emissions to a 
flare shall meet the applicable requirements in Sec. 65.143 
for closed vent systems; Sec. 65.147 for flares; and 
Sec. 65.157(a), (b), and (c) for provisions regarding flare 
compliance determinations; and the monitoring, recordkeeping, and 
reporting requirements referenced therein. No other provisions of this 
subpart apply to process vent emissions routed through a closed vent 
system to a flare.

[[Page 98]]

    (2) Nonflare control device. Owners or operators subject to 
Sec. 65.63(a)(2) or 40 CFR 60.562-1(a)(1)(i)(A) or (B) who 
route process vent emissions to a nonflare control device shall meet the 
applicable requirements in Sec. 65.143 for closed vent 
systems; the requirements applicable to the control devices being used 
in Sec.Sec. 65.148 through 65.152 or Sec. 
65.155; the applicable general monitoring requirements of Sec. 
65.156; the applicable performance test requirements and procedures of 
Sec.Sec. 65.157 and 65.158; and the monitoring, 
recordkeeping, and reporting requirements referenced therein. Owners or 
operators subject to the halogen reduction device requirements of 
Sec. 65.63(b)(1) must also comply with Sec. 65.154 
and the monitoring, recordkeeping, and reporting requirements referenced 
therein. The requirements of Sec.Sec. 65.144 through 
65.146 do not apply to process vents. No other provisions of this 
subpart apply to process vent emissions routed through a closed vent 
system to a nonflare control device.
    (3) Final recovery devices. Owners or operators subject to 
Sec. 65.63(a)(3) who use a final recovery device to maintain 
the TRE index value of a Group 2A process vent above 1.0 shall meet the 
requirements in Sec. 65.153, and the monitoring, 
recordkeeping, and reporting requirements referenced therein applicable 
to the recovery device being used and the applicable monitoring 
requirements in Sec. 65.156, and the recordkeeping and 
reporting requirements referenced therein, except for Sec. 
65.156(c)(2)(ii). No other provisions of this subpart apply to Group 2A 
process vents.
    (c) Transfer rack requirements. The owner or operator expressly 
referenced to this subpart from subpart E of this part shall comply with 
the following requirements, as applicable:
    (1) Closed vent system and flare. Owners or operators subject to 
Sec. 65.83(a)(2) who route transfer rack emissions through a 
closed vent system to a flare shall meet the applicable requirements in 
Sec. 65.143 for closed vent systems; Sec. 65.147 for 
flares; and Sec. 65.157(a), (b), and (c) for provisions 
regarding flare compliance determinations; and the monitoring, 
recordkeeping, and reporting requirements referenced therein. No other 
provisions of this subpart apply to transfer rack emissions routed 
through a closed vent system to a flare.
    (2) Closed vent system and nonflare control device for low-
throughput transfer racks. Owners or operators of low-throughput 
transfer racks subject to Sec. 65.83(a)(1) who route low-
throughput transfer rack emissions through a closed vent system to a 
nonflare control device shall meet the applicable requirements in 
Sec. 65.143 for closed vent systems and Sec. 65.145 
for nonflare control devices and the monitoring, recordkeeping, and 
reporting requirements referenced therein. Owners or operators subject 
to the halogen reduction requirements of Sec. 65.83(b)(1) must 
also comply with the recordkeeping requirement of Sec. 
65.160(d) and the reporting requirement of Sec. 65.165(d). No 
other provisions of this subpart apply to low-throughput transfer rack 
emissions routed through a closed vent system to a nonflare control 
device unless specifically required in the monitoring plan submitted 
under Sec. 65.145(c).
    (3) Closed vent system and nonflare control devices for high-
throughput transfer racks. Owners or operators of high-throughput 
transfer racks subject to Sec. 65.83(a)(1) who route high-
throughput transfer rack emissions through a closed vent system to a 
nonflare control device shall meet the applicable requirements in 
Sec. 65.143 for closed vent systems; the requirements 
applicable to the control device being used in 
Sec.Sec. 65.148 through 65.152 or Sec. 
65.155; the applicable general monitoring of Sec. 65.156; the 
applicable performance test requirements and procedures of 
Sec.Sec. 65.157 and 65.158; and the monitoring, 
recordkeeping, and reporting requirements referenced therein. Owners or 
operators subject to the halogen reduction device requirements of 
Sec. 65.83(b)(1) must also comply with Sec. 65.154 
and the monitoring, recordkeeping, and reporting requirements referenced 
therein. The requirements of Sec.Sec. 65.144 through 
65.146 do not apply to high-throughput transfer rack emissions routed 
through a closed vent system to a nonflare control device. No other 
provisions of this subpart apply to high-throughput transfer rack 
emissions routed through a closed vent system to a nonflare control 
device.

[[Page 99]]

    (4) Route to a fuel gas system or to a process. Owners or operators 
subject to Sec. 65.83(a)(4) of this part who route transfer 
rack emissions to a fuel gas system or to a process shall meet the 
applicable requirements in Sec. 65.144 and the monitoring, 
recordkeeping, and reporting requirements referenced therein. No other 
provisions of this subpart apply to transfer rack emissions being routed 
to a fuel gas system or to a process.
    (d) Equipment leak requirements. The owner or operator expressly 
referenced to this subpart from subpart F of this part shall comply with 
the following requirements, as applicable:
    (1) Closed vent system and flare. Owners or operators subject to 
Sec. 65.115(b) who route equipment leak emissions through a 
closed vent system to a flare shall meet the requirements in 
Sec. 65.143 for closed vent systems; Sec. 65.147 for 
flares; and Sec. 65.157(a), (b), and (c) for provisions 
regarding flare compliance determinations; and the monitoring, 
recordkeeping, and reporting requirements referenced therein. No other 
provisions of this subpart apply to equipment leak emissions routed 
through a closed vent system to a flare.
    (2) Closed vent system and nonflare control device. Owners or 
operators subject to Sec. 65.115(b) who route equipment leak 
emissions through a closed vent system to a nonflare control device 
shall meet the requirements in Sec. 65.143 for closed vent 
systems, Sec. 65.146 for nonflare control devices used for 
equipment leak emissions, and the monitoring, recordkeeping, and 
reporting requirements referenced therein. No other provisions of this 
subpart apply to equipment leak emissions routed through a closed vent 
system to a nonflare control device.
    (3) Route to a fuel gas system or to a process. Owners or operators 
subject to Sec. 65.115(b) who route equipment leak emissions 
to a fuel gas system or to a process shall meet the requirements in 
Sec. 65.144 and the monitoring, recordkeeping, and reporting 
requirements referenced therein. No other provisions of this subpart 
apply to equipment leak emissions being routed to a fuel gas system or 
to a process.
    (e) Combined emissions. When emissions of different kinds (for 
example, emissions from process vents, transfer racks, and/or storage 
vessels) are combined, the owner or operator shall comply with the 
requirements of either paragraph (e)(1) or (2) of this section:
    (1) Comply with the applicable requirements of this subpart for each 
kind of emissions in the stream (for example, the requirements of 
Sec. 65.142(b) for process vents, and the requirements of 
Sec. 65.142(c) for transfer racks); or
    (2) Comply with the first set of requirements identified in 
paragraphs (e)(2)(i) through (iii) of this section which applies to any 
individual emission stream that is included in the combined stream. 
Compliance with the first applicable set of requirements identified in 
paragraphs (e)(2)(i) through (iii) of this section constitutes 
compliance with all other requirements in paragraphs (e)(2)(i) through 
(iii) of this section applicable to other types of emissions in the 
combined stream. The hierarchy is as follows:
    (i) The requirements of Sec. 65.142(b) for Group 1 process 
vents, including applicable monitoring, recordkeeping, and reporting;
    (ii) The requirements of Sec. 65.142(c) for high-
throughput transfer racks, including applicable monitoring, 
recordkeeping, and reporting;
    (iii) The requirements of Sec. 65.142(a) for control of 
emissions from storage vessels or low-throughput transfer racks, 
including monitoring, recordkeeping, and reporting.


Sec. 65.143  Closed vent systems.

    (a) Closed vent system equipment and operating requirements. The 
provisions of paragraph (a) of this section apply to closed vent systems 
collecting regulated material from a storage vessel, process vent, 
transfer rack, or equipment leaks.
    (1) Collection of emissions. Each closed vent system shall be 
designed and operated to collect the regulated material vapors from the 
emission point and to route the collected vapors to a control device.
    (2) Period of operation. Closed vent systems used to comply with the 
provisions of this subpart shall be operated at all times when emissions 
are vented to them.

[[Page 100]]

    (3) Bypass monitoring. Except for pressure relief devices needed for 
safety purposes, low leg drains, high point bleeds, analyzer vents, and 
open-ended valves or lines, the owner or operator shall comply with 
either of the following provisions for each closed vent system that 
contains bypass lines that could divert a vent stream to the atmosphere:
    (i) Properly install, maintain, and operate a flow indicator that 
takes a reading at least once every 15 minutes. Records shall be 
generated as specified in Sec. 65.163(a)(1)(i). The flow 
indicator shall be installed at the entrance to any bypass line.
    (ii) Secure the bypass line valve in the non-diverting position with 
a car-seal or a lock-and-key type configuration. A visual inspection of 
the seal or closure mechanism shall be performed at least once every 
month to ensure the valve is maintained in the non-diverting position 
and the vent stream is not diverted through the bypass line. Records 
shall be generated as specified in Sec. 65.163(a)(1)(ii).
    (4) Loading arms at transfer racks. Each closed vent system 
collecting regulated material from a transfer rack shall be designed and 
operated so that regulated material vapors collected at one loading arm 
will not pass through another loading arm in the rack to the atmosphere.
    (5) Pressure relief devices in a transfer rack's closed vent system. 
The owner or operator of a transfer rack subject to the provisions of 
this subpart shall ensure that no pressure relief device in the transfer 
rack's closed vent system shall open to the atmosphere during loading. 
Pressure relief devices needed for safety purposes are not subject to 
paragraph (a)(5) of this section.
    (b) Closed vent system inspection requirements. The provisions of 
paragraph (b) of this section apply to closed vent systems collecting 
regulated material from a storage vessel, transfer rack or equipment 
leaks. Inspection records shall be generated as specified in 
Sec. 65.163(a)(3) and (4).
    (1) Except for closed vent systems operated and maintained under 
negative pressure and as provided in paragraphs (b)(2) and (3) of this 
section, each closed vent system shall be inspected as specified in 
paragraph (b)(1)(i) or (ii) of this section.
    (i) If the closed vent system is constructed of hard-piping, the 
owner or operator shall comply with the following requirements:
    (A) Conduct an initial inspection according to the procedures in 
paragraph (c) of this section; and
    (B) Conduct annual visual inspections for visible, audible, or 
olfactory indications of leaks.
    (ii) If the closed vent system is constructed of ductwork, the owner 
or operator shall conduct an initial and annual inspection according to 
the procedures in paragraph (c) of this section.
    (2) Any parts of the closed vent system that are designated as 
described in Sec. 65.163(a)(2) as unsafe to inspect are exempt 
from the inspection requirements of paragraph (b)(1) of this section if 
the following conditions are met:
    (i) The owner or operator determines that the equipment is unsafe to 
inspect because inspecting personnel would be exposed to an imminent or 
potential danger as a consequence of complying with paragraph (b)(1) of 
this section; and
    (ii) The owner or operator has a written plan that requires 
inspection of the equipment as frequently as practical during safe-to-
inspect times. Inspection is not required more than once annually.
    (3) Any parts of the closed vent system that are designated, as 
described in Sec. 65.163(a)(2), as difficult-to-inspect are 
exempt from the inspection requirements of paragraph (b)(1) of this 
section if the following provisions apply:
    (i) The owner or operator determines that the equipment cannot be 
inspected without elevating the inspecting personnel more than 2 meters 
(7 feet) above a support surface; and
    (ii) The owner or operator has a written plan that requires 
inspection of the equipment at least once every 5 years.
    (c) Closed vent system inspection procedures. The provisions of 
paragraph (c) of this section apply to closed vent systems collecting 
regulated material from a storage vessel, transfer rack, or equipment 
leaks.
    (1) Each closed vent system subject to paragraph (c) of this section 
shall be

[[Page 101]]

inspected according to the procedures specified in paragraphs (c)(1)(i) 
through (vii) of this section.
    (i) Inspections shall be conducted in accordance with Method 21 of 
appendix A of 40 CFR part 60 except as specified in this section.
    (ii) Except as provided in paragraph (c)(1)(iii) of this section, 
the detection instrument shall meet the performance criteria of Method 
21 of appendix A of 40 CFR part 60, except the instrument response 
factor criteria in section 3.1.2(a) of Method 21 shall be for the 
representative composition of the process fluid not each individual 
organic compound in the stream. For process streams that contain 
nitrogen, air, water, or other inerts that are not organic hazardous air 
pollutants or volatile organic compounds, the response factor shall be 
determined on an inert-free basis. The response factor may be determined 
at any concentration for which the monitoring for leaks will be 
conducted. Maintain the record specified by Sec. 65.163(a)(5).
    (iii) If no instrument is available at the plant site that will meet 
the performance criteria specified in paragraph (c)(1)(ii) of this 
section, the instrument readings may be adjusted by multiplying by the 
representative response factor of the process fluid calculated on an 
inert-free basis as described in paragraph (c)(1)(ii) of this section.
    (iv) The detection instrument shall be calibrated before use on each 
day of its use by the procedures specified in Method 21 of appendix A of 
40 CFR part 60.
    (v) Calibration gases shall be as specified in the following:
    (A) Zero air (less than 10 parts per million hydrocarbon in air).
    (B) Mixtures of methane in air at a concentration less than 10,000 
parts per million. A calibration gas other than methane in air may be 
used if the instrument does not respond to methane or if the instrument 
does not meet the performance criteria specified in paragraph (c)(1)(ii) 
of this section. In such cases, the calibration gas may be a mixture of 
one or more of the compounds to be measured in air.
    (C) If the detection instrument's design allows for multiple 
calibration scales, then the lower scale shall be calibrated with a 
calibration gas that is no higher than 2,500 parts per million.
    (vi) An owner or operator may elect to adjust or not adjust 
instrument readings for background. If an owner or operator elects not 
to adjust readings for background, all such instrument readings shall be 
compared directly to 500 parts per million to determine whether there is 
a leak. If an owner or operator elects to adjust instrument readings for 
background, the owner or operator shall measure background concentration 
using the procedures in this section. The owner or operator shall 
subtract the background reading from the maximum concentration indicated 
by the instrument.
    (vii) If the owner or operator elects to adjust for background, the 
arithmetic difference between the maximum concentration indicated by the 
instrument and the background level shall be compared with 500 parts per 
million for determining whether there is a leak.
    (2) The instrument probe shall be traversed around all potential 
leak interfaces as close to the interface as possible as described in 
Method 21 of appendix A of 40 CFR part 60.
    (3) Except as provided in paragraph (c)(4) of this section, 
inspections shall be performed when the equipment is in regulated 
material service or in use with any other detectable gas or vapor.
    (4) Inspections of the closed vent system collecting regulated 
material from a transfer rack shall be performed only while a tank truck 
or railcar is being loaded or is otherwise pressurized to normal 
operating conditions with regulated material or any other detectable gas 
or vapor.
    (d) Closed vent system leak repair provisions. The provisions of 
paragraph (d) of this section apply to closed vent systems collecting 
regulated material from a storage vessel, transfer rack, or equipment 
leak.
    (1) If there are visible, audible, or olfactory indications of leaks 
at the time of the annual visual inspections required by paragraph 
(b)(1)(i)(B) of this section, the owner or operator shall follow either 
of the following procedures:

[[Page 102]]

    (i) The owner or operator shall eliminate the indications of the 
leak.
    (ii) The owner or operator shall monitor the equipment according to 
the procedures in paragraph (c) of this section.
    (2) Leaks as indicated by an instrument reading greater than 500 
parts per million by volume above background shall be repaired as soon 
as practical except as provided in paragraph (d)(3) of this section. 
Records shall be generated as specified in Sec. 65.163(a)(3) 
when a leak is detected.
    (i) A first attempt at repair shall be made no later than 5 calendar 
days after the leak is detected.
    (ii) Except as provided in paragraph (d)(3) of this section, repairs 
shall be completed no later than 15 calendar days after the leak is 
detected or at the beginning of the next introduction of vapors to the 
system, whichever is later.
    (3) Delay of repair of a closed vent system for which leaks have 
been detected is allowed if repair within 15 days after a leak is 
detected is technically infeasible without a closed vent system 
shutdown, as defined in Sec. 65.2, or if the owner or operator 
determines that emissions resulting from immediate repair would be 
greater than the emissions likely to result from delay of repair. Repair 
of such equipment shall be completed as soon as practical, but not later 
than the end of the next closed vent system shutdown.


Sec. 65.144  Fuel gas systems and processes to which storage vessel, 
          transfer rack, or equipment leak regulated material emissions 
          are routed.

    (a) Equipment and operating requirements for fuel gas systems and 
processes. (1) Except during periods of startup, shutdown, and 
malfunction as specified in Sec. 65.3(a), the fuel gas system 
or process shall be operating at all times when regulated material 
emissions are routed to it.
    (2) The owner or operator of a transfer rack subject to the 
provisions of this subpart shall ensure that no pressure relief device 
in the transfer rack's system returning vapors to a fuel gas system or 
process shall open to the atmosphere during loading. Pressure relief 
devices needed for safety purposes are not subject to this paragraph 
(a)(2).
    (3) Each process piping system collecting regulated material from a 
transfer rack shall be designed and operated so that regulated material 
vapors collected at one loading arm will not pass through another 
loading arm in the rack to the atmosphere.
    (b) Fuel gas system and process compliance determination. (1) If 
emissions are routed to a fuel gas system, there is no requirement to 
conduct a performance test or design evaluation.
    (2) For storage vessels and transfer racks, and if emissions are 
routed to a process, the regulated material in the emissions shall 
predominantly meet one of, or a combination of, the following 
conditions, and the compliance demonstration requirements in paragraph 
(b)(3) of this section, if applicable:
    (i) Recycled and/or consumed in the same manner as a material that 
fulfills the same function in that process;
    (ii) Transformed by chemical reaction into materials that are not 
regulated materials;
    (iii) Incorporated into a product; and/or
    (iv) Recovered.
    (3) To demonstrate compliance with paragraph (b)(2) of this section 
for a storage vessel, the owner or operator shall prepare a design 
evaluation (or engineering assessment) that demonstrates the extent to 
which one or more of the conditions specified in paragraphs (b)(2)(i) 
through (iv) of this section are being met. The owner or operator shall 
submit the design evaluation as specified in Sec. 
65.165(a)(1).
    (c) Statement of connection to fuel gas system. For storage vessels 
and transfer racks, the owner or operator shall submit the statement of 
connection reports for fuel gas systems specified in Sec. 
65.165(a)(2) and/or (a)(3), as appropriate.


Sec. 65.145  Nonflare control devices used to control emissions from 
          storage vessels or low-throughput transfer racks.

    (a) Nonflare control device equipment and operating requirements. 
The owner or operator shall operate and maintain the nonflare control 
device, including a

[[Page 103]]

halogen reduction device for a low-throughput transfer rack, so that the 
monitored parameters defined as required in paragraph (c) of this 
section remain within the ranges specified in the Initial Compliance 
Status Report whenever emissions of regulated material are routed to the 
control device and halogen reduction device, except during periods of 
startup, shutdown, and malfunction as specified in Sec. 
65.3(a).
    (b) Nonflare control device design evaluation or performance test 
requirements. When using a control device other than a flare, the owner 
or operator shall comply with the requirements in paragraph (b)(1)(i), 
(ii), or (iii) of this section except as provided in paragraph (b)(2) of 
this section. Owners or operators of halogenated low-throughput transfer 
rack vent streams routed to a combustion device and then to a halogen 
reduction device to meet the specifications of Sec. 
65.83(b)(1), must also meet the requirements of paragraph (b)(3) of this 
section.
    (1) Unless a design evaluation or performance test as required in 
the referencing subpart was previously conducted and submitted for the 
storage vessel or low-throughput transfer rack, the owner or operator 
shall either prepare and submit with the Initial Compliance Status 
Report, as specified in Sec. 65.165(b), a design evaluation 
that includes the information specified in paragraph (b)(1)(i) of this 
section, or the results of the performance test as described in 
paragraph (b)(1)(ii) or (iii) of this section.
    (i) Design evaluation. The design evaluation shall include 
documentation demonstrating that the control device being used achieves 
the required control efficiency during the reasonably expected maximum 
storage vessel filling or transfer loading rate. This documentation is 
to include a description of the gas stream that enters the control 
device, including flow and regulated material content; and additionally 
for storage vessels, the effects of varying liquid level conditions; and 
the information specified in paragraphs (b)(1)(i)(A) through (E) of this 
section, as applicable. This documentation shall be submitted with the 
Initial Compliance Status Report as specified in Sec. 
65.165(b).
    (A) The efficiency determination is to include consideration of all 
vapors, gases, and liquids, other than fuels, received by the control 
device.
    (B) If an enclosed combustion device with a minimum residence time 
of 0.5 seconds and a minimum temperature of 760 C is used 
to meet the emission reduction requirement specified in Sec. 
65.42(b)(5) for storage vessels, or Sec. 65.83(a)(1) for 
transfer racks, documentation that those conditions exist is sufficient 
to meet the requirements of paragraph (b)(1)(i) of this section.
    (C) Except as provided in paragraph (b)(1)(i)(B) of this section for 
enclosed combustion devices, the design evaluation shall include the 
estimated autoignition temperature of the stream being combusted, the 
flow rate of the stream, the combustion temperature, and the residence 
time at the combustion temperature.
    (D) For carbon adsorbers, the design evaluation shall include the 
estimated affinity of the regulated pollutant vapors for carbon, the 
amount of carbon in each bed, the number of beds, the humidity, the 
temperature, the flow rate of the inlet stream and, if applicable, the 
desorption schedule, the regeneration stream pressure or temperature, 
and the flow rate of the regeneration stream. For vacuum desorption, 
pressure drop shall be included.
    (E) For condensers, the design evaluation shall include the final 
temperature of the stream vapors, the type of condenser, and the design 
flow rate of the emission stream.
    (ii) Performance test. A performance test is acceptable to 
demonstrate compliance with Sec. 65.42(b)(5) for storage 
vessels, and Sec. 65.83(a)(1) for low-throughput transfer 
racks. The owner or operator is not required to prepare a design 
evaluation for the control device as described in paragraph (b)(1)(i) of 
this section if a performance test will be performed that meets the 
following criteria:
    (A) The performance test demonstrates that the control device 
achieves greater than or equal to the required control efficiency 
specified in Sec. 65.42(b)(5) for storage vessels, or 
Sec. 65.83(a)(1) for transfer racks; and

[[Page 104]]

    (B) The performance test meets the applicable performance test 
requirements of Sec.Sec. 65.157 and 65.158, and the 
results are submitted as part of the Initial Compliance Status Report as 
specified in Sec. 65.165(b).
    (iii) If the control device used to comply with Sec. 
65.42(b)(5) for storage vessels, or with Sec. 65.83(a)(1) for 
low-throughput transfer racks, as applicable, is also used to comply 
with Sec. 65.63(a)(2) for process vents, or Sec. 
65.83(a)(1) for high-throughput transfer racks, a performance test 
required by Sec.Sec. 65.148(b), 65.149(b), 
65.150(b), 65.151(b), 65.152(b), or 65.155(b) is acceptable to 
demonstrate compliance with Sec. 65.42(b)(5) for storage 
vessels, or Sec. 65.83(a)(1) for low-throughput transfer 
racks, as applicable. The owner or operator is not required to prepare a 
design evaluation for the control device as described in paragraph 
(b)(1)(i) of this section, if a performance test will be performed which 
meets the following criteria:
    (A) The performance test demonstrates that the control device 
achieves greater than or equal to the required control efficiency 
specified in Sec. 65.42(b)(5) for storage vessels, or 
Sec. 65.83(a)(1) for transfer racks; and
    (B) The performance test is submitted as part of the Initial 
Compliance Status Report as specified in Sec. 65.165(b).
    (2) A design evaluation or performance test is not required if the 
owner or operator uses a combustion device meeting the criteria in 
paragraph (b)(2)(i), (ii), (iii), or (iv) of this section and reports as 
specified in Sec. 65.165(f).
    (i) A boiler or process heater with a design heat input capacity of 
44 megawatts (150 million British thermal units per hour) or greater.
    (ii) A boiler or process heater burning hazardous waste for which 
the owner or operator meets either of the following requirements:
    (A) The boiler or process heater has been issued a final permit 
under 40 CFR part 270 and complies with the requirements of 40 CFR part 
266, subpart H; or
    (B) The boiler or process heater has certified compliance with the 
interim status requirements of 40 CFR part 266, subpart H.
    (iii) A hazardous waste incinerator for which the owner or operator 
meets either of the following requirements:
    (A) The incinerator has been issued a final permit under 40 CFR part 
270 and complies with the requirements of 40 CFR part 264, subpart O; or
    (B) The incinerator has certified compliance with the interim status 
requirements of 40 CFR part 265, subpart O.
    (iv) A boiler or process heater into which the vent stream is 
introduced with the primary fuel.
    (3) Halogen reduction devices used for transfer racks. Unless a 
design evaluation or performance test as required in the referencing 
subpart was previously conducted and submitted for a halogen reduction 
device following a combustion device for a low-throughput transfer rack, 
the owner or operator shall either prepare and submit with the Initial 
Compliance Status Report, as specified in Sec. 65.165(b), a 
design evaluation that includes the information specified in paragraph 
(b)(3)(i) of this section, or the results of the performance test as 
described in paragraph (b)(3)(ii) or (iii) of this section. The 
provisions of this paragraph (b)(3) apply to owners or operators using a 
halogen reduction device following a combustion device to comply with 
Sec. 65.83(b)(1).
    (i) Design evaluation. The design evaluation shall include 
documentation demonstrating that the halogen reduction device being used 
achieves the required control efficiency during the reasonably expected 
maximum transfer loading rate. This documentation is to include a 
description of the gas stream that enters the halogen reduction device, 
including flow and regulated material content. The efficiency 
determination is to include consideration of all vapors, gases, and 
liquids, other than fuels, received by the halogen reduction device. 
This documentation shall be submitted with the Initial Compliance Status 
Report as specified in Sec. 65.165(b).
    (ii) Performance test. A performance test is acceptable to 
demonstrate compliance with Sec. 65.83(b)(1) for low-
throughput transfer racks. The owner or operator is not required to 
prepare a

[[Page 105]]

design evaluation for the halogen reduction device as described in 
paragraph (b)(3)(i) of this section if a performance test will be 
performed that meets the following criteria:
    (A) The performance test demonstrates that the halogen reduction 
device achieves greater than or equal to the required control efficiency 
specified in Sec. 65.83(b)(1) for transfer racks; and
    (B) The performance test meets the applicable performance test 
requirements of Sec.Sec. 65.157 and 65.158, and the 
results are submitted as part of the Initial Compliance Status Report as 
specified in Sec. 65.165(b).
    (iii) If the halogen reduction device used to comply with 
Sec. 65.83(b)(1) for low-throughput transfer racks, is also 
used to comply with Sec. 65.63(b)(1) for process vents, or 
Sec. 65.83(b)(1) for high-throughput transfer racks, a 
performance test required by Sec. 65.154(b) is acceptable to 
demonstrate compliance with Sec. 65.83(b)(1) for low-
throughput transfer racks. The owner or operator is not required to 
prepare a design evaluation for the halogen reduction device as 
described in paragraph (b)(3)(i) of this section, if a performance test 
will be performed which meets the following criteria:
    (A) The performance test demonstrates that the halogen reduction 
device achieves greater than or equal to the required control efficiency 
specified in Sec. 65.83(b)(1) for transfer racks; and
    (B) The performance test is submitted as part of the Initial 
Compliance Status Report as specified in Sec. 65.165(b).
    (c) Nonflare control device monitoring requirements. (1) Unless 
previously established under an applicable standard prior to the 
implementation date of this part as specified in Sec. 65.1(f), 
the owner or operator shall submit with the Initial Compliance Status 
Report a monitoring plan containing the information specified in 
Sec. 65.165(b) to identify the parameters that will be 
monitored to assure proper operation of the control device. The owner or 
operator of a halogenated low-throughput transfer rack vent stream 
routed to a combustion device and then to a halogen reduction device to 
meet the specifications of Sec. 65.83(b)(1) shall submit with 
the Initial Compliance Status Report a monitoring plan containing the 
information specified in Sec. 65.165(b) to identify the 
parameters that will be monitored to assure proper operation of the 
halogen reduction device.
    (2) The owner or operator shall monitor the parameters specified in 
the Initial Compliance Status Report or in the operating permit. Records 
shall be generated as specified in Sec. 65.163(b)(1).


Sec. 65.146  Nonflare control devices used for equipment leaks only.

    (a) Equipment and operating requirements. (1) Owners or operators 
using a nonflare control device to meet the applicable requirements in 
Sec. 65.115(b) shall meet the requirements of this section.
    (2) Control devices used to comply with the provisions of this 
subpart shall be operated at all times when emissions are vented to 
them.
    (b) Performance test requirements. A performance test is not 
required for any nonflare control device used only to control emissions 
from equipment leaks.
    (c) Monitoring requirements. Owners or operators of control devices 
that are used only to comply with the provisions of Sec. 
65.115(b) shall monitor these control devices to ensure that they are 
operated and maintained in conformance with their design. The owner or 
operator shall maintain the records as specified in Sec. 
65.163(d).


Sec. 65.147  Flares.

    (a) Flare equipment and operating requirements. Flares subject to 
this subpart shall meet the performance requirements of paragraphs 
(a)(1) through (7) of this section.
    (1) Flares shall be operated at all times when emissions are vented 
to them.
    (2) Flares shall be designed for and operated with no visible 
emissions as determined by the methods specified in paragraph (b)(3)(i) 
of this section, except for periods not to exceed a total of 5 minutes 
during any 2 consecutive hours.
    (3) Flares shall be operated with a flare flame or at least one 
pilot flame present at all times, as determined by

[[Page 106]]

the methods specified in paragraph (c) of this section.
    (4) An owner/operator has the choice of adhering to either the heat 
content specifications in paragraph (a)(4)(ii) of this section and the 
maximum tip velocity specifications in paragraph (a)(6) of this section, 
or adhering to the requirements in paragraph (a)(4)(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 Equation 147-1 of this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.008

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. 65.13).

    (B) The actual exit velocity of a flare shall be determined by the 
method specified in paragraph (b)(3)(iii) of this section.
    (ii) Flares shall be used only when the net heating value of the gas 
being combusted is 11.2 megajoules per standard cubic meter (300 British 
thermal units per standard cubic foot) or greater if the flare is steam-
assisted or air-assisted, or when the net heating value of the gas being 
combusted is 7.45 megajoules per standard cubic meter (200 British 
thermal units per standard cubic foot) 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 (b)(3)(ii) of this 
section.
    (5) Flares used to comply with this section shall be steam-assisted, 
air-assisted, or nonassisted.
    (6) Steam-assisted and nonassisted flares shall be designed for and 
operated with an exit velocity as determined by the methods specified in 
paragraph (b)(3)(iii) of this section, less than 18.3 meters per second 
(60 feet per sec) except as provided in the following two paragraphs, as 
applicable:
    (i) Steam-assisted and nonassisted flares shall be designed for and 
operated with an exit velocity as determined by the methods specified in 
paragraph (b)(3)(iii) of this section, equal to or less than 122 meters 
per second (400 feet per second) if the net heating value of the gas 
being combusted is greater than 37.3 megajoules per standard cubic meter 
(1,000 British thermal units per standard cubic foot).
    (ii) Steam-assisted and nonassisted flares shall be designed for and 
operated with an exit velocity as determined by the methods specified in 
paragraph (b)(3)(iii) of this section, less than the velocity, V max, 
and less than 122 meters per second (400 feet per sec), where the 
maximum permitted velocity, Vmax, is determined by Equation 
147-2 of this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.009

Where:

Vmax = Maximum permitted velocity, meters per second.
28.8 = Constant.
31.7 = Constant.
HT = The net heating value as determined in paragraph 
(b)(3)(ii) of this section.

    (7) Air-assisted flares shall be designed for and operated with an 
exit velocity as determined by the methods specified in paragraph 
(b)(3)(iii) of this section, less than the velocity, Vmax, 
where the maximum permitted velocity, Vmax, is determined by 
Equation 147-3 of this section:

[[Page 107]]

[GRAPHIC] [TIFF OMITTED] TR14DE00.010

Where:

Vmax = Maximum permitted velocity, meters per second.
8.706 = Constant.
0.7084 = Constant.
HT = The net heating value as determined in paragraph 
(b)(3)(ii) of this section.

    (b) Flare compliance determination. (1) Unless an initial flare 
compliance determination of the flare was previously conducted and 
submitted under the referencing subpart, the owner or operator shall 
conduct an initial flare compliance determination of any flare used to 
comply with the provisions of this subpart. Flare compliance 
determination records shall be kept as specified in Sec. 
65.159(a) and (b) and a flare compliance determination report shall be 
submitted as specified in Sec. 65.164. An owner or operator is 
not required to conduct a performance test to determine percent emission 
reduction or outlet regulated material or TOC concentration when a flare 
is used.
    (2) Unless already permitted by the applicable title V permit, if an 
owner or operator elects to use a flare to replace an existing control 
device at a later date, the owner or operator shall notify the 
Administrator, either by amendment of the regulated source's title V 
permit or, if title V is not applicable, by submission of the notice 
specified in Sec. 65.167(a). Upon implementing the change, a 
flare compliance determination shall be performed using the methods 
specified in paragraph (b)(3) of this section within 180 days. The 
compliance determination report shall be submitted to the Administrator 
within 60 days of completing the determination as provided in 
Sec. 65.164(b)(2). If an owner or operator elects to use a 
flare to replace an existing final recovery device that is used on a 
Group 2A process vent, the owner or operator shall comply with the 
applicable provisions of Sec.Sec. 65.63(e) and 
65.67(b) and submit the notification specified in Sec. 
65.167(a).
    (3) Flare compliance determinations shall meet the requirements 
specified in paragraphs (b)(3)(i) through (iv) of this section.
    (i) Method 22 of appendix A of part 60 shall be used to determine 
the compliance of flares with the visible emission provisions of this 
subpart. The observation period is 2 hours, except for transfer racks as 
provided in either one of the following:
    (A) For transfer racks, if the loading cycle is less than 2 hours, 
then the observation period for that run shall be for the entire loading 
cycle.
    (B) For transfer racks, if additional loading cycles are initiated 
within the 2-hour period, then visible emissions observations shall be 
conducted for the additional cycles.
    (ii) The net heating value of the gas being combusted in a flare 
shall be calculated using Equation 147-4 of this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.011

Where:

HT = Net heating value of the sample, megajoules per standard 
cubic meter; where the net enthalpy per mole of offgas is based on 
combustion at 25 C and 760 millimeters of mercury (30 
inches of mercury), but the standard temperature for determining the 
volume corresponding to 1 mole is 20 C;
K1 = 1.740 x 10-7 (parts per million by 
volume)-1 (gram-mole per standard cubic meter) (megajoules 
per kilocalories), where the standard temperature for gram mole per 
standard cubic meter is 20 C;
Dj = Concentration of sample component j, in parts per 
million by volume on a wet basis, as measured for organics by Method 18 
of appendix A of 40 CFR part 60 and measured for hydrogen and carbon 
monoxide by American Society for Testing and Materials (ASTM) D1946-77 
(incorporated by reference as specified in Sec. 65.13); and
Hj = Net heat of combustion of sample component j, 
kilocalories per gram-mole at 25 C and 760 millimeters of 
mercury (30 inches of mercury). The heats of combustion of stream 
components may be determined using ASTM D2382-76 (incorporated by 
reference as specified in Sec. 65.13) if published values are 
not available or cannot be calculated.

    (iii) The actual exit velocity of a flare shall be determined by 
dividing

[[Page 108]]

the volumetric flow rate (in units of standard temperature and 
pressure), as determined by Method 2, 2A, 2C, or 2D of appendix A of 40 
CFR part 60 as appropriate, by the unobstructed (free) cross-sectional 
area of the flare tip.
    (iv) Flare flame or pilot monitors, as applicable, shall be operated 
during any flare compliance determination.
    (c) Flare monitoring requirements. Where a flare is used, a device 
(including but not limited to a thermocouple, ultraviolet beam sensor, 
or infrared sensor) capable of continuously detecting that at least one 
pilot flame or the flare flame is present is required. Flame monitoring 
and compliance records shall be kept as specified in Sec. 
65.159(c) and (d).


Sec. 65.148  Incinerators.

    (a) Incinerator equipment and operating requirements. (1) Owners or 
operators using incinerators to meet the 98 weight-percent emission 
reduction or 20 parts per million by volume outlet concentration 
requirement as specified in Sec. 65.63(a)(2), or 40 CFR 
60.562-1(a)(1)(i)(A) for process vents, or Sec. 65.83(a)(1) 
for high-throughput transfer racks, as applicable, shall meet the 
requirements of this section.
    (2) Incinerators used to comply with the provisions of this subpart 
shall be operated at all times when emissions are vented to them.
    (b) Incinerator performance test requirements. (1) Unless an initial 
performance test was previously conducted and submitted under the 
referencing subpart and except as specified in Sec. 65.157(b) 
and paragraph (b)(2) of this section, the owner or operator shall 
conduct an initial performance test of any incinerator used to comply 
with the provisions of this subpart according to the procedures in 
Sec.Sec. 65.157 and 65.158. Performance test records 
shall be kept as specified in Sec. 65.160(a) and (b), and a 
performance test report shall be submitted as specified in 
Sec. 65.164. As provided in Sec. 65.145(b)(1), a 
performance test may be used as an alternative to the design evaluation 
for storage vessels and low-throughput transfer rack controls. As 
provided in Sec. 65.146(b), no performance test is required 
for equipment leaks.
    (2) An owner or operator is not required to conduct a performance 
test for a hazardous waste incinerator for which the owner or operator 
has been issued a final permit under 40 CFR part 270 and complies with 
the requirements of 40 CFR part 264, subpart O, or has certified 
compliance with the interim status requirements of 40 CFR part 265, 
subpart O. The owner or operator shall report as specified in 
Sec. 65.165(f).
    (3) Unless already permitted by the applicable title V permit, if an 
owner or operator elects to use an incinerator to replace an existing 
control device at a later date, the owner or operator shall notify the 
Administrator, either by amendment of the regulated source's title V 
permit or, if title V is not applicable, by submission of the notice 
specified in Sec. 65.167(a) before implementing the change. 
Upon implementing the change, an incinerator performance test shall be 
performed using the methods specified in Sec. 65.157 and 
within 180 days if required by paragraph (b)(1) of this section. The 
performance test report shall be submitted to the Administrator within 
60 days of completing the determination as provided in Sec. 
65.164(b)(2). If an owner or operator elects to use an incinerator to 
replace an existing recovery device that is used on a Group 2A process 
vent, the owner or operator shall comply with the applicable provisions 
of Sec.Sec. 65.63(e) and 65.67(b) and submit the 
notification specified in Sec. 65.167(a).
    (c) Incinerator monitoring requirements. (1) Where an incinerator is 
used, a temperature monitoring device capable of providing a continuous 
record that meets the provisions specified in paragraph (c)(1)(i) or 
(ii) of this section is required. Monitoring results shall be recorded 
as specified in Sec. 65.161. General requirements for 
monitoring and continuous parameter monitoring systems are contained in 
Sec. 65.156.
    (i) Where an incinerator other than a catalytic incinerator is used, 
a temperature monitoring device shall be installed in the fire box or in 
the ductwork immediately downstream of the fire box in a position before 
any substantial heat exchange occurs.
    (ii) Where a catalytic incinerator is used, temperature monitoring 
devices

[[Page 109]]

shall be installed in the gas stream immediately before and after the 
catalyst bed.
    (2) The owner or operator shall establish a range for monitored 
parameters that indicates proper operation of the incinerator. In order 
to establish the range, the information required in Sec. 
65.165(c) shall be submitted in the Initial Compliance Status Report or 
the operating permit application or amendment. The range may be based 
upon a prior performance test meeting the specifications of 
Sec. 65.157(b)(1) or upon existing ranges or limits 
established under a referencing subpart.


Sec. 65.149  Boilers and process heaters.

    (a) Boiler and process heater equipment and operating requirements. 
(1) Owners or operators using boilers and process heaters to meet the 98 
weight-percent emission reduction or 20 parts per million by volume 
outlet concentration requirement as specified in Sec. 
65.63(a)(2), or 40 CFR 60.562-1(a)(1)(i)(B) for process vents, or 
Sec. 65.83(a)(1) for high-throughput transfer racks, as 
applicable, shall meet the requirements of this section.
    (2) The vent stream shall be introduced into the flame zone of the 
boiler or process heater.
    (3) Boilers and process heaters used to comply with the provisions 
of this subpart shall be operated at all times when emissions are vented 
to them.
    (b) Boiler and process heater performance test requirements. (1) 
Unless an initial performance test was previously conducted and 
submitted under the referencing subpart, and except as specified in 
Sec. 65.157(b) and paragraph (b)(2) of this section, the owner 
or operator shall conduct an initial performance test of any boiler or 
process heater used to comply with the provisions of this subpart 
according to the procedures in Sec.Sec. 65.157 and 
65.158. Performance test records shall be kept as specified in 
Sec. 65.160(a) and (b), and a performance test report shall be 
submitted as specified in Sec. 65.164. As provided in 
Sec. 65.145(b)(1), a performance test may be used as an 
alternative to the design evaluation for storage vessels and low-
throughput transfer rack controls. As provided in Sec. 
65.146(b), no performance test is required to demonstrate compliance for 
equipment leaks.
    (2) An owner or operator is not required to conduct a performance 
test when any of the control devices specified in paragraphs (b)(2)(i) 
through (iii) of this section are used. The owner or operator shall 
report as specified in Sec. 65.165(f).
    (i) A boiler or process heater with a design heat input capacity of 
44 megawatts (150 million British thermal units per hour) or greater.
    (ii) A boiler or process heater into which the vent stream is 
introduced with the primary fuel or is used as the primary fuel.
    (iii) A boiler or process heater burning hazardous waste for which 
the owner or operator meets either of the following requirements:
    (A) The boiler or process heater has been issued a final permit 
under 40 CFR part 270 and complies with the requirements of 40 CFR part 
266, subpart H; or
    (B) The boiler or process heater has certified compliance with the 
interim status requirements of 40 CFR part 266, subpart H.
    (3) Unless already permitted by the applicable title V permit, if an 
owner or operator elects to use a boiler or process heater to replace an 
existing control device at a later date, the owner or operator shall 
notify the Administrator, either by amendment of the regulated source's 
title V permit or, if title V is not applicable, by submission of the 
notice specified in Sec. 65.167(a) before implementing the 
change. Upon implementing the change, a boiler or process heater 
performance test shall be performed using the methods specified in 
Sec.Sec. 65.157 and 65.158 within 180 days if 
required by paragraph (b)(1) of this section. The performance test 
report shall be submitted to the Administrator within 60 days of 
completing the determination as provided in Sec. 65.164(b)(2). 
If an owner or operator elects to use a boiler or process heater to 
replace an existing recovery device that is used on a Group 2A process 
vent, the owner or operator shall comply with the applicable provisions 
of Sec.Sec. 65.63(e) and 65.67(b) and submit the 
notification specified in Sec. 65.167(a).
    (c) Boiler and process heater monitoring requirements. (1) Where a 
boiler or process heater of less than 44 megawatts

[[Page 110]]

(150 million British thermal units per hour) design heat input capacity 
is used and the regulated vent stream is not introduced as or with the 
primary fuel, a temperature monitoring device in the fire box capable of 
providing a continuous record is required. Any boiler or process heater 
in which all vent streams are introduced with primary fuel or are used 
as the primary fuel is exempt from monitoring. Monitoring results shall 
be recorded as specified in Sec. 65.161. General requirements 
for monitoring and continuous parameter monitoring systems are contained 
in Sec. 65.156.
    (2) Where monitoring is required, the owner or operator shall 
establish a range for monitored parameters that indicates proper 
operation of the boiler or process heater. In order to establish the 
range, the information required in Sec. 65.165(c) shall be 
submitted in the Initial Compliance Status Report or the operating 
permit application or amendment. The range may be based upon a prior 
performance test meeting the specifications of Sec. 
65.157(b)(1) or upon existing ranges or limits established under a 
referencing subpart.


Sec. 65.150  Absorbers used as control devices.

    (a) Absorber equipment and operating requirements. (1) Owners or 
operators using absorbers to meet the 98 weight-percent emission 
reduction or 20 parts per million by volume outlet concentration 
requirements as specified in Sec. 65.63(a)(2), or 40 CFR 
60.562-1(a)(1)(i)(A) for process vents, or Sec. 65.83(a)(1) 
for high-throughput transfer racks, as applicable, shall meet the 
requirements of this section.
    (2) Absorbers used to comply with the provisions of this subpart 
shall be operated at all times when emissions are vented to them.
    (b) Absorber performance test requirements. (1) Unless an initial 
performance test was previously conducted and submitted under the 
referencing subpart and except as specified in Sec. 65.157(b), 
the owner or operator shall conduct an initial performance test of any 
absorber used as a control device to comply with the provisions of this 
subpart according to the procedures in Sec.Sec. 
65.157 and 65.158. Performance test records shall be kept as specified 
in Sec. 65.160(a) and (b), and a performance test report shall 
be submitted as specified in Sec. 65.164. As provided in 
Sec. 65.145(b)(1), a performance test may be used as an 
alternative to the design evaluation for storage vessels and low-
throughput transfer rack controls. As provided in Sec. 
65.146(b), no performance test is required to demonstrate compliance for 
equipment leaks.
    (2) Unless already permitted by the applicable title V permit, if an 
owner or operator elects to use an absorber to replace an existing 
recovery or control device at a later date, the owner or operator shall 
notify the Administrator, either by amendment of the regulated source's 
title V permit or, if title V is not applicable, by submission of the 
notice specified in Sec. 65.167(a) before implementing the 
change. Upon implementing the change, either of the following 
provisions, as applicable, shall be followed:
    (i) Replace final recovery device. If an owner or operator elects to 
replace the final recovery device on a process vent with an absorber 
used as a control device, the owner or operator shall comply with the 
applicable provisions of Sec.Sec. 65.63(e) and 
65.67(b).
    (ii) Replace control device. If an owner or operator elects to 
replace a control device on a Group 1 process vent or a high-throughput 
transfer rack with an absorber used as a control device, the owner or 
operator shall perform a performance test using the methods specified in 
Sec.Sec. 65.157 and 65.158 within 180 days. The 
performance test report shall be submitted to the Administrator within 
60 days of completing the test as provided in Sec. 
65.164(b)(2).
    (c) Absorber monitoring requirements. (1) Where an absorber is used 
as a control device, either an organic monitoring device capable of 
providing a continuous record or a scrubbing liquid temperature 
monitoring device and a specific gravity monitoring device, each capable 
of providing a continuous record, shall be used. Monitoring results 
shall be recorded as specified in Sec. 65.161. General 
requirements for monitoring and continuous parameter monitoring systems 
are contained in Sec. 65.156.
    (2) The owner or operator shall establish a range for monitored 
parameters

[[Page 111]]

that indicates proper operation of the absorber. In order to establish 
the range, the information required in Sec. 65.165(c) shall be 
submitted in the Initial Compliance Status Report or the operating 
permit application or amendment. The range may be based upon a prior 
performance test meeting the specifications of Sec. 
65.157(b)(1) or upon existing ranges or limits established under a 
referencing subpart.


Sec. 65.151  Condensers used as control devices.

    (a) Condenser equipment and operating requirements. (1) Owners or 
operators using condensers to meet the 98 weight-percent emission 
reduction or 20 parts per million by volume outlet concentration 
requirements as specified in Sec. 65.63(a)(2), or 40 CFR 
60.562-1(a)(1)(i)(A) for process vents, or Sec. 65.83(a)(1) 
for high-throughput transfer racks, as applicable, shall meet the 
requirements of this section.
    (2) Condensers used to comply with the provisions of this subpart 
shall be operated at all times when emissions are vented to them.
    (b) Condenser performance test requirements. (1) Unless an initial 
performance test was previously conducted and submitted under the 
referencing subpart and except as specified in Sec. 65.157(b), 
the owner or operator shall conduct an initial performance test of any 
condenser used as a control device to comply with the provisions of this 
subpart according to the procedures in Sec.Sec. 
65.157 and 65.158. Performance test records shall be kept as specified 
in Sec. 65.160(a) and (b), and a performance test report shall 
be submitted as specified in Sec. 65.164. As provided in 
Sec. 65.145(b)(1), a performance test may be used as an 
alternative to the design evaluation for storage vessels and low-
throughput transfer rack controls. As provided in Sec. 
65.146(b), no performance test is required to demonstrate compliance for 
equipment leaks.
    (2) Unless already permitted by the applicable title V permit, if an 
owner or operator elects to use a condenser to replace an existing 
recovery or control device at a later date, the owner or operator shall 
notify the Administrator, either by amendment of the regulated source's 
title V permit or, if title V is not applicable, by submission of the 
notice specified in Sec. 65.167(a) before implementing the 
change. Upon implementing the change, either of the following 
provisions, as applicable, shall be followed:
    (i) Replace final recovery device. If an owner or operator elects to 
replace the final recovery device on a process vent with a condenser 
used as a control device, the owner or operator shall comply with the 
applicable provisions of Sec.Sec. 65.63(e) and 
65.67(b).
    (ii) Replace control device. If an owner or operator elects to 
replace a control device on a Group 1 process vent or a high-throughput 
transfer rack with a condenser used as a control device, the owner or 
operator shall perform a performance test using the methods specified in 
Sec.Sec. 65.157 and 65.158 within 180 days. The 
performance test report shall be submitted to the Administrator within 
60 days of completing the test as provided in Sec. 
65.164(b)(2).
    (c) Condenser monitoring requirements. (1) Where a condenser is used 
as a control device, an organic monitoring device capable of providing a 
continuous record or a condenser exit (product side) temperature 
monitoring device capable of providing a continuous record shall be 
used. Monitoring results shall be recorded as specified in 
Sec. 65.161. General requirements for monitoring and 
continuous parameter monitoring systems are contained in Sec. 
65.156.
    (2) The owner or operator shall establish a range for monitored 
parameters that indicates proper operation of the condenser. In order to 
establish the range, the information required in Sec. 
65.165(c) shall be submitted in the Initial Compliance Status Report or 
the operating permit application or amendment. The range may be based 
upon a prior performance test meeting the specifications in 
Sec. 65.157(b)(1) or upon existing ranges or limits 
established under a referencing subpart.


Sec. 65.152  Carbon adsorbers used as control devices.

    (a) Carbon adsorber equipment and operating requirements. (1) Owners 
or operators using carbon adsorbers to meet the 98 weight-percent 
emission reduction or 20 parts per million by volume outlet 
concentration requirements as

[[Page 112]]

specified in Sec. 65.63(a)(2), or 40 CFR 60.562-1(a)(1)(i)(A) 
for process vents, or Sec. 65.83(a)(1) for high-throughput 
transfer racks, as applicable, shall meet the requirements of this 
section.
    (2) Carbon adsorbers used to comply with the provisions of this 
subpart shall be operated at all times when emissions are vented to 
them.
    (b) Carbon adsorber performance test requirements. (1) Unless an 
initial performance test was previously conducted and submitted under 
the referencing subpart and except as specified in Sec. 
65.157(b), the owner or operator shall conduct an initial performance 
test of any carbon absorber used as a control device to comply with the 
provisions of this subpart according to the procedures in 
Sec.Sec. 65.157 and 65.158. Performance test records 
shall be kept as specified in Sec. 65.160(a) and (b), and a 
performance test report shall be submitted as specified in 
Sec. 65.164. As provided in Sec. 65.145(b)(1), a 
performance test may be used as an alternative to the design evaluation 
for storage vessels and low-throughput transfer rack controls. As 
provided in Sec. 65.146(b), no performance test is required to 
demonstrate compliance for equipment leaks.
    (2) Unless already permitted by the applicable title V permit, if an 
owner or operator elects to use a carbon adsorber to replace an existing 
recovery or control device at a later date, the owner or operator shall 
notify the Administrator either by amendment of the regulated source's 
title V permit or, if title V is not applicable, by submission of the 
notice specified in Sec. 65.167(a) before implementing the 
change. Upon implementing the change, either of the following 
provisions, as applicable, shall be followed:
    (i) Replace final recovery device. If an owner or operator elects to 
replace the final recovery device on a process vent with a carbon 
adsorber used as a control device, the owner or operator shall comply 
with the applicable provisions of Sec.Sec. 65.63(e) 
and 65.67(b).
    (ii) Replace control device. If an owner or operator elects to 
replace a control device on a Group 1 process vent or high-throughput 
transfer rack with a carbon adsorber used as a control device, the owner 
or operator shall perform a performance test using the methods specified 
in Sec.Sec. 65.157 and 65.158 within 180 days. The 
performance test report shall be submitted to the Administrator within 
60 days of completing the test as provided in Sec. 
65.164(b)(2).
    (c) Carbon adsorber monitoring requirements. (1) Where a carbon 
adsorber is used as a control device, an organic monitoring device 
capable of providing a continuous record, or an integrating regeneration 
stream flow monitoring device having an accuracy of �10 
percent or better capable of recording the total regeneration stream 
mass or volumetric flow for each regeneration cycle, and a carbon-bed 
temperature monitoring device capable of recording the carbon bed 
temperature after each regeneration and within 15 minutes of completing 
any cooling cycle, shall be used. Monitoring results shall be recorded 
as specified in Sec. 65.161. General requirements for 
monitoring and continuous parameter monitoring systems are contained in 
Sec. 65.156.
    (2) The owner or operator shall establish a range for monitored 
parameters that indicates proper operation of the carbon adsorber. Where 
the regeneration stream flow and carbon-bed temperature are monitored, 
the range shall be in terms of the total regeneration stream flow per 
regeneration cycle and the temperature of the carbon-bed determined 
within 15 minutes of the completion of the regeneration cooling cycle. 
In order to establish the range, the information required in 
Sec. 65.165(c) shall be submitted in the Initial Compliance 
Status Report or the operating permit application or amendment. The 
range may be based upon a prior performance test meeting the 
specifications in Sec. 65.157(b)(1) or upon existing ranges or 
limits established under a referencing subpart.


Sec. 65.153  Absorbers, condensers, carbon adsorbers, and other 
          recovery devices used as final recovery devices.

    (a) Final recovery device equipment and operating requirements. (1) 
Owners or operators using a recovery device to meet the requirement to 
operate and maintain a TRE above 1.0 as specified in Sec. 
65.63(a)(3) for process vents shall meet the requirements of this 
section.

[[Page 113]]

    (2) Recovery devices used to comply with the provisions of this 
subpart shall be operated at all times when emissions are vented to 
them.
    (b) Recovery device performance test requirements. (1) There are no 
performance test requirements for recovery devices. Records of TRE index 
value determination shall be generated as specified in Sec. 
65.160(c).
    (2) Replace a final recovery device or control device. Unless 
already permitted by the applicable title V permit, if an owner or 
operator elects to use a recovery device to replace an existing final 
recovery or control device at a later date, the owner or operator shall 
notify the Administrator, either by amendment of the regulated source's 
title V permit or, if title V is not applicable, by submission of the 
notice specified in Sec. 65.167(a) before implementing the 
change. Upon implementing the change, the owner or operator shall comply 
with the applicable provisions of Sec.Sec. 65.63(e) 
and 65.67(b).
    (c) Recovery device monitoring requirements. (1) Where an absorber 
is the final recovery device in the recovery system and the TRE index 
value is between 1.0 and 4.0, either an organic monitoring device 
capable of providing a continuous record, or a scrubbing liquid 
temperature monitoring device and a specific gravity monitoring device, 
each capable of providing a continuous record, shall be used. Monitoring 
results shall be recorded as specified in Sec. 65.161. General 
requirements for monitoring and continuous parameter monitoring systems 
are contained in Sec. 65.156.
    (2) Where a condenser is the final recovery device in the recovery 
system and the TRE index value is between 1.0 and 4.0, an organic 
monitoring device capable of providing a continuous record, or a 
condenser exit (product side) temperature monitoring device capable of 
providing a continuous record, shall be used. Monitoring results shall 
be recorded as specified in Sec. 65.161. General requirements 
for monitoring and continuous parameter monitoring systems are contained 
in Sec. 65.156.
    (3) Where a carbon adsorber is the final recovery device in the 
recovery system and the TRE index value is between 1.0 and 4.0, an 
organic monitoring device capable of providing a continuous record, or 
an integrating regeneration stream flow monitoring device having an 
accuracy of �10 percent or better capable of recording the 
total regeneration stream mass or volumetric flow for each regeneration 
cycle, and a carbon-bed temperature monitoring device capable of 
recording the carbon-bed temperature after each regeneration and within 
15 minutes of completing any cooling cycle, shall be used. Monitoring 
results shall be recorded as specified in Sec. 65.161. General 
requirements for monitoring and continuous parameter monitoring systems 
are contained in Sec. 65.156.
    (4) Unless previously approved by the Administrator under an 
applicable standard prior to the implementation date of this part, as 
specified in Sec. 65.1(f), if an owner or operator uses a 
recovery device other than those listed in this subpart, the owner or 
operator shall submit a description of planned monitoring, reporting and 
recordkeeping procedures as required under Sec. 65.162(e). The 
Administrator will approve or deny the proposed monitoring, reporting 
and recordkeeping requirements as part of the review of the submission 
or permit application or by other appropriate means.
    (5) The owner or operator shall establish a range for monitored 
parameters that indicates proper operation of the recovery device. In 
order to establish the range, the information required in Sec. 
65.165(c) shall be submitted in the Initial Compliance Status Report or 
the operating permit application or amendment. The range may be based 
upon a prior performance test meeting the specifications in 
Sec. 65.157(b)(1) or upon existing ranges or limits 
established under a referencing subpart. Where the regeneration stream 
flow and carbon-bed temperature are monitored, the range shall be in 
terms of the total regeneration stream flow per regeneration cycle, and 
the temperature of the carbon-bed determined within 15 minutes of the 
completion of the regeneration cooling cycle.


Sec. 65.154  Halogen scrubbers and other halogen reduction devices.

    (a) Halogen scrubber and other halogen reduction device equipment 
and operating requirements. (1) An owner or operator

[[Page 114]]

of halogen scrubbers and other halogen reduction devices subject to this 
subpart shall reduce the overall emissions of hydrogen halides and 
halogens by 99 percent, or reduce the outlet mass of total hydrogen 
halides and halogens to less than 0.45 kilograms per hour (0.99 pound 
per hour) as specified in Sec. 65.63(b) for process vents, or 
Sec. 65.83(b) for transfer racks, as applicable, and shall 
meet the requirements of this section.
    (2) Halogen scrubbers and other halogen reduction devices used to 
comply with the provisions of this subpart shall be operated at all 
times when emissions are vented to them.
    (b) Halogen scrubber and other halogen reduction device performance 
test requirements. Unless an initial performance test was previously 
conducted and submitted under the referencing subpart, an owner or 
operator of a combustion device followed by a halogen scrubber or other 
halogen reduction device to control halogenated vent streams in 
accordance with Sec. 65.63(b)(1) for process vents, or 
Sec. 65.83(b)(1) for transfer racks shall conduct an initial 
performance test to determine compliance with the control efficiency or 
emission limits for hydrogen halides and halogens according to the 
procedures in Sec.Sec. 65.157 and 65.158. 
Performance test records shall be kept as specified in Sec. 
65.160(a) and (b), and a performance test report shall be submitted as 
specified in Sec. 65.164.
    (c) Halogen scrubber and other halogen reduction device monitoring 
requirements. (1) Where a halogen scrubber is used, the monitoring 
equipment specified in paragraphs (c)(1)(i) and (ii) of this section is 
required for the scrubber. Monitoring results shall be recorded as 
specified in Sec. 65.161. General requirements for monitoring 
and continuous parameter monitoring systems are contained in 
Sec. 65.156.
    (i) A pH monitoring device capable of providing a continuous record 
shall be installed to monitor the pH of the scrubber effluent.
    (ii) A flow meter capable of providing a continuous record shall be 
located at the scrubber influent for liquid flow. Gas stream flow shall 
be determined using one of the following procedures:
    (A) The owner or operator may determine gas stream flow using the 
design blower capacity, with appropriate adjustments for pressure drop.
    (B) If the scrubber is subject to regulations in 40 CFR parts 264 
through 266 that have required a determination of the liquid to gas (L/
G) ratio prior to the applicable compliance date for the chemical 
manufacturing process unit of which it is part, as specified in 40 CFR 
63.100(k) (if the referencing subpart is 40 CFR part 63, subpart F), or 
prior to the implementation date as specified in Sec. 65.1(f) 
(for all other referencing subparts), the owner or operator may 
determine gas stream flow by the method that had been utilized to comply 
with those regulations. A determination that was conducted prior to that 
compliance date may be utilized to comply with this subpart if it is 
still representative.
    (C) The owner or operator may prepare and implement a gas stream 
flow determination plan that documents an appropriate method that will 
be used to determine the gas stream flow. The plan shall require 
determination of gas stream flow by a method that will at least provide 
a value for either a representative or the highest gas stream flow 
anticipated in the scrubber during representative operating conditions 
other than startups, shutdowns, or malfunctions. The plan shall include 
a description of the methodology to be followed and an explanation of 
how the selected methodology will reliably determine the gas stream flow 
and a description of the records that will be maintained to document the 
determination of gas stream flow. The owner or operator shall maintain 
the plan as specified in Sec. 65.5.
    (2) Where a halogen reduction device other than a scrubber is used, 
the procedures in Sec. 65.162(e) shall be followed to 
establish monitoring parameters.
    (3) The owner or operator shall establish a range for monitored 
parameters that indicates proper operation of the scrubber or other 
halogen reduction device. In order to establish the range, the 
information required in Sec. 65.165(c) shall be submitted in 
the Initial Compliance Status Report or the operating permit application 
or amendment. The range may be based upon a prior performance test 
meeting the specifications in Sec. 65.157(b)(1), or upon 
existing

[[Page 115]]

ranges or limits established under a referencing subpart.


Sec. 65.155  Other control devices.

    (a) Other control device equipment and operating requirements. (1) 
Owners or operators using a control device other than one listed in 
Sec.Sec. 65.147 through 65.152 to meet the 98 
weight-percent emission reduction or 20 parts per million by volume 
outlet concentration requirements specified in Sec. 
65.63(a)(2), or 40 CFR 60.562-1(a)(1)(i)(A) for process vents, or 
Sec. 65.83(a)(1) for high-throughput transfer racks, as 
applicable, shall meet the requirements of this section.
    (2) Other control devices used to comply with the provisions of this 
subpart shall be operated at all times when emissions are vented to 
them.
    (b) Other control device performance test requirements. (1) Unless 
an initial performance test was previously conducted and submitted under 
the referencing subpart, an owner or operator of a control device other 
than those specified in Sec.Sec. 65.147 through 
65.152, to comply with Sec. 65.63(a)(2) for process vents, or 
Sec. 65.83(a)(1) for high-throughput transfer racks, shall 
perform an initial performance test according to the procedures in 
Sec.Sec. 65.157 and 65.158. Performance test records 
shall be kept as specified in Sec. 65.160(a) and (b), and a 
performance test report shall be submitted as specified in 
Sec. 65.164.
    (2) Unless already permitted by the applicable title V permit, if an 
owner or operator elects to use another control device to replace an 
existing control device at a later date, the owner or operator shall 
notify the Administrator, either by amendment of the regulated source's 
title V permit or, if title V is not applicable, by submission of the 
notice specified in Sec. 65.167(a) before implementing the 
change. Upon implementing the change, another control device performance 
test shall be performed using the methods specified in 
Sec.Sec. 65.157 and 65.158 within 180 days if 
required by paragraph (b)(1) of this section. The performance test 
report shall be submitted to the Administrator within 60 days of 
completing the determination as provided in Sec. 65.164(b)(2). 
If an owner or operator elects to use a control device to replace an 
existing recovery device that is used on a Group 2A process vent, the 
owner or operator shall comply with the applicable provisions of 
Sec.Sec. 65.63(e) and 65.67(b) and submit the 
notification specified in Sec. 65.167(a).
    (c) Other control device monitoring requirements. (1) Unless 
previously submitted and approved under the referencing subpart, if an 
owner or operator uses a control device other than those listed in this 
subpart, the owner or operator shall submit a description of planned 
monitoring, reporting, and recordkeeping procedures as required under 
Sec. 65.162(e). The Administrator will approve, deny, or 
modify based on the reasonableness of the proposed monitoring, 
reporting, and recordkeeping requirements as part of the review of the 
submission or permit application or by other appropriate means.
    (2) The owner or operator shall establish a range for monitored 
parameters that indicates proper operation of the control device. To 
establish the range, the information required in Sec. 
65.165(c) shall be submitted in the Initial Compliance Status Report or 
the operating permit application or amendment. The range may be based 
upon a prior performance test meeting the specifications in 
Sec. 65.157(b)(1) or upon existing ranges or limits 
established under a referencing subpart.


Sec. 65.156  General monitoring requirements for control and recovery 
          devices.

    (a) General monitoring requirement applicability. (1) This section 
applies to the owner or operator of a regulated source required to 
monitor under this subpart.
    (2) Flares subject to Sec. 65.147(c) are not subject to 
the requirements of this section.
    (3) Flow indicators are not subject to the requirements of this 
section.
    (b) Conduct of monitoring. (1) Monitoring shall be conducted as set 
forth in this section and in the relevant sections of this subpart 
unless either of the following provisions applies:
    (i) The Administrator specifies or approves the use of minor or 
intermediate changes in the specified monitoring requirements or 
procedures as provided in Sec. 65.7(b), (c), and (d); or

[[Page 116]]

    (ii) The Administrator specifies or approves the use of major 
changes in the specified monitoring requirements or procedures as 
provided in Sec. 65.7(b), (c), and (d).
    (2) When one CPMS is used as a backup to another CPMS, the owner or 
operator shall report the results from the CPMS used to meet the 
monitoring requirements of this subpart. If both such CPMS are used 
during a particular reporting period to meet the monitoring requirements 
of this part, then the owner or operator shall report the results from 
each CPMS for the relevant compliance period.
    (c) Operation and maintenance of continuous parameter monitoring 
systems. (1) All monitoring equipment shall be installed, calibrated, 
maintained, and operated according to manufacturers specifications or 
other written procedures that provide adequate assurance that the 
equipment would reasonably be expected to monitor accurately.
    (2) The owner or operator of a regulated source shall maintain and 
operate each CPMS as specified in this section or in a relevant subpart 
and in a manner consistent with good air pollution control practices.
    (i) The owner or operator of a regulated source shall ensure the 
immediate repair or replacement of CPMS parts to correct 
``routine'' or otherwise predictable CPMS 
malfunctions. The necessary parts for routine repairs of the affected 
equipment shall be readily available.
    (ii) Except for Group 2A process vents, if the startup, shutdown, 
and malfunction plan is followed during a CPMS startup, shutdown, or 
malfunction and the CPMS is repaired immediately, this action shall be 
reported in the semiannual startup, shutdown, and malfunction report 
required under Sec. 65.6(c).
    (iii) The Administrator's determination of whether acceptable 
operation and maintenance procedures are being used for the CPMS will be 
based on information that may include, but is not limited to, review of 
operation and maintenance procedures, operation and maintenance records, 
manufacturer's recommendations and specifications, and inspection of the 
CPMS.
    (3) All CPMS shall be installed and operational, and the data 
verified as specified in this subpart either prior to or in conjunction 
with conducting performance tests. Verification of operational status 
shall, at a minimum, include completion of the manufacturer's written 
specifications or recommendations for installation, operation, and 
calibration of the system or other written procedures that provide 
adequate assurance that the equipment would reasonably be expected to 
monitor accurately.
    (4) All CPMS shall be installed such that representative 
measurements of parameters from the regulated source are obtained.
    (5) In accordance with Sec. 65.3(a)(3), except for system 
breakdowns, repairs, maintenance periods, instrument adjustments or 
checks to maintain precision and accuracy, calibration checks, and zero 
and span adjustments, all CPMS shall be in continuous operation when 
emissions are being routed to the monitored device.
    (d) Except for Group 2A process vents, the parameter monitoring data 
shall be used to determine compliance with the required operating 
conditions for the monitored control devices. For each excursion, except 
for excused excursions and the excursions described in paragraph (d)(3) 
of this section, the owner or operator shall be deemed to have failed to 
have applied the control in a manner that achieves the required 
operating conditions.
    (1) An excursion means any of the three cases listed in paragraphs 
(d)(1)(i) through (iii) of this section. For a control device where 
multiple parameters are monitored, if one or more of the parameters 
meets the excursion criteria in paragraph (d)(1)(i), (ii), or (iii) of 
this section, this is considered a single excursion for the day for the 
control device.
    (i) When the daily average value of one or more monitored parameters 
is outside the permitted range.
    (ii) When the period of control or recovery device operation is 4 
hours or greater in an operating day, and monitoring data are 
insufficient to constitute a valid hour of data for at least 75 percent 
of the operating hours.

[[Page 117]]

    (iii) When the period of control or recovery device operation is 
less than 4 hours in an operating day, and more than 1 hour during the 
period of operation does not constitute a valid hour of data due to 
insufficient monitoring data.
    (iv) Monitoring data are insufficient to constitute a valid hour of 
data as used in paragraphs (d)(1)(ii) and (iii) of this section, if 
measured values are unavailable for any of the 15-minute periods within 
the hour. For data compression systems approved under Sec. 
65.162(d)(4), monitoring data are insufficient to calculate a valid hour 
of data if there are less than four data values recorded during the 
hour.
    (2) One excused excursion for each control device or recovery device 
for each semiannual period is allowed.
    (3) The following excursions are not violations and do not count as 
excused excursions:
    (i) Excursions which occur during periods of startup, shutdown, and 
malfunction, when the source is being operated during such periods in 
accordance with its startup, shutdown, and malfunction plan as required 
by Sec. 65.6.
    (ii) Excursions which occur due to failure to collect a valid hour 
of data during periods of startup, shutdown, and malfunction, when the 
source is being operated during such periods in accordance with its 
startup, shutdown, and malfunction plan as required by Sec. 
65.6.
    (iii) Excursions which occur during periods of nonoperation of the 
regulated source or portion thereof, resulting in cessation of the 
emissions to which monitoring applies.
    (4) Nothing in paragraph (d) of this section shall be construed to 
allow or excuse a monitoring parameter excursion caused by any activity 
that violates other applicable provisions of this part.
    (5) Paragraph (d) of this section applies to emission points and 
control devices for which continuous monitoring is required by this 
subpart, and to alternatives to continuous monitoring systems such as 
provided in Sec. 65.162(d)(3) and (d)(4). Paragraph (d)(3) of 
this section also applies to emission points and control devices which 
are not subject to continuous monitoring requirements, such as 
inspections of the closed vent system.
    (e) Alternative monitoring parameter. An owner or operator may 
request approval to monitor control, recovery, halogen scrubber, or 
halogen reduction device operating parameters other than those specified 
in this subpart by following the procedures specified in Sec. 
65.162(e).


Sec. 65.157  Performance test and flare compliance determination 
          requirements.

    (a) Performance tests and flare compliance determinations. Where 
Sec.Sec. 65.145 through 65.155 require, or the owner 
or operator elects to conduct, a performance test of a nonflare control 
device or a halogen reduction device, or a compliance determination for 
a flare, the requirements of paragraphs (b) through (d) of this section 
apply.
    (b) Prior test results and waivers. Initial performance tests and 
initial flare compliance determinations are required only as specified 
in this subpart.
    (1) Unless requested by the Administrator, an owner or operator is 
not required to conduct a performance test or flare compliance 
determination under this subpart if a prior performance test or 
compliance determination was conducted using the same methods specified 
in Sec. 65.158, and either no process changes have been made 
since the test or the owner or operator can demonstrate to the 
Administrator's satisfaction that the results of the performance test, 
with or without adjustments, reliably demonstrate compliance despite 
process changes.
    (2) Individual performance tests and flare compliance determinations 
may be waived upon written application to the Administrator per 
Sec. 65.164(b)(3) if, in the Administrator's judgment, the 
source is meeting the relevant standard(s) on a continuous basis, or the 
source is being operated under an extension of compliance under 40 CFR 
part 63, or a waiver of compliance under 40 CFR part 61, or the owner or 
operator has requested an extension of compliance under 40 CFR part 63, 
or a waiver of compliance under 40 CFR part 61, and the Administrator is 
still considering that request.

[[Page 118]]

    (3) Approval of any waiver granted under this section shall not 
abrogate the Administrator's authority under the Act or in any way 
prohibit the Administrator from later canceling the waiver. The 
cancellation will be made only after notification is given to the owner 
or operator of the source.
    (c) Performance tests and flare compliance determinations schedule. 
(1) Unless a waiver of performance testing or flare compliance 
determination is obtained under this section or the conditions of 
another subpart of this part, the owner or operator shall perform such 
tests specified in the following:
    (i) Within 180 days after the effective date of a relevant standard 
for a new source that has an initial startup date before the effective 
date of that standard; or
    (ii) Within 180 days after initial startup for a new source that has 
an initial startup date after the effective date of a relevant standard; 
or
    (iii) Within 180 days after the compliance date specified in a 
referencing subpart for an existing source or within 180 days after 
startup of an existing source if the source begins operation after the 
effective date of the relevant 40 CFR part 63 emission standard; or
    (iv) Within 180 days after the compliance date for an existing 
source subject to an emission standard established pursuant to section 
112(f) of the Act; or
    (v) Within 180 days after the termination date of the source's 
extension of compliance or a waiver of compliance for an existing source 
that obtains an extension of compliance under 40 CFR 63.6(i) or a waiver 
of compliance under 40 CFR 61.11; or
    (vi) Within 180 days after the compliance date for a new source, 
subject to an emission standard established pursuant to section 112(f) 
of the Act, for which construction or reconstruction is commenced after 
the proposal date of a relevant standard established pursuant to section 
112(d) of the Act but before the proposal date of the relevant standard 
established pursuant to section 112(f) of the Act (see 40 CFR 
63.6(b)(4)); or
    (vii) When a promulgated emission standard under 40 CFR part 63 is 
more stringent than the standard that was proposed (see 40 CFR 
63.6(b)(3)), the owner or operator of a new or reconstructed source 
subject to that standard for which construction or reconstruction is 
commenced between the proposal and promulgation dates of the standard 
shall comply with performance testing requirements within 180 days after 
the standard's effective date or within 180 days after startup of the 
source, whichever is later. If the promulgated standard is more 
stringent than the proposed standard, the owner or operator may choose 
to demonstrate compliance initially with either the proposed or the 
promulgated standard. If the owner or operator chooses to comply with 
the proposed standard initially, the owner or operator shall conduct a 
second performance test within 3 years and 180 days after the effective 
date of the standard, or after startup of the source, whichever is 
later, to demonstrate compliance with the promulgated standard.
    (2) The Administrator may require an owner or operator to conduct 
performance tests and compliance determinations at the regulated source 
at any time when the action is authorized by section 114 of the Act.
    (d) Performance testing facilities. If required to do performance 
testing, the owner or operator of each new regulated source and, at the 
request of the Administrator, the owner or operator of each existing 
regulated source, shall provide performance testing facilities as 
specified in the following:
    (1) Sampling ports adequate for test methods applicable to such 
source. This includes, as applicable, the following requirements:
    (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; and
    (5) Any other facilities that the Administrator deems necessary for 
safe and adequate testing of a source.

[[Page 119]]


Sec. 65.158  Performance test procedures for control devices.

    (a) General procedures. Where Sec.Sec. 65.145 
through 65.155 require, or the owner or operator elects to conduct, a 
performance test of a control device or a halogen reduction device, an 
owner or operator shall comply with the requirements of (a)(1) through 
(3) of this section, as applicable.
    (1) Performance tests shall be conducted at maximum representative 
operating conditions for the process unless the Administrator specifies 
or approves alternate operating conditions. During the performance test, 
an owner or operator may operate the control or halogen reduction device 
at maximum or minimum representative operating conditions for monitored 
control or halogen reduction device parameters, whichever results in 
lower emission reduction. Operations during periods of startup, 
shutdown, and malfunction shall not constitute representative conditions 
for the purpose of a performance test.
    (2) Performance tests shall be conducted and data shall be reduced 
in accordance with the test methods and procedures set forth in this 
subpart, in each relevant standard, and, if required, in applicable 
appendices of 40 CFR parts 51, 60, 61, and 63 unless the Administrator 
allows revisions to the test methods as specified in one or more of the 
following five paragraphs:
    (i) The Administrator specifies or approves, in specific cases, the 
use of a test method with minor or intermediate changes in methodology; 
or
    (ii) The Administrator approves the use of a major change to a test 
method, the results of which the Administrator has determined to be 
adequate for indicating whether a specific regulated source is in 
compliance; or
    (iii) Intermediate and major changes to a test method shall be 
validated using the applicable procedures of Method 301 of appendix A of 
40 CFR part 63; or
    (iv) The Administrator waives the requirement for the performance 
test as provided in Sec. 65.157(b)(2) because the owner or 
operator of a regulated source has demonstrated by other means to the 
Administrator's satisfaction that the regulated source is in compliance 
with the relevant standard; or
    (v) The Administrator approves the use of an equivalent method.
    (3) Each performance test shall consist of three separate runs using 
the applicable test method. Except as provided in paragraphs (a)(3)(i) 
and (ii) of this section, each run shall be conducted for at least 1 
hour and under the conditions specified in this section. For the purpose 
of determining compliance with an applicable standard, the arithmetic 
mean 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.
    (i) For control devices that are used to control emissions from 
high-throughput transfer racks, and that are capable of continuous vapor 
processing but do not handle continuous emissions or emissions from 
high-throughput transfer racks that load simultaneously from multiple 
loading arms, each run shall represent at least one complete tank truck 
or tank car loading period during which regulated materials are loaded, 
and samples shall be collected using integrated sampling or grab samples 
taken at least four times per hour at approximately equal intervals of 
time, such as 15-minute intervals.
    (ii) For intermittent vapor processing systems used for controlling 
high-throughput transfer rack emissions that do not handle continuous 
emissions or multiple loading arms of a high-throughput transfer rack 
that load simultaneously, each run shall represent at least one complete 
control device cycle, and samples shall be collected using integrated 
sampling or grab samples taken at least four times per hour at 
approximately equal intervals of time, such as 15-minute intervals.
    (b) Test methods. Where Sec.Sec. 65.145 through 
65.155 require, or the owner or

[[Page 120]]

operator elects to conduct, a performance test of a control device or a 
halogen reduction device, an owner or operator shall conduct that 
performance test using the procedures in paragraphs (b)(1) through (4) 
of this section, as applicable. The regulated material concentration and 
percent reduction may be measured as either total regulated material or 
as TOC (minus methane and ethane) according to the procedures specified.
    (1) Method 1 or 1A of appendix A of 40 CFR part 60 as appropriate, 
shall be used for selection of the sampling sites.
    (i) For determination of compliance with a percent reduction 
requirement of total regulated material or TOC, sampling sites shall be 
located at the inlet of the control device as specified in the following 
and at the outlet of the control device:
    (A) For process vents, the control device inlet sampling site shall 
be located after the final product recovery device.
    (B) If a vent stream is introduced with the combustion air or as a 
secondary fuel into a boiler or process heater with a design capacity 
less than 44 megawatts (150 million British thermal units per hour), 
selection of the location of the inlet sampling sites shall ensure the 
measurement of total regulated material or TOC (minus methane and 
ethane) concentrations, as applicable, in all vent streams and primary 
and secondary fuels introduced into the boiler or process heater.
    (ii) For determination of compliance with the 20 parts per million 
by volume total regulated material or TOC limit in Sec. 
65.63(a)(2), Sec. 65.83(a)(1), and 40 CFR 60.562-
1(a)(1)(i)(A), the sampling site shall be located at the outlet of the 
control device.
    (2) The gas volumetric flow rate shall be determined using Method 2, 
2A, 2C, or 2D of appendix A of 40 CFR part 60, as appropriate.
    (3) To determine compliance with the 20 parts per million by volume 
total regulated material or TOC (minus methane and ethane) limit, the 
owner or operator shall use Method 18 of appendix A of 40 CFR part 60 to 
measure either TOC minus methane and ethane or total regulated material, 
as applicable. Alternatively, any other method or data that have been 
validated according to the applicable procedures in Method 301 of 
appendix A of 40 CFR part 63 may be used. Method 25A may be used for 
transfer racks as detailed in paragraph (b)(3)(iv) of this section. The 
procedures specified in paragraphs (b)(3)(i) through (iv) of this 
section shall be used to calculate parts per million by volume 
concentration, corrected to 3 percent oxygen.
    (i) Except as provided in paragraphs (a)(3)(i) and (ii) of this 
section, the minimum sampling time for each run shall be 1 hour in which 
either an integrated sample or a minimum of four grab samples shall be 
taken. If grab sampling is used, then the samples shall be taken at 
approximately equal intervals in time, such as 15 minute intervals 
during the run.
    (ii) The concentration of either TOC (minus methane or ethane) or 
total regulated material shall be calculated according to the following 
two paragraphs, as appropriate:
    (A) The TOC concentration (CTOC) is the sum of the 
concentrations of the individual components and shall be computed for 
each run using Equation 158-1 of this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.012

Where:

CREG, or CTOC= Concentration of total regulated 
material or concentration of TOC (minus methane and ethane), dry basis, 
parts per million by volume.
x = Number of samples in the sample run.
n = Number of components in the sample.

[[Page 121]]

Cji = Concentration of sample components j of sample i, dry 
basis, parts per million by volume.

    (B) The total regulated material (CREG) shall be computed 
according to equation 158-1 of this section except that only the 
regulated species shall be summed. Where the regulated material is 
organic HAP's, the list of organic HAP's provided in table 2 of 40 CFR 
part 63, subpart F, shall be used.
    (iii) The concentration of TOC or total regulated material, as 
applicable, shall be corrected to 3 percent oxygen if a combustion 
device is the control device.
    (A) The emission rate correction factor (or excess air) integrated 
sampling and analysis procedures of Method 3B of appendix A of 40 CFR 
part 60 shall be used to determine the oxygen concentration. The 
sampling site shall be the same as that of the regulated material or 
organic compound samples, and the samples shall be taken during the same 
time that the regulated material or organic compound samples are taken.
    (B) The concentration corrected to 3 percent oxygen (Cc) 
shall be computed using Equation 158-2 of this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.013

Where:

Cc = Concentration of TOC or regulated material corrected to 
3 percent oxygen, dry basis, parts per million by volume.
Cm = Concentration of TOC (minus methane and ethane) or 
regulated material, dry basis, parts per million by volume.
%O2d = Concentration of oxygen, dry basis, percentage by 
volume.

    (iv) Method 25A of appendix A of 40 CFR part 60 may be used for the 
purpose of determining compliance with the 20 parts per million by 
volume limit specified in Sec. 65.83(a)(1) for transfer racks. 
If Method 25A of appendix A of 40 CFR part 60 is used, the following 
procedures shall be used to calculate the concentration of organic 
compounds (CTOC):
    (A) The principal organic HAP in the vent stream shall be used as 
the calibration gas.
    (B) The span value for Method 25A of appendix A of 40 CFR part 60 
shall be between 1.5 and 2.5 times the concentration being measured.
    (C) Use of Method 25A of appendix A of 40 CFR part 60 is acceptable 
if the response from the high-level calibration gas is at least 20 times 
the standard deviation of the response from the zero calibration gas 
when the instrument is zeroed on the most sensitive scale.
    (D) The concentration of TOC shall be corrected to 3 percent oxygen 
using the procedures and equation in paragraph (b)(3)(iii) of this 
section.
    (4) To determine compliance with a percent reduction requirement, 
the owner or operator shall use Method 18 of appendix A of 40 CFR part 
60; alternatively, any other method or data that have been validated 
according to the applicable procedures in Method 301 of appendix A of 40 
CFR part 63 may be used. Method 25A of appendix A of 40 CFR part 60 may 
be used for transfer racks as detailed in paragraph (b)(4)(v) of this 
section. Procedures specified in paragraphs (b)(4)(i) through (v) of 
this section shall be used to calculate percent reduction efficiency.
    (i) Except as provided in paragraphs (a)(3)(i) and (ii) of this 
section, the minimum sampling time for each run shall be 1 hour in which 
either an integrated sample or a minimum of four grab samples shall be 
taken. If grab sampling is used, then the samples shall be taken at 
approximately equal intervals in time, such as 15-minute intervals 
during the run.
    (ii) The mass rate of either TOC (minus methane and ethane) or total 
regulated material (Ei, Eo) shall be computed as 
applicable.
    (A) Equations 158-3 and 158-4 of this section shall be used:
    [GRAPHIC] [TIFF OMITTED] TR14DE00.014
    
    [GRAPHIC] [TIFF OMITTED] TR14DE00.015
    
Where:

Ei, Eo = Emission rate of TOC (minus methane and 
ethane) (ETOC) or emission rate of total organic HAP 
(EHAP) in the sample at

[[Page 122]]

the inlet and outlet of the control device, respectively, dry basis, 
kilogram per hour.
K2 = Constant, 2.494x10-6(parts per 
million)-1 (gram-mole per standard cubic meter) (kilogram per 
gram) (minute per hour), where standard temperature (gram-mole per 
standard cubic meter) is 20 C.
n = Number of components in the sample.
Cij, Coj = Concentration on a dry basis of organic 
compound j in parts per million by volume of the gas stream at the inlet 
and outlet of the control device, respectively. If the TOC emission rate 
is being calculated, Cij and Coj include all 
organic compounds measured minus methane and ethane; if the total 
organic HAP emissions rate is being calculated, only organic HAP are 
included.
Mij, Moj = Molecular weight of organic compound j, 
gram per gram-mole, of the gas stream at the inlet and outlet of the 
control device, respectively.
Qi, Qo = Process vent flow rate, dry standard 
cubic meter per minute, at a temperature of 20 C, at the 
inlet and outlet of the control device, respectively.

    (B) Where the mass rate of TOC is being calculated, all organic 
compounds (minus methane and ethane) measured by Method 18 of appendix A 
of 40 CFR part 60 are summed using equations 158-3 and 158-4 of this 
section.
    (C) Where the mass rate of total regulated material is being 
calculated, only the species comprising the regulated material shall be 
summed using equations 158-3 and 158-4 of this section. Where the 
regulated material is organic HAP's, the list of organic HAP's provided 
in table 2 of 40 CFR part 63, subpart F, shall be used.
    (iii) The percent reduction in TOC (minus methane and ethane) or 
total regulated material shall be calculated using Equation 158-5 of 
this section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.016

Where:

R = Control efficiency of control device, percent.
Ei = Mass rate of TOC (minus methane and ethane) or total 
regulated material at the inlet to the control device as calculated 
under paragraph (b)(4)(ii) of this section, kilograms TOC per hour or 
kilograms regulated material per hour.
Eo = Mass rate of TOC (minus methane and ethane) or total 
regulated material at the outlet of the control device, as calculated 
under paragraph (b)(4)(ii) of this section, kilograms TOC per hour or 
kilograms total regulated material per hour.

    (iv) If the vent stream entering a boiler or process heater with a 
design capacity less than 44 megawatts (150 million British thermal 
units) is introduced with the combustion air or as a secondary fuel, the 
weight-percent reduction of total regulated material or TOC (minus 
methane and ethane) across the device shall be determined by comparing 
the TOC (minus methane and ethane) or total regulated material in all 
combusted vent streams and primary and secondary fuels with the TOC 
(minus methane and ethane) or total regulated material exiting the 
combustion device, respectively.
    (v) Method 25A of appendix A of 40 CFR part 60 may also be used for 
the purpose of determining compliance with the percent reduction 
requirement for transfer racks.
    (A) If Method 25A of appendix A of 40 CFR part 60 is used to measure 
the concentration of organic compounds (CTOC), the principal 
regulated material in the vent stream shall be used as the calibration 
gas.
    (B) An emission testing interval shall consist of each 15-minute 
period during the performance test. For each interval, a reading from 
each measurement shall be recorded.
    (C) The average organic compound concentration and the volume 
measurement shall correspond to the same emissions testing interval.
    (D) The mass at the inlet and outlet of the control device during 
each testing interval shall be calculated using Equation 158-6 of this 
section:
[GRAPHIC] [TIFF OMITTED] TR14DE00.017

Where:

Mj = Mass of organic compounds emitted during testing 
interval j, kilograms.
F = 10-6 = Conversion factor, (cubic meters regulated 
material per cubic meters air) * (parts per million by volume) 
-1.
K = Density, kilograms per standard cubic meter regulated material. You 
may use 659 kilograms per standard cubic meter regulated material. 
(Note: The density term cancels out when the percent reduction is 
calculated. Therefore, the density used has no effect. The density of 
hexane is given so that it can be used to maintain the units of 
Mj.)

[[Page 123]]

Vs = Volume of air-vapor mixture exhausted at standard 
conditions, 20 C and 760 millimeters of mercury (30 inches 
of mercury), standard cubic meters.
Ct = Total concentration of organic compounds (as measured) 
at the exhaust vent, parts per million by volume, dry basis.

    (E) The organic compound mass emission rates at the inlet and outlet 
of the control device shall be calculated as follows:
[GRAPHIC] [TIFF OMITTED] TR14DE00.018

[GRAPHIC] [TIFF OMITTED] TR14DE00.019

Where:

Ei, Eo = Mass flow rate of organic compounds at 
the inlet (i) and outlet (o) of the control device, kilograms per hour.
n = Number of testing intervals.
Mij, Moj = Mass of organic compounds at the inlet 
(i) or outlet (o) during testing interval j, kilograms.
T = Total time of all testing intervals, hours.

    (c) Halogen test method. An owner or operator using a halogen 
scrubber or other halogen reduction device to control halogenated vent 
streams in compliance with Sec. 65.63(b)(1) for process vents, 
or Sec. 65.83(b)(1) for transfer racks, who is required to 
conduct a performance test to determine compliance with the control 
efficiency or emission limits for hydrogen halides and halogens, as 
specified in Sec. 65.154(b), shall comply with the following 
procedures:
    (1) For an owner or operator determining compliance with the percent 
reduction of total hydrogen halides and halogens, sampling sites shall 
be located at the inlet and outlet of the scrubber or other halogen 
reduction device used to reduce halogen emissions. For an owner or 
operator determining compliance with the less than 0.45 kilogram per 
hour (0.99 pounds per hour) outlet emission limit for total hydrogen 
halides and halogens, the sampling site shall be located at the outlet 
of the scrubber or other halogen reduction device and prior to any 
releases to the atmosphere.
    (2) Except as provided in paragraph (a)(2) of this section, Method 
26 or Method 26A of appendix A of 40 CFR part 60 shall be used to 
determine the concentration, in milligrams per dry standard cubic meter, 
of total hydrogen halides and halogens that may be present in the vent 
stream. The mass emissions of each hydrogen halide and halogen compound 
shall be calculated from the measured concentrations and the gas stream 
flow rate.
    (3) To determine compliance with the percent removal efficiency, the 
mass emissions for any hydrogen halides and halogens present at the 
inlet of the halogen reduction device shall be summed together. The mass 
emissions of the compounds present at the outlet of the scrubber or 
other halogen reduction device shall be summed together. Percent 
reduction shall be determined by comparison of the summed inlet and 
outlet measurements.
    (4) To demonstrate compliance with the less than 0.45 kilogram per 
hour (0.99 pound per hour) outlet emission limit, the test results must 
show that the mass emission rate of total hydrogen halides and halogens 
measured at the outlet of the scrubber or other halogen reduction device 
is below 0.45 kilogram per hour (0.99 pound per hour).


Sec. 65.159  Flare compliance determination and monitoring records.

    (a) Conditions of flare compliance determination records. Upon 
request, the owner or operator shall make available to the Administrator 
such records as may be necessary to determine the conditions of flare 
compliance determinations performed pursuant to Sec. 
65.147(b).
    (b) Flare compliance determination records. When using a flare to 
comply with this subpart, record the following information for each 
flare compliance determination performed pursuant to Sec. 
65.147(b):
    (1) Flare design (i.e., steam-assisted, air-assisted, or 
nonassisted);
    (2) All visible emission readings, heat content determinations, flow 
rate measurements, and exit velocity determinations made during the 
flare compliance determination; and

[[Page 124]]

    (3) All periods during the flare compliance determination when all 
pilot flames are absent or, if only the flare flame is monitored, all 
periods when the flare flame is absent.
    (c) Monitoring records. Each owner or operator shall keep up to date 
and readily accessible hourly records of whether the flare flame or 
pilot flame monitors are continuously operating during the hour and 
whether the flare flame or at least one pilot flame is continuously 
present during the hour. For transfer racks, hourly records are required 
only while the transfer vent stream is being vented.
    (d) Compliance records. (1) Each owner or operator shall keep 
records of the times and duration of all periods during which the flare 
flame and all the pilot flames are absent. This record shall be 
submitted in the periodic reports as specified in Sec. 
65.166(c).
    (2) Each owner or operator shall keep records of the times and 
durations of all periods during which the flare flame or pilot flame 
monitors are not operating.


Sec. 65.160  Performance test and TRE index value determination 
          records.

    (a) Availability of performance tests records. Upon request, the 
owner or operator shall make available to the Administrator such records 
as may be necessary to determine the conditions of performance tests 
performed pursuant to Sec.Sec. 65.148(b), 65.149(b), 
65.150(b), 65.151(b), 65.152(b), 65.154(b), or 65.155(b).
    (b) Nonflare control device and halogen reduction device performance 
test records. Each owner or operator subject to the provisions of this 
subpart shall keep up-to-date, readily accessible records of the data 
specified in paragraphs (b)(1) through (3) of this section, as 
applicable, measured during each performance test performed pursuant to 
Sec.Sec. 65.148(b), 65.149(b), 65.150(b), 65.151(b), 
65.152(b), 65.154(b), or 65.155(b), and also include that data in the 
Initial Compliance Status Report as specified in Sec. 
65.164(a). The same data specified in paragraphs (b)(1) through (3) of 
this section, as applicable, shall be submitted in the reports of all 
subsequently required performance tests where either the emission 
control efficiency of a nonflare control device or the outlet 
concentration of TOC or regulated material is determined.
    (1) Nonflare combustion device. Where an owner or operator subject 
to the provisions of paragraph (b) of this section seeks to demonstrate 
compliance with a percent reduction requirement or a parts per million 
by volume requirement using a nonflare combustion device, the following 
information shall be recorded:
    (i) For thermal incinerators, record the fire box temperature 
measured at least every 15 minutes and averaged over the full period of 
the performance test.
    (ii) For catalytic incinerators, record the upstream and downstream 
temperatures and the temperature difference across the catalyst bed 
measured at least every 15 minutes and averaged over the full period of 
the performance test.
    (iii) For an incinerator, record the percent reduction of regulated 
material or TOC achieved by the incinerator determined as specified in 
Sec. 65.158(b)(4), as applicable, or the concentration of 
regulated material or TOC (parts per million by volume, by compound) 
determined as specified in Sec. 65.158(b)(3) at the outlet of 
the incinerator.
    (iv) For a boiler or process heater, record a description of the 
location at which the vent stream is introduced into the boiler or 
process heater.
    (v) For boilers or process heaters with a design heat input capacity 
less than 44 megawatts (150 British thermal units per hour) and where 
the vent stream is not introduced with or as the primary fuel, record 
the fire box temperature measured at least every 15 minutes and averaged 
over the full period of the performance test.
    (vi) For a boiler or process heater with a design heat input 
capacity of less than 44 megawatts (150 British thermal units per hour) 
and where the vent stream is not introduced with or as the primary fuel, 
record the percent reduction of regulated material or TOC, or the 
concentration of regulated material or TOC (parts per million by volume, 
by compound) determined as specified in Sec. 65.158(b)(3) at 
the outlet of the combustion device.
    (2) Other nonflare control devices. Where an owner or operator seeks 
to

[[Page 125]]

use an absorber, condenser, or carbon adsorber as a control device, the 
following information shall be recorded, as applicable:
    (i) Where an absorber is used as the control device, the exit 
specific gravity and average exit temperature of the absorbing liquid 
measured at least every 15 minutes and averaged over the same time 
period as the performance test (both measured while the vent stream is 
normally routed and constituted); or
    (ii) Where a condenser is used as the control device, the average 
exit (product side) temperature measured at least every 15 minutes and 
averaged over the same time period as the performance test while the 
vent stream is routed and constituted normally; or
    (iii) Where a carbon adsorber is used as the control device, the 
total regeneration stream mass flow during each carbon-bed regeneration 
cycle during the period of the performance test measured at least every 
15 minutes and averaged over the same time period as the performance 
test (full carbon-bed cycle), and temperature of the carbon-bed after 
each regeneration during the period of the performance test (and within 
15 minutes of completion of any cooling cycle or cycles); or
    (iv) As an alternative to paragraph (b)(2)(i), (ii), or (iii) of 
this section, the concentration level or reading indicated by the 
organics monitoring device at the outlet of the absorber, condenser, or 
carbon adsorber measured at least every 15 minutes and averaged over the 
same time period as the performance test while the vent stream is 
normally routed and constituted; and
    (v) For an absorber, condenser, or carbon adsorber used as a control 
device, the percent reduction of regulated material or TOC achieved by 
the control device determined as specified in Sec. 
65.158(b)(4), or the concentration of regulated material or TOC (parts 
per million by volume, by compound) determined as specified in 
Sec. 65.158(b)(3) at the outlet of the control device.
    (3) Halogen reduction devices. When using a scrubber following a 
combustion device to control a halogenated vent stream, record the 
following information:
    (i) The percent reduction or scrubber outlet mass emission rate of 
total hydrogen halides and halogens as specified in Sec. 
65.158(c);
    (ii) The pH of the scrubber effluent averaged over the time period 
of the performance test; and
    (iii) The scrubber liquid-to-gas ratio averaged over the time period 
of the performance test.
    (c) Recovery device monitoring records during the TRE index value 
determination. For Group 2A process vents, the following records, as 
applicable, shall be maintained and reported as specified in 
Sec. 65.164(a)(3):
    (1) Where an absorber is the final recovery device in the recovery 
system, the exit specific gravity and average exit temperature of the 
absorbing liquid measured at least every 15 minutes and averaged over 
the same time period as the TRE index value determination (both measured 
while the vent stream is normally routed and constituted); or
    (2) Where a condenser is the final recovery device in the recovery 
system, the average exit (product side) temperature measured at least 
every 15 minutes and averaged over the same time period as the TRE index 
value determination while the vent stream is routed and constituted 
normally; or
    (3) Where a carbon adsorber is the final recovery device in the 
recovery system, the total regeneration stream mass flow measured at 
least every 15 minutes and averaged over the same time during each 
carbon-bed regeneration cycle during the period of the TRE index value 
determination, and temperature of the carbon-bed after each regeneration 
during the period of the TRE index value determination (and within 15 
minutes of completion of any cooling cycle or cycles); or
    (4) As an alternative to paragraph (c)(1), (2), or (3) of this 
section, the concentration level or reading indicated by an organics 
monitoring device at the outlet of the absorber, condenser, or carbon 
adsorber measured at least every 15 minutes and averaged over the same 
time period as the TRE index value determination while the vent stream 
is normally routed and constituted; and
    (5) All measurements and calculations performed to determine the TRE

[[Page 126]]

index value of the vent stream as specified in Sec. 65.64(h).
    (d) Halogen concentration records. Record the halogen concentration 
in the vent stream determined according to the procedures as specified 
in Sec. 65.63(b) or Sec. 65.83(b). Submit this 
record in the Initial Compliance Status Report, as specified in 
Sec. 65.165(d). If the owner or operator designates the vent 
stream as halogenated, then this shall be recorded and reported in the 
Initial Compliance Status Report.


Sec. 65.161  Continuous records and monitoring system data handling.

    (a) Continuous records. Where this subpart requires a monitoring 
device capable of providing a continuous record, the owner or operator 
shall maintain the record specified in paragraph (a)(1), (2), (3), or 
(4) of this section, as applicable (The provisions of this section apply 
to owners and operators of storage vessels and low-throughput transfer 
racks only if specified by the applicable monitoring plan established 
under Sec. 65.165(c)(1) and (2)):
    (1) A record of values measured at least once every 15 minutes or 
each measured value for systems that measure more frequently than once 
every 15 minutes; or
    (2) A record of block average values for 15-minute or shorter 
periods calculated from all measured data values during each period or 
from at least one measured data value per minute if measured more 
frequently than once per minute; or
    (3) For data collected from an automated continuous parameter 
monitoring system, a record of block hourly average values calculated 
from each 15-minute block average period or from at least one measured 
value per minute if measured more frequently than once per minute, and a 
record of the most recent 3 valid hours of continuous (15-minute or 
shorter) records meeting the requirements of paragraph (a)(1) or (2) of 
this section. Records meeting the requirements of paragraph (a)(1) or 
(2) of this section shall also be kept for all periods that include CPMS 
breakdown or malfunction. During these periods, it is not necessary to 
calculate hourly averages; or
    (4) A record as required by an alternative approved under 
Sec. 65.162(d).
    (b) Excluded data. Monitoring data recorded during the following 
periods shall not be included in any average computed to determine 
compliance under this subpart:
    (1) Monitoring system breakdowns, repairs, preventive maintenance, 
calibration checks, and zero (low-level) and high-level adjustments;
    (2) Periods of non-operation of the process unit (or portion 
thereof), resulting in cessation of the emissions to which the 
monitoring applies; and
    (3) Startups, shutdowns, and malfunctions.
    (c) Records of daily averages. In addition to the records specified 
in paragraph (a) of this section, owners or operators shall also keep 
records as specified in paragraphs (c)(1) and (2) of this section unless 
an alternative monitoring or recordkeeping system has been requested and 
approved under Sec. 65.162(d).
    (1) Except as specified in paragraph (c)(2) of this section, daily 
average values of each continuously monitored parameter shall be 
calculated for each operating day. Data meeting the specifications of 
paragraph (b) of this section shall not be included in the average. The 
data shall be reported in the periodic report as specified in 
Sec. 65.166(f), if applicable.
    (i) The daily average shall be calculated as the average of all 
values for a monitored parameter recorded during the operating day as 
specified in paragraph (a)(1), (2), or (3) of this section. The average 
shall cover a 24-hour period if operation is continuous, or the number 
of hours of operation per operating day if operation is not continuous 
(for example, for high-throughput transfer racks, the average shall 
cover periods of loading). If values are measured more frequently than 
once per minute, a single value for each minute may be used to calculate 
the daily average instead of all measured values.
    (ii) The operating day shall be the period defined in the operating 
permit or the Initial Compliance Status Report. It may be from midnight 
to midnight or another daily period.
    (2) If all monitored parameter values recorded under paragraph 
(a)(1), (2), or

[[Page 127]]

(3) of this section, during an operating day are within the range 
established in the Initial Compliance Status Report or in the operating 
permit, the owner or operator does not have to calculate a daily average 
value for the operating day and may record that all values were within 
the range. The owner or operator must continue to retain the raw data, 
15-minute averages, or the hourly averages required under paragraph 
(a)(1), (2), or (3) of this section.
    (d) Valid data. Unless determined to be excluded data according to 
paragraph (b) of this section, the data collected pursuant to paragraphs 
(a) through (c) of this section shall be considered valid.
    (e) Alternative recordkeeping. For any parameter with respect to any 
item of equipment, the owner or operator may implement the recordkeeping 
requirements in paragraph (e)(1) or (2) of this section as alternatives 
to the continuous parameter monitoring and recordkeeping provisions 
listed in paragraphs (a) through (c) of this section. The owner or 
operator shall retain each record required by paragraph (e)(1) or (2) of 
this section as provided in Sec. 65.4.
    (1) The owner or operator may retain only the daily average value 
and is not required to retain more frequently monitored operating 
parameter values for a monitored parameter with respect to an item of 
equipment if the requirements of paragraphs (e)(1)(i) through (vi) of 
this section are met. The owner or operator shall notify the 
Administrator of implementation of paragraph (e)(1) of this section in 
the Initial Compliance Status Report as required in Sec. 
65.165(e) or, if the Initial Compliance Status Report has already been 
submitted, in the periodic report as required in Sec. 
65.166(f)(4) immediately preceding implementation of the requirements of 
paragraph (e)(1) of this section.
    (i) The monitoring system can detect unrealistic or impossible data 
during periods of operation other than startups, shutdowns, or 
malfunctions (for example, a temperature reading of -200 C 
on a boiler) and will alert the operator by alarm or other means. The 
owner or operator shall record the occurrence. All instances of the 
alarm or other alert in an operating day constitute a single occurrence.
    (ii) The monitoring system shall generate a running average of the 
monitoring values, updated at least hourly throughout each operating 
day, that have been obtained during that operating day, and the 
capability to observe this average is readily available to the 
Administrator on-site during the operating day. All instances in an 
operating day constitute a single occurrence. The owner or operator 
shall record the occurrence of any period meeting the following 
criteria:
    (A) The running average is above the maximum or below the minimum 
established limits;
    (B) The running average is based on at least six 1-hour average 
values;
    (C) The running average reflects a period of operation other than a 
startup, shutdown, or malfunction.
    (iii) The monitoring system shall be capable of detecting unchanging 
data during periods of operation other than startups, shutdowns, or 
malfunctions except in circumstances where the presence of unchanging 
data is the expected operating condition based on past experience (for 
example, pH in some scrubbers), and will alert the operator by alarm or 
other means. The owner or operator shall record the occurrence. All 
instances of the alarm or other alert in an operating day constitute a 
single occurrence.
    (iv) The monitoring system shall alert the owner or operator by an 
alarm if the running average parameter value calculated under paragraph 
(e)(1)(ii) of this section reaches a set point that is appropriately 
related to the established limit for the parameter that is being 
monitored.
    (v) The owner or operator shall verify and document the proper 
functioning of the monitoring system, including its ability to comply 
with the requirements of paragraph (e)(1) of this section, at the 
following times:
    (A) Upon initial installation;
    (B) Annually after initial installation; and
    (C) After any change to the programming or equipment constituting 
the

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monitoring system, that might reasonably be expected to alter the 
monitoring system's ability to comply with the requirements of this 
section.
    (vi) The owner or operator shall retain the following records:
    (A) Identification of each parameter for each item of equipment for 
which the owner or operator has elected to comply with the requirements 
of Sec. 65.162(e).
    (B) A description of the applicable monitoring system(s) and of how 
compliance will be achieved with each requirement of paragraphs 
(e)(1)(i) through (v) of this section. The description shall identify 
the location and format (for example, on-line storage; log entries) for 
each required record. If the description changes, the owner or operator 
shall retain both the current and the most recent outdated description.
    (C) A description and the date of any change to the monitoring 
system that would reasonably be expected to affect its ability to comply 
with the requirements of paragraph (e)(1) of this section.
    (D) Owners and operators shall retain the current description of the 
monitoring system as long as the description is current, but not less 
than 5 years from the date of its creation. The current description 
shall be retained on-site at all times or be accessible from a central 
location by computer or other means that provide access within 2 hours 
after a request. The owner or operator shall retain the most recent 
outdated description at least until 5 years from the date of its 
creation. The outdated description shall be retained on-site (or 
accessible from a central location by computer that provides access 
within 2 hours after a request) at least 6 months after being outdated. 
Thereafter, the outdated description may be stored off-site.
    (2) If an owner or operator has elected to implement the 
requirements of paragraph (e)(1) of this section and a period of 6 
consecutive months has passed without an excursion as defined in 
paragraph (e)(2)(iv) of this section, the owner or operator is no longer 
required to record the daily average value for that parameter for that 
unit of equipment for any operating day when the daily average value is 
less than the maximum or greater than the minimum established limit. 
With approval by the Administrator, monitoring data generated prior to 
the compliance date of this subpart shall be credited toward the period 
of 6 consecutive months if the parameter limit and the monitoring were 
required and/or approved by the Administrator.
    (i) If the owner or operator elects not to retain the daily average 
values, the owner or operator shall notify the Administrator in the next 
periodic report. The notification shall identify the parameter and unit 
of equipment.
    (ii) If there is an excursion as defined in paragraph (e)(2)(iv) of 
this section on any operating day after the owner or operator has ceased 
recording daily averages as provided in paragraph (e)(2) of this 
section, the owner or operator shall immediately resume retaining the 
daily average value for each day and shall notify the Administrator in 
the next periodic report. The owner or operator shall continue to retain 
each daily average value until another period of 6 consecutive months 
has passed without an excursion.
    (iii) The owner or operator shall retain the records specified in 
paragraphs (e)(1)(i) through (vi) of this section for the duration 
specified in Sec. 65.4. For any calendar week, if compliance 
with paragraphs (e)(1)(i) through (iv) of this section does not result 
in retention of a record of at least one occurrence or measured 
parameter value, the owner or operator shall record and retain at least 
one parameter value during a period of operation other than a startup, 
shutdown, or malfunction.
    (iv) For purposes of paragraph (e) of this section, an excursion 
means that the daily average value of monitoring data for a parameter is 
greater than the maximum or less than the minimum established value 
except as provided in the following:
    (A) The daily average value during any startup, shutdown, or 
malfunction shall not be considered an excursion for purposes of this 
paragraph (e) if the owner or operator follows the applicable provisions 
of the startup, shutdown, and malfunction plan required by 
Sec. 65.6.
    (B) Excused excursions described in Sec. 65.156(d)(2) and 
excursions described in

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Sec. 65.156(d)(3) do not count toward the number of excursions 
for purposes of this paragraph (e).


Sec. 65.162  Nonflare control and recovery device monitoring records.

    (a) Monitoring system records. For process vents and high-throughput 
transfer racks, the owner or operator subject to this subpart shall keep 
the records specified in paragraph (a) of this section as well as 
records specified elsewhere in this part.
    (1) For CPMS used to comply with this part, a record of the 
procedure used for calibrating the CPMS.
    (2) For CPMS used to comply with this subpart, records of the 
following information, as applicable:
    (i) The date and time of completion of calibration and preventive 
maintenance of the CPMS;
    (ii) The ``as found'' and 
``as left'' CPMS readings whenever an 
adjustment is made that affects the CPMS reading and a 
``no adjustment'' statement otherwise;
    (iii) The start time and duration or start and stop time of any 
periods when the CPMS is inoperative or malfunctioning;
    (iv) Records of the occurrence and duration of each startup, 
shutdown, and malfunction of CPMS used to comply with this part during 
which excess emissions (as defined in Sec. 65.3(a)(4)) occur; 
and
    (v) For each startup, shutdown, and malfunction during which excess 
emissions as defined in Sec. 65.3(a)(4) of this part occur, 
records whether the procedures specified in the source's startup, 
shutdown, and malfunction plan were followed and documentation of 
actions taken that are not consistent with the plan. These records may 
take the form of a checklist, or other form of recordkeeping that 
confirms conformance with the startup, shutdown, and malfunction plan 
for the event.
    (3) Records of startup, shutdown, and malfunction and CPMS 
calibration and maintenance are not required if they pertain solely to 
Group 2A process vents.
    (b) Combustion control and halogen reduction device monitoring 
records. (1) Each owner or operator using a combustion control or 
halogen reduction device to comply with this subpart shall keep, as 
applicable, up-to-date and readily accessible continuous records, as 
specified in Sec. 65.161(a); and records of the equipment 
operating parameters specified to be monitored under Sec. 
65.148(c) (incinerator monitoring); Sec. 65.149(c) (boiler and 
process heater monitoring); Sec. 65.154(c) (halogen reduction 
device monitoring); Sec. 65.155(c) (other control device 
monitoring); or specified by the Administrator in accordance with 
paragraph (e) of this section.
    (2) Each owner or operator shall keep records of the daily average 
value of each continuously monitored parameter for each operating day 
determined according to the procedures specified in Sec. 
65.161(c)(1). For catalytic incinerators, record the daily average of 
the temperature upstream of the catalyst bed and the daily average of 
the temperature differential across the bed. For halogen scrubbers, 
record the daily average pH and the liquid-to-gas ratio.
    (3) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible records of periods of 
operation during which the parameter boundaries are exceeded and report 
these exceedances as specified in Sec. 65.166(f)(1). The 
parameter boundaries are established pursuant to Sec. 
65.148(c)(2) (incinerator monitoring), Sec. 65.149(c)(2) 
(boiler and process heater monitoring), Sec. 65.154(c)(2) 
(halogen reduction device monitoring), or Sec. 65.155(c)(2) 
(other control device monitoring), as applicable.
    (c) Monitoring records for recovery devices on Group 2A process 
vents and for absorbers, condensers, carbon adsorbers, or other 
noncombustion systems used as control devices. (1) Each owner or 
operator using a recovery device to achieve and maintain a TRE index 
value greater than 1.0 but less than 4.0 or using an absorber, 
condenser, carbon adsorber, or other noncombustion system as a control 
device shall keep readily accessible, continuous records, as specified 
in Sec. 65.161(a), of the equipment operating parameters 
specified to be monitored under Sec. 65.150(c) (absorber 
monitoring), Sec. 65.151(c) (condenser monitoring), 
Sec. 65.152(c) (carbon adsorber monitoring), Sec. 
65.153(c) (recovery device monitoring) or Sec. 65.155(c) 
(other control

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device monitoring), or specified by the Administrator in accordance with 
paragraph (e) of this section. For transfer racks, continuous records 
are required while the transfer vent stream is being vented.
    (2) Each owner or operator shall keep records of the daily average 
value of each continuously monitored parameter for each operating day 
determined according to the procedures specified in Sec. 
65.161(c)(1). If carbon adsorber regeneration stream flow and carbon bed 
regeneration temperature are monitored, the following records shall be 
kept instead of the daily averages, and the records shall be reported as 
specified in Sec. 65.166(f)(2):
    (i) Records of total regeneration stream mass or volumetric flow for 
each carbon-bed regeneration cycle; and
    (ii) Records of the temperature of the carbon bed after each 
regeneration and within 15 minutes of completing any cooling cycle.
    (3) Each owner or operator subject to the provisions of this subpart 
shall keep up-to-date, readily accessible records of periods of 
operation during which the parameter boundaries are exceeded and report 
these exceedances as specified in Sec. 65.166(f)(1). The 
parameter boundaries are established pursuant to Sec. 
65.150(c)(2) (absorber monitoring), Sec. 65.151(c)(2) 
(condenser monitoring), Sec. 65.152(c)(2) (carbon adsorber 
monitoring), or Sec. 65.155(c)(2) (other control device 
monitoring), as applicable.
    (d) Alternatives to the continuous operating parameter monitoring 
and recordkeeping provisions. An owner or operator may request approval 
to use alternatives to the continuous operating parameter monitoring and 
recordkeeping provisions listed in Sec.Sec. 
65.148(c), 65.149(c), 65.150(c), 65.151(c), 65.152(c), 65.153(c), 
65.154(c), 65.160, and paragraphs (b) and (c) of this section.
    (1) Requests shall be included in the operating permit application 
or as otherwise specified by the permitting authority and shall contain 
the information specified in paragraphs (d)(3) through (5) of this 
section, as applicable.
    (2) The provisions in Sec. 65.7(c) shall govern the review 
and approval of requests.
    (3) An owner or operator of a source that does not have an automated 
monitoring and recording system capable of measuring parameter values at 
least once every 15 minutes and generating continuous records may 
request approval to use a nonautomated system with less frequent 
monitoring.
    (i) The requested system shall include manual reading and recording 
of the value of the relevant operating parameter no less frequently than 
once per hour. Daily average values shall be calculated from these 
hourly values and recorded.
    (ii) The request shall contain the following information:
    (A) A description of the planned monitoring and recordkeeping 
system;
    (B) Documentation that the source does not have an automated 
monitoring and recording system capable of meeting the specified 
requirements;
    (C) Justification for requesting an alternative monitoring and 
recordkeeping system; and
    (D) Demonstration to the Administrator's satisfaction that the 
proposed monitoring frequency is sufficient to represent control device 
operating conditions considering typical variability of the specific 
process and control device operating parameter being monitored.
    (4) An owner or operator may request approval to use an automated 
data compression recording system that does not record monitored 
operating parameter values at a set frequency (for example, once every 
15 minutes) but records all values that meet set criteria for variation 
from previously recorded values.
    (i) The requested system shall be designed to perform the following 
functions:
    (A) Measure the operating parameter value at least once every 15 
minutes;
    (B) Record at least four values each hour during periods of 
operation;
    (C) Record the date and time when monitors are turned off or on;
    (D) Recognize unchanging data that may indicate the monitor is not 
functioning properly, alert the operator, and record the incident; and
    (E) Compute daily average values of the monitored operating 
parameter

[[Page 131]]

based on recorded data. If the daily average is not an excursion as 
defined in Sec. 65.161(e)(2)(iv), the data for that operating 
day may be converted to hourly average values, and the four or more 
individual records for each hour in the operating day may be discarded.
    (ii) The request shall contain a description of the monitoring 
system and data compression recording system, including the criteria 
used to determine which monitored values are recorded and retained, the 
method for calculating averages, and a demonstration that the system 
meets all criteria in paragraph (d)(4)(i) of this section.
    (5) An owner or operator may request approval to use other 
alternative monitoring and recordkeeping systems as specified in 
Sec. 65.7(b). The application shall contain a description of 
the proposed alternative system. In addition, the application shall 
include information justifying the owner or operator's request for an 
alternative monitoring method, such as the technical or economic 
infeasibility, or the impracticality, of the regulated source using the 
required method.
    (e) Monitoring a different parameter than those listed. The owner or 
operator who has been directed by Sec. 65.154(c)(2) or 
Sec. 65.155(c)(1) to set monitoring parameters, or who 
requests as allowed by Sec. 65.156(e) approval to monitor a 
different parameter than those listed in Sec.Sec. 
65.148(c), 65.149(c), 65.150(c), 65.151(c), 65.152(c), 65.153(c), 
65.154(c), 65.160, or paragraph (b) or (c) of this section, shall submit 
the following information with the operating permit application or as 
otherwise specified by the permitting authority:
    (1) A description of the parameter(s) to be monitored to ensure the 
process, control technology, or pollution prevention measure is operated 
in conformance with its design and achieves the specified emission 
limit, percent reduction, or nominal efficiency, and an explanation of 
the criteria used to select the parameter(s).
    (2) A description of the methods and procedures that will be used to 
demonstrate that the parameter indicates proper operation of the control 
device, the schedule for this demonstration, and a statement that the 
owner or operator will establish a range for the monitored parameter as 
part of the Initial Compliance Status Report required in Sec. 
65.5(d) unless this information has already been included in the 
operating permit application or previously established under a 
referencing subpart.
    (3) The frequency and content of monitoring, recording, and 
reporting if monitoring and recording is not continuous, or if reports 
of daily average values when the monitored parameter value is outside 
the range established in the operating permit or Initial Compliance 
Status Report will not be included in Periodic Reports as specified in 
Sec. 65.166(e). The rationale for the proposed monitoring, 
recording, and reporting system shall be included.


Sec. 65.163  Other records.

    (a) Closed vent system records. For closed vent systems, the owner 
or operator shall record the following information, as applicable:
    (1) For each closed vent system that contains bypass lines that 
could divert a vent stream away from the control device and to the 
atmosphere, the owner or operator shall keep a record of the information 
specified in either paragraph (a)(1)(i) or (ii) of this section, as 
applicable. The information shall be reported as specified in 
Sec. 65.166(b).
    (i) Hourly records of whether the flow indicator specified under 
Sec. 65.143(a)(3)(i) was operating and whether a diversion was 
detected at any time during the hour, as well as records of the times of 
all periods when the vent stream is diverted from the control device or 
the flow indicator is not operating.
    (ii) Where a seal mechanism is used to comply with Sec. 
65.143(a)(3)(ii), hourly records of flow are not required. In such 
cases, the owner or operator shall record that the monthly visual 
inspection of the seals or closure mechanisms has been done and shall 
record the occurrence of all periods when the seal mechanism is broken, 
the bypass line valve position has changed, or the key for a lock-and-
key type lock has been checked out, and records of any car-seal that has 
been broken.
    (2) For closed vent systems collecting regulated material from a 
storage vessel, transfer rack, or equipment leak, the owner or operator 
shall record the

[[Page 132]]

identification of all parts of the closed vent system that are 
designated as unsafe or difficult-to-inspect pursuant to Sec. 
65.143(b)(2) or (3), an explanation of why the equipment is unsafe or 
difficult-to-inspect, and the plan for inspecting the equipment as 
required by Sec. 65.143(b)(2)(ii) or (b)(3)(ii).
    (3) For a closed vent system collecting regulated material from a 
storage vessel, transfer rack, or equipment leaks, when a leak is 
detected as specified in Sec. 65.143(d)(1), the information 
specified in paragraphs (a)(3)(i) through (vi) of this section shall be 
recorded. The data shall be reported as specified in Sec. 
65.166(b)(1).
    (i) The instrument and the equipment identification number and the 
operator name, initials, or identification number.
    (ii) The date the leak was detected and the date of the first 
attempt to repair the leak.
    (iii) The date of successful repair of the leak.
    (iv) The maximum instrument reading measured by the procedures in 
Sec. 65.143(c) after the leak is successfully repaired or 
determined to be nonrepairable.
    (v) ``Repair delayed'' and the reason 
for the delay if a leak is not repaired within 15 calendar days after 
discovery of the leak. The owner or operator may develop a written 
procedure that identifies the conditions that justify a delay of repair. 
In such cases, reasons for delay of repair may be documented by citing 
the relevant sections of the written procedure.
    (vi) Copies of the periodic reports if records are not maintained on 
a computerized database capable of generating summary reports from the 
records.
    (4) For each instrumental or visual inspection conducted in 
accordance with Sec. 65.143(b)(1) for closed vent systems 
collecting regulated material from a storage vessel, transfer rack, or 
equipment leaks during which no leaks are detected, the owner or 
operator shall record that the inspection was performed, the date of the 
inspection, and a statement that no leaks were detected.
    (5) For instrument response factor criteria determinations performed 
pursuant to Sec. 65.143(c)(1)(ii), the owner or operator shall 
maintain a record of an engineering assessment that identifies the 
representative composition of the process fluid. This assessment shall 
be based on knowledge of the compounds present in the process, 
similarity of response factors for the materials present, the range of 
compositions encountered during monitoring, or other information 
available to the owner or operator.
    (b) Storage vessel and transfer rack records. For storage vessels, 
an owner or operator shall keep readily accessible records of the 
information specified in paragraphs (b)(1) through (3) of this section, 
as applicable. For low-throughput transfer racks, an owner or operator 
shall keep readily accessible records of the information specified in 
paragraph (b)(1) of this section.
    (1) A record of the measured values of the parameters monitored in 
accordance with Sec. 65.145(c)(2) and report in the periodic 
report as specified in Sec. 65.166(e), if applicable.
    (2) A record of the planned routine maintenance performed on the 
control system during which the control system does not meet the 
applicable specifications of Sec.Sec. 65.143(a), 
65.145(a), or 65.147(a), as applicable, due to the planned routine 
maintenance. Such a record shall include the information specified in 
paragraphs (b)(2)(i) through (iii) of this section. This information 
shall be submitted in the periodic reports as specified in 
Sec. 65.166(d)(1).
    (i) The first time of day and date the requirements of 
Sec.Sec. 65.143(a), 65.145(a), or 65.147(a), as 
applicable, were not met at the beginning of the planned routine 
maintenance.
    (ii) The first time of day and date the requirements of 
Sec.Sec. 65.143(a), 65.145(a), or 65.147(a), as 
applicable, were met at the conclusion of the planned routine 
maintenance.
    (iii) A description of the type of maintenance performed.
    (3) Bypass records for storage vessel emissions routed to a process 
or fuel gas system. An owner or operator who uses the bypass provisions 
of Sec. 65.144(a)(2) shall keep in a readily accessible 
location the following records:

[[Page 133]]

    (i) The reason it was necessary to bypass the process equipment or 
fuel gas system;
    (ii) The duration of the period when the process equipment or fuel 
gas system was bypassed;
    (iii) Documentation or certification of compliance with the 
applicable provisions of Sec. 65.42(b)(6).
    (c) Regulated source and control equipment startup, shutdown and 
malfunction records. (1) Records of the occurrence and duration of each 
startup, shutdown, and malfunction of process equipment or of air 
pollution control equipment used to comply with this part during which 
excess emissions (as defined in Sec. 65.3(a)(4)) occur.
    (2) For each startup, shutdown, and malfunction during which excess 
emissions occur, records whether the procedures specified in the 
source's startup, shutdown, and malfunction plan were followed, and 
documentation of actions taken that are not consistent with the plan. 
For example, if a startup, shutdown, and malfunction plan includes 
procedures for routing control device emissions to a backup control 
device (for example, the incinerator for a halogenated stream could be 
routed to a flare during periods when the primary control device is out 
of service), records must be kept of whether the plan was followed. 
These records may take the form of a checklist or other form of 
recordkeeping that confirms conformance with the startup, shutdown, and 
malfunction plan for the event.
    (3) Records of startup, shutdown, and malfunction and continuous 
monitoring system calibration and maintenance are not required if they 
pertain solely to Group 2A process vents.
    (d) Equipment leak records. The owner or operator shall maintain 
records of the information specified in paragraphs (d)(1) and (2) of 
this section for closed vent systems and control devices subject to the 
provisions of subpart F of this part. The owner or operator shall meet 
the record retention requirements of Sec. 65.4, except the 
records specified in paragraph (d)(1) of this section shall be kept as 
long as the equipment is in operation.
    (1) The following design specifications and performance 
demonstrations:
    (i) Detailed schematics, design specifications of the control 
device, and piping and instrumentation diagrams.
    (ii) The dates and descriptions of any changes in the design 
specifications.
    (iii) A description of the parameter or parameters monitored as 
required in Sec. 65.146(c) to ensure that control devices are 
operated and maintained in conformance with their design, and an 
explanation of why that parameter (or parameters) was selected for the 
monitoring.
    (2) The following records of operation of closed vent systems and 
control devices:
    (i) Dates and durations when the closed vent systems and control 
devices required in Sec. 65.115(b) are not operated as 
designed as indicated by the monitored parameters, including periods 
when a flare flame or at least one pilot flame is not present.
    (ii) Dates and durations during which the monitoring system or 
monitoring device is inoperative.
    (iii) Dates and durations of startups and shutdowns of control 
devices required in Sec. 65.115(b).
    (e) Records of monitored parameters outside of range. The owner or 
operator shall record the occurrences and the cause of periods when the 
monitored parameters are outside of the parameter ranges documented in 
the Initial Compliance Status Report in accordance with Sec. 
65.165(b). This information shall be reported in the periodic report as 
specified in Sec. 65.166(e).


Sec. 65.164  Performance test and flare compliance determination 
          notifications and reports.

    (a) Performance test and flare compliance determination reports. 
Performance test reports and flare compliance determination reports 
shall be submitted as specified in paragraphs (a)(1) through (3) of this 
section.
    (1) For performance tests or flare compliance determinations, the 
Initial Compliance Status Report or report required by paragraph (b)(2) 
of this section shall include one complete test report as specified in 
paragraph (a)(2) of this section for each test method used for a 
particular kind of emission point, and other applicable information 
specified in paragraph (a)(3) of this section.

[[Page 134]]

For additional tests performed for the same kind of emission point using 
the same method, the results and any other information required in 
applicable sections of this subpart or in other subparts of this part 
shall be submitted, but a complete test report is not required.
    (2) A complete test report shall include a brief process 
description, sampling site description, description of sampling and 
analysis procedures and any modifications to standard procedures, 
quality assurance procedures, record of operating conditions during the 
test, record of preparation of standards, record of calibrations, raw 
data sheets for field sampling, raw data sheets for field and laboratory 
analyses, documentation of calculations, and any other information 
required by the test method.
    (3) The performance test or flare compliance determination report 
shall also include the following information, as applicable:
    (i) For flare compliance determinations, the owner or operator shall 
submit the records specified in Sec. 65.159(b).
    (ii) For nonflare combustion device and halogen reduction device 
performance tests as required under Sec.Sec. 
65.148(b), 65.149(b), 65.150(b), 65.151(b), 65.152(b), 65.154(b), or 
65.155(b), the owner or operator shall submit the applicable records 
specified in Sec. 65.160(b).
    (iii) For Group 2A process vents, the owner or operator shall submit 
the records specified in Sec. 65.160(c), as applicable.
    (b) Other notifications and reports. (1) The owner or operator shall 
notify the Administrator of the intention to conduct a performance test 
at least 30 calendar days before the performance test is scheduled to 
allow 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 as soon as possible of any delay 
in the original test date. The owner or operator shall provide at least 
7 days prior notice of the rescheduled date of the performance test or 
arrange a rescheduled date with the Administrator by mutual agreement.
    (2) Unless specified differently in this subpart or another subpart 
of this part, performance test and flare compliance determination 
reports not submitted as part of an Initial Compliance Status Report 
shall be submitted to the Administrator within 60 days of completing the 
test or determination.
    (3) Any application for a waiver of an initial performance test or 
flare compliance determination as allowed by Sec. 
65.157(b)(2), shall be submitted no later than 90 calendar days before 
the performance test or flare compliance determination is required. The 
application for a waiver shall include information justifying the owner 
or operator's request for a waiver, such as the technical or economic 
infeasibility, or the impracticality, of the source performing the test.


Sec. 65.165  Initial Compliance Status Reports.

    (a) An owner or operator who elects to comply with Sec. 
65.144 by routing emissions from a storage vessel or transfer rack to a 
process or to a fuel gas system shall submit as part of the Initial 
Compliance Status Report the following information, as applicable:
    (1) If storage vessel emissions are routed to a process, the owner 
or operator shall submit the information specified in Sec. 
65.144(b)(3).
    (2) As specified in Sec. 65.144(c), if storage vessel 
emissions are routed to a fuel gas system, the owner or operator shall 
submit a statement that the emission stream is connected to a fuel gas 
system.
    (3) As specified in Sec. 65.144(c), report that the 
transfer rack emission stream is being routed to a fuel gas system or 
process when complying with the requirements of Sec. 
65.83(a)(4).
    (b) An owner or operator who elects to comply with Sec. 
65.145 by routing emissions from a storage vessel or low-throughput 
transfer rack to a nonflare control device or halogen reduction device 
shall submit with the Initial Compliance Status Report required by 
Sec. 65.5(d) the applicable information specified in 
paragraphs (b)(1) through (6) of this section. Owners and operators who 
elect to comply with

[[Page 135]]

Sec. 65.145(b)(1)(i) or (b)(3)(i) by submitting a design 
evaluation shall submit the information specified in paragraphs (b)(1) 
through (4) of this section. Owners and operators who elect to comply 
with Sec. 65.145(b)(1)(ii) or (b)(3)(ii) by submitting 
performance test results shall submit the information specified in 
paragraphs (b)(1), (2), (4), and (5) of this section. Owners and 
operators who elect to comply with Sec. 65.145(b)(1)(iii) or 
(b)(3)(iii) by submitting performance test results for a shared control 
device or halogen reduction device shall submit the information 
specified in paragraph (b)(6) of this section.
    (1) A description of the parameter or parameters to be monitored to 
ensure that the control device or halogen reduction device is being 
properly operated and maintained, an explanation of the criteria used 
for selection of that parameter (or parameters), and the frequency with 
which monitoring will be performed (for example, when the liquid level 
in the storage vessel is being raised). If continuous records are 
specified, indicate whether the provisions of Sec. 65.166(f) 
apply.
    (2) The operating range for each monitoring parameter identified in 
the monitoring plan required by Sec. 65.145(c)(1). The 
specified operating range shall represent the conditions for which the 
control device or halogen reduction device is being properly operated 
and maintained.
    (3) The documentation specified in Sec. 65.145(b)(1)(i), 
if the owner or operator elects to prepare a design evaluation; and the 
documentation specified in Sec. 65.145(b)(3)(i), if the owner 
or operator elects to prepare a design evaluation for a halogen 
reduction device.
    (4) The provisions of Sec. 65.166(f) do not apply to any 
low-throughput transfer rack for which the owner or operator has elected 
to comply with Sec. 65.145 or to any storage vessel for which 
the owner or operator is not required to keep continuous records, as 
specified by the applicable monitoring plan established under 
Sec. 65.145(c)(1) and (2). If continuous records are required, 
the owner or operator shall specify in the monitoring plan whether the 
provisions of Sec. 65.166(f) apply.
    (5) A summary of the results of the performance test described in 
Sec. 65.145(b)(1)(ii), (1)(iii), (3)(ii), and/or (3)(iii), as 
applicable. If a performance test is conducted as provided in 
Sec. 65.145(b)(1)(ii) and/or (b)(3)(ii), submit the results of 
the performance test, including the information specified in 
Sec. 65.164(a)(1) and (2).
    (6) Identification of the storage vessel or low-throughput transfer 
rack and control device and/or halogen reduction device for which the 
performance test will be submitted, and identification of the emission 
point(s), if any, that share the control device and/or halogen reduction 
device with the storage vessel or low-throughput transfer rack and for 
which the performance test will be conducted.
    (c) The owner or operator shall submit as part of the Initial 
Compliance Status Report the operating range for each monitoring 
parameter identified for each control, recovery, or halogen reduction 
device as determined in Sec.Sec. 65.148(c)(2), 
65.149(c)(2), 65.150(c)(2), 65.151(c)(2), 65.152(c)(2), 65.153(c)(5), 
65.154(c)(3), and 65.155(c)(2). The specified operating range shall 
represent the conditions for which the control, recovery, or halogen 
reduction device is being properly operated and maintained. This report 
shall include the information in paragraphs (c)(1) through (3) of this 
section, as applicable, unless the range and the operating day 
definition have been established in the operating permit:
    (1) The specific range of the monitored parameter(s) for each 
emission point.
    (2) The rationale for the specific range for each parameter for each 
emission point, including any data and calculations used to develop the 
range and a description of why the range indicates proper operation of 
the control, recovery, or halogen reduction device, as specified in the 
following, as applicable:
    (i) If a performance test or TRE index value determination is 
required by this subpart or another subpart of this part for a control, 
recovery or halogen removal device, the range shall be based on the 
parameter values measured during the TRE index value determination or 
performance test and may be supplemented by engineering assessments

[[Page 136]]

and/or manufacturer's recommendations. The TRE index value 
determinations and performance testing is not required to be conducted 
over the entire range of permitted parameter values.
    (ii) If a performance test or TRE index value determination is not 
required by this subpart or other subparts of this part for a control, 
recovery, or halogen reduction device, the range may be based solely on 
engineering assessments and/or manufacturer's recommendations.
    (iii) The range may be based on ranges or limits previously 
established under a referencing subpart.
    (3) A definition of the source's operating day for purposes of 
determining daily average values of monitored parameters. The definition 
shall specify the times at which an operating day begins and ends.
    (d) Halogen reduction device. The owner or operator shall submit as 
part of the Initial Compliance Status Report the information recorded 
pursuant to Sec. 65.160(d).
    (e) Alternative recordkeeping. The owner or operator shall notify 
the Administrator in the Initial Compliance Status Report if the 
alternative recordkeeping provisions of Sec. 65.161(e)(1) are 
being implemented. If the Initial Compliance Status Report has been 
submitted, the notification must be in the periodic report submitted 
immediately preceding implementation of the alternative, as provided in 
Sec. 65.166(f)(4).
    (f) Exemptions from performance tests and design evaluation. The 
owner or operator shall identify in the Initial Compliance Status Report 
whether an exemption from performance testing or conducting a design 
evaluation, as provided in Sec.Sec. 65.145(b)(2), 
65.148(b)(2), or 65.149(b)(2), is being invoked, and which of the 
provisions of Sec.Sec. 65.145(b)(2), 65.148(b)(2), 
or 65.149(b)(2) apply.


Sec. 65.166  Periodic reports.

    (a) Periodic reports shall include the reporting period dates, the 
total source operating time for the reporting period, and, as 
applicable, all information specified in this section and in other 
subparts of this part, including reports of periods when monitored 
parameters are outside their established ranges.
    (b) For closed vent systems subject to the requirements of 
Sec. 65.143, the owner or operator shall submit as part of the 
periodic report the following information, as applicable:
    (1) The information recorded in Sec. 65.163(a)(3)(ii) 
through (v);
    (2) Reports of the times of all periods recorded under 
Sec. 65.163(a)(1)(i) when the vent stream is diverted from the 
control device through a bypass line; and
    (3) Reports of all times recorded under Sec. 
65.163(a)(1)(ii) when maintenance is performed on car-sealed valves, 
when the seal is broken, when the bypass line valve position is changed, 
or the key for a lock-and-key type configuration has been checked out.
    (c) For flares subject to this subpart, report all periods when all 
pilot flames were absent or the flare flame was absent as recorded in 
Sec. 65.159(d)(1).
    (d) For storage vessels, the owner or operator shall include in each 
periodic report required the following information:
    (1) For the 6-month period covered by the periodic report, the 
information recorded in Sec. 65.163(b)(2)(i) through (iii).
    (2) For the time period covered by the periodic report and the 
previous periodic report, the total number of hours that the control 
system did not meet the requirements of Sec.Sec. 
65.143(a), 65.145(a), or 65.147(a) due to planned routine maintenance.
    (3) A description of the planned routine maintenance that is 
anticipated to be performed for the control system during the next 6-
month periodic reporting period when the control system is not expected 
to meet the required control efficiency. This description shall include 
the type of maintenance necessary, planned frequency of maintenance, and 
expected lengths of maintenance periods.
    (e) If a nonflare control device, including a halogen reduction 
device for a low-throughput transfer rack, is used to control emissions 
from storage vessels or low-throughput transfer racks, the periodic 
report shall identify and state the cause for each occurrence when the 
monitored parameters were

[[Page 137]]

outside of the parameter ranges documented in the Initial Compliance 
Status Report in accordance with Sec. 65.165(b).
    (f) For process vents and high-throughput transfer racks, periodic 
reports shall include the following information:
    (1) Periodic reports shall include the daily average values of 
monitored parameters, calculated as specified in Sec. 
65.161(c)(1) for any days when the daily average value is outside the 
bounds as specified in Sec. 65.162(b)(3) or (c)(3), or the 
data availability requirements defined in Sec. 65.156(d)(1) 
are not met, whether these excursions are excused or unexcused 
excursions. For excursions caused by lack of monitoring data, the 
duration of periods when monitoring data were not collected shall be 
specified.
    (2) Report all carbon-bed regeneration cycles during which the 
parameters recorded under Sec. 65.162(c)(2) were outside the 
ranges established in the Initial Compliance Status Report or in the 
operating permit.
    (3) The provisions of paragraphs (f)(1) and (2) of this section do 
not apply to any low-throughput transfer rack for which the owner or 
operator has elected to comply with Sec. 65.145, or to any 
storage vessel for which the owner or operator is not required by the 
applicable monitoring plan established under Sec. 65.165(c)(1) 
and (2) to keep continuous records. If continuous records are required, 
the owner or operator shall specify in the monitoring plan whether the 
provisions of paragraphs (f)(1) and (2) of this section apply.
    (4) If the owner or operator has chosen to use the alternative 
recordkeeping provisions of Sec. 65.161(e)(1) and has not 
notified the Administrator in the Initial Compliance Status Report that 
the alternative recordkeeping provisions are being implemented as 
provided in Sec. 65.165(e), the owner or operator shall notify 
the Administrator in the periodic report submitted immediately before 
implementation of the alternative.


Sec. 65.167  Other reports.

    (a) Replacing an existing control or recovery device. As specified 
in Sec.Sec. 65.147(b)(2), 65.148(b)(3), 
65.149(b)(3), 65.150(b)(2), 65.151(b)(2), 65.152(b)(2), or 65.153(b)(2), 
if an owner or operator at a facility not required to obtain a title V 
permit elects at a later date to use a different control or recovery 
device, then the Administrator shall be notified by the owner or 
operator before implementing the change. This notification may be 
included in the facility's periodic reporting and shall include a 
description of any changes made to the closed vent system.
    (b) Startup, shutdown, and malfunction periodic reports. Startup, 
shutdown, and malfunction periodic reports shall be submitted as 
required in Sec. 65.6(c).


Sec.Sec. 65.168-65.169  [Reserved]



PART 66 - ASSESSMENT AND COLLECTION OF NONCOMPLIANCE PENALTIES BY EPA--Table of Contents




                   Subpart A - Purpose and Scope

Sec.
66.1 Applicability and effective date.
66.2 Program description.
66.3 Definitions.
66.4 Limitation on review of regulations.
66.5 Savings clause.
66.6 Effect of litigation; time limits.

                Subpart B - Notice of Noncompliance

66.11 Issuance of notices of noncompliance.
66.12 Content of notices of noncompliance.
66.13 Duties of source owner or operator upon receipt of a notice of 
          noncompliance.

         Subpart C - Calculation of Noncompliance Penalties

66.21 How to calculate the penalty.
66.22 Contracting out penalty calculation.
66.23 Interim recalculation of penalty.

      Subpart D - Exemption Requests; Revocation of Exemptions

66.31 Exemptions based on an order, extension or suspension.
66.32 De Minimis exemptions.
66.33 De Minimis exemptions: malfunctions.
66.34 Termination of exemptions.
66.35 Revocation of exemptions.

   Subpart E - Decisions on Exemption Requests and Challenges to 
                        Notices of Noncompliance

66.41 Decision on petitions.
66.42 Procedure for hearings.

[[Page 138]]

66.43 Final decision; submission of penalty calculation.

             Subpart F - Review of Penalty Calculation

66.51 Action upon receipt of penalty calculation.
66.52 Petitions for reconsideration of calculation.
66.53 Decisions on petitions.
66.54 Procedures for hearing.

                        Subpart G - Payment

66.61 Duty to pay.
66.62 Method of payment.
66.63 Nonpayment penalty.

            Subpart H - Compliance and Final Adjustment

66.71 Determination of compliance.
66.72 Additional payment or reimbursement.
66.73 Petition for reconsideration and procedure for hearing.
66.74 Payment or reimbursement.

                      Subpart I - Final Action

66.81 Final action.

  Subpart J - Supplemental Rules for Formal Adjudicatory Hearings

66.91 Applicability of supplemental rules.
66.92 Commencement of hearings.
66.93 Time limits.
66.94 Presentation of evidence.
66.95 Decisions of Presiding Officer; appeal to the Administrator.

Appendix A to Part 66 - Technical Support Document [Note]
Appendix B to Part 66 - Instruction Manual [Note]
Appendix C to Part 66 - Computer Program [Note]

    Authority: Sec. 120, Clean Air Act, as amended, 42 U.S.C. 7420.

    Source: 45 FR 50110, July 28, 1980, unless otherwise noted.



                   Subpart A - Purpose and Scope



Sec. 66.1  Applicability and effective date.

    (a) This part applies to all proceedings for the assessment by EPA 
of a noncompliance penalty as provided by section 120 of the Clean Air 
Act. This penalty is designed to recover the economic advantage which 
might otherwise accrue to a source by reason of its failure to comply 
with air pollution control standards after receipt of a notice of 
noncompliance.
    (b) These regulations shall be effective October 27, 1980.



Sec. 66.2  Program description.

    This part sets forth the procedures by which EPA will administer the 
noncompliance penalty provisions of section 120 of the Clean Air Act. 
Subpart A describes the scope of the part, defines key terms and states 
the manner of operation of these provisions subpart B states which 
sources of air pollution are subject to these penalties and the form and 
substance of the notice of noncompliance. Subpart C and the accompanying 
Technical Support Document and Manual state how a source must compute 
the penalty which it owes. Subpart D describes the conditions under 
which an exemption from the penalty may be available, and subpart E sets 
forth the procedures for requesting such an exemption. Subpart F states 
how EPA will review penalties calculated by sources under subpart C, and 
subpart G describes the method of payment. Subpart H provides for 
adjustment of the penalty after the source has come into compliance and 
the actual costs of doing so are known. Finally, subpart I states which 
actions under these regulations are subject to judicial review and on 
what conditions, and subpart J provides supplemental procedures for 
adjudicatory hearings.



Sec. 66.3  Definitions.

    In this part and part 67:
    (a) Act means the Clean Air Act, 42 U.S.C. 7401 et seq. as amended 
on August 7, 1977, except where the context specifically indicates 
otherwise.
    (b) Affiliated entity means a person who directly, or indirectly 
through one or more intermediaries, controls, is controlled by, or is 
under common control with the owner or operator of a source.
    (c) Applicable legal requirements means any of the following:
    (1) In the case of any major source, any emission limitation, 
emission standard, or compliance schedule under any EPA-approved State 
implementation plan (regardless of whether the source is subject to a 
Federal or State consent decree);
    (2) In the case of any source, an emission limitation, emission 
standard,

[[Page 139]]

standard of performance, or other requirement (including, but not 
limited to, work practice standards) established under section 111 or 
112 of the Act;
    (3) In the case of a source that is subject to a federal or 
federally approved state judicial consent decree or EPA approved 
extension, order, or suspension, any interim emission control 
requirement or schedule of compliance under that consent decree, 
extension, order or suspension;
    (4) In the case of a nonferrous smelter which has received a primary 
nonferrous smelter order issued or approved by EPA under Section 119 of 
the Act, any interim emission control requirement (including a 
requirement relating to the use of supplemental or intermittent 
controls) or schedule of compliance under that order.
    (d) Approved Section 120 program means a State program to assess and 
collect Section 120 penalties that has been approved by the 
Administrator.
    (e) Computer program means the computer program used to calculate 
noncompliance penalties under section 120 of the Clean Air Act. This 
computer program appears as appendix C to these regulations.
    (f) Control (including the terms controlling, controlled by, and 
under common control with) means the power to direct or cause the 
direction of the management and policies of a person or organization, 
whether by the ownership of stock, voting rights, by contract, or 
otherwise.
    (g) Environmental Appeals Board shall mean the Board within the 
Agency described in Sec. 1.25 of this title. The Administrator 
delegates authority to the Environmental Appeals Board to issue final 
decisions in appeals filed under this part. Appeals directed to the 
Administrator, rather than to the Environmental Appeals Board, will not 
be considered. This delegation of authority to the Environmental Appeals 
Board does not preclude the Environmental Appeals Board from referring 
an appeal or a motion filed under this part to the Administrator for 
decision when the Environmental Appeals Board, in its discretion, deems 
it appropriate to do so. When an appeal or motion is referred to the 
Administrator, all parties shall be so notified and the rules in this 
part referring to the Environmental Appeals Board shall be interpreted 
as referring to the Administrator.
    (h) Major stationary source means any stationary facility or source 
of air pollutants which directly emits, or has the potential to emit, 
one hundred tons per year or more of any air pollutant regulated by EPA 
under the Clean Air Act.
    (i) Manual means the Noncompliance Penalties Instruction Manual 
which accompanies these regulations. This Manual appears as appendix B 
to these regulations.
    (j) Owner or operator means any person who owns, leases, operates or 
supervises a facility, building, structure or installation which emits 
or has the potential to emit any air pollutant regulated by EPA under 
the Act.
    (k) Potential to emit means the capability at maximum design 
capacity to emit a pollutant after the application of air pollution 
control equipment. Annual potential shall be based on the larger of the 
maximum annual rated capacity of the stationary source assuming 
continuous operation, or on a projection of actual annual emissions. 
Enforceable permit conditions on the type of materials combusted or 
processed may be used in determining the annual potential. Fugitive 
emissions, to the extent quantifiable, will be considered in determining 
annual potential for those stationary sources whose fugitive emissions 
are regulated by the applicable state implementation plan.
    (l) Source means any source of air pollution subject to applicable 
legal requirements as defined in paragraph (c).
    (m) Technical Support Document means the Noncompliance Penalties 
Technical Support Document which accompanies these regulations. The 
Technical Support Document appears as appendix A to these regulations.

All other terms are defined as they are in the Act.

[45 FR 50110, July 28, 1980, as amended at 57 FR 5328, Feb. 13, 1992]



Sec. 66.4  Limitation on review of regulations.

    No applicable legal requirement, which could have been reviewed or

[[Page 140]]

challenged by means of the timely filing of an appropriate petition, no 
provision of this part or part 67 or appendices A, B or C, may be 
challenged, reviewed or re-examined in any hearing conducted under this 
part or part 67. This limitation on review includes, but is not limited 
to:
    (a) Arguments that the statute is more or less restrictive than the 
regulations, e.g., that exemptions other than those provided herein 
should be granted.
    (b) Arguments that the economic model does not accurately calculate 
the economic benefits of noncompliance, or that parameters, terms and 
conditions other than those provided for in the model should be used or 
that evidence other than that described in the Technical Support 
Document for establishing inputs should be considered.



Sec. 66.5  Savings clause.

    Proceedings under these regulations for imposition of a penalty 
under section 120 are in addition to any other proceedings related to 
permits, orders, payments, sanctions or other requirements of State or 
Federal law. No action under this part or part 67 shall affect in any 
way any administrative, civil or criminal enforcement proceeding brought 
under any provision of the Clean Air Act or State or local law.



Sec. 66.6  Effect of litigation; time limits.

    (a) The existence of any litigation on the validity of these 
regulations shall not affect the authority of the Agency to issue 
notices of noncompliance or to conduct subsequent administrative 
proceedings under parts 66 and 67.
    (b) Failure of the Environmental Appeals Board or the Presiding 
Officer at a hearing to meet any of the time limits contained in this 
part 66 and part 67 of this chapter shall not affect the validity of any 
proceeding under these regulations.
    (c) The filing of any petition for reconsideration under this part 
or part 67 or the institution of EPA review of a State determination 
under part 67 shall not toll the accrual of noncompliance penalties. The 
penalty will be calculated from the date on which the source owner or 
operator receives a notice of noncompliance.

[45 FR 50110, July 28, 1980, as amended at 57 FR 5329, Feb. 13, 1992]



                Subpart B - Notice of Noncompliance



Sec. 66.11  Issuance of notices of noncompliance.

    (a) The Administrator shall issue a notice of noncompliance to the 
owner or operator of any source which he determines is in violation of 
applicable legal requirements and which is located in a State without an 
approved section 120 program.
    (b) The Administrator shall send a notice of noncompliance to the 
owner or operator of any source located in a State with an approved 
section 120 program when he determines as provided in part 67 that the 
source is in violation of applicable legal requirements and the State 
has failed to send a notice of noncompliance to it, or has failed to 
pursue diligently any subsequent steps for the assessment or collection 
of the penalty.
    (c) Failure of EPA or a State to issue a notice of noncompliance 
within 30 days after discovery of a violation shall not affect the 
obligation of a source owner or operator to pay a noncompliance penalty 
but shall affect the date from which the penalty is calculated. The 
penalty shall be calculated from the earliest date that the owner or 
operator of the source received a notice of noncompliance under this 
section, whether issued by EPA or the State.



Sec. 66.12  Content of notices of noncompliance.

    (a) Each notice of noncompliance shall be in writing and shall 
include:
    (1) A specific reference to each applicable legal requirement of 
which the source is in violation;
    (2) A brief statement of the factual basis for the finding of 
violation, together with a reference to any supporting materials and a 
statement of when and where they may be inspected;
    (3) Instructions on calculating the amount of the penalty owed and 
the schedule for payments. Such instructions shall include (i) a 
statement of the date from which penalties should

[[Page 141]]

be calculated and (ii) a copy of the Technical Support Document and the 
Manual;
    (4) Notice of the right to petition for a hearing to challenge the 
finding of noncompliance or to claim an exemption; and
    (5) Notice that the penalty continues to accrue during the pendency 
of any hearings granted under this part or Part 67.
    (b) Each notice of noncompliance shall be transmitted to the source 
owner or operator either by personal service or by registered or 
certified mail, return receipt requested.



Sec. 66.13  Duties of source owner or operator upon receipt of a notice of noncompliance.

    (a) Within forty-five days after receiving a notice of noncompliance 
a source owner or operator shall either:
    (1) Calculate the amount of the penalty owed and the appropriate 
quarterly payment schedule, as provided in the Technical Support 
Document and Instruction Manual, and transmit that calculation, together 
with supporting data sufficient to allow verification of the penalty 
calculation, to the Administrator; or
    (2) Submit a petition for reconsideration, alleging that the source 
is not in violation of applicable legal requirements or that the source 
owner or operator is entitled to an exemption pursuant to 
Sec.Sec. 66.31 through 66.33, or both. A source 
owner or operator must present both grounds in the petition if he wishes 
to preserve a claim to an exemption in the event that the source is 
found to be in violation. Issues relating to the existence of a 
violation or entitlement to an exemption not raised in the petition 
shall be deemed waived.
    (b) Any submittal pursuant to this subsection shall specify the 
identity of the person responsible for the payment of any noncompliance 
penalty, and to whom any reimbursement, if necessary, shall be sent.
    (c) A source owner or operator may amend any petition for 
reconsideration pursuant to paragraph (a) of this section within 45 days 
from receipt of a notice of noncompliance. Amendment of such petition 
after 45 days will be permitted only if based on unforeseeable 
conditions occurring after termination of the 45 day period, or upon 
consent of the Administrator.



         Subpart C - Calculation of Noncompliance Penalties



Sec. 66.21  How to calculate the penalty.

    (a) All noncompliance penalties shall be calculated in accordance 
with the Technical Support Document and the Manual.
    (b) Where the Administrator determines that no existing technology 
or other emissions control method results in emission levels which 
satisfy the applicable legal requirement, the penalty calculation shall 
be based on the cost of the capital equipment, operation and maintenance 
practices, or other methods of control which best approximates the 
degree of control required. In such a case, the Administrator may 
include in the penalty the costs of participation in an EPA approved 
research and development program where he determines that such 
participation would be appropriate. Information on appropriate research 
and development programs will be available from the regional offices or 
from the Office of Research and Development.



Sec. 66.22  Contracting out penalty calculation.

    Upon the failure of a source owner or operator, who does not submit 
a petition for reconsideration as provided in Sec. 
66.13(a)(2), to submit the information described in Sec. 
66.13(a)(1) within 45 days of receipt of a notice of noncompliance, or 
upon submission of incorrect information as determined pursuant to 
Sec. 66.51, the Administrator may enter into a contract with 
any qualified person who is not an affiliated entity and who has no 
financial interest in the owner or operator of the source to assist in 
determining the amount of the penalty assessment or payment schedule 
with respect to such source owner or operator. The cost of this contract 
may be added to the penalty to be assessed against the owner or operator 
of the source. The data used in calculating the penalty shall be 
furnished to the source owner or operator at the time that the penalty 
calculation is reported.

[[Page 142]]



Sec. 66.23  Interim recalculation of penalty.

    (a) The Administrator, upon concluding that a previously approved 
penalty calculation no longer is accurate, may:
    (1) Request, in writing, that the source owner or operator submit a 
revised calculation in the form specified in Sec. 66.13(a). 
The Administrator shall respond to any information submitted in 
accordance with the provisions of Sec. 66.51.
    (2) Notify the source owner or operator, in writing, that the 
penalty has been recalculated based upon information in the 
Administrator's possession. The source owner or operator shall respond 
as provided in Sec. 66.52.
    (b) If a source owner or operator believes that, because of changed 
circumstances, a penalty calculation which has been accepted by EPA no 
longer is accurate, he may submit a revised penalty calculation and 
schedule to the Administrator. The revised calculation shall be in the 
form specified in Sec. 66.13(a)(1). The Administrator shall 
respond in accordance with the provisions of Sec. 66.51. The 
decision to accept the interim calculation or to grant a hearing on this 
issue shall be solely within the discretion of the Administrator.



      Subpart D - Exemption Requests; Revocation of Exemptions



Sec. 66.31  Exemptions based on an order, extension or suspension.

    (a) A source owner or operator who would otherwise be subject to a 
noncompliance penalty will be exempted from that penalty during the 
period for which, and upon a demonstration that, its noncompliance with 
applicable legal requirements is or was due solely to;
    (1) A conversion by such source from the burning of petroleum 
products or natural gas, or both, as the permanent primary energy source 
to the burning of coal pursuant to an order under section 113(d)(5) or 
section 119 of the Act as in effect before August 7, 1977.
    (2) In the case of a coal-burning source, the issuance of a 
prohibition to that source against burning petroleum products or natural 
gas, or both, by means of an order under sections 2(a) and (b) of the 
Energy Supply and Environmental Coordination Act of 1974, the Powerplant 
and Industrial Fuel Use Act, or under any legislation which amends or 
supersedes these provisions, Provided, That the source had received an 
extension under the second sentence of section 119(c)(1) of the Act as 
in effect before August 7, 1977.
    (3) The use of innovative technology by the source owner or operator 
pursuant to an enforcement order under section 113(d)(4) of the Act.
    (4) An inability to comply with an applicable legal requirement 
resulting from reasons entirely beyond the control of the owner or 
operator of such source or of any affiliated entity, Provided, That
    (i) The source owner or operator has received an order under section 
113(d) (or an order under section 113 issued before August 7, 1977) or a 
federal or EPA-approved State judicial decree or order which has the 
effect of permitting a delay in complying with the legal requirement at 
issue, and
    (ii) That the source owner or operator meets the requirements of 
paragraphs (c) and (d) of this section.
    (5) The existence of an energy or employment emergency demonstrated 
by issuance of an order under section 110(f) or 110(g) of the Act, 
unless such order is disapproved by EPA.
    (b) To qualify for an exemption under this section, the source owner 
or operator must have received the order, extension or suspension or 
consent decree described in the paragraph of the section pursuant to 
which the exemption is claimed. No exemption may be sought which, if 
granted, would exceed the terms of the relevant extension, order, 
suspension, or consent decree, except as provided in paragraph (e) of 
this section. No exemption may be sought which is based on a claim that 
the source owner or operator is entitled to any such order, extension, 
suspension, or consent decree even though it has not been issued.
    (c) In any exemption claim based on paragraph (a)(4) of this 
section, the source owner or operator must demonstrate:
    (1) That the source owner or operator or an affiliated entity in no 
manner

[[Page 143]]

sought, caused, encouraged or contributed to the inability; and
    (2) That the source owner or operator in no way unduly delayed 
negotiation for needed equipment or fuel supply or made unusual demands 
not typical in its industry, or placed unusual restrictions on the 
supplier, or delayed in any other manner the delivery of goods or the 
completion of the necessary construction.
    (d)(1) No exemption will be granted pursuant to paragraph (a)(4) of 
this section unless the owner or operator of the source demonstrates 
that, with respect to a situation described in paragraph (c), all 
reasonable steps were taken to prevent the situation causing the 
inability to comply, that procuring the needed pollution control 
equipment or fuel supply was given and continues to be given the highest 
possible priority in the planning and budgeting process of the owner or 
operator of the source, and that alternative sources of equipment and 
fuel have been explored without success.
    (2) Any exemption granted under paragraph (a)(4) of this section 
shall cease to be effective when the inability to comply ceases to be 
entirely beyond the control of the source owner or operator as defined 
in this section.
    (e) Except in the case of exemptions based on orders under section 
113 (d)(4) or (d)(5) or suspensions under section 110(g), the 
Administrator may grant an exemption with retroactive effect to the date 
of the event giving rise to the section 120 predicate order, extension, 
suspension, or consent decree. In such cases, the exemption from the 
noncompliance penalty shall run from the date that the basis for the 
exemption first occurred.

[45 FR 50110, July 20, 1980, as amended at 50 FR 36734, Sept. 9, 1985]



Sec. 66.32  De Minimis exemptions.

    (a) The Administrator may, upon notice and opportunity for public 
hearing, exempt the owner or operator of any source from a penalty where 
he finds that a particular instance of noncompliance was de minimis in 
nature and duration.
    (b) A petition for an exemption on the ground that the violation 
described in a notice of noncompliance was de minimis in nature and 
duration may only raise issues related to entitlement to an exemption 
and shall contain or be accompanied by supporting documentation. Issues 
relating to entitlement to a de minimis exemption not raised in the 
petition shall be deemed waived.
    (c) In ruling upon such a petition, the Administrator shall 
consider:
    (1) The magnitude of the excess emissions and whether the source's 
noncompliance is recurring or persistent;
    (2) The steps the source owner or operator is taking to eliminate 
the cause of the excess emissions and to minimize such emissions;
    (3) Whether any significant economic savings are likely to accrue to 
the owner or operator of the source as a result of the noncompliance;
    (4) The character of the emissions, and their impact on ambient air 
quality; and
    (5) The duration of the violation.
    (d) A hearing on a petition for a de minimis exemption shall be 
informal. The hearing shall be scheduled upon notice to the public. 
Reasonable opportunity to testify and for submission of questions by the 
public to the petitioner shall be afforded. The decision of the hearing 
officer will be made in writing within a reasonable period of time after 
the close of the hearing.



Sec. 66.33  De Minimis exemptions: malfunctions.

    (a) The Administrator may, upon notice and opportunity for a public 
hearing, exempt the owner or operator of a source if he finds with 
respect to a particular instance of noncompliance, that such 
noncompliance was de minimis in nature and duration, and was caused 
solely by a sudden and unavoidable breakdown of process or pollution 
control equipment.
    (b) A petition for an exemption on the ground that the violation was 
de minimis and was caused by a sudden and unavoidable breakdown of 
process or pollution control equipment may only raise issues related to 
entitlement to an exemption and shall contain or be accompanied by 
supporting documentation. Issues relating to entitlement to an exemption 
that are not raised in the petition shall be deemed

[[Page 144]]

waived. In making such finding the Administrator shall consider whether:
    (1) The violation was de minimis in nature and duration within the 
meaning of Sec. 66.32;
    (2) The air pollution control equipment, process equipment, or 
processes, including appropriate back-up systems, were designed, and 
have been maintained and operated in a manner consistent with good 
practice for minimizing emissions;
    (3) Repair of the malfunctioning equipment was undertaken and 
carried out in an expeditious fashion as soon as the owner or operator 
knew or should have known that the malfunction existed or that 
applicable emission limitations were being violated or were likely to be 
violated;
    (4) All practicable steps were taken to minimize the impact of the 
excess emissions (including any bypass) on ambient air quality;
    (5) The excess emissions were not part of a pattern indicative of 
inadequate design, operation, or maintenance;
    (6) Off-shift and overtime labor were utilized where necessary to 
ensure that repairs were made as expeditiously as possible or that 
emissions were minimized to the maximum extent possible; and
    (7) The level of economic savings, if any, accruing to the source 
owner or operator was de minimis.
    (c) Any activity that could have been foreseen, avoided or planned 
for, or any breakdown that could have been avoided by the exercise of 
reasonable diligence shall not constitute grounds for an exemption under 
this section. Such activities include, but are not limited to, sudden 
breakdowns avoidable by better maintenance procedures, phasing in and 
out of process equipment and routine maintenance.
    (d) A hearing on any petition for an exemption based upon the 
unavoidable breakdown of pollution control equipment shall be informal. 
The hearing shall be scheduled upon notice to the public. Reasonable 
opportunity to testify and for submission of questions by the public to 
the petitioner shall be afforded. The decision of the hearing officer 
will be made in writing within a reasonable period of time after the 
close of the hearing.



Sec. 66.34  Termination of exemptions.

    (a) Exemptions pursuant to Sec. 66.31(a) (1), (2), (3), 
and (5) will cease to be effective upon termination or revocation of the 
order on which the exemption is based.
    (b) Exemptions pursuant to Sec. 66.31(a)(4) will cease to 
be effective when the order or decree is terminated or revoked, or the 
inability to comply ceases to be for reasons entirely beyond the control 
of the source owner or operator as defined in Sec. 66.31(c).
    (c) Exemptions granted pursuant to Sec. 66.32 or 
Sec. 66.33 shall terminate at the time specified in the 
exemption.
    (d) The Administrator shall notify the source owner or operator, in 
writing, that the exemption has terminated, and shall specify the date 
from which the penalty shall be calculated. The notice shall be 
transmitted as required by Sec. 66.12. The source owner or 
operator shall respond to this notice within 45 days of its receipt and 
in the form provided in Sec. 66.13.



Sec. 66.35  Revocation of exemptions.

    (a) The Administrator may upon notice and opportunity for a hearing 
revoke an exemption granted to the owner or operator of any source at 
any time in accordance with paragraphs (b) and (c) below.
    (b) An exemption may be revoked and a penalty for the period of non-
exempted noncompliance assessed if:
    (1) The grounds for the exemption no longer exist or never did 
exist, or
    (2) In the case of an exemption under Sec. 66.31, the 
source owner or operator has failed to comply with any interim emission 
control requirements or schedules of compliance (including increments of 
progress) contained in the extension, order, suspension or EPA-approved 
consent decree on which the exemption was based.
    (c) The Administrator shall provide the source owner or operator 
written notice containing the information required by Sec. 
66.12 and a statement of the reasons for revocation. The notice shall 
also specify the date from which the source owner or operator must 
calculate a penalty. The notice shall be

[[Page 145]]

transmitted as required by Sec. 66.12. The source owner or 
operator shall respond to this notice within 45 days of its receipt and 
in the form provided in Sec. 66.13.



   Subpart E - Decisions on Exemption Requests and Challenges to 
                        Notices of Noncompliance



Sec. 66.41  Decision on petitions.

    (a) Within thirty days after receiving a petition filed under 
Sec. 66.13, the Administrator shall notify the source owner or 
operator in writing that:
    (1) The petition demonstrates that the source owner or operator is 
entitled to part or all of the relief requested and that the notice of 
noncompliance is withdrawn or modified accordingly;
    (2) The petition does not contain sufficient information to 
demonstrate that the source owner or operator is entitled to part or all 
of the relief requested. The Administrator shall specify what 
deficiencies exist and request that the source owner or operator 
supplement his petition within thirty days of receipt of that request. 
If the petition is not supplemented adequately within this time, or, if 
supplemented adequately, still fails to demonstrate entitlement to 
relief, the Administrator shall grant a hearing under paragraph (a)(3) 
of this section. Any supplemental material provided pursuant to the 
Administrator's request shall be evaluated as provided in paragraphs 
(a)(1) and (a)(3) of this section.
    (3) A hearing is granted on the issue of whether the source is in 
violation of applicable legal requirements or is entitled to an 
exemption under Sec.Sec. 66.31, 66.32, 66.33, or on 
both.

[45 FR 50110, July 20, 1980, as amended at 50 FR 36734, Sept. 9, 1985]



Sec. 66.42  Procedure for hearings.

    (a) Except as provided in Sec.Sec. 66.32 and 
66.33, hearings granted under Sec. 66.41(a)(3) shall be held 
as provided in Subpart J.
    (b) If hearings are granted pursuant to both Sec. 66.32 or 
Sec. 66.33 and under Subpart J, a consolidated hearing in 
accordance with Subpart J shall be held. At the consolidated hearing the 
issues that would otherwise have been considered at a hearing under 
Sec. 66.32 or Sec. 66.33 shall be considered 
pursuant to the procedures for a hearing provided in those sections.
    (c) The Presiding Officer at a hearing granted under Sec. 
66.41 shall issue an initial decision within 90 days after the 
Administrator grants the hearing, unless the duration of the hearing or 
the deadline for decision is extended by the Presiding Officer upon 
agreement of the parties. Failure to issue a decision (whether or not by 
consent) within 90 days shall not affect the validity of the proceedings 
or the accrual of penalties in any manner.



Sec. 66.43  Final decision; submission of penalty calculation.

    Within forty-five days after EPA has notified the owner or operator 
of a source of the final Agency decision that it is in violation of 
applicable legal requirements or is not entitled to an exemption, the 
owner or operator shall submit the information required by 
Sec. 66.13(a), including appropriate compliance and payment 
schedules and extra interest owed for the period of delay. The penalty 
shall be calculated from the date of receipt of the original notice of 
noncompliance.



             Subpart F - Review of Penalty Calculation



Sec. 66.51  Action upon receipt of penalty calculation.

    (a) Within thirty days after receipt of a penalty calculation 
provided pursuant to Sec. 66.13(a)(1) or Sec. 66.43, 
the Administrator shall notify the source owner or operator in writing, 
that:
    (1) The penalty is provisionally accepted as calculated, subject to 
any recalculation that may be necessary under Sec. 66.72 after 
the source has achieved compliance; or
    (2) The penalty is incorrect and has been recalculated based on the 
data provided by the source owner or operator, or other data. The 
Administrator shall provide a brief statement of the basis for the 
recalculation and shall identify when and where any supporting data may 
be examined. The Administrator shall also notify the source

[[Page 146]]

owner or operator of the right to petition for a hearing under 
Sec. 66.52; or
    (3) The source owner or operator has not submitted any calculation, 
or the information submitted is inadequate to enable EPA to verify the 
owner or operator's penalty calculation. The Administrator shall specify 
what deficiencies exist and request the source owner or operator to 
supplement his submission within thirty days of receipt of that request. 
If an inadequate supplemental submission is made within this time, EPA 
may calculate the penalty itself or as provided in Sec. 66.22.
    (b) Supplemental material provided pursuant to paragraph (a)(3) of 
this section shall be evaluated as provided in paragraph (a).



Sec. 66.52  Petitions for reconsideration of calculation.

    Within forty-five days after receipt of notice under Sec. 
66.51(a)(2) that the penalty has been recalculated by EPA, a source 
owner or operator who wishes to challenge EPA's recalculation shall 
petition in writing for reconsideration. A statement of all arguments on 
which the owner or operator relies, including all necessary supporting 
data and a substitute penalty calculation and payment schedule shall be 
included in or accompany this petition. Issues not raised in the 
petition shall be deemed waived.



Sec. 66.53  Decisions on petitions.

    Within thirty days after receiving a petition for reconsideration 
under Sec. 66.52 the Administrator shall:
    (a) Accept the penalty calculation of the owner or operator to the 
extent the Administrator concludes it is correct; or
    (b) Grant a hearing to the extent he does not conclude that the 
petition is correct.

[45 FR 50110, July 20, 1980, as amended at 50 FR 36734, Sept. 9, 1985]



Sec. 66.54  Procedures for hearing.

    (a) Hearings granted under Sec. 66.53 shall be held as 
provided in subpart J.
    (b) The Presiding Officer at a hearing granted under Sec. 
66.53 shall issue an initial decision within ninety days after the 
Administrator grants the hearing, unless the duration of the hearing or 
the deadline for decision is extended by the Presiding Officer upon 
agreement of the parties. Failure to issue a decision (whether or not by 
consent) within 90 days shall not affect the validity of the proceedings 
or the accrual of penalties in any manner.



                        Subpart G - Payment



Sec. 66.61  Duty to pay.

    (a) Except where the owner or operator has submitted a petition 
pursuant to Sec. 66.13(a)(2), the first installment of the 
penalty shall be paid on the date six months after receipt of the notice 
of noncompliance.
    (b) Where the source owner has filed a petition pursuant to 
Sec. 66.13(a)(2), the first installment consisting of payment 
of penalties for all quarters ``missed'' as 
well as for the upcoming quarter shall be paid on the date six months 
after a final administrative decision affirming the source owner or 
operator's liability. Installments shall be paid quarterly thereafter 
until compliance is achieved. Quarters shall be measured in increments 
of three calendar months from the date the first payment is due.
    (c) A source owner or operator who submits a petition pursuant to 
Sec. 66.52 shall pay the penalty amount calculated by the 
owner or operator under Sec. 66.13 or Sec. 66.43 or 
any penalty calculated by EPA where the owner or operator has failed to 
calculate such penalty. Within 45 days after EPA has notified the owner 
or operator of a final administrative action after hearings on such 
petition, the owner or operator shall submit any necessary modification 
to the penalty. The revised penalty will be calculated in accordance 
with the Technical Support Document and the Manual, and a revised 
schedule, including appropriate adjustments for overpayments or 
underpayments made, will be established.



Sec. 66.62  Method of payment.

    Payments in excess of $10,000 under this part shall be made by wire 
transfer payable to the U.S. Treasury. Payments under this part which 
are less than $10,000 shall be made by cashier's or certified check made 
payable to the United States Treasury, sent by registered mail, return 
receipt requested,

[[Page 147]]

and addressed to the Administrator, Environmental Protection Agency, 
1200 Pennsylvania Ave., NW., Washington, DC 20460. Payment by check is 
made on the due date if it is postmarked on or before the due date. 
Payment by wire transfer is made on the due date if the Treasury's 
account is credited on or before the due date.



Sec. 66.63  Nonpayment penalty.

    (a) Any source owner or operator who fails to make timely payment 
under Sec. 66.61 shall pay in addition to the penalty owed a 
quarterly nonpayment penalty. The nonpayment penalty shall be calculated 
as of the due date of the noncompliance penalty payment and shall be 
equal to 20 percent of the aggregate amount of the noncompliance 
penalties and nonpayment penalties due and owing from the owner or 
operator on the due date. Partial payments shall be credited first 
against the nonpayment penalty, then against the noncompliance penalty.
    (b) The Administrator shall notify the source owner or operator in 
writing of the amount of any nonpayment penalty for which the owner or 
operator is liable. Failure of the Administrator to provide such notice 
immediately shall not affect the legal obligation of the source owner or 
operator to pay such penalty. Such nonpayment penalty, as well as the 
past due noncompliance penalty, shall be payable immediately.



            Subpart H - Compliance and Final Adjustment



Sec. 66.71  Determination of compliance.

    (a) An owner or operator of a source who is paying a noncompliance 
penalty under this part shall notify the Administrator in writing when 
he believes that the source has come into and is maintaining compliance 
with all applicable legal requirements. The notice shall be accompanied 
by any factual data, analytical materials, and legal arguments which the 
source owner or operator believes support such claim.
    (b) Within 30 days of receipt of a source owner's submittal, the 
Administrator shall determine whether the source has achieved and is 
maintaining compliance with applicable legal requirements, and shall 
notify the source owner or operator of this determination in writing. If 
the Administrator is unable to conclude, on the basis of the information 
submitted, whether the source has achieved and is maintaining compliance 
with applicable legal requirements, he shall inform the owner or 
operator of any additional material that is needed. Within 30 days of 
receipt of such additional material, the Administrator shall determine 
whether the source has achieved and is maintaining compliance, and shall 
notify the source owner or operator of this determination in writing.
    (c) If the Administrator determines that the source has not achieved 
or is not maintaining compliance with applicable legal requirements, the 
source owner or operator may petition for reconsideration within 30 days 
of receipt of the determination. The source owner or operator shall 
include in this petition any necessary supporting material. Issues not 
raised in the petition will be deemed waived. The procedures of 
Sec. 66.41 shall be followed upon the receipt of such 
petition.
    (d) In the event that the applicable legal requirement (as defined 
in Sec. 66.3(c)) the violation of which forms the basis for 
the penalty is superseded by another applicable legal requirement (as 
defined in Sec. 66.3(c)) the owner or operator of a source 
liable for a noncompliance penalty under this part shall notify the 
Administrator in writing that the owner or operator believes that the 
applicable legal requirement is superseded and that the period of 
noncompliance covered by the notice of noncompliance is ended. The 
notice shall be accompanied by the legal arguments which the source 
owner or operator believes support such a claim. Within 30 days of 
receipt of a source owner or operator's notice, the Administrator shall 
determine whether the period of covered noncompliance is ended and shall 
notify the source owner or operator of this determination in writing. In 
cases where the superseding EPA-approved requirement was not approved by 
EPA within the time period required by statute, the period of covered 
noncompliance shall be deemed to have ended on the date when

[[Page 148]]

EPA under the statute should have acted.

[45 FR 50110, July 20, 1980, as amended at 50 FR 36734, Sept. 9, 1985]



Sec. 66.72  Additional payment or reimbursement.

    (a) Within 120 days after the source owner or operator receives 
notification pursuant to Sec. 66.71(b) that it has achieved 
and is maintaining compliance with applicable legal requirements, or 
within 120 days after receipt of a decision to that effect upon petition 
and hearing, or within 120 days after receipt of a decision to that 
effect upon an appeal to the Environmental Appeals Board, the source 
owner or operator shall submit to the Administrator a revised penalty 
calculation as provided in the Technical Support Document and the 
Manual, together with data necessary for verification. The revised 
calculation shall include interest on any underpayment.
    (b) Within thirty days after receiving a revised penalty calculation 
provided pursuant to paragraph (a) of this section, the Administrator 
shall inform the source owner or operator in writing that:
    (1) The revised penalty is correct as calculated;
    (2) The revised penalty is incorrect and has been recalculated based 
on the data provided by the source owner or operator or on other data. 
The Administrator shall provide to the source owner or operator a brief 
statement of the basis of the recalculation and shall identify when and 
where any supporting data may be examined. The Administrator shall also 
notify the source owner or operator of the right to petition for 
reconsideration under Sec. 66.73; or
    (3) The source owner or operator has not submitted any penalty 
calculation, or has not submitted enough material to enable EPA to 
verify the penalty calculation. The Administrator shall specify what 
deficiencies exist and shall require the source owner or operator to 
furnish the supplemental material within thirty days of receipt of the 
notice. The supplemental material submitted will be evaluated in the 
same manner as the original submittal.
    (c) If a source owner or operator fails to submit or to complete a 
revised penalty calculation when due under this section or the 
calculation submitted is incorrect, the Administrator may recalculate 
the penalty or may enter into a contract for independent calculation of 
the penalty as provided in Sec. 66.22.
    (d) Within 120 days after the source owner or operator receives 
notification pursuant to Sec. 66.71(d) that the period of 
covered noncompliance ended on the date the applicable legal requirement 
was superseded (or, in event of EPA delay past an applicable statutory 
deadline, on the date the applicable legal requirement would have been 
superseded if there had been no delay past the statutory deadline), the 
source owner or operator shall submit to the Administrator a revised 
penalty calculation as provided in the Technical Support Document and 
Manual together with data necessary for verification. The revised 
calculation shall include interest on any underpayment. Paragraphs (b) 
and (c) shall apply to calculations submitted under this paragraph.

[45 FR 50110, July 20, 1980 as amended at 50 FR 36734, Sept. 9, 1985; 57 
FR 5329, Feb. 13, 1992]



Sec. 66.73  Petition for reconsideration and procedure for hearing.

    Within forty-five days of receipt of a notice under Sec. 
66.72(b) (2) a source owner or operator may petition for reconsideration 
in the form and manner provided in Sec. 66.52. The petition 
shall be evaluated as provided in Sec. 66.53 and any hearing 
shall be held in conformity with Sec. 66.54.



Sec. 66.74  Payment or reimbursement.

    (a) Within thirty days after any adjustment of a noncompliance 
penalty under this Subpart has become administratively final:
    (1) Any deficiency owed by the source owner or operator shall be 
paid as provided in Sec. 66.62.
    (2) Any reimbursement shall be paid by check from the United States 
payable to the order of the source owner or operator, and sent by 
registered or certified mail, return receipt requested.
    (b) Any payment under paragraph (a) of this section, shall include 
interest

[[Page 149]]

on the amount of the deficiency or reimbursement due, from the date the 
deficiency or reimbursement arose, at a rate determined by the Secretary 
of the Treasury. Such payment shall be calculated in accordance with the 
Technical Support Document and the Manual.
    (c) Any source owner or operator who fails to make timely payment of 
a deficiency shall pay a nonpayment penalty. The nonpayment penalty 
shall be calculated as of the due date of the deficiency payment and 
shall be equal to 20% of the deficiency not paid. Such nonpayment 
penalty (in addition to the amount of the deficiency owed) shall be 
payable immediately. If any part of the nonpayment penalty or deficiency 
shall remain unpaid at the end of three calendar months from the due 
date of the deficiency, a further nonpayment penalty shall be due equal 
to 20% of the sum of all payments due and owing. Partial payments shall 
be credited first against the nonpayment penalty, then the deficiency.



                      Subpart I - Final Action



Sec. 66.81  Final action.

    (a) A final Agency action appealable to the courts by the source 
owner or operator includes and is limited to the following, provided the 
conditions of paragraph (b) of this section are met:
    (1) A notice of determination that a source is in violation of 
applicable legal requirements;
    (2) A notice of decision to deny or revoke an exemption under 
subpart D;
    (3) A notice of revision by EPA of a penalty calculation or schedule 
under subpart F;
    (4) A notice of decision by EPA that the source is not in final 
compliance or any revision by EPA of a final penalty calculation under 
subpart H; and
    (5) A notice of denial of a petition for reconsideration under 
Sec. 66.71 or Sec. 66.73.
    (6) A decision by the Administrator upon completion of any review of 
a State action pursuant to part 67.
    (b) The actions listed in paragraph (a) of this section constitute 
final Agency action only if all administrative remedies have been 
exhausted. To exhaust administrative remedies, a source owner or 
operator must first petition for reconsideration of the decision in 
question and, if unsuccessful after hearing or after denial of hearing, 
appeal the decision in question to the Environmental Appeals Board. The 
action becomes final upon the completion of review by the Environmental 
Appeals Board and notice thereof to the owner or operator of the source.
    (c) Where a petition seeks reconsideration both of the finding of 
noncompliance and of the finding of liability on the ground that the 
source owner or operator is entitled to an exemption, both questions 
must be decided before any review by the Environmental Appeals Board is 
sought, except on agreement of the parties.

[45 FR 50110, July 20, 1980, as amended at 50 FR 36734, Sept. 9, 1985; 
57 FR 5329, Feb. 13, 1992]



  Subpart J - Supplemental Rules for Formal Adjudicatory Hearings



Sec. 66.91  Applicability of supplemental rules.

    The Supplemental Rules in this subpart, in conjunction with the 
Consolidated Rules of Practice (40 CFR part 22) shall govern all 
hearings held under this part. To the extent that the provisions of 
these Supplemental Rules or any other provision of this part are 
inconsistent with the Consolidated Rules, the provisions of this part 
shall govern.



Sec. 66.92  Commencement of hearings.

    (a) The provisions of 40 CFR 22.08 (Consolidated Rules of Practice) 
shall become applicable when the Administrator grants a hearing.
    (b) Upon granting a hearing the Administrator shall immediately 
transmit to the appropriate Regional Hearing Clerk two copies of the 
notice granting the hearing and:
    (1) In the case of a hearing pursuant to Sec. 66.42, two 
copies of the notice of noncompliance under Sec. 66.11 (or the 
revocation notice under Sec. 66.34) and of the petition of the 
owner or operator under Sec. 66.13, together with supporting 
documents; and
    (2) In the case of a hearing pursuant to Sec. 66.53 or 
Sec. 66.73, two copies of the penalty calculation of the 
source owner or operator provided pursuant to

[[Page 150]]

Sec. 66.13(a) or Sec. 66.72, and of any Agency 
recalculation pursuant to Sec. 66.51(a)(2) or Sec. 
66.72(b)(2), and of the petition of the source owner or operator for 
reconsideration pursuant to Sec. 66.52 or Sec. 
66.73, together with supporting documents.
    (3) The Regional Hearing Clerk shall open and maintain the official 
file of the proceeding upon receipt of the documents referred to in 
paragraphs (b)(1) and (2) of this section.
    (c) Upon granting a hearing the Administrator shall request the 
Chief Administrative Law Judge to designate an Administrative Law Judge 
to serve as the Presiding Officer. The Chief Administrative Law Judge 
shall make this designation within seven days of receiving the request, 
and shall notify the Regional Hearing Clerk of his action. The Regional 
Hearing Clerk shall forward to the Presiding Officer one set of the 
documents described in paragraph (b).



Sec. 66.93  Time limits.

    The Presiding Officer upon designation shall notify the parties and 
shall, if appropriate, schedule a prehearing conference (or alternative 
procedures) under 40 CFR 22.19 and shall notify the parties of the date 
of hearing under 40 CFR 22.21. The Presiding Officer shall issue an 
initial decision no later than ninety days after the hearing is granted, 
unless an extension of the hearing schedule or of the deadline for 
decision is agreed to by the parties. To that end, the Presiding Officer 
may establish such deadlines as are reasonable and necessary. Failure to 
issue a decision within 90 days or further extended deadline (whether or 
not by consent) shall not affect the validity of the proceedings.



Sec. 66.94  Presentation of evidence.

    (a) In hearings pursuant to Sec. 66.42 EPA shall present 
evidence of violation of applicable legal requirements. The source owner 
or operator shall then present any rebuttal evidence.
    (b) In hearings under Sec. 66.42 the source owner or 
operator shall present evidence of entitlement to an exemption. EPA 
shall then present any rebuttal evidence.
    (c) In hearings under Sec.Sec. 66.54 and 66.73 
EPA shall present evidence that its calculation or revisions of the 
source owner or operator's penalty calculations are correct. The source 
owner or operator shall then present any rebuttal evidence.
    (d) Each matter of controversy shall be determined by the Presiding 
Officer upon a preponderance of the evidence.
    (e) Any documentation submitted pursuant to Sec. 66.92(b) 
shall automatically be received into evidence in the hearing.



Sec. 66.95  Decisions of the Presiding Officer; Appeal to the Administrator.

    (a) The Presiding Officer shall dispose of the issues raised in the 
hearing in a single written decision. Such decision shall terminate the 
Presiding Officer's consideration of those issues.
    (b) Penalty calculations and payment schedules, if any, established 
by the decision of the Presiding Officer shall be based solely on the 
parameters, terms and conditions of the Technical Support Document, 
Manual, and Computer Program.
    (c) An appeal to the Environmental Appeals Board from a decision of 
the Presiding Officer shall be made by petition filed within twenty (20) 
days from receipt by a party of the Presiding Officer's decision. The 
Environmental Appeals Board shall rule on the appeal within 30 days of 
receipt of a petition. No appeal may be made before receipt of the 
decision of the Presiding Officer.

[45 FR 50110, July 20, 1980, as amended at 57 FR 5329, Feb. 13, 1992]

    Appendix A to Part 66 - Technical Support Document

    Note: For text of appendix A see appendix A to part 67.

        Appendix B to Part 66 - Instruction Manual

    Note: For text of appendix B see appendix B to part 67.

         Appendix C to Part 66 - Computer Program

    Note: For text of appendix C see appendix C to part 67.

[[Page 151]]



PART 67 - EPA APPROVAL OF STATE NONCOMPLIANCE PENALTY PRO[chyph]GRAM--Table of Contents




                   Subpart A - Purpose and Scope

Sec.
67.1 Purpose and scope.

               Subpart B - Approval of State Programs

67.11 Standards for approval of State programs.
67.12 Application for approval of programs.
67.13 Approval.
67.14 Amendments to the program.
67.15 Revocation.

 Subpart C - Federal Notice of Noncompliance to Sources in States 
                         With Approved Programs

67.21 Federal notice of noncompliance to owners or operators of sources 
          in States with approved programs.

 Subpart D - EPA Review of State Compliance or Exemption Decisions

67.31 Review by the Administrator.
67.32 Procedure where no formal State hearing was held.
67.33 Procedure where a formal State hearing was held.

        Subpart E - EPA Review of State Penalty Assessments

67.41 When EPA may review.
67.42 Procedure where no formal State hearing was held.
67.43 Procedure where a formal State hearing was held.

Appendix A to Part 67 - Technical Support Document [Note]
Appendix B to Part 67 - Instruction Manual [Note]
Appendix C to Part 67 - Computer Program [Note]

    Authority: Sec. 120 of the Clean Air Act, as amended, 42 U.S.C. 
7420, unless otherwise noted.

    Source: 45 FR 50117, July 28, 1980, unless otherwise noted.



                   Subpart A - Purpose and Scope



Sec. 67.1  Purpose and scope.

    This part describes the standards and procedures under which EPA 
will approve State programs for administering the noncompliance penalty 
program under section 120 of the Clean Air Act and will evaluate actions 
taken by States with approved programs. Subpart A describes the purpose 
of the part. Subpart B states the conditions under which EPA will 
approve State programs to administer the noncompliance penalty 
provisions. Subparts C and D state when and how EPA will issue its own 
notices to owners or operators of sources in States with approved 
programs, and how it will review State decisions to grant or deny 
exemptions from the penalty. Finally, subpart E states how EPA will 
review State assessments of a penalty.



               Subpart B - Approval of State Programs



Sec. 67.11  Standards for approval of State programs.

    (a) The Administrator shall approve any program submitted by a 
State, or by a local governmental agency where no program has been 
submitted by a State, for administering the noncompliance penalty 
provisions of section 120 of the Clean Air Act upon finding that the 
program conforms to the requirements of the Act and to those of this 
part and 40 CFR part 66. References to ``State 
program'' in this part shall be read as including local 
governmental agencies and their programs.
    (b) The Administrator shall not approve any State program that does 
not provide explicitly for:
    (1) Issuance of a notice of noncompliance, in a manner consistent 
with procedures under part 66, upon discovery by the State or upon 
notification by EPA of a violation of applicable legal requirements, 
which notice satisfies the informational requirements set forth in 
Sec. 66.13.
    (2) Levels of staffing and funding satisfactory, in the judgment of 
the Administrator, to implement and enforce the requirements of section 
120 in that State, together with adequate provision for maintaining such 
levels;
    (3) A capability to carry out the financial analysis and procedures 
specified in these regulations and the Technical Support Document, 
Instruction Manual, and related Computer Program, available from the 
Director of Stationary Source Compliance Division, EN-341, 1200 
Pennsylvania Ave.,

[[Page 152]]

NW., Washington, DC 20460, together with adequate provision for 
maintaining such capability. Such capability may be provided by trained 
State personnel or through qualified contractors;
    (4) Except as provided in paragraph (a)(6) of this section, an 
administrative hearing whenever the owner or operator of a source 
submits a petition for reconsideration of a notice of noncompliance on 
the ground that the source either is not in violation of applicable 
legal requirements, or is entitled to an exemption, or both, or submits 
a petition to challenge a recalculation of the penalty by the State, 
provided that such petitions raise issues of fact that would require a 
hearing under part 66. This hearing need not conform to the requirements 
of 5 U.S.C. 554 as long as its procedures provide for:
    (i) An initial decision by the hearing officer on the record;
    (ii) A hearing officer who has not performed investigative or 
litigating functions in any enforcement action against the source owner 
or operator in question;
    (iii) Opportunity for public participation on reasonable notice, 
including intervention, by interested persons;
    (iv) Opportunity for cross-examination or an equivalent opportunity 
for confrontation between persons advocating differing positions on 
material factual matters; and
    (v) An initial decision by the hearing officer within ninety days of 
commencement of the hearing unless such period is extended upon 
agreement of the parties.
    (5) Explicit provision for:
    (i) Notice to the Administrator of any determination granting an 
exemption, or finding a source in violation of applicable legal 
requirements, and any penalty calculation and payment schedule approved 
or calculated by the State, together with any information necessary to 
verify its accuracy;
    (ii) Within 30 days of receipt of a request from the Administrator, 
transmission of a copy of the record of the hearing held under paragraph 
(a)(4) or (6) of this section, including any proffered evidence and a 
ruling on its admissibility and the State's decision on the merits; and
    (iii) Additional reporting and recordkeeping, if necessary, adequate 
to enable the Administrator to review the State's administration of the 
program and determine whether it conforms to the Act and to part 66 of 
these regulations. Such requirements will be specified in the Notice of 
Delegation to the State.
    (6) A hearing on the question of whether the owner or operator of a 
source is entitled to an exemption pursuant to Sec. 66.32 or 
66.33 may be informal. The hearing shall be scheduled upon notice to the 
public. Reasonable opportunity to testify and for submission of 
questions to the petitioner by members of the public shall be afforded. 
A record of the hearing shall be made, and the decision of the hearing 
officer made in writing within a reasonable period of time after the 
close of the hearing.
    (c) The State may delegate all or part of its responsibilities under 
its program to a local governmental agency to implement the program 
within the jurisdiction of the local agency, Provided that the program 
of the local government agency meets the requirements of this section.
    (d) No State penalty program or program of one of its agents shall 
be disapproved because it is more stringent than the program established 
by part 66 or by section 120 where the State or local agent concludes 
that it has independent authority under State or local law to implement 
and administer the more stringent portions of the program.

[45 FR 50117, July 28, 1980, as amended at 54 FR 25259, June 14, 1989]



Sec. 67.12  Application for approval of programs.

    A state that wishes to administer a section 120 program shall submit 
an application in writing to the Administrator describing its proposed 
program. All necessary supporting materials shall accompany the 
application.



Sec. 67.13  Approval.

    (a) The Administrator shall evaluate any application submitted under 
Sec. 67.12 and shall:

[[Page 153]]

    (1) Approve the program and delegate authority to the State to 
administer the program if he determines that the requirements of 
Sec. 67.11 have been and will be met; or
    (2) Request additional information if he determines that the 
information submitted is not sufficient to allow him to determine 
whether the requirements of Sec. 67.11 have been and will be 
met; or
    (3) Disapprove the State program if he determines that the 
information submitted establishes that the requirements of 
Sec. 67.11 have not been or will not be met.
    (b) The Administrator shall notify the State in writing of his 
action under paragraph (a) of this section and shall state the reasons 
for his action.
    (c) In all cases of delegation (whether or not express provision is 
made in the notice of delegation) the Administrator shall retain 
continuing authority to issue notices of noncompliance, review exemption 
requests or penalty calculations, or take any other steps set forth in 
part 66 to assess and collect these penalties. Such authority shall be 
exercised pursuant to the provisions of Sec. 67.21.
    (d) The Administrator shall retain exclusive authority to assess and 
collect penalties against source owners or operators of facilities in 
the State who were issued notices of noncompliance pursuant to part 66 
prior to the effective date of the delegation, except to the extent the 
Administrator specifically delegates such authority to the State.



Sec. 67.14  Amendments to the program.

    A State or local agent with a program approved pursuant to 
Sec. 67.13 may propose amendments to that program to the 
Administrator. The Administrator shall evaluate whether the State or 
local agent's program as amended would conform to the requirements of 
Sec. 67.11 and shall respond as provided in Sec. 
67.13.



Sec. 67.15  Revocation.

    If the Administrator determines that a State with a program approved 
under Sec. 67.13 is not administering the program in 
conformity with the requirements of the Act or Sec. 67.11, or 
the delegation of authority, he shall provide the State written notice 
of that determination, setting forth his reasons. Copies of all 
supporting materials shall accompany the notice if requested, or shall 
be placed on file in the appropriate Regional Office and made available 
for inspection during normal business hours. The State shall have 90 
days in which to respond in writing to this determination. If the 
Administrator finds after reviewing the State response that (a) the 
State is in fact administering the program in conformity with 
Sec. 67.11, or (b) there are reasonable grounds to believe the 
State program will immediately be brought into conformity with that 
section, he shall withdraw his determination. If he finds that neither 
of these conditions has been met, he shall withdraw the delegation of 
authority to the State.



 Subpart C - Federal Notice of Noncompliance to Sources in States 
                         With Approved Programs



Sec. 67.21  Federal notice of noncompliance to owners or operators of sources in States with approved programs.

    (a) The Administrator shall issue a notice of noncompliance to the 
owner or operator of any source in a State with an approved program if 
he determines that the State or its local agent has failed to issue such 
notice, provided that he shall first give 30 days notice to the State of 
his intent to issue a notice of noncompliance to the owner or operator 
of the source in question unless the State or its agent does so first. 
Any notice issued by the Administrator pursuant to this section shall be 
deemed to be issued pursuant to the provisions of part 66.
    (b) The issuance of a notice of noncompliance shall operate to 
withdraw EPA delegation of authority to the State with respect to the 
particular facility in question.
    (c) If the Administrator determines that the State or local agent 
has issued a notice of noncompliance but has failed to pursue diligently 
subsequent steps for the assessment and collection of the penalty, he 
shall notify the

[[Page 154]]

State of his intent to withdraw delegation of authority to the State 
with respect to the facility in question and take appropriate actions 
pursuant to part 66 unless the State or local agent, within 30 days, 
takes appropriate action in accordance with the requirements of this 
part. In either case the penalty will be calculated from the date of the 
State notice.



 Subpart D - EPA Review of State Compliance or Exemption Decisions



Sec. 67.31  Review by the Administrator.

    (a) The Administrator may, on his own initiative, review any 
determination by a State or its agent that a source owner or operator is 
or is not in compliance with applicable legal requirements or is or is 
not entitled to an exemption, to determine whether that determination 
conforms to the requirements of the Act and part 66 (as modified by 
Sec. 67.11).
    (b) The Administrator shall review any such determination upon 
receipt of a petition alleging that the State's determination does not 
conform to the requirements of the Act and part 66 (as modified by 
Sec. 67.11). Such petition must be filed within 20 days of 
issuance of the State's decision.
    (c) The Administrator shall give notice in writing to the State or 
local agent, to the owner or operator of the source, and to the 
petitioner of his intent to review the determination. Such notice shall 
be given within 90 days of the Administrator's receipt of the State or 
local agent's determination. Unless otherwise provided, such notice 
shall not withdraw EPA's delegation of authority to the State or local 
agent over the particular facility in question.
    (d) No such State determination shall become final until the 
expiration of 90 days after the Administrator's receipt of the notice 
required by Sec. 67.11(b)(5).
    (1) If the Administrator does not issue a notice of intent to review 
within that period, the State determination shall, upon expiration of 
such period, constitute final action of the Administrator under section 
120 of the Act.
    (2) If the Administrator issues a notice of intent to review within 
that period, the State determination shall not become final until the 
Administrator takes final action after reviewing the determination.
    (e) Except as otherwise provided, a State determination shall be 
approved if there was a reasonable basis in law and in fact for making 
the determination.



Sec. 67.32  Procedure where no formal State hearing was held.

    (a) In reviewing a decision that a source is in compliance with 
applicable legal requirements or entitled to an exemption for which no 
hearing conforming to Sec. 67.11(b) (4) or (6) was held, the 
Administrator shall evaluate the accuracy and adequacy of the documents 
transmitted to him pursuant to Sec. 67.11(b)(5) and shall 
invite submission of comments on issues identified by him as relevant to 
his review.
    (b) If the Administrator concludes that no hearing need have been 
held and that the State determination was correct, he shall notify the 
State, the source owner or operator, and other participants of his 
determination, which shall constitute final agency action by EPA under 
authority of section 120. If the Administrator concludes that the 
petition of the source owner or operator presented information which, if 
true, would have altered the owner or operator's liability for a 
penalty, he shall upon notice to the State or local agent schedule a 
hearing in accordance with subpart E of part 66. Such notice shall 
operate as a withdrawal of EPA's delegation of authority to the State or 
local agent over the facility in question unless the State or local 
agent schedules a hearing within 15 days of receipt of the notice.
    (c) If the Administrator concludes that the State determination did 
not conform to the requirements of the Act or of part 66 (as modified by 
Sec. 67.11), he shall by written notice revoke the 
determination. Such revocation shall operate as a withdrawal of EPA's 
delegation of authority to the State or local agent over the facility in 
question. The source owner or operator may then petition for review of 
the Administrator's decision pursuant to the provisions of 
Sec. 66.13.
    (d) Unless otherwise provided in the Administrator's notice to the 
State or

[[Page 155]]

local agent, any noncompliance penalties owed by the source owner or 
operator shall be paid to the State or local agent. The Administrator 
shall send a copy of this notice to the source owner or operator.



Sec. 67.33  Procedure where a formal State hearing was held.

    (a) In reviewing a decision that a source is in compliance with 
applicable legal requirements or is entitled to an exemption for which a 
hearing conforming to Sec. 67.11(b) (4) or (6) was held, the 
Administrator may invite comment on issues identified by him as relevant 
to his review and shall propose or make findings as to the correctness 
of the determination and the accuracy and adequacy of the material 
transmitted pursuant to Sec. 67.11(b)(5).
    (b) The Administrator shall notify all participants in the State 
hearing of his findings and conclusions. If the Administrator concludes 
that the State determination conformed to the requirements of the Act 
and of part 66 (as modified by Sec. 66.11), the 
Administrator's determination shall constitute final administrative 
action by EPA under authority of Section 120. If the Administrator finds 
that the State determination did not conform to the requirements of the 
Act and of part 66 (as modified by Sec. 67.11), the findings 
shall constitute proposed findings and the notice shall invite 
participants to file exceptions thereto. If the Administrator considers 
it desirable, he may schedule a time for argument.
    (c) Within 60 days of receipt of any briefs or exceptions or after 
oral argument pursuant to paragraph (b), the Administrator shall affirm, 
modify, or revoke his proposed findings that the State's determination 
did not conform to the requirements of the Act or of part 66 (as 
modified by Sec. 67.11). The decision shall be in writing. 
Notice and a copy of the decision shall be provided to the source owner 
or operator and to all other participants in the State hearing. The 
decision shall constitute a final administrative action by EPA under 
authority of section 120.
    (d) If the Administrator finds that deficiencies in the hearing 
record prevent him from determining whether the determination of the 
State or local agent conformed to the requirements of the Act and part 
66 (as modified by Sec. 67.11), he shall notify the State or 
local agent of his finding and specify what deficiencies exist and 
schedule a hearing pursuant to subpart E of part 66. Such notice shall 
operate as a withdrawal of EPA's delegation of authority to the State or 
local agent over the facility in question unless the State or local 
agent schedules a supplemental hearing to correct the deficiencies 
within 15 days of receipt of the notice.
    (e) If the Administrator concludes that the source is in violation 
of applicable legal requirements or is not entitled to an exemption, or 
both, and unless otherwise ordered in the decision, the source owner or 
operator shall submit a penalty calculation to the State within 45 days 
of receipt of the notice of determination.



        Subpart E - EPA Review of State Penalty Assessments



Sec. 67.41  When EPA may review.

    (a) The Administrator may on his own initiative or on petition 
review any initial, interim, or final penalty calculation made or 
approved by the State or local agent to determine whether it conforms to 
the requirements of the Act, of part 66, of the Technical Support 
Document and the Instruction Manual. The Administrator shall notify the 
State or local agent in writing of his intention to review the 
calculation within 60 days of receipt by EPA of the calculation or any 
item considered by the State in making or approving such calculation, 
whichever occurs later.
    (b) No such State determination shall become final until the 
expiration of 90 days after the Administrator's receipt of the notice 
required by Sec. 67.11(b)(5).
    (1) If the Administrator does not issue a notice of intent to review 
within that period, the State determination shall, upon expiration of 
such period, constitute final action of the Administrator under section 
120 of the Act.
    (2) If the Administrator issues a notice of intent to review within 
that period, the State determination shall not become final until the 
Administrator takes final action after reviewing the determination.

[[Page 156]]

    (c) Except as otherwise provided, a State determination shall be 
approved if there was a reasonable basis in law and in fact for making 
the determination.



Sec. 67.42  Procedure where no formal State hearing was held.

    (a) In reviewing a penalty calculation for which no hearing 
conforming to the requirements of Sec. 67.11(b)(4) was held, 
the Administrator shall evaluate the accuracy and adequacy of the data 
contained in the documents transmitted to him pursuant to Sec. 
67.11(b)(5) and shall invite comments on issues identified by him as 
relevant to his review.
    (b) If the Administrator concludes that no hearing need have been 
held and that the State determination was correct, he shall notify the 
State, the source owner or operator, and other participants of his 
determination, which shall constitute final agency action by EPA under 
authority of section 120. If the Administrator concludes that the 
petition of the source owner or operator for reconsideration of a 
recalculation presented information which, if true, would have altered 
the amount of the penalty calculated, he shall upon notice to the State 
schedule a hearing in accordance with subpart F of part 66. Such notice 
shall operate as a withdrawal of EPA's delegation of authority to the 
State or local agent over the facility in question unless the State or 
local agent schedules a hearing within 15 days of receipt of the notice.
    (c) If the Administrator concludes that the determination of the 
State or local agent not to hold a hearing was proper but that the 
penalty calculation does not conform to the requirements of the Act or 
of part 66, he shall by written notice revoke the determination and 
issue a notice of recalculation to the source owner or operator pursuant 
to Sec. 66.51. A copy of the notice of recalculation shall be 
provided to the State or local agent. The notice of recalculation shall 
constitute final administrative action by EPA under authority of section 
120 unless the source owner or operator petitions for reconsideration 
under Sec. 66.52, in which case it shall operate as a 
withdrawal by EPA of its delegation of authority to the State or local 
agent over the facility in question.
    (d) Unless otherwise provided in the Administrator's notice, 
noncompliance penalties finally determined to be owed shall be paid to 
the State or local agent.



Sec. 67.43  Procedure where a formal State hearing was held.

    (a) In reviewing a penalty calculation for which a hearing 
conforming to Sec. 67.11(b)(4) was held, the Administrator may 
invite comment on issues identified by him as relevant to his review and 
shall propose or make findings as to the correctness of the 
determination and shall evaluate the accuracy and adequacy of the 
material transmitted pursuant to Sec. 67.11(b)(5).
    (b) The Administrator shall notify all participants in the State 
hearing of his findings and conclusions. If the Administrator finds that 
the State determination conformed to the requirements of the Act, part 
66 (as modified by Sec. 67.11), the Technical Support 
Document, and the Instruction Manual, his determination shall constitute 
a final action pursuant to section 120. If the Administrator finds that 
the State determination did not conform to the requirements of the Act 
or of part 66 (as modified by Sec. 67.11) or to the Technical 
Support Document or Instruction Manual, the findings shall constitute 
proposed findings, and the notice shall invite participants to file 
exceptions to his proposed findings and, if necessary, schedule a time 
for argument.
    (c) Within 60 days of receipt of any briefs or exceptions or after 
oral argument, the Administrator shall affirm, modify, or revoke his 
proposed findings that the State or local agent's determination did not 
conform to the requirements of the Act or of part 66 (as modified by 
Sec. 67.11) or the Technical Support Document or Instruction 
Manual. The decision shall be in writing. Notice and a copy of the 
decision, which shall constitute final administrative action by EPA 
pursuant to section 120, shall be provided to the source owner or 
operator and to all other participants in the State hearing.
    (d) If the Administrator finds that deficiencies in the State or 
local agent's hearing record prevent him

[[Page 157]]

from determining whether the State or local agent's determination 
conformed to the requirements of the Act and part 66 (as modified by 
Sec. 67.11) or the Technical Support Document or Instruction 
Manual, he shall notify the State or local agent of his decision and 
specify what dificiencies exist and schedule a hearing in accordance 
with subpart F of part 66. Such notice shall operate to withdraw EPA's 
delegation of authority to the State or local agent over the facility in 
question unless the State or local agent within 15 days schedules a 
supplemental hearing to correct the deficiencies.
    (e) Unless otherwise provided in the Administrator's notice to the 
State or local agent, any noncompliance penalties owed by the source 
owner or operator shall be paid to the State or local agent.

    Appendix A to Part 67 - Technical Support Document

    Note: EPA will make copies of appendix A available from: Director, 
Stationary Source Compliance Division, EN-341, 1200 Pennsylvania Ave., 
NW., Washington, DC 20460.

[54 FR 25259, June 20, 1989]

        Appendix B to Part 67 - Instruction Manual

    Note: EPA will make copies of appendix B available from: Director, 
Stationary Source Compliance Division, EN-341, 1200 Pennsylvania Ave., 
NW., Washington, DC 20460.

[54 FR 25259, June 20, 1989]

         Appendix C to Part 67 - Computer Program

    Note: EPA will make copies of appendix C available from: Director, 
Stationary Source Compliance Division, EN-341, 1200 Pennsylvania., NW., 
Washington, DC 20460.

[54 FR 25259, June 20, 1989]



PART 68 - CHEMICAL ACCIDENT PREVENTION PROVISIONS--Table of Contents




                        Subpart A - General

Sec.
68.1 Scope.
68.2 Stayed provisions.
68.3 Definitions.
68.10 Applicability.
68.12 General requirements.
68.15 Management.

                   Subpart B - Hazard Assessment

68.20 Applicability.
68.22 Offsite consequence analysis parameters.
68.25 Worst-case release scenario analysis.
68.28 Alternative release scenario analysis.
68.30 Defining offsite impacts - population.
68.33 Defining offsite impacts - environment.
68.36 Review and update.
68.39 Documentation.
68.42 Five-year accident history.

              Subpart C - Program 2 Prevention Program

68.48 Safety information.
68.50 Hazard review.
68.52 Operating procedures.
68.54 Training.
68.56 Maintenance.
68.58 Compliance audits.
68.60 Incident investigation.

              Subpart D - Program 3 Prevention Program

68.65 Process safety information.
68.67 Process hazard analysis.
68.69 Operating procedures.
68.71 Training.
68.73 Mechanical integrity.
68.75 Management of change.
68.77 Pre-startup review.
68.79 Compliance audits.
68.81 Incident investigation.
68.83 Employee participation.
68.85 Hot work permit.
68.87 Contractors.

                   Subpart E - Emergency Response

68.90 Applicability.
68.95 Emergency response program.

 Subpart F - Regulated Substances for Accidental Release Prevention

68.100 Purpose.
68.115 Threshold determination.
68.120 Petition process.
68.125 Exemptions.
68.126 Exclusion.
68.130 List of substances.

                  Subpart G - Risk Management Plan

68.150 Submission.
68.151 Assertion of claims of confidential business information.
68.152 Substantiating claims of confidential business information.
68.155 Executive summary.
68.160 Registration.
68.165 Offsite consequence analysis.
68.168 Five-year accident history.
68.170 Prevention program/Program 2.
68.175 Prevention program/Program 3.
68.180 Emergency response program.

[[Page 158]]

68.185 Certification.
68.190 Updates.

                   Subpart H - Other Requirements

68.200 Recordkeeping.
68.210 Availability of information to the public.
68.215 Permit content and air permitting authority or designated agency 
          requirements.
68.220 Audits.

Appendix A to Part 68 - Table of Toxic Endpoints

    Authority: 42 U.S.C 7412(r), 7601 (a)(1).

    Source: 59 FR 4493, Jan. 31, 1994, unless otherwise noted.



                        Subpart A - General



Sec. 68.1  Scope.

    This part sets forth the list of regulated substances and 
thresholds, the petition process for adding or deleting substances to 
the list of regulated substances, the requirements for owners or 
operators of stationary sources concerning the prevention of accidental 
releases, and the State accidental release prevention programs approved 
under section 112(r). The list of substances, threshold quantities, and 
accident prevention regulations promulgated under this part do not limit 
in any way the general duty provisions under section 112(r)(1).



Sec. 68.2  Stayed provisions.

    (a) Notwithstanding any other provision of this part, the 
effectiveness of the following provisions is stayed from March 2, 1994 
to December 22, 1997.
    (1) In Sec. 68.3, the definition of ``stationary 
source,'' to the extent that such definition includes 
naturally occurring hydrocarbon reservoirs or transportation subject to 
oversight or regulation under a state natural gas or hazardous liquid 
program for which the state has in effect a certification to DOT under 
49 U.S.C. 60105;
    (2) Section 68.115(b)(2) of this part, to the extent that such 
provision requires an owner or operator to treat as a regulated 
flammable substance:
    (i) Gasoline, when in distribution or related storage for use as 
fuel for internal combustion engines;
    (ii) Naturally occurring hydrocarbon mixtures prior to entry into a 
petroleum refining process unit or a natural gas processing plant. 
Naturally occurring hydrocarbon mixtures include any of the following: 
condensate, crude oil, field gas, and produced water, each as defined in 
paragraph (b) of this section;
    (iii) Other mixtures that contain a regulated flammable substance 
and that do not have a National Fire Protection Association flammability 
hazard rating of 4, the definition of which is in the NFPA 704, Standard 
System for the Identification of the Fire Hazards of Materials, National 
Fire Protection Association, Quincy, MA, 1990, available from the 
National Fire Protection Association, 1 Batterymarch Park, Quincy, MA 
02269-9101; and
    (3) Section 68.130(a).
    (b) From March 2, 1994 to December 22, 1997, the following 
definitions shall apply to the stayed provisions described in paragraph 
(a) of this section:
    Condensate means hydrocarbon liquid separated from natural gas that 
condenses because of changes in temperature, pressure, or both, and 
remains liquid at standard conditions.
    Crude oil means any naturally occurring, unrefined petroleum liquid.
    Field gas means gas extracted from a production well before the gas 
enters a natural gas processing plant.
    Natural gas processing plant means any processing site engaged in 
the extraction of natural gas liquids from field gas, fractionation of 
natural gas liquids to natural gas products, or both. A separator, 
dehydration unit, heater treater, sweetening unit, compressor, or 
similar equipment shall not be considered a ``processing 
site'' unless such equipment is physically located within 
a natural gas processing plant (gas plant) site.
    Petroleum refining process unit means a process unit used in an 
establishment primarily engaged in petroleum refining as defined in the 
Standard Industrial Classification code for petroleum refining (2911) 
and used for the following: Producing transportation fuels (such as 
gasoline, diesel fuels, and jet fuels), heating fuels (such as kerosene, 
fuel gas distillate, and fuel oils), or lubricants; separating 
petroleum; or separating, cracking, reacting, or reforming intermediate 
petroleum streams. Examples of such units include, but are

[[Page 159]]

not limited to, petroleum based solvent units, alkylation units, 
catalytic hydrotreating, catalytic hydrorefining, catalytic 
hydrocracking, catalytic reforming, catalytic cracking, crude 
distillation, lube oil processing, hydrogen production, isomerization, 
polymerization, thermal processes, and blending, sweetening, and 
treating processes. Petroleum refining process units include sulfur 
plants.
    Produced water means water extracted from the earth from an oil or 
natural gas production well, or that is separated from oil or natural 
gas after extraction.
    (c) Notwithstanding any other provision of this part, the 
effectiveness of part 68 is stayed from June 21, 1999 to December 21, 
1999 with respect to regulated flammable hydrocarbon substances when the 
substance is intended for use as a fuel and does not exceed 67,000 
pounds in a process that is not manufacturing the fuel, does not contain 
greater than a threshold quantity of another regulated substance, and is 
not collocated or interconnected to another covered process.

[59 FR 4493, Jan. 31, 1994, as amended at 61 FR 31731, June 20, 1996; 64 
FR 29170, May 28, 1999]



Sec. 68.3  Definitions.

    For the purposes of this part:
    Accidental release means an unanticipated emission of a regulated 
substance or other extremely hazardous substance into the ambient air 
from a stationary source.
    Act means the Clean Air Act as amended (42 U.S.C. 7401 et seq.)
    Administrative controls mean written procedural mechanisms used for 
hazard control.
    Administrator means the administrator of the U.S. Environmental 
Protection Agency.
    AIChE/CCPS means the American Institute of Chemical Engineers/Center 
for Chemical Process Safety.
    API means the American Petroleum Institute.
    Article means a manufactured item, as defined under 29 CFR 
1910.1200(b), that is formed to a specific shape or design during 
manufacture, that has end use functions dependent in whole or in part 
upon the shape or design during end use, and that does not release or 
otherwise result in exposure to a regulated substance under normal 
conditions of processing and use.
    ASME means the American Society of Mechanical Engineers.
    CAS means the Chemical Abstracts Service.
    Catastrophic release means a major uncontrolled emission, fire, or 
explosion, involving one or more regulated substances that presents 
imminent and substantial endangerment to public health and the 
environment.
    Classified information means ``classified 
information'' as defined in the Classified Information 
Procedures Act, 18 U.S.C. App. 3, section 1(a) as ``any 
information or material that has been determined by the United States 
Government pursuant to an executive order, statute, or regulation, to 
require protection against unauthorized disclosure for reasons of 
national security.''
    Condensate means hydrocarbon liquid separated from natural gas that 
condenses due to changes in temperature, pressure, or both, and remains 
liquid at standard conditions.
    Covered process means a process that has a regulated substance 
present in more than a threshold quantity as determined under 
Sec. 68.115.
    Crude oil means any naturally occurring, unrefined petroleum liquid.
    Designated agency means the state, local, or Federal agency 
designated by the state under the provisions of Sec. 68.215(d) 
.
    DOT means the United States Department of Transportation.
    Environmental receptor means natural areas such as national or state 
parks, forests, or monuments; officially designated wildlife 
sanctuaries, preserves, refuges, or areas; and Federal wilderness areas, 
that could be exposed at any time to toxic concentrations, radiant heat, 
or overpressure greater than or equal to the endpoints provided in 
Sec. 68.22(a) , as a result of an accidental release and that 
can be identified on local U. S. Geological Survey maps.
    Field gas means gas extracted from a production well before the gas 
enters a natural gas processing plant.
    Hot work means work involving electric or gas welding, cutting, 
brazing, or

[[Page 160]]

similar flame or spark-producing operations.
    Implementing agency means the state or local agency that obtains 
delegation for an accidental release prevention program under subpart E, 
40 CFR part 63. The implementing agency may, but is not required to, be 
the state or local air permitting agency. If no state or local agency is 
granted delegation, EPA will be the implementing agency for that state.
    Injury means any effect on a human that results either from direct 
exposure to toxic concentrations; radiant heat; or overpressures from 
accidental releases or from the direct consequences of a vapor cloud 
explosion (such as flying glass, debris, and other projectiles) from an 
accidental release and that requires medical treatment or 
hospitalization.
    Major change means introduction of a new process, process equipment, 
or regulated substance, an alteration of process chemistry that results 
in any change to safe operating limits, or other alteration that 
introduces a new hazard.
    Mechanical integrity means the process of ensuring that process 
equipment is fabricated from the proper materials of construction and is 
properly installed, maintained, and replaced to prevent failures and 
accidental releases.
    Medical treatment means treatment, other than first aid, 
administered by a physician or registered professional personnel under 
standing orders from a physician.
    Mitigation or mitigation system means specific activities, 
technologies, or equipment designed or deployed to capture or control 
substances upon loss of containment to minimize exposure of the public 
or the environment. Passive mitigation means equipment, devices, or 
technologies that function without human, mechanical, or other energy 
input. Active mitigation means equipment, devices, or technologies that 
need human, mechanical, or other energy input to function.
    NAICS means North American Industry Classification System.
    NFPA means the National Fire Protection Association.
    Natural gas processing plant (gas plant) means any processing site 
engaged in the extraction of natural gas liquids from field gas, 
fractionation of mixed natural gas liquids to natural gas products, or 
both, classified as North American Industrial Classification System 
(NAICS) code 211112 (previously Standard Industrial Classification (SIC) 
code 1321).
    Offsite means areas beyond the property boundary of the stationary 
source, and areas within the property boundary to which the public has 
routine and unrestricted access during or outside business hours.
    OSHA means the U.S. Occupational Safety and Health Administration. 
Owner or operator means any person who owns, leases, operates, controls, 
or supervises a stationary source.
    Petroleum refining process unit means a process unit used in an 
establishment primarily engaged in petroleum refining as defined in 
NAICS code 32411 for petroleum refining (formerly SIC code 2911) and 
used for the following: Producing transportation fuels (such as 
gasoline, diesel fuels, and jet fuels), heating fuels (such as kerosene, 
fuel gas distillate, and fuel oils), or lubricants; Separating 
petroleum; or Separating, cracking, reacting, or reforming intermediate 
petroleum streams. Examples of such units include, but are not limited 
to, petroleum based solvent units, alkylation units, catalytic 
hydrotreating, catalytic hydrorefining, catalytic hydrocracking, 
catalytic reforming, catalytic cracking, crude distillation, lube oil 
processing, hydrogen production, isomerization, polymerization, thermal 
processes, and blending, sweetening, and treating processes. Petroleum 
refining process units include sulfur plants.
    Population means the public.
    Process means any activity involving a regulated substance including 
any use, storage, manufacturing, handling, or on-site movement of such 
substances, or combination of these activities. For the purposes of this 
definition, any group of vessels that are interconnected, or separate 
vessels that are located such that a regulated substance could be 
involved in a potential release, shall be considered a single process.

[[Page 161]]

    Produced water means water extracted from the earth from an oil or 
natural gas production well, or that is separated from oil or natural 
gas after extraction.
    Public means any person except employees or contractors at the 
stationary source.
    Public receptor means offsite residences, institutions (e.g., 
schools, hospitals), industrial, commercial, and office buildings, 
parks, or recreational areas inhabited or occupied by the public at any 
time without restriction by the stationary source where members of the 
public could be exposed to toxic concentrations, radiant heat, or 
overpressure, as a result of an accidental release.
    Regulated substance is any substance listed pursuant to section 
112(r)(3) of the Clean Air Act as amended, in Sec. 68.130.
    Replacement in kind means a replacement that satisfies the design 
specifications.
    Retail facility means a stationary source at which more than one-
half of the income is obtained from direct sales to end users or at 
which more than one-half of the fuel sold, by volume, is sold through a 
cylinder exchange program.
    RMP means the risk management plan required under subpart G of this 
part.
    Stationary source means any buildings, structures, equipment, 
installations, or substance emitting stationary activities which belong 
to the same industrial group, which are located on one or more 
contiguous properties, which are under the control of the same person 
(or persons under common control), and from which an accidental release 
may occur. The term stationary source does not apply to transportation, 
including storage incident to transportation, of any regulated substance 
or any other extremely hazardous substance under the provisions of this 
part. A stationary source includes transportation containers used for 
storage not incident to transportation and transportation containers 
connected to equipment at a stationary source for loading or unloading. 
Transportation includes, but is not limited to, transportation subject 
to oversight or regulation under 49 CFR parts 192, 193, or 195, or a 
state natural gas or hazardous liquid program for which the state has in 
effect a certification to DOT under 49 U.S.C. section 60105. A 
stationary source does not include naturally occurring hydrocarbon 
reservoirs. Properties shall not be considered contiguous solely because 
of a railroad or pipeline right-of-way.
    Threshold quantity means the quantity specified for regulated 
substances pursuant to section 112(r)(5) of the Clean Air Act as 
amended, listed in Sec. 68.130 and determined to be present at 
a stationary source as specified in Sec. 68.115 of this part.
    Typical meteorological conditions means the temperature, wind speed, 
cloud cover, and atmospheric stability class, prevailing at the site 
based on data gathered at or near the site or from a local 
meteorological station.
    Vessel means any reactor, tank, drum, barrel, cylinder, vat, kettle, 
boiler, pipe, hose, or other container.
    Worst-case release means the release of the largest quantity of a 
regulated substance from a vessel or process line failure that results 
in the greatest distance to an endpoint defined in Sec. 
68.22(a).

[59 FR 4493, Jan. 31, 1994, as amended at 61 FR 31717, June 20, 1996; 63 
FR 644, Jan. 6, 1998; 64 FR 979, Jan. 6, 1999; 65 FR 13250, Mar. 13, 
2000]



Sec. 68.10  Applicability.

    (a) An owner or operator of a stationary source that has more than a 
threshold quantity of a regulated substance in a process, as determined 
under Sec. 68.115, shall comply with the requirements of this 
part no later than the latest of the following dates:
    (1) June 21, 1999;
    (2) Three years after the date on which a regulated substance is 
first listed under Sec. 68.130; or
    (3) The date on which a regulated substance is first present above a 
threshold quantity in a process.
    (b) Program 1 eligibility requirements. A covered process is 
eligible for Program 1 requirements as provided in Sec. 
68.12(b) if it meets all of the following requirements:
    (1) For the five years prior to the submission of an RMP, the 
process has

[[Page 162]]

not had an accidental release of a regulated substance where exposure to 
the substance, its reaction products, overpressure generated by an 
explosion involving the substance, or radiant heat generated by a fire 
involving the substance led to any of the following offsite:
    (i) Death;
    (ii) Injury; or
    (iii) Response or restoration activities for an exposure of an 
environmental receptor;
    (2) The distance to a toxic or flammable endpoint for a worst-case 
release assessment conducted under Subpart B and Sec. 68.25 is 
less than the distance to any public receptor, as defined in 
Sec. 68.30; and
    (3) Emergency response procedures have been coordinated between the 
stationary source and local emergency planning and response 
organizations.
    (c) Program 2 eligibility requirements. A covered process is subject 
to Program 2 requirements if it does not meet the eligibility 
requirements of either paragraph (b) or paragraph (d) of this section.
    (d) Program 3 eligibility requirements. A covered process is subject 
to Program 3 if the process does not meet the requirements of paragraph 
(b) of this section, and if either of the following conditions is met:
    (1) The process is in NAICS code 32211, 32411, 32511, 325181, 
325188, 325192, 325199, 325211, 325311, or 32532; or
    (2) The process is subject to the OSHA process safety management 
standard, 29 CFR 1910.119.
    (e) If at any time a covered process no longer meets the eligibility 
criteria of its Program level, the owner or operator shall comply with 
the requirements of the new Program level that applies to the process 
and update the RMP as provided in Sec. 68.190.
    (f) The provisions of this part shall not apply to an Outer 
Continental Shelf (``OCS'') source, as 
defined in 40 CFR 55.2.

[61 FR 31717, June 20, 1996, as amended at 63 FR 645, Jan. 6, 1998; 64 
FR 979, Jan. 6, 1999]



Sec. 68.12  General requirements.

    (a) General requirements. The owner or operator of a stationary 
source subject to this part shall submit a single RMP, as provided in 
Sec.Sec. 68.150 to 68.185. The RMP shall include a 
registration that reflects all covered processes.
    (b) Program 1 requirements. In addition to meeting the requirements 
of paragraph (a) of this section, the owner or operator of a stationary 
source with a process eligible for Program 1, as provided in 
Sec. 68.10(b), shall:
    (1) Analyze the worst-case release scenario for the process(es), as 
provided in Sec. 68.25; document that the nearest public 
receptor is beyond the distance to a toxic or flammable endpoint defined 
in Sec. 68.22(a); and submit in the RMP the worst-case release 
scenario as provided in Sec. 68.165;
    (2) Complete the five-year accident history for the process as 
provided in Sec. 68.42 of this part and submit it in the RMP 
as provided in Sec. 68.168;
    (3) Ensure that response actions have been coordinated with local 
emergency planning and response agencies; and
    (4) Certify in the RMP the following: ``Based on the 
criteria in 40 CFR 68.10, the distance to the specified endpoint for the 
worst-case accidental release scenario for the following process(es) is 
less than the distance to the nearest public receptor: [list 
process(es)]. Within the past five years, the process(es) has (have) had 
no accidental release that caused offsite impacts provided in the risk 
management program rule (40 CFR 68.10(b)(1)). No additional measures are 
necessary to prevent offsite impacts from accidental releases. In the 
event of fire, explosion, or a release of a regulated substance from the 
process(es), entry within the distance to the specified endpoints may 
pose a danger to public emergency responders. Therefore, public 
emergency responders should not enter this area except as arranged with 
the emergency contact indicated in the RMP. The undersigned certifies 
that, to the best of my knowledge, information, and belief, formed after 
reasonable inquiry, the information submitted is true, accurate, and 
complete. [Signature, title, date signed].''
    (c) Program 2 requirements. In addition to meeting the requirements 
of paragraph (a) of this section, the owner or operator of a stationary 
source with a process subject to Program 2, as provided in 
Sec. 68.10(c), shall:

[[Page 163]]

    (1) Develop and implement a management system as provided in 
Sec. 68.15;
    (2) Conduct a hazard assessment as provided in 
Sec.Sec. 68.20 through 68.42;
    (3) Implement the Program 2 prevention steps provided in 
Sec.Sec. 68.48 through 68.60 or implement the 
Program 3 prevention steps provided in Sec.Sec. 
68.65 through 68.87;
    (4) Develop and implement an emergency response program as provided 
in Sec.Sec. 68.90 to 68.95; and
    (5) Submit as part of the RMP the data on prevention program 
elements for Program 2 processes as provided in Sec. 68.170.
    (d) Program 3 requirements. In addition to meeting the requirements 
of paragraph (a) of this section, the owner or operator of a stationary 
source with a process subject to Program 3, as provided in 
Sec. 68.10(d) shall:
    (1) Develop and implement a management system as provided in 
Sec. 68.15;
    (2) Conduct a hazard assessment as provided in 
Sec.Sec. 68.20 through 68.42;
    (3) Implement the prevention requirements of 
Sec.Sec. 68.65 through 68.87;
    (4) Develop and implement an emergency response program as provided 
in Sec.Sec. 68.90 to 68.95 of this part; and
    (5) Submit as part of the RMP the data on prevention program 
elements for Program 3 processes as provided in Sec. 68.175.

[61 FR 31718, June 20, 1996]



Sec. 68.15  Management.

    (a) The owner or operator of a stationary source with processes 
subject to Program 2 or Program 3 shall develop a management system to 
oversee the implementation of the risk management program elements.
    (b) The owner or operator shall assign a qualified person or 
position that has the overall responsibility for the development, 
implementation, and integration of the risk management program elements.
    (c) When responsibility for implementing individual requirements of 
this part is assigned to persons other than the person identified under 
paragraph (b) of this section, the names or positions of these people 
shall be documented and the lines of authority defined through an 
organization chart or similar document.

[61 FR 31718, June 20, 1996]



                   Subpart B - Hazard Assessment

    Source: 61 FR 31718, June 20, 1996, unless otherwise noted.



Sec. 68.20  Applicability.

    The owner or operator of a stationary source subject to this part 
shall prepare a worst-case release scenario analysis as provided in 
Sec. 68.25 of this part and complete the five-year accident 
history as provided in Sec. 68.42. The owner or operator of a 
Program 2 and 3 process must comply with all sections in this subpart 
for these processes.



Sec. 68.22  Offsite consequence analysis parameters.

    (a) Endpoints. For analyses of offsite consequences, the following 
endpoints shall be used:
    (1) Toxics. The toxic endpoints provided in appendix A of this part.
    (2) Flammables. The endpoints for flammables vary according to the 
scenarios studied:
    (i) Explosion. An overpressure of 1 psi.
    (ii) Radiant heat/exposure time. A radiant heat of 5 kw/
m2 for 40 seconds.
    (iii) Lower flammability limit. A lower flammability limit as 
provided in NFPA documents or other generally recognized sources.
    (b) Wind speed/atmospheric stability class. For the worst-case 
release analysis, the owner or operator shall use a wind speed of 1.5 
meters per second and F atmospheric stability class. If the owner or 
operator can demonstrate that local meteorological data applicable to 
the stationary source show a higher minimum wind speed or less stable 
atmosphere at all times during the previous three years, these minimums 
may be used. For analysis of alternative scenarios, the owner or 
operator may use the typical meteorological conditions for the 
stationary source.
    (c) Ambient temperature/humidity. For worst-case release analysis of 
a regulated toxic substance, the owner or operator shall use the highest 
daily

[[Page 164]]

maximum temperature in the previous three years and average humidity for 
the site, based on temperature/humidity data gathered at the stationary 
source or at a local meteorological station; an owner or operator using 
the RMP Offsite Consequence Analysis Guidance may use 25 C 
and 50 percent humidity as values for these variables. For analysis of 
alternative scenarios, the owner or operator may use typical 
temperature/humidity data gathered at the stationary source or at a 
local meteorological station.
    (d) Height of release. The worst-case release of a regulated toxic 
substance shall be analyzed assuming a ground level (0 feet) release. 
For an alternative scenario analysis of a regulated toxic substance, 
release height may be determined by the release scenario.
    (e) Surface roughness. The owner or operator shall use either urban 
or rural topography, as appropriate. Urban means that there are many 
obstacles in the immediate area; obstacles include buildings or trees. 
Rural means there are no buildings in the immediate area and the terrain 
is generally flat and unobstructed.
    (f) Dense or neutrally buoyant gases. The owner or operator shall 
ensure that tables or models used for dispersion analysis of regulated 
toxic substances appropriately account for gas density.
    (g) Temperature of released substance. For worst case, liquids other 
than gases liquified by refrigeration only shall be considered to be 
released at the highest daily maximum temperature, based on data for the 
previous three years appropriate for the stationary source, or at 
process temperature, whichever is higher. For alternative scenarios, 
substances may be considered to be released at a process or ambient 
temperature that is appropriate for the scenario.



Sec. 68.25  Worst-case release scenario analysis.

    (a) The owner or operator shall analyze and report in the RMP:
    (1) For Program 1 processes, one worst-case release scenario for 
each Program 1 process;
    (2) For Program 2 and 3 processes:
    (i) One worst-case release scenario that is estimated to create the 
greatest distance in any direction to an endpoint provided in appendix A 
of this part resulting from an accidental release of regulated toxic 
substances from covered processes under worst-case conditions defined in 
Sec. 68.22;
    (ii) One worst-case release scenario that is estimated to create the 
greatest distance in any direction to an endpoint defined in 
Sec. 68.22(a) resulting from an accidental release of 
regulated flammable substances from covered processes under worst-case 
conditions defined in Sec. 68.22; and
    (iii) Additional worst-case release scenarios for a hazard class if 
a worst-case release from another covered process at the stationary 
source potentially affects public receptors different from those 
potentially affected by the worst-case release scenario developed under 
paragraphs (a)(2)(i) or (a)(2)(ii) of this section.
    (b) Determination of worst-case release quantity. The worst-case 
release quantity shall be the greater of the following:
    (1) For substances in a vessel, the greatest amount held in a single 
vessel, taking into account administrative controls that limit the 
maximum quantity; or
    (2) For substances in pipes, the greatest amount in a pipe, taking 
into account administrative controls that limit the maximum quantity.
    (c) Worst-case release scenario - toxic gases. (1) For 
regulated toxic substances that are normally gases at ambient 
temperature and handled as a gas or as a liquid under pressure, the 
owner or operator shall assume that the quantity in the vessel or pipe, 
as determined under paragraph (b) of this section, is released as a gas 
over 10 minutes. The release rate shall be assumed to be the total 
quantity divided by 10 unless passive mitigation systems are in place.
    (2) For gases handled as refrigerated liquids at ambient pressure:
    (i) If the released substance is not contained by passive mitigation 
systems or if the contained pool would have a depth of 1 cm or less, the 
owner

[[Page 165]]

or operator shall assume that the substance is released as a gas in 10 
minutes;
    (ii) If the released substance is contained by passive mitigation 
systems in a pool with a depth greater than 1 cm, the owner or operator 
may assume that the quantity in the vessel or pipe, as determined under 
paragraph (b) of this section, is spilled instantaneously to form a 
liquid pool. The volatilization rate (release rate) shall be calculated 
at the boiling point of the substance and at the conditions specified in 
paragraph (d) of this section.
    (d) Worst-case release scenario - toxic liquids. (1) For 
regulated toxic substances that are normally liquids at ambient 
temperature, the owner or operator shall assume that the quantity in the 
vessel or pipe, as determined under paragraph (b) of this section, is 
spilled instantaneously to form a liquid pool.
    (i) The surface area of the pool shall be determined by assuming 
that the liquid spreads to 1 centimeter deep unless passive mitigation 
systems are in place that serve to contain the spill and limit the 
surface area. Where passive mitigation is in place, the surface area of 
the contained liquid shall be used to calculate the volatilization rate.
    (ii) If the release would occur onto a surface that is not paved or 
smooth, the owner or operator may take into account the actual surface 
characteristics.
    (2) The volatilization rate shall account for the highest daily 
maximum temperature occurring in the past three years, the temperature 
of the substance in the vessel, and the concentration of the substance 
if the liquid spilled is a mixture or solution.
    (3) The rate of release to air shall be determined from the 
volatilization rate of the liquid pool. The owner or operator may use 
the methodology in the RMP Offsite Consequence Analysis Guidance or any 
other publicly available techniques that account for the modeling 
conditions and are recognized by industry as applicable as part of 
current practices. Proprietary models that account for the modeling 
conditions may be used provided the owner or operator allows the 
implementing agency access to the model and describes model features and 
differences from publicly available models to local emergency planners 
upon request.
    (e) Worst-case release scenario - flammable gases. The owner or 
operator shall assume that the quantity of the substance, as determined 
under paragraph (b) of this section and the provisions below, vaporizes 
resulting in a vapor cloud explosion. A yield factor of 10 percent of 
the available energy released in the explosion shall be used to 
determine the distance to the explosion endpoint if the model used is 
based on TNT equivalent methods.
    (1) For regulated flammable substances that are normally gases at 
ambient temperature and handled as a gas or as a liquid under pressure, 
the owner or operator shall assume that the quantity in the vessel or 
pipe, as determined under paragraph (b) of this section, is released as 
a gas over 10 minutes. The total quantity shall be assumed to be 
involved in the vapor cloud explosion.
    (2) For flammable gases handled as refrigerated liquids at ambient 
pressure:
    (i) If the released substance is not contained by passive mitigation 
systems or if the contained pool would have a depth of one centimeter or 
less, the owner or operator shall assume that the total quantity of the 
substance is released as a gas in 10 minutes, and the total quantity 
will be involved in the vapor cloud explosion.
    (ii) If the released substance is contained by passive mitigation 
systems in a pool with a depth greater than 1 centimeter, the owner or 
operator may assume that the quantity in the vessel or pipe, as 
determined under paragraph (b) of this section, is spilled 
instantaneously to form a liquid pool. The volatilization rate (release 
rate) shall be calculated at the boiling point of the substance and at 
the conditions specified in paragraph (d) of this section. The owner or 
operator shall assume that the quantity which becomes vapor in the first 
10 minutes is involved in the vapor cloud explosion.
    (f) Worst-case release scenario - flammable liquids. The owner 
or operator shall assume that the quantity of the

[[Page 166]]

substance, as determined under paragraph (b) of this section and the 
provisions below, vaporizes resulting in a vapor cloud explosion. A 
yield factor of 10 percent of the available energy released in the 
explosion shall be used to determine the distance to the explosion 
endpoint if the model used is based on TNT equivalent methods.
    (1) For regulated flammable substances that are normally liquids at 
ambient temperature, the owner or operator shall assume that the entire 
quantity in the vessel or pipe, as determined under paragraph (b) of 
this section, is spilled instantaneously to form a liquid pool. For 
liquids at temperatures below their atmospheric boiling point, the 
volatilization rate shall be calculated at the conditions specified in 
paragraph (d) of this section.
    (2) The owner or operator shall assume that the quantity which 
becomes vapor in the first 10 minutes is involved in the vapor cloud 
explosion.
    (g) Parameters to be applied. The owner or operator shall use the 
parameters defined in Sec. 68.22 to determine distance to the 
endpoints. The owner or operator may use the methodology provided in the 
RMP Offsite Consequence Analysis Guidance or any commercially or 
publicly available air dispersion modeling techniques, provided the 
techniques account for the modeling conditions and are recognized by 
industry as applicable as part of current practices. Proprietary models 
that account for the modeling conditions may be used provided the owner 
or operator allows the implementing agency access to the model and 
describes model features and differences from publicly available models 
to local emergency planners upon request.
    (h) Consideration of passive mitigation. Passive mitigation systems 
may be considered for the analysis of worst case provided that the 
mitigation system is capable of withstanding the release event 
triggering the scenario and would still function as intended.
    (i) Factors in selecting a worst-case scenario. Notwithstanding the 
provisions of paragraph (b) of this section, the owner or operator shall 
select as the worst case for flammable regulated substances or the worst 
case for regulated toxic substances, a scenario based on the following 
factors if such a scenario would result in a greater distance to an 
endpoint defined in Sec. 68.22(a) beyond the stationary source 
boundary than the scenario provided under paragraph (b) of this section:
    (1) Smaller quantities handled at higher process temperature or 
pressure; and
    (2) Proximity to the boundary of the stationary source.

[61 FR 31718, June 20, 1996, as amended at 64 FR 28700, May 26, 1999]



Sec. 68.28  Alternative release scenario analysis.

    (a) The number of scenarios. The owner or operator shall identify 
and analyze at least one alternative release scenario for each regulated 
toxic substance held in a covered process(es) and at least one 
alternative release scenario to represent all flammable substances held 
in covered processes.
    (b) Scenarios to consider. (1) For each scenario required under 
paragraph (a) of this section, the owner or operator shall select a 
scenario:
    (i) That is more likely to occur than the worst-case release 
scenario under Sec. 68.25; and
    (ii) That will reach an endpoint offsite, unless no such scenario 
exists.
    (2) Release scenarios considered should include, but are not limited 
to, the following, where applicable:
    (i) Transfer hose releases due to splits or sudden hose uncoupling;
    (ii) Process piping releases from failures at flanges, joints, 
welds, valves and valve seals, and drains or bleeds;
    (iii) Process vessel or pump releases due to cracks, seal failure, 
or drain, bleed, or plug failure;
    (iv) Vessel overfilling and spill, or overpressurization and venting 
through relief valves or rupture disks; and
    (v) Shipping container mishandling and breakage or puncturing 
leading to a spill.
    (c) Parameters to be applied. The owner or operator shall use the 
appropriate parameters defined in Sec. 68.22 to determine 
distance to the endpoints. The owner or operator may use either the 
methodology provided in the RMP Offsite Consequence Analysis Guidance

[[Page 167]]

or any commercially or publicly available air dispersion modeling 
techniques, provided the techniques account for the specified modeling 
conditions and are recognized by industry as applicable as part of 
current practices. Proprietary models that account for the modeling 
conditions may be used provided the owner or operator allows the 
implementing agency access to the model and describes model features and 
differences from publicly available models to local emergency planners 
upon request.
    (d) Consideration of mitigation. Active and passive mitigation 
systems may be considered provided they are capable of withstanding the 
event that triggered the release and would still be functional.
    (e) Factors in selecting scenarios. The owner or operator shall 
consider the following in selecting alternative release scenarios:
    (1) The five-year accident history provided in Sec. 68.42; 
and
    (2) Failure scenarios identified under Sec. 68.50 or 
Sec. 68.67.



Sec. 68.30  Defining offsite impacts - population.

    (a) The owner or operator shall estimate in the RMP the population 
within a circle with its center at the point of the release and a radius 
determined by the distance to the endpoint defined in Sec. 
68.22(a).
    (b) Population to be defined. Population shall include residential 
population. The presence of institutions (schools, hospitals, prisons), 
parks and recreational areas, and major commercial, office, and 
industrial buildings shall be noted in the RMP.
    (c) Data sources acceptable. The owner or operator may use the most 
recent Census data, or other updated information, to estimate the 
population potentially affected.
    (d) Level of accuracy. Population shall be estimated to two 
significant digits.



Sec. 68.33  Defining offsite impacts - environment.

    (a) The owner or operator shall list in the RMP environmental 
receptors within a circle with its center at the point of the release 
and a radius determined by the distance to the endpoint defined in 
Sec. 68.22(a) of this part.
    (b) Data sources acceptable. The owner or operator may rely on 
information provided on local U.S. Geological Survey maps or on any data 
source containing U.S.G.S. data to identify environmental receptors.



68.36  Review and update.

    (a) The owner or operator shall review and update the offsite 
consequence analyses at least once every five years.
    (b) If changes in processes, quantities stored or handled, or any 
other aspect of the stationary source might reasonably be expected to 
increase or decrease the distance to the endpoint by a factor of two or 
more, the owner or operator shall complete a revised analysis within six 
months of the change and submit a revised risk management plan as 
provided in Sec. 68.190.



Sec. 68.39  Documentation.

    The owner or operator shall maintain the following records on the 
offsite consequence analyses:
    (a) For worst-case scenarios, a description of the vessel or 
pipeline and substance selected as worst case, assumptions and 
parameters used, and the rationale for selection; assumptions shall 
include use of any administrative controls and any passive mitigation 
that were assumed to limit the quantity that could be released. 
Documentation shall include the anticipated effect of the controls and 
mitigation on the release quantity and rate.
    (b) For alternative release scenarios, a description of the 
scenarios identified, assumptions and parameters used, and the rationale 
for the selection of specific scenarios; assumptions shall include use 
of any administrative controls and any mitigation that were assumed to 
limit the quantity that could be released. Documentation shall include 
the effect of the controls and mitigation on the release quantity and 
rate.
    (c) Documentation of estimated quantity released, release rate, and 
duration of release.
    (d) Methodology used to determine distance to endpoints.

[[Page 168]]

    (e) Data used to estimate population and environmental receptors 
potentially affected.



Sec. 68.42  Five-year accident history.

    (a) The owner or operator shall include in the five-year accident 
history all accidental releases from covered processes that resulted in 
deaths, injuries, or significant property damage on site, or known 
offsite deaths, injuries, evacuations, sheltering in place, property 
damage, or environmental damage.
    (b) Data required. For each accidental release included, the owner 
or operator shall report the following information:
    (1) Date, time, and approximate duration of the release;
    (2) Chemical(s) released;
    (3) Estimated quantity released in pounds and, for mixtures 
containing regulated toxic substances, percentage concentration by 
weight of the released regulated toxic substance in the liquid mixture;
    (4) Five- or six-digit NAICS code that most closely corresponds to 
the process;
    (5) The type of release event and its source;
    (6) Weather conditions, if known;
    (7) On-site impacts;
    (8) Known offsite impacts;
    (9) Initiating event and contributing factors if known;
    (10) Whether offsite responders were notified if known; and
    (11) Operational or process changes that resulted from investigation 
of the release.
    (c) Level of accuracy. Numerical estimates may be provided to two 
significant digits.

[61 FR 31718, June 20, 1996, as amended at 64 FR 979, Jan. 6, 1999]



              Subpart C - Program 2 Prevention Program

    Source: 61 FR 31721, June 20, 1996, unless otherwise noted.



Sec. 68.48  Safety information.

    (a) The owner or operator shall compile and maintain the following 
up-to-date safety information related to the regulated substances, 
processes, and equipment:
    (1) Material Safety Data Sheets that meet the requirements of 29 CFR 
1910.1200(g);
    (2) Maximum intended inventory of equipment in which the regulated 
substances are stored or processed;
    (3) Safe upper and lower temperatures, pressures, flows, and 
compositions;
    (4) Equipment specifications; and
    (5) Codes and standards used to design, build, and operate the 
process.
    (b) The owner or operator shall ensure that the process is designed 
in compliance with recognized and generally accepted good engineering 
practices. Compliance with Federal or state regulations that address 
industry-specific safe design or with industry-specific design codes and 
standards may be used to demonstrate compliance with this paragraph.
    (c) The owner or operator shall update the safety information if a 
major change occurs that makes the information inaccurate.



Sec. 68.50  Hazard review.

    (a) The owner or operator shall conduct a review of the hazards 
associated with the regulated substances, process, and procedures. The 
review shall identify the following:
    (1) The hazards associated with the process and regulated 
substances;
    (2) Opportunities for equipment malfunctions or human errors that 
could cause an accidental release;
    (3) The safeguards used or needed to control the hazards or prevent 
equipment malfunction or human error; and
    (4) Any steps used or needed to detect or monitor releases.
    (b) The owner or operator may use checklists developed by persons or 
organizations knowledgeable about the process and equipment as a guide 
to conducting the review. For processes designed to meet industry 
standards or Federal or state design rules, the hazard review shall, by 
inspecting all equipment, determine whether the process is designed, 
fabricated, and operated in accordance with the applicable standards or 
rules.

[[Page 169]]

    (c) The owner or operator shall document the results of the review 
and ensure that problems identified are resolved in a timely manner.
    (d) The review shall be updated at least once every five years. The 
owner or operator shall also conduct reviews whenever a major change in 
the process occurs; all issues identified in the review shall be 
resolved before startup of the changed process.



Sec. 68.52  Operating procedures.

    (a) The owner or operator shall prepare written operating procedures 
that provide clear instructions or steps for safely conducting 
activities associated with each covered process consistent with the 
safety information for that process. Operating procedures or 
instructions provided by equipment manufacturers or developed by persons 
or organizations knowledgeable about the process and equipment may be 
used as a basis for a stationary source's operating procedures.
    (b) The procedures shall address the following:
    (1) Initial startup;
    (2) Normal operations;
    (3) Temporary operations;
    (4) Emergency shutdown and operations;
    (5) Normal shutdown;
    (6) Startup following a normal or emergency shutdown or a major 
change that requires a hazard review;
    (7) Consequences of deviations and steps required to correct or 
avoid deviations; and
    (8) Equipment inspections.
    (c) The owner or operator shall ensure that the operating procedures 
are updated, if necessary, whenever a major change occurs and prior to 
startup of the changed process.



Sec. 68.54  Training.

    (a) The owner or operator shall ensure that each employee presently 
operating a process, and each employee newly assigned to a covered 
process have been trained or tested competent in the operating 
procedures provided in Sec. 68.52 that pertain to their 
duties. For those employees already operating a process on June 21, 
1999, the owner or operator may certify in writing that the employee has 
the required knowledge, skills, and abilities to safely carry out the 
duties and responsibilities as provided in the operating procedures.
    (b) Refresher training. Refresher training shall be provided at 
least every three years, and more often if necessary, to each employee 
operating a process to ensure that the employee understands and adheres 
to the current operating procedures of the process. The owner or 
operator, in consultation with the employees operating the process, 
shall determine the appropriate frequency of refresher training.
    (c) The owner or operator may use training conducted under Federal 
or state regulations or under industry-specific standards or codes or 
training conducted by covered process equipment vendors to demonstrate 
compliance with this section to the extent that the training meets the 
requirements of this section.
    (d) The owner or operator shall ensure that operators are trained in 
any updated or new procedures prior to startup of a process after a 
major change.



Sec. 68.56  Maintenance.

    (a) The owner or operator shall prepare and implement procedures to 
maintain the on-going mechanical integrity of the process equipment. The 
owner or operator may use procedures or instructions provided by covered 
process equipment vendors or procedures in Federal or state regulations 
or industry codes as the basis for stationary source maintenance 
procedures.
    (b) The owner or operator shall train or cause to be trained each 
employee involved in maintaining the on-going mechanical integrity of 
the process. To ensure that the employee can perform the job tasks in a 
safe manner, each such employee shall be trained in the hazards of the 
process, in how to avoid or correct unsafe conditions, and in the 
procedures applicable to the employee's job tasks.
    (c) Any maintenance contractor shall ensure that each contract 
maintenance employee is trained to perform the maintenance procedures 
developed under paragraph (a) of this section.

[[Page 170]]

    (d) The owner or operator shall perform or cause to be performed 
inspections and tests on process equipment. Inspection and testing 
procedures shall follow recognized and generally accepted good 
engineering practices. The frequency of inspections and tests of process 
equipment shall be consistent with applicable 
manufacturers' recommendations, industry standards or 
codes, good engineering practices, and prior operating experience.



Sec. 68.58  Compliance audits.

    (a) The owner or operator shall certify that they have evaluated 
compliance with the provisions of this subpart at least every three 
years to verify that the procedures and practices developed under the 
rule are adequate and are being followed.
    (b) The compliance audit shall be conducted by at least one person 
knowledgeable in the process.
    (c) The owner or operator shall develop a report of the audit 
findings.
    (d) The owner or operator shall promptly determine and document an 
appropriate response to each of the findings of the compliance audit and 
document that deficiencies have been corrected.
    (e) The owner or operator shall retain the two (2) most recent 
compliance audit reports. This requirement does not apply to any 
compliance audit report that is more than five years old.



Sec. 68.60  Incident investigation.

    (a) The owner or operator shall investigate each incident which 
resulted in, or could reasonably have resulted in a catastrophic 
release.
    (b) An incident investigation shall be initiated as promptly as 
possible, but not later than 48 hours following the incident.
    (c) A summary shall be prepared at the conclusion of the 
investigation which includes at a minimum:
    (1) Date of incident;
    (2) Date investigation began;
    (3) A description of the incident;
    (4) The factors that contributed to the incident; and,
    (5) Any recommendations resulting from the investigation.
    (d) The owner or operator shall promptly address and resolve the 
investigation findings and recommendations. Resolutions and corrective 
actions shall be documented.
    (e) The findings shall be reviewed with all affected personnel whose 
job tasks are affected by the findings.
    (f) Investigation summaries shall be retained for five years.



              Subpart D - Program 3 Prevention Program

    Source: 61 FR 31722, June 20, 1996, unless otherwise noted.



Sec. 68.65  Process safety information.

    (a) In accordance with the schedule set forth in Sec. 
68.67, the owner or operator shall complete a compilation of written 
process safety information before conducting any process hazard analysis 
required by the rule. The compilation of written process safety 
information is to enable the owner or operator and the employees 
involved in operating the process to identify and understand the hazards 
posed by those processes involving regulated substances. This process 
safety information shall include information pertaining to the hazards 
of the regulated substances used or produced by the process, information 
pertaining to the technology of the process, and information pertaining 
to the equipment in the process.
    (b) Information pertaining to the hazards of the regulated 
substances in the process. This information shall consist of at least 
the following:
    (1) Toxicity information;
    (2) Permissible exposure limits;
    (3) Physical data;
    (4) Reactivity data:
    (5) Corrosivity data;
    (6) Thermal and chemical stability data; and
    (7) Hazardous effects of inadvertent mixing of different materials 
that could foreseeably occur.
    Note to paragraph (b):
    Material Safety Data Sheets meeting the requirements of 29 CFR 
1910.1200(g) may be used to comply with this requirement to the extent 
they contain the information required by this subparagraph.
    (c) Information pertaining to the technology of the process.

[[Page 171]]

    (1) Information concerning the technology of the process shall 
include at least the following:
    (i) A block flow diagram or simplified process flow diagram;
    (ii) Process chemistry;
    (iii) Maximum intended inventory;
    (iv) Safe upper and lower limits for such items as temperatures, 
pressures, flows or compositions; and,
    (v) An evaluation of the consequences of deviations.
    (2) Where the original technical information no longer exists, such 
information may be developed in conjunction with the process hazard 
analysis in sufficient detail to support the analysis.
    (d) Information pertaining to the equipment in the process.
    (1) Information pertaining to the equipment in the process shall 
include:
    (i) Materials of construction;
    (ii) Piping and instrument diagrams (P&ID's);
    (iii) Electrical classification;
    (iv) Relief system design and design basis;
    (v) Ventilation system design;
    (vi) Design codes and standards employed;
    (vii) Material and energy balances for processes built after June 
21, 1999; and
    (viii) Safety systems (e.g. interlocks, detection or suppression 
systems).
    (2) The owner or operator shall document that equipment complies 
with recognized and generally accepted good engineering practices.
    (3) For existing equipment designed and constructed in accordance 
with codes, standards, or practices that are no longer in general use, 
the owner or operator shall determine and document that the equipment is 
designed, maintained, inspected, tested, and operating in a safe manner.



Sec. 68.67  Process hazard analysis.

    (a) The owner or operator shall perform an initial process hazard 
analysis (hazard evaluation) on processes covered by this part. The 
process hazard analysis shall be appropriate to the complexity of the 
process and shall identify, evaluate, and control the hazards involved 
in the process. The owner or operator shall determine and document the 
priority order for conducting process hazard analyses based on a 
rationale which includes such considerations as extent of the process 
hazards, number of potentially affected employees, age of the process, 
and operating history of the process. The process hazard analysis shall 
be conducted as soon as possible, but not later than June 21, 1999. 
Process hazards analyses completed to comply with 29 CFR 1910.119(e) are 
acceptable as initial process hazards analyses. These process hazard 
analyses shall be updated and revalidated, based on their completion 
date.
    (b) The owner or operator shall use one or more of the following 
methodologies that are appropriate to determine and evaluate the hazards 
of the process being analyzed.
    (1) What-If;
    (2) Checklist;
    (3) What-If/Checklist;
    (4) Hazard and Operability Study (HAZOP);
    (5) Failure Mode and Effects Analysis (FMEA);
    (6) Fault Tree Analysis; or
    (7) An appropriate equivalent methodology.
    (c) The process hazard analysis shall address:
    (1) The hazards of the process;
    (2) The identification of any previous incident which had a likely 
potential for catastrophic consequences.
    (3) Engineering and administrative controls applicable to the 
hazards and their interrelationships such as appropriate application of 
detection methodologies to provide early warning of releases. 
(Acceptable detection methods might include process monitoring and 
control instrumentation with alarms, and detection hardware such as 
hydrocarbon sensors.);
    (4) Consequences of failure of engineering and administrative 
controls;
    (5) Stationary source siting;
    (6) Human factors; and
    (7) A qualitative evaluation of a range of the possible safety and 
health effects of failure of controls.
    (d) The process hazard analysis shall be performed by a team with 
expertise in engineering and process operations, and the team shall 
include at least one employee who has experience and knowledge specific 
to the process being

[[Page 172]]

evaluated. Also, one member of the team must be knowledgeable in the 
specific process hazard analysis methodology being used.
    (e) The owner or operator shall establish a system to promptly 
address the team's findings and recommendations; assure that the 
recommendations are resolved in a timely manner and that the resolution 
is documented; document what actions are to be taken; complete actions 
as soon as possible; develop a written schedule of when these actions 
are to be completed; communicate the actions to operating, maintenance 
and other employees whose work assignments are in the process and who 
may be affected by the recommendations or actions.
    (f) At least every five (5) years after the completion of the 
initial process hazard analysis, the process hazard analysis shall be 
updated and revalidated by a team meeting the requirements in paragraph 
(d) of this section, to assure that the process hazard analysis is 
consistent with the current process. Updated and revalidated process 
hazard analyses completed to comply with 29 CFR 1910.119(e) are 
acceptable to meet the requirements of this paragraph.
    (g) The owner or operator shall retain process hazards analyses and 
updates or revalidations for each process covered by this section, as 
well as the documented resolution of recommendations described in 
paragraph (e) of this section for the life of the process.



Sec. 68.69  Operating procedures.

    (a) The owner or operator shall develop and implement written 
operating procedures that provide clear instructions for safely 
conducting activities involved in each covered process consistent with 
the process safety information and shall address at least the following 
elements.
    (1) Steps for each operating phase:
    (i) Initial startup;
    (ii) Normal operations;
    (iii) Temporary operations;
    (iv) Emergency shutdown including the conditions under which 
emergency shutdown is required, and the assignment of shutdown 
responsibility to qualified operators to ensure that emergency shutdown 
is executed in a safe and timely manner.
    (v) Emergency operations;
    (vi) Normal shutdown; and,
    (vii) Startup following a turnaround, or after an emergency 
shutdown.
    (2) Operating limits:
    (i) Consequences of deviation; and
    (ii) Steps required to correct or avoid deviation.
    (3) Safety and health considerations:
    (i) Properties of, and hazards presented by, the chemicals used in 
the process;
    (ii) Precautions necessary to prevent exposure, including 
engineering controls, administrative controls, and personal protective 
equipment;
    (iii) Control measures to be taken if physical contact or airborne 
exposure occurs;
    (iv) Quality control for raw materials and control of hazardous 
chemical inventory levels; and,
    (v) Any special or unique hazards.
    (4) Safety systems and their functions.
    (b) Operating procedures shall be readily accessible to employees 
who work in or maintain a process.
    (c) The operating procedures shall be reviewed as often as necessary 
to assure that they reflect current operating practice, including 
changes that result from changes in process chemicals, technology, and 
equipment, and changes to stationary sources. The owner or operator 
shall certify annually that these operating procedures are current and 
accurate.
    (d) The owner or operator shall develop and implement safe work 
practices to provide for the control of hazards during operations such 
as lockout/tagout; confined space entry; opening process equipment or 
piping; and control over entrance into a stationary source by 
maintenance, contractor, laboratory, or other support personnel. These 
safe work practices shall apply to employees and contractor employees.



Sec. 68.71  Training.

    (a) Initial training. (1) Each employee presently involved in 
operating a process, and each employee before being involved in 
operating a newly assigned process, shall be trained in an overview

[[Page 173]]

of the process and in the operating procedures as specified in 
Sec. 68.69. The training shall include emphasis on the 
specific safety and health hazards, emergency operations including 
shutdown, and safe work practices applicable to the employee's job 
tasks.
    (2) In lieu of initial training for those employees already involved 
in operating a process on June 21, 1999 an owner or operator may certify 
in writing that the employee has the required knowledge, skills, and 
abilities to safely carry out the duties and responsibilities as 
specified in the operating procedures.
    (b) Refresher training. Refresher training shall be provided at 
least every three years, and more often if necessary, to each employee 
involved in operating a process to assure that the employee understands 
and adheres to the current operating procedures of the process. The 
owner or operator, in consultation with the employees involved in 
operating the process, shall determine the appropriate frequency of 
refresher training.
    (c) Training documentation. The owner or operator shall ascertain 
that each employee involved in operating a process has received and 
understood the training required by this paragraph. The owner or 
operator shall prepare a record which contains the identity of the 
employee, the date of training, and the means used to verify that the 
employee understood the training.



Sec. 68.73  Mechanical integrity.

    (a) Application. Paragraphs (b) through (f) of this section apply to 
the following process equipment:
    (1) Pressure vessels and storage tanks;
    (2) Piping systems (including piping components such as valves);
    (3) Relief and vent systems and devices;
    (4) Emergency shutdown systems;
    (5) Controls (including monitoring devices and sensors, alarms, and 
interlocks) and,
    (6) Pumps.
    (b) Written procedures. The owner or operator shall establish and 
implement written procedures to maintain the on-going integrity of 
process equipment.
    (c) Training for process maintenance activities. The owner or 
operator shall train each employee involved in maintaining the on-going 
integrity of process equipment in an overview of that process and its 
hazards and in the procedures applicable to the employee's job tasks to 
assure that the employee can perform the job tasks in a safe manner.
    (d) Inspection and testing. (1) Inspections and tests shall be 
performed on process equipment.
    (2) Inspection and testing procedures shall follow recognized and 
generally accepted good engineering practices.
    (3) The frequency of inspections and tests of process equipment 
shall be consistent with applicable manufacturers' 
recommendations and good engineering practices, and more frequently if 
determined to be necessary by prior operating experience.
    (4) The owner or operator shall document each inspection and test 
that has been performed on process equipment. The documentation shall 
identify the date of the inspection or test, the name of the person who 
performed the inspection or test, the serial number or other identifier 
of the equipment on which the inspection or test was performed, a 
description of the inspection or test performed, and the results of the 
inspection or test.
    (e) Equipment deficiencies. The owner or operator shall correct 
deficiencies in equipment that are outside acceptable limits (defined by 
the process safety information in Sec. 68.65) before further 
use or in a safe and timely manner when necessary means are taken to 
assure safe operation.
    (f) Quality assurance. (1) In the construction of new plants and 
equipment, the owner or operator shall assure that equipment as it is 
fabricated is suitable for the process application for which they will 
be used.
    (2) Appropriate checks and inspections shall be performed to assure 
that equipment is installed properly and consistent with design 
specifications and the manufacturer's instructions.
    (3) The owner or operator shall assure that maintenance materials, 
spare parts and equipment are suitable for the process application for 
which they will be used.

[[Page 174]]



Sec. 68.75  Management of change.

    (a) The owner or operator shall establish and implement written 
procedures to manage changes (except for ``replacements in 
kind'') to process chemicals, technology, equipment, and 
procedures; and, changes to stationary sources that affect a covered 
process.
    (b) The procedures shall assure that the following considerations 
are addressed prior to any change:
    (1) The technical basis for the proposed change;
    (2) Impact of change on safety and health;
    (3) Modifications to operating procedures;
    (4) Necessary time period for the change; and,
    (5) Authorization requirements for the proposed change.
    (c) Employees involved in operating a process and maintenance and 
contract employees whose job tasks will be affected by a change in the 
process shall be informed of, and trained in, the change prior to start-
up of the process or affected part of the process.
    (d) If a change covered by this paragraph results in a change in the 
process safety information required by Sec. 68.65 of this 
part, such information shall be updated accordingly.
    (e) If a change covered by this paragraph results in a change in the 
operating procedures or practices required by Sec. 68.69, such 
procedures or practices shall be updated accordingly.



Sec. 68.77  Pre-startup review.

    (a) The owner or operator shall perform a pre-startup safety review 
for new stationary sources and for modified stationary sources when the 
modification is significant enough to require a change in the process 
safety information.
    (b) The pre-startup safety review shall confirm that prior to the 
introduction of regulated substances to a process:
    (1) Construction and equipment is in accordance with design 
specifications;
    (2) Safety, operating, maintenance, and emergency procedures are in 
place and are adequate;
    (3) For new stationary sources, a process hazard analysis has been 
performed and recommendations have been resolved or implemented before 
startup; and modified stationary sources meet the requirements contained 
in management of change, Sec. 68.75.
    (4) Training of each employee involved in operating a process has 
been completed.



Sec. 68.79  Compliance audits.

    (a) The owner or operator shall certify that they have evaluated 
compliance with the provisions of this subpart at least every three 
years to verify that procedures and practices developed under this 
subpart are adequate and are being followed.
    (b) The compliance audit shall be conducted by at least one person 
knowledgeable in the process.
    (c) A report of the findings of the audit shall be developed.
    (d) The owner or operator shall promptly determine and document an 
appropriate response to each of the findings of the compliance audit, 
and document that deficiencies have been corrected.
    (e) The owner or operator shall retain the two (2) most recent 
compliance audit reports.

[61 FR 31722, June 20, 1996, as amended at 64 FR 979, Jan. 6, 1999]



Sec. 68.81  Incident investigation.

    (a) The owner or operator shall investigate each incident which 
resulted in, or could reasonably have resulted in a catastrophic release 
of a regulated substance.
    (b) An incident investigation shall be initiated as promptly as 
possible, but not later than 48 hours following the incident.
    (c) An incident investigation team shall be established and consist 
of at least one person knowledgeable in the process involved, including 
a contract employee if the incident involved work of the contractor, and 
other persons with appropriate knowledge and experience to thoroughly 
investigate and analyze the incident.
    (d) A report shall be prepared at the conclusion of the 
investigation which includes at a minimum:
    (1) Date of incident;
    (2) Date investigation began;
    (3) A description of the incident;

[[Page 175]]

    (4) The factors that contributed to the incident; and,
    (5) Any recommendations resulting from the investigation.
    (e) The owner or operator shall establish a system to promptly 
address and resolve the incident report findings and recommendations. 
Resolutions and corrective actions shall be documented.
    (f) The report shall be reviewed with all affected personnel whose 
job tasks are relevant to the incident findings including contract 
employees where applicable.
    (g) Incident investigation reports shall be retained for five years.



Sec. 68.83  Employee participation.

    (a) The owner or operator shall develop a written plan of action 
regarding the implementation of the employee participation required by 
this section.
    (b) The owner or operator shall consult with employees and their 
representatives on the conduct and development of process hazards 
analyses and on the development of the other elements of process safety 
management in this rule.
    (c) The owner or operator shall provide to employees and their 
representatives access to process hazard analyses and to all other 
information required to be developed under this rule.



Sec. 68.85  Hot work permit.

    (a) The owner or operator shall issue a hot work permit for hot work 
operations conducted on or near a covered process.
    (b) The permit shall document that the fire prevention and 
protection requirements in 29 CFR 1910.252(a) have been implemented 
prior to beginning the hot work operations; it shall indicate the 
date(s) authorized for hot work; and identify the object on which hot 
work is to be performed. The permit shall be kept on file until 
completion of the hot work operations.



Sec. 68.87  Contractors.

    (a) Application. This section applies to contractors performing 
maintenance or repair, turnaround, major renovation, or specialty work 
on or adjacent to a covered process. It does not apply to contractors 
providing incidental services which do not influence process safety, 
such as janitorial work, food and drink services, laundry, delivery or 
other supply services.
    (b) Owner or operator responsibilities. (1) The owner or operator, 
when selecting a contractor, shall obtain and evaluate information 
regarding the contract owner or operator's safety performance and 
programs.
    (2) The owner or operator shall inform contract owner or operator of 
the known potential fire, explosion, or toxic release hazards related to 
the contractor's work and the process.
    (3) The owner or operator shall explain to the contract owner or 
operator the applicable provisions of subpart E of this part.
    (4) The owner or operator shall develop and implement safe work 
practices consistent with Sec. 68.69(d), to control the 
entrance, presence, and exit of the contract owner or operator and 
contract employees in covered process areas.
    (5) The owner or operator shall periodically evaluate the 
performance of the contract owner or operator in fulfilling their 
obligations as specified in paragraph (c) of this section.
    (c) Contract owner or operator responsibilities. (1) The contract 
owner or operator shall assure that each contract employee is trained in 
the work practices necessary to safely perform his/her job.
    (2) The contract owner or operator shall assure that each contract 
employee is instructed in the known potential fire, explosion, or toxic 
release hazards related to his/her job and the process, and the 
applicable provisions of the emergency action plan.
    (3) The contract owner or operator shall document that each contract 
employee has received and understood the training required by this 
section. The contract owner or operator shall prepare a record which 
contains the identity of the contract employee, the date of training, 
and the means used to verify that the employee understood the training.
    (4) The contract owner or operator shall assure that each contract 
employee follows the safety rules of the stationary source including the 
safe work practices required by Sec. 68.69(d).

[[Page 176]]

    (5) The contract owner or operator shall advise the owner or 
operator of any unique hazards presented by the contract owner or 
operator's work, or of any hazards found by the contract owner or 
operator's work.



                   Subpart E - Emergency Response

    Source: 61 FR 31725, June 20, 1996, unless otherwise noted.



Sec. 68.90  Applicability.

    (a) Except as provided in paragraph (b) of this section, the owner 
or operator of a stationary source with Program 2 and Program 3 
processes shall comply with the requirements of Sec. 68.95.
    (b) The owner or operator of stationary source whose employees will 
not respond to accidental releases of regulated substances need not 
comply with Sec. 68.95 of this part provided that they meet 
the following:
    (1) For stationary sources with any regulated toxic substance held 
in a process above the threshold quantity, the stationary source is 
included in the community emergency response plan developed under 42 
U.S.C. 11003;
    (2) For stationary sources with only regulated flammable substances 
held in a process above the threshold quantity, the owner or operator 
has coordinated response actions with the local fire department; and
    (3) Appropriate mechanisms are in place to notify emergency 
responders when there is a need for a response.



Sec. 68.95  Emergency response program.

    (a) The owner or operator shall develop and implement an emergency 
response program for the purpose of protecting public health and the 
environment. Such program shall include the following elements:
    (1) An emergency response plan, which shall be maintained at the 
stationary source and contain at least the following elements:
    (i) Procedures for informing the public and local emergency response 
agencies about accidental releases;
    (ii) Documentation of proper first-aid and emergency medical 
treatment necessary to treat accidental human exposures; and
    (iii) Procedures and measures for emergency response after an 
accidental release of a regulated substance;
    (2) Procedures for the use of emergency response equipment and for 
its inspection, testing, and maintenance;
    (3) Training for all employees in relevant procedures; and
    (4) Procedures to review and update, as appropriate, the emergency 
response plan to reflect changes at the stationary source and ensure 
that employees are informed of changes.
    (b) A written plan that complies with other Federal contingency plan 
regulations or is consistent with the approach in the National Response 
Team's Integrated Contingency Plan Guidance (``One 
Plan'') and that, among other matters, includes the 
elements provided in paragraph (a) of this section, shall satisfy the 
requirements of this section if the owner or operator also complies with 
paragraph (c) of this section.
    (c) The emergency response plan developed under paragraph (a)(1) of 
this section shall be coordinated with the community emergency response 
plan developed under 42 U.S.C. 11003. Upon request of the local 
emergency planning committee or emergency response officials, the owner 
or operator shall promptly provide to the local emergency response 
officials information necessary for developing and implementing the 
community emergency response plan.



 Subpart F - Regulated Substances for Accidental Release Prevention

    Source: 59 FR 4493, Jan. 31, 1994, unless otherwise noted. 
Redesignated at 61 FR 31717, June 20, 1996.



Sec. 68.100  Purpose.

    This subpart designates substances to be listed under section 
112(r)(3), (4), and (5) of the Clean Air Act, as amended, identifies 
their threshold quantities, and establishes the requirements for 
petitioning to add or delete substances from the list.



Sec. 68.115  Threshold determination.

    (a) A threshold quantity of a regulated substance listed in 
Sec. 68.130 is present at a stationary source if the

[[Page 177]]

total quantity of the regulated substance contained in a process exceeds 
the threshold.
    (b) For the purposes of determining whether more than a threshold 
quantity of a regulated substance is present at the stationary source, 
the following exemptions apply:
    (1) Concentrations of a regulated toxic substance in a mixture. If a 
regulated substance is present in a mixture and the concentration of the 
substance is below one percent by weight of the mixture, the amount of 
the substance in the mixture need not be considered when determining 
whether more than a threshold quantity is present at the stationary 
source. Except for oleum, toluene 2,4-diisocyanate, toluene 2,6-
diisocyanate, and toluene diisocyanate (unspecified isomer), if the 
concentration of the regulated substance in the mixture is one percent 
or greater by weight, but the owner or operator can demonstrate that the 
partial pressure of the regulated substance in the mixture (solution) 
under handling or storage conditions in any portion of the process is 
less than 10 millimeters of mercury (mm Hg), the amount of the substance 
in the mixture in that portion of the process need not be considered 
when determining whether more than a threshold quantity is present at 
the stationary source. The owner or operator shall document this partial 
pressure measurement or estimate.
    (2) Concentrations of a regulated flammable substance in a mixture. 
(i) General provision. If a regulated substance is present in a mixture 
and the concentration of the substance is below one percent by weight of 
the mixture, the mixture need not be considered when determining whether 
more than a threshold quantity of the regulated substance is present at 
the stationary source. Except as provided in paragraph (b)(2) (ii) and 
(iii) of this section, if the concentration of the substance is one 
percent or greater by weight of the mixture, then, for purposes of 
determining whether a threshold quantity is present at the stationary 
source, the entire weight of the mixture shall be treated as the 
regulated substance unless the owner or operator can demonstrate that 
the mixture itself does not have a National Fire Protection Association 
flammability hazard rating of 4. The demonstration shall be in 
accordance with the definition of flammability hazard rating 4 in the 
NFPA 704, Standard System for the Identification of the Hazards of 
Materials for Emergency Response, National Fire Protection Association, 
Quincy, MA, 1996. Available from the National Fire Protection 
Association, 1 Batterymarch Park, Quincy, MA 02269-9101. This 
incorporation by reference was approved by the Director of the Federal 
Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. Copies 
may be inspected at the Environmental Protection Agency Air Docket 
(6102), Attn: Docket No. A-96-O8, Waterside Mall, 401 M. St. SW., 
Washington DC; or at the Office of Federal Register at 800 North Capitol 
St., NW, Suite 700, Washington, DC. Boiling point and flash point shall 
be defined and determined in accordance with NFPA 30, Flammable and 
Combustible Liquids Code, National Fire Protection Association, Quincy, 
MA, 1996. Available from the National Fire Protection Association, 1 
Batterymarch Park, Quincy, MA 02269-9101. This incorporation by 
reference was approved by the Director of the Federal Register in 
accordance with 5 U.S.C. 552(a) and 1 CFR part 51. Copies may be 
inspected at the Environmental Protection Agency Air Docket (6102), 
Attn: Docket No. A-96-O8, Waterside Mall, 401 M. St. SW., Washington DC; 
or at the Office of Federal Register at 800 North Capitol St., NW., 
Suite 700, Washington, DC. The owner or operator shall document the 
National Fire Protection Association flammability hazard rating.
    (ii) Gasoline. Regulated substances in gasoline, when in 
distribution or related storage for use as fuel for internal combustion 
engines, need not be considered when determining whether more than a 
threshold quantity is present at a stationary source.
    (iii) Naturally occurring hydrocarbon mixtures. Prior to entry into 
a natural gas processing plant or a petroleum refining process unit, 
regulated substances in naturally occurring hydrocarbon mixtures need 
not be considered when determining whether more than a threshold 
quantity is present at a stationary source. Naturally occurring

[[Page 178]]

hydrocarbon mixtures include any combination of the following: 
condensate, crude oil, field gas, and produced water, each as defined in 
Sec. 68.3 of this part.
    (3) Articles. Regulated substances contained in articles need not be 
considered when determining whether more than a threshold quantity is 
present at the stationary source.
    (4) Uses. Regulated substances, when in use for the following 
purposes, need not be included in determining whether more than a 
threshold quantity is present at the stationary source:
    (i) Use as a structural component of the stationary source;
    (ii) Use of products for routine janitorial maintenance;
    (iii) Use by employees of foods, drugs, cosmetics, or other personal 
items containing the regulated substance; and
    (iv) Use of regulated substances present in process water or non-
contact cooling water as drawn from the environment or municipal 
sources, or use of regulated substances present in air used either as 
compressed air or as part of combustion.
    (5) Activities in laboratories. If a regulated substance is 
manufactured, processed, or used in a laboratory at a stationary source 
under the supervision of a technically qualified individual as defined 
in Sec. 720.3(ee) of this chapter, the quantity of the 
substance need not be considered in determining whether a threshold 
quantity is present. This exemption does not apply to:
    (i) Specialty chemical production;
    (ii) Manufacture, processing, or use of substances in pilot plant 
scale operations; and
    (iii) Activities conducted outside the laboratory.

[59 FR 4493, Jan. 31, 1994. Redesignated at 61 FR 31717, June 20, 1996, 
as amended at 63 FR 645, Jan. 6, 1998]



Sec. 68.120  Petition process.

    (a) Any person may petition the Administrator to modify, by addition 
or deletion, the list of regulated substances identified in 
Sec. 68.130. Based on the information presented by the 
petitioner, the Administrator may grant or deny a petition.
    (b) A substance may be added to the list if, in the case of an 
accidental release, it is known to cause or may be reasonably 
anticipated to cause death, injury, or serious adverse effects to human 
health or the environment.
    (c) A substance may be deleted from the list if adequate data on the 
health and environmental effects of the substance are available to 
determine that the substance, in the case of an accidental release, is 
not known to cause and may not be reasonably anticipated to cause death, 
injury, or serious adverse effects to human health or the environment.
    (d) No substance for which a national primary ambient air quality 
standard has been established shall be added to the list. No substance 
regulated under title VI of the Clean Air Act, as amended, shall be 
added to the list.
    (e) The burden of proof is on the petitioner to demonstrate that the 
criteria for addition and deletion are met. A petition will be denied if 
this demonstration is not made.
    (f) The Administrator will not accept additional petitions on the 
same substance following publication of a final notice of the decision 
to grant or deny a petition, unless new data becomes available that 
could significantly affect the basis for the decision.
    (g) Petitions to modify the list of regulated substances must 
contain the following:
    (1) Name and address of the petitioner and a brief description of 
the organization(s) that the petitioner represents, if applicable;
    (2) Name, address, and telephone number of a contact person for the 
petition;
    (3) Common chemical name(s), common synonym(s), Chemical Abstracts 
Service number, and chemical formula and structure;
    (4) Action requested (add or delete a substance);
    (5) Rationale supporting the petitioner's position; that is, how the 
substance meets the criteria for addition and deletion. A short summary 
of the rationale must be submitted along with a more detailed narrative; 
and
    (6) Supporting data; that is, the petition must include sufficient 
information to scientifically support the request to modify the list. 
Such information shall include:

[[Page 179]]

    (i) A list of all support documents;
    (ii) Documentation of literature searches conducted, including, but 
not limited to, identification of the database(s) searched, the search 
strategy, dates covered, and printed results;
    (iii) Effects data (animal, human, and environmental test data) 
indicating the potential for death, injury, or serious adverse human and 
environmental impacts from acute exposure following an accidental 
release; printed copies of the data sources, in English, should be 
provided; and
    (iv) Exposure data or previous accident history data, indicating the 
potential for serious adverse human health or environmental effects from 
an accidental release. These data may include, but are not limited to, 
physical and chemical properties of the substance, such as vapor 
pressure; modeling results, including data and assumptions used and 
model documentation; and historical accident data, citing data sources.
    (h) Within 18 months of receipt of a petition, the Administrator 
shall publish in the Federal Register a notice either denying the 
petition or granting the petition and proposing a listing.



Sec. 68.125  Exemptions.

    Agricultural nutrients. Ammonia used as an agricultural nutrient, 
when held by farmers, is exempt from all provisions of this part.



Sec. 68.126  Exclusion.

    Flammable Substances Used as Fuel or Held for Sale as Fuel at Retail 
Facilities. A flammable substance listed in Tables 3 and 4 of 
Sec. 68.130 is nevertheless excluded from all provisions of 
this part when the substance is used as a fuel or held for sale as a 
fuel at a retail facility.

[65 FR 13250, Mar. 13, 2000]



Sec. 68.130  List of substances.

    (a) Regulated toxic and flammable substances under section 112(r) of 
the Clean Air Act are the substances listed in Tables 1, 2, 3, and 4. 
Threshold quantities for listed toxic and flammable substances are 
specified in the tables.
    (b) The basis for placing toxic and flammable substances on the list 
of regulated substances are explained in the notes to the list.

 Table 1 to Sec. 68.130 - List of Regulated Toxic
  Substances and Threshold Quantities for Accidental Release Prevention
            [Alphabetical Order - 77 Substances]
------------------------------------------------------------------------
                                                 Threshold
         Chemical name               CAS No.      quantity    Basis for
                                                   (lbs)       listing
------------------------------------------------------------------------
Acrolein [2-Propenal]..........        107-02-8      5,000  b
Acrylonitrile [2-                      107-13-1     20,000  b
 Propenenitrile].
Acrylyl chloride [2-Propenoyl          814-68-6      5,000  b
 chloride].
Allyl alcohol [2-Propen-l-ol]..       107-18-61     15,000  b
Allylamine [2-Propen-l-amine]..        107-11-9     10,000  b
Ammonia (anhydrous)............       7664-41-7     10,000  a, b
Ammonia (conc 20% or greater)..       7664-41-7     20,000  a, b
Arsenous trichloride...........       7784-34-1     15,000  b
Arsine.........................       7784-42-1      1,000  b
Boron trichloride [Borane,           10294-34-5      5,000  b
 trichloro-].
Boron trifluoride [Borane,            7637-07-2      5,000  b
 trifluoro-].
Boron trifluoride compound with        353-42-4     15,000  b
 methyl ether (1:1) [Boron,
 trifluoro [oxybis [metane]]-,
 T-4-.
Bromine........................       7726-95-6     10,000  a, b
Carbon disulfide...............         75-15-0     20,000  b
Chlorine.......................       7782-50-5      2,500  a, b
Chlorine dioxide [Chlorine           10049-04-4      1,000  c
 oxide (ClO2)].
Chloroform [Methane, trichloro-         67-66-3     20,000  b
 ].
Chloromethyl ether [Methane,           542-88-1      1,000  b
 oxybis[chloro-].
Chloromethyl methyl ether              107-30-2      5,000  b
 [Methane, chloromethoxy-].
Crotonaldehyde [2-Butenal].....       4170-30-3     20,000  b
Crotonaldehyde, (E)- [2-               123-73-9     20,000  b
 Butenal, (E)-].
Cyanogen chloride..............        506-77-4     10,000  c
Cyclohexylamine                        108-91-8     15,000  b
 [Cyclohexanamine].
Diborane.......................      19287-45-7      2,500  b
Dimethyldichlorosilane [Silane,         75-78-5      5,000  b
 dichlorodimethyl-].

[[Page 180]]

 
1,1-Dimethylhydrazine                   57-14-7     15,000  b
 [Hydrazine, 1,1-dimethyl-].
Epichlorohydrin [Oxirane,              106-89-8     20,000  b
 (chloromethyl)-].
Ethylenediamine [1,2-                  107-15-3     20,000  b
 Ethanediamine].
Ethyleneimine [Aziridine]......        151-56-4     10,000  b
Ethylene oxide [Oxirane].......         75-21-8     10,000  a, b
Fluorine.......................       7782-41-4      1,000  b
Formaldehyde (solution)........         50-00-0     15,000  b
Furan..........................        110-00-9      5,000  b
Hydrazine......................        302-01-2     15,000  b
Hydrochloric acid (conc 37% or        7647-01-0     15,000  d
 greater).
Hydrocyanic acid...............         74-90-8      2,500  a, b
Hydrogen chloride (anhydrous)         7647-01-0      5,000  a
 [Hydrochloric acid].
Hydrogen fluoride/Hydrofluoric        7664-39-3      1,000  a, b
 acid (conc 50% or greater)
 [Hydrofluoric acid].
Hydrogen selenide..............       7783-07-5        500  b
Hydrogen sulfide...............       7783-06-4     10,000  a, b
Iron, pentacarbonyl- [Iron           13463-40-6      2,500  b
 carbonyl (Fe(CO)5), (TB-5-11)-
 ].
Isobutyronitrile                        78-82-0     20,000  b
 [Propanenitrile, 2-methyl-].
Isopropyl chloroformate                108-23-6     15,000  b
 [Carbonochloridic acid, 1-
 methylethyl ester].
Methacrylonitrile [2-                  126-98-7     10,000  b
 Propenenitrile, 2-methyl-].
Methyl chloride [Methane,               74-87-3     10,000  a
 chloro-].
Methyl chloroformate                    79-22-1      5,000  b
 [Carbonochloridic acid,
 methylester].
Methyl hydrazine [Hydrazine,            60-34-4     15,000  b
 methyl-].
Methyl isocyanate [Methane,            624-83-9     10,000  a, b
 isocyanato-].
Methyl mercaptan [Methanethiol]         74-93-1     10,000  b
Methyl thiocyanate [Thiocyanic         556-64-9     20,000  b
 acid, methyl ester].
Methyltrichlorosilane [Silane,          75-79-6      5,000  b
 trichloromethyl-].
Nickel carbonyl................      13463-39-3      1,000  b
Nitric acid (conc 80% or              7697-37-2     15,000  b
 greater).
Nitric oxide [Nitrogen oxide         10102-43-9     10,000  b
 (NO)].
Oleum (Fuming Sulfuric acid)          8014-95-7     10,000  e
 [Sulfuric acid, mixture with
 sulfur trioxide] \1\.
Peracetic acid [Ethaneperoxoic          79-21-0     10,000  b
 acid].
Perchloromethylmercaptan               594-42-3     10,000  b
 [Methanesulfenyl chloride,
 trichloro-].
Phosgene [Carbonic dichloride].         75-44-5        500  a, b
Phosphine......................       7803-51-2      5,000  b
Phosphorus oxychloride               10025-87-3      5,000  b
 [Phosphoryl chloride].
Phosphorus trichloride                7719-12-2     15,000  b
 [Phosphorous trichloride].
Piperidine.....................        110-89-4     15,000  b
Propionitrile [Propanenitrile].        107-12-0     10,000  b
Propyl chloroformate                   109-61-5     15,000  b
 [Carbonochloridic acid,
 propylester].
Propyleneimine [Aziridine, 2-           75-55-8     10,000  b
 methyl-].
Propylene oxide [Oxirane,               75-56-9     10,000  b
 methyl-].
Sulfur dioxide (anhydrous).....       7446-09-5      5,000  a, b

[[Page 181]]

 
Sulfur tetrafluoride [Sulfur          7783-60-0      2,500  b
 fluoride (SF4), (T-4)-].
Sulfur trioxide................       7446-11-9     10,000  a, b
Tetramethyllead [Plumbane,              75-74-1     10,000  b
 tetramethyl-].
Tetranitromethane [Methane,            509-14-8     10,000  b
 tetranitro-].
Titanium tetrachloride                7550-45-0      2,500  b
 [Titanium chloride (TiCl4) (T-
 4)-].
Toluene 2,4-diisocyanate               584-84-9     10,000  a
 [Benzene, 2,4-diisocyanato-1-
 methyl-] \1\.
Toluene 2,6-diisocyanate                91-08-7     10,000  a
 [Benzene, 1,3-diisocyanato-2-
 methyl-] \1\.
Toluene diisocyanate                 26471-62-5     10,000  a
 (unspecified isomer) [Benzene,
 1,3-diisocyanatomethyl-] \1\.
Trimethylchlorosilane [Silane,          75-77-4     10,000  b
 chlorotrimethyl-].
Vinyl acetate monomer [Acetic          108-05-4     15,000  b
 acid ethenyl ester].
------------------------------------------------------------------------
\1\ The mixture exemption in Sec. 68.115(b)(1) does not apply
  to the substance.
 
Note: Basis for Listing:
a Mandated for listing by Congress.
b On EHS list, vapor pressure 10 mmHg or greater.
c Toxic gas.
d Toxicity of hydrogen chloride, potential to release hydrogen chloride,
  and history of accidents.
e Toxicity of sulfur trioxide and sulfuric acid, potential to release
  sulfur trioxide, and history of accidents.


 Table 2 to Sec. 68.130 - List of Regulated Toxic
  Substances and Threshold Quantities for Accidental Release Prevention
             [CAS Number Order - 77 Substances]
------------------------------------------------------------------------
                                                 Threshold
        CAS No.               Chemical name       quantity    Basis for
                                                   (lbs)       listing
------------------------------------------------------------------------
50-00-0................  Formaldehyde               15,000  b
                          (solution).
57-14-7................  1,1-Dimethylhydrazine      15,000  b
                          [Hydrazine, 1,1-
                          dimethyl-].
60-34-4................  Methyl hydrazine           15,000  b
                          [Hydrazine, methyl-].
67-66-3................  Chloroform [Methane,       20,000  b
                          trichloro-].
74-87-3................  Methyl chloride            10,000  a
                          [Methane, chloro-].
74-90-8................  Hydrocyanic acid......      2,500  a, b
74-93-1................  Methyl mercaptan           10,000  b
                          [Methanethiol].
75-15-0................  Carbon disulfide......     20,000  b
75-21-8................  Ethylene oxide             10,000  a, b
                          [Oxirane].
75-44-5................  Phosgene [Carbonic            500  a, b
                          dichloride].
75-55-8................  Propyleneimine             10,000  b
                          [Aziridine, 2-methyl-
                          ].
75-56-9................  Propylene oxide            10,000  b
                          [Oxirane, methyl-].
75-74-1................  Tetramethyllead            10,000  b
                          [Plumbane,
                          tetramethyl-].
75-77-4................  Trimethylchlorosilane      10,000  b
                          [Silane,
                          chlorotrimethyl-].
75-78-5................  Dimethyldichlorosilane      5,000  b
                          [Silane,
                          dichlorodimethyl-].
75-79-6................  Methyltrichlorosilane       5,000  b
                          [Silane,
                          trichloromethyl-].
78-82-0................  Isobutyronitrile           20,000  b
                          [Propanenitrile, 2-
                          methyl-].
79-21-0................  Peracetic acid             10,000  b
                          [Ethaneperoxoic acid].
79-22-1................  Methyl chloroformate        5,000  b
                          [Carbonochloridic
                          acid, methylester].
91-08-7................  Toluene 2,6-               10,000  a
                          diisocyanate
                          [Benzene, 1,3-
                          diisocyanato-2-methyl-
                          ]\1\.
106-89-8...............  Epichlorohydrin            20,000  b
                          [Oxirane,
                          (chloromethyl)-].
107-02-8...............  Acrolein [2-Propenal].      5,000  b
107-11-9...............  Allylamine [2-Propen-1-    10,000  b
                          amine].
107-12-0...............  Propionitrile              10,000  b
                          [Propanenitrile].
107-13-1...............  Acrylonitrile [2-          20,000  b
                          Propenenitrile].
107-15-3...............  Ethylenediamine [1,2-      20,000  b
                          Ethanediamine].
107-18-6...............  Allyl alcohol [2-          15,000  b
                          Propen-1-ol].
107-30-2...............  Chloromethyl methyl         5,000  b
                          ether [Methane,
                          chloromethoxy-].
108-05-4...............  Vinyl acetate monomer      15,000  b
                          [Acetic acid ethenyl
                          ester].
108-23-6...............  Isopropyl                  15,000  b
                          chloroformate
                          [Carbonochloridic
                          acid, 1-methylethyl
                          ester].
108-91-8...............  Cyclohexylamine            15,000  b
                          [Cyclohexanamine].

[[Page 182]]

 
109-61-5...............  Propyl chloroformate       15,000  b
                          [Carbonochloridic
                          acid, propylester].
110-00-9...............  Furan.................      5,000  b
110-89-4...............  Piperidine............     15,000  b
123-73-9...............  Crotonaldehyde, (E)-       20,000  b
                          [2-Butenal, (E)-].
126-98-7...............  Methacrylonitrile [2-      10,000  b
                          Propenenitrile, 2-
                          methyl-].
151-56-4...............  Ethyleneimine              10,000  b
                          [Aziridine].
302-01-2...............  Hydrazine.............     15,000  b
353-42-4...............  Boron trifluoride          15,000  b
                          compound with methyl
                          ether (1:1) [Boron,
                          trifluoro[oxybis[meth
                          ane]]-, T-4-.
506-77-4...............  Cyanogen chloride.....     10,000  c
509-14-8...............  Tetranitromethane          10,000  b
                          [Methane, tetranitro-
                          ].
542-88-1...............  Chloromethyl ether          1,000  b
                          [Methane,
                          oxybis[chloro-].
556-64-9...............  Methyl thiocyanate         20,000  b
                          [Thiocyanic acid,
                          methyl ester].
584-84-9...............  Toluene 2,4-               10,000  a
                          diisocyanate
                          [Benzene, 2,4-
                          diisocyanato-1-methyl-
                          ]\1\.
594-42-3...............  Perchloromethylmercapt     10,000  b
                          an [Methanesulfenyl
                          chloride, trichloro-].
624-83-9...............  Methyl isocyanate          10,000  a, b
                          [Methane, isocyanato-
                          ].
814-68-6...............  Acrylyl chloride [2-        5,000  b
                          Propenoyl chloride].
4170-30-3..............  Crotonaldehyde [2-         20,000  b
                          Butenal].
7446-09-5..............  Sulfur dioxide              5,000  a, b
                          (anhydrous).
7446-11-9..............  Sulfur trioxide.......     10,000  a, b
7550-45-0..............  Titanium tetrachloride      2,500  b
                          [Titanium chloride
                          (TiCl4) (T-4)-].
7637-07-2..............  Boron trifluoride           5,000  b
                          [Borane, trifluoro-].
7647-01-0..............  Hydrochloric acid          15,000  d
                          (conc 37% or greater).
7647-01-0..............  Hydrogen chloride           5,000  a
                          (anhydrous)
                          [Hydrochloric acid].
7664-39-3..............  Hydrogen fluoride/          1,000  a, b
                          Hydrofluoric acid
                          (conc 50% or greater)
                          [Hydrofluoric acid].
7664-41-7..............  Ammonia (anhydrous)...     10,000  a, b
7664-41-7..............  Ammonia (conc 20% or       20,000  a, b
                          greater).
7697-37-2..............  Nitric acid (conc 80%      15,000  b
                          or greater).
7719-12-2..............  Phosphorus trichloride     15,000  b
                          [Phosphorous
                          trichloride].
7726-95-6..............  Bromine...............     10,000  a, b
7782-41-4..............  Fluorine..............      1,000  b
7782-50-5..............  Chlorine..............      2,500  a, b
7783-06-4..............  Hydrogen sulfide......     10,000  a, b
7783-07-5..............  Hydrogen selenide.....        500  b
7783-60-0..............  Sulfur tetrafluoride        2,500  b
                          [Sulfur fluoride
                          (SF4), (T-4)-].
7784-34-1..............  Arsenous trichloride..     15,000  b
7784-42-1..............  Arsine................      1,000  b
7803-51-2..............  Phosphine.............      5,000  b
8014-95-7..............  Oleum (Fuming Sulfuric     10,000  e
                          acid) [Sulfuric acid,
                          mixture with sulfur
                          trioxide]\1\.
10025-87-3.............  Phosphorus oxychloride      5,000  b
                          [Phosphoryl chloride].
10049-04-4.............  Chlorine dioxide            1,000  c
                          [Chlorine oxide
                          (ClO2)].
10102-43-9.............  Nitric oxide [Nitrogen     10,000  b
                          oxide (NO)].
10294-34-5.............  Boron trichloride           5,000  b
                          [Borane, trichloro-].
13463-39-3.............  Nickel carbonyl.......      1,000  b
13463-40-6.............  Iron, pentacarbonyl-        2,500  b
                          [Iron carbonyl
                          (Fe(CO)5), (TB-5-11)-
                          ].
19287-45-7.............  Diborane..............      2,500  b
26471-62-5.............  Toluene diisocyanate       10,000  a
                          (unspecified isomer)
                          [Benzene, 1,3-
                          diisocyanatomethyl-
                          1]\1\.
------------------------------------------------------------------------
\1\ The mixture exemption in Sec. 68.115(b)(1) does not apply
  to the substance.
Note: Basis for Listing:
a Mandated for listing by Congress.
b On EHS list, vapor pressure 10 mmHg or greater.
c Toxic gas.
d Toxicity of hydrogen chloride, potential to release hydrogen chloride,
  and history of accidents.
e Toxicity of sulfur trioxide and sulfuric acid, potential to release
  sulfur trioxide, and history of accidents.


    Table 3 to Sec. 68.130 - List of Regulated
Flammable Substances \1\ and Threshold Quantities for Accidental Release
                               Prevention
            [Alphabetical Order - 63 Substances]
------------------------------------------------------------------------
                                                 Threshold
         Chemical name               CAS No.      quantity    Basis for
                                                   (lbs)       listing
------------------------------------------------------------------------
Acetaldehyde...................         75-07-0     10,000  g
Acetylene [Ethyne].............         74-86-2     10,000  f
Bromotrifluorethylene [Ethene,         598-73-2     10,000  f
 bromotrifluoro-].
1,3-Butadiene..................        106-99-0     10,000  f

[[Page 183]]

 
Butane.........................        106-97-8     10,000  f
1-Butene.......................        106-98-9     10,000  f
2-Butene.......................        107-01-7     10,000  f
Butene.........................      25167-67-3     10,000  f
2-Butene-cis...................        590-18-1     10,000  f
2-Butene-trans [2-Butene, (E)].        624-64-6     10,000  f
Carbon oxysulfide [Carbon oxide        463-58-1     10,000  f
 sulfide (COS)].
Chlorine monoxide [Chlorine           7791-21-1     10,000  f
 oxide].
2-Chloropropylene [1-Propene, 2-       557-98-2     10,000  g
 chloro-].
1-Chloropropylene [1-Propene, 1-       590-21-6     10,000  g
 chloro-].
Cyanogen [Ethanedinitrile].....        460-19-5     10,000  f
Cyclopropane...................         75-19-4     10,000  f
Dichlorosilane [Silane,               4109-96-0     10,000  f
 dichloro-].
Difluoroethane [Ethane, 1,1-            75-37-6     10,000  f
 difluoro-].
Dimethylamine [Methanamine, N-         124-40-3     10,000  f
 methyl-].
2,2-Dimethylpropane [Propane,          463-82-1     10,000  f
 2,2-dimethyl-].
Ethane.........................         74-84-0     10,000  f
Ethyl acetylene [1-Butyne].....        107-00-6     10,000  f
Ethylamine [Ethanamine]........         75-04-7     10,000  f
Ethyl chloride [Ethane, chloro-         75-00-3     10,000  f
 ].
Ethylene [Ethene]..............         74-85-1     10,000  f
Ethyl ether [Ethane, 1,1'               60-29-7     10,000  g
         -oxybis-].
Ethyl mercaptan [Ethanethiol]..         75-08-1     10,000  g
Ethyl nitrite [Nitrous acid,           109-95-5     10,000  f
 ethyl ester].
Hydrogen.......................       1333-74-0     10,000  f
Isobutane [Propane, 2-methyl]..         75-28-5     10,000  f
Isopentane [Butane, 2-methyl-].         78-78-4     10,000  g
Isoprene [1,3-Butadinene, 2-            78-79-5     10,000  g
 methyl-].
Isopropylamine [2-Propanamine].         75-31-0     10,000  g
Isopropyl chloride [Propane, 2-         75-29-6     10,000  g
 chloro-].
Methane........................         74-82-8     10,000  f
Methylamine [Methanamine]......         74-89-5     10,000  f
3-Methyl-1-butene..............        563-45-1     10,000  f
2-Methyl-1-butene..............        563-46-2     10,000  g
Methyl ether [Methane, oxybis-]        115-10-6     10,000  f
Methyl formate [Formic acid,           107-31-3     10,000  g
 methyl ester].
2-Methylpropene [1-Propene, 2-         115-11-7     10,000  f
 methyl-].
1,3-Pentadinene................        504-60-9     10,000  f
Pentane........................        109-66-0     10,000  g
1-Pentene......................        109-67-1     10,000  g
2-Pentene, (E)-................        646-04-8     10,000  g
2-Pentene, (Z)-................        627-20-3     10,000  g
Propadiene [1,2-Propadiene]....        463-49-0     10,000  f
Propane........................         74-98-6     10,000  f
Propylene [1-Propene]..........        115-07-1     10,000  f
Propyne [1-Propyne]............         74-99-7     10,000  f
Silane.........................       7803-62-5     10,000  f
Tetrafluoroethylene [Ethene,           116-14-3     10,000  f
 tetrafluoro-].
Tetramethylsilane [Silane,              75-76-3     10,000  g
 tetramethyl-].
Trichlorosilane [Silane,             10025-78-2     10,000  g
 trichloro-].
Trifluorochloroethylene                 79-38-9     10,000  f
 [Ethene, chlorotrifluoro-].
Trimethylamine [Methanamine,            75-50-3     10,000  f
 N,N-dimethyl-].
Vinyl acetylene [1-Buten-3-yne]        689-97-4     10,000  f
Vinyl chloride [Ethene, chloro-         75-01-4     10,000  a, f
 ].
Vinyl ethyl ether [Ethene,             109-92-2     10,000  g
 ethoxy-].
Vinyl fluoride [Ethene, fluoro-         75-02-5     10,000  f
 ].
Vinylidene chloride [Ethene,            75-35-4     10,000  g
 1,1-dichloro-].
Vinylidene fluoride [Ethene,            75-38-7     10,000  f
 1,1-difluoro-].
Vinyl methyl ether [Ethene,            107-25-5     10,000  f
 methoxy-].
------------------------------------------------------------------------
\1\ A flammable substance when used as a fuel or held for sale as a fuel
  at a retail facility is excluded from all provisions of this part (see
  Sec. 68.126).
 
 Note: Basis for Listing:
 a Mandated for listing by Congress.
 f Flammable gas.
 g Volatile flammable liquid.


[[Page 184]]


    Table 4 to Sec. 68.130 - List of Regulated Flammable Substances \1\ and Threshold
                                  Quantities for Accidental Release Prevention
                                 [CAS Number Order - 63 Substances]
----------------------------------------------------------------------------------------------------------------
                                                                                 Threshold
            CAS No.                       Chemical name              CAS No.      quantity    Basis for listing
                                                                                   (lbs)
----------------------------------------------------------------------------------------------------------------
60-29-7........................  Ethyl ether [Ethane,                   60-29-7     10,000  g
                                  1,1[prime]-oxybis-].
74-82-8........................  Methane.......................         74-82-8     10,000  f
74-84-0........................  Ethane........................         74-84-0     10,000  f
74-85-1........................  Ethylene [Ethene].............         74-85-1     10,000  f
74-86-2........................  Acetylene [Ethyne]............         74-86-2     10,000  f
74-89-5........................  Methylamine [Methanamine].....         74-89-5     10,000  f
74-98-6........................  Propane.......................         74-98-6     10,000  f
74-99-7........................  Propyne [1-Propyne]...........         74-99-7     10,000  f
75-00-3........................  Ethyl chloride [Ethane, chloro-        75-00-3     10,000  f
                                  ].
75-01-4........................  Vinyl chloride [Ethene, chloro-        75-01-4     10,000  a, f
                                  ].
75-02-5........................  Vinyl fluoride [Ethene, fluoro-        75-02-5     10,000  f
                                  ].
75-04-7........................  Ethylamine [Ethanamine].......         75-04-7     10,000  f
75-07-0........................  Acetaldehyde..................         75-07-0     10,000  g
75-08-1........................  Ethyl mercaptan [Ethanethiol].         75-08-1     10,000  g
75-19-4........................  Cyclopropane..................         75-19-4     10,000  f
75-28-5........................  Isobutane [Propane, 2-methyl].         75-28-5     10,000  f
75-29-6........................  Isopropyl chloride [Propane, 2-        75-29-6     10,000  g
                                  chloro-].
75-31-0........................  Isopropylamine [2-Propanamine]         75-31-0     10,000  g
75-35-4........................  Vinylidene chloride [Ethene,           75-35-4     10,000  g
                                  1,1-dichloro-].
75-37-6........................  Difluoroethane [Ethane, 1,1-           75-37-6     10,000  f
                                  difluoro-].
75-38-7........................  Vinylidene fluoride [Ethene,           75-38-7     10,000  f
                                  1,1-difluoro-].
75-50-3........................  Trimethylamine [Methanamine,           75-50-3     10,000  f
                                  N, N-dimethyl-].
75-76-3........................  Tetramethylsilane [Silane,             75-76-3     10,000  g
                                  tetramethyl-].
78-78-4........................  Isopentane [Butane, 2-methyl-]         78-78-4     10,000  g
78-79-5........................  Isoprene [1,3,-Butadiene, 2-           78-79-5     10,000  g
                                  methyl-].
79-38-9........................  Trifluorochloroethylene                79-38-9     10,000  f
                                  [Ethene, chlorotrifluoro-].
106-97-8.......................  Butane........................        106-97-8     10,000  f
106-98-9.......................  1-Butene......................        106-98-9     10,000  f
196-99-0.......................  1,3-Butadiene.................        106-99-0     10,000  f
107-00-6.......................  Ethyl acetylene [1-Butyne]....        107-00-6     10,000  f
107-01-7.......................  2-Butene......................        107-01-7     10,000  f
107-25-5.......................  Vinyl methyl ether [Ethene,           107-25-5     10,000  f
                                  methoxy-].
107-31-3.......................  Methyl formate [Formic acid,          107-31-3     10,000  g
                                  methyl ester].
109-66-0.......................  Pentane.......................        109-66-0     10,000  g
109-67-1.......................  1-Pentene.....................        109-67-1     10,000  g
109-92-2.......................  Vinyl ethyl ether [Ethene,            109-92-2     10,000  g
                                  ethoxy-].
109-95-5.......................  Ethyl nitrite [Nitrous acid,          109-95-5     10,000  f
                                  ethyl ester].
115-07-1.......................  Propylene [1-Propene].........        115-07-1     10,000  f
115-10-6.......................  Methyl ether [Methane, oxybis-        115-10-6     10,000  f
                                  ].
115-11-7.......................  2-Methylpropene [1-Propene, 2-        115-11-7     10,000  f
                                  methyl-].
116-14-3.......................  Tetrafluoroethylene [Ethene,          116-14-3     10,000  f
                                  tetrafluoro-].
124-40-3.......................  Dimethylamine [Methanamine, N-        124-40-3     10,000  f
                                  methyl-].
460-19-5.......................  Cyanogen [Ethanedinitrile]....        460-19-5     10,000  f
463-49-0.......................  Propadiene [1,2-Propadiene]...        463-49-0     10,000  f
463-58-1.......................  Carbon oxysulfide [Carbon             463-58-1     10,000  f
                                  oxide sulfide (COS)].
463-82-1.......................  2,2-Dimethylpropane [Propane,         463-82-1     10,000  f
                                  2,2-dimethyl-].
504-60-9.......................  1,3-Pentadiene................        504-60-9     10,000  f
557-98-2.......................  2-Chloropropylene [1-Propene,         557-98-2     10,000  g
                                  2-chloro-].
563-45-1.......................  3-Methyl-1-butene.............        563-45-1     10,000  f
563-46-2.......................  2-Methyl-1-butene.............        563-46-2     10,000  g
590-18-1.......................  2-Butene-cis..................        590-18-1     10,000  f
590-21-6.......................  1-Chloropropylene [1-Propene,         590-21-6     10,000  g
                                  1-chloro-].
598-73-2.......................  Bromotrifluorethylene [Ethene,        598-73-2     10,000  f
                                  bromotrifluoro-].
624-64-6.......................  2-Butene-trans [2-Butene, (E)]        624-64-6     10,000  f
627-20-3.......................  2-Pentene, (Z)-...............        627-20-3     10,000  g
646-04-8.......................  2-Pentene, (E)-...............        646-04-8     10,000  g
689-97-4.......................  Vinyl acetylene [1-Buten-3-           689-97-4     10,000  f
                                  yne].
1333-74-0......................  Hydrogen......................       1333-74-0     10,000  f
4109-96-0......................  Dichlorosilane [Silane,              4109-96-0     10,000  f
                                  dichloro-].
7791-21-1......................  Chlorine monoxide [Chlorine          7791-21-1     10,000  f
                                  oxide].
7803-62-5......................  Silane........................       7803-62-5     10,000  f
10025-78-2.....................  Trichlorosilane                     10025-78-2     10,000  g
                                  [Silane,trichloro-].
25167-67-3.....................  Butene........................      25167-67-3     10,000  f
----------------------------------------------------------------------------------------------------------------
\1\ A flammable substance when used as a fuel or held for sale as a fuel at a retail facility is excluded from
  all provisions of this part (see Sec. 68.126).
 
 Note: Basis for Listing:
 a Mandated for listing by Congress.

[[Page 185]]

 
 f Flammable gas.
 g Volatile flammable liquid.


[59 FR 4493, Jan. 31, 1994. Redesignated at 61 FR 31717, June 20, 1996, 
as amended at 62 FR 45132, Aug. 25, 1997; 63 FR 645, Jan. 6, 1998; 65 FR 
13250, Mar. 13, 2000]



                  Subpart G - Risk Management Plan

    Source: 61 FR 31726, June 20, 1996, unless otherwise noted.



Sec. 68.150  Submission.

    (a) The owner or operator shall submit a single RMP that includes 
the information required by Sec.Sec. 68.155 through 
68.185 for all covered processes. The RMP shall be submitted in a method 
and format to a central point as specified by EPA prior to June 21, 
1999.
    (b) The owner or operator shall submit the first RMP no later than 
the latest of the following dates:
    (1) June 21, 1999;
    (2) Three years after the date on which a regulated substance is 
first listed under Sec. 68.130; or
    (3) The date on which a regulated substance is first present above a 
threshold quantity in a process.
    (c) Subsequent submissions of RMPs shall be in accordance with 
Sec. 68.190.
    (d) Notwithstanding the provisions of Sec.Sec. 
68.155 to 68.190, the RMP shall exclude classified information. Subject 
to appropriate procedures to protect such information from public 
disclosure, classified data or information excluded from the RMP may be 
made available in a classified annex to the RMP for review by Federal 
and state representatives who have received the appropriate security 
clearances.
    (e) Procedures for asserting that information submitted in the RMP 
is entitled to protection as confidential business information are set 
forth in Sec.Sec. 68.151 and 68.152.

[61 FR 31726, June 20, 1996, as amended at 64 FR 979, Jan. 6, 1999]



Sec. 68.151  Assertion of claims of confidential business information.

    (a) Except as provided in paragraph (b) of this section, an owner or 
operator of a stationary source required to report or otherwise provide 
information under this part may make a claim of confidential business 
information for any such information that meets the criteria set forth 
in 40 CFR 2.301.
    (b) Notwithstanding the provisions of 40 CFR part 2, an owner or 
operator of a stationary source subject to this part may not claim as 
confidential business information the following information:
    (1) Registration data required by Sec. 68.160(b)(1) 
through (b)(6) and (b)(8), (b)(10) through (b)(13) and NAICS code and 
Program level of the process set forth in Sec. 68.160(b)(7);
    (2) Offsite consequence analysis data required by Sec. 
68.165(b)(4), (b)(9), (b)(10), (b)(11), and (b)(12).
    (3) Accident history data required by Sec. 68.168;
    (4) Prevention program data required by Sec. 68.170(b), 
(d), (e)(1), (f) through (k);
    (5) Prevention program data required by Sec. 68.175(b), 
(d), (e)(1), (f) through (p); and
    (6) Emergency response program data required by Sec. 
68.180.
    (c) Notwithstanding the procedures specified in 40 CFR part 2, an 
owner or operator asserting a claim of CBI with respect to information 
contained in its RMP, shall submit to EPA at the time it submits the RMP 
the following:
    (1) The information claimed confidential, provided in a format to be 
specified by EPA;
    (2) A sanitized (redacted) copy of the RMP, with the notation 
``CBI'' substituted for the information 
claimed confidential, except that a generic category or class name shall 
be substituted for any chemical name or identity claimed confidential; 
and
    (3) The document or documents substantiating each claim of 
confidential business information, as described in Sec. 
68.152.

[64 FR 979, Jan. 6, 1999]



Sec. 68.152  Substantiating claims of confidential business information.

    (a) An owner or operator claiming that information is confidential 
business information must substantiate that claim by providing 
documentation

[[Page 186]]

that demonstrates that the claim meets the substantive criteria set 
forth in 40 CFR 2.301.
    (b) Information that is submitted as part of the substantiation may 
be claimed confidential by marking it as confidential business 
information. Information not so marked will be treated as public and may 
be disclosed without notice to the submitter. If information that is 
submitted as part of the substantiation is claimed confidential, the 
owner or operator must provide a sanitized and unsanitized version of 
the substantiation.
    (c) The owner, operator, or senior official with management 
responsibility of the stationary source shall sign a certification that 
the signer has personally examined the information submitted and that 
based on inquiry of the persons who compiled the information, the 
information is true, accurate, and complete, and that those portions of 
the substantiation claimed as confidential business information would, 
if disclosed, reveal trade secrets or other confidential business 
information.

[64 FR 980, Jan. 6, 1999]



Sec. 68.155  Executive summary.

    The owner or operator shall provide in the RMP an executive summary 
that includes a brief description of the following elements:
    (a) The accidental release prevention and emergency response 
policies at the stationary source;
    (b) The stationary source and regulated substances handled;
    (c) The worst-case release scenario(s) and the alternative release 
scenario(s), including administrative controls and mitigation measures 
to limit the distances for each reported scenario;
    (d) The general accidental release prevention program and chemical-
specific prevention steps;
    (e) The five-year accident history;
    (f) The emergency response program; and
    (g) Planned changes to improve safety.



Sec. 68.160  Registration.

    (a) The owner or operator shall complete a single registration form 
and include it in the RMP. The form shall cover all regulated substances 
handled in covered processes.
    (b) The registration shall include the following data:
    (1) Stationary source name, street, city, county, state, zip code, 
latitude and longitude, method for obtaining latitude and longitude, and 
description of location that latitude and longitude represent;
    (2) The stationary source Dun and Bradstreet number;
    (3) Name and Dun and Bradstreet number of the corporate parent 
company;
    (4) The name, telephone number, and mailing address of the owner or 
operator;
    (5) The name and title of the person or position with overall 
responsibility for RMP elements and implementation;
    (6) The name, title, telephone number, and 24-hour telephone number 
of the emergency contact;
    (7) For each covered process, the name and CAS number of each 
regulated substance held above the threshold quantity in the process, 
the maximum quantity of each regulated substance or mixture in the 
process (in pounds) to two significant digits, the five- or six-digit 
NAICS code that most closely corresponds to the process, and the Program 
level of the process;
    (8) The stationary source EPA identifier;
    (9) The number of full-time employees at the stationary source;
    (10) Whether the stationary source is subject to 29 CFR 1910.119;
    (11) Whether the stationary source is subject to 40 CFR part 355;
    (12) If the stationary source has a CAA Title V operating permit, 
the permit number; and
    (13) The date of the last safety inspection of the stationary source 
by a Federal, state, or local government agency and the identity of the 
inspecting entity.
    (14) Source or Parent Company E-Mail Address (Optional);
    (15) Source Homepage address (Optional)
    (16) Phone number at the source for public inquiries (Optional);
    (17) Local Emergency Planning Committee (Optional);

[[Page 187]]

    (18) OSHA Voluntary Protection Program status (Optional);

[61 FR 31726, June 20, 1996, as amended at 64 FR 980, Jan. 6, 1999]



Sec. 68.165  Offsite consequence analysis.

    (a) The owner or operator shall submit in the RMP information:
    (1) One worst-case release scenario for each Program 1 process; and
    (2) For Program 2 and 3 processes, one worst-case release scenario 
to represent all regulated toxic substances held above the threshold 
quantity and one worst-case release scenario to represent all regulated 
flammable substances held above the threshold quantity. If additional 
worst-case scenarios for toxics or flammables are required by 
Sec. 68.25(a)(2)(iii), the owner or operator shall submit the 
same information on the additional scenario(s). The owner or operator of 
Program 2 and 3 processes shall also submit information on one 
alternative release scenario for each regulated toxic substance held 
above the threshold quantity and one alternative release scenario to 
represent all regulated flammable substances held above the threshold 
quantity.
    (b) The owner or operator shall submit the following data:
    (1) Chemical name;
    (2) Percentage weight of the chemical in a liquid mixture (toxics 
only);
    (3) Physical state (toxics only);
    (4) Basis of results (give model name if used);
    (5) Scenario (explosion, fire, toxic gas release, or liquid spill 
and evaporation);
    (6) Quantity released in pounds;
    (7) Release rate;
    (8) Release duration;
    (9) Wind speed and atmospheric stability class (toxics only);
    (10) Topography (toxics only);
    (11) Distance to endpoint;
    (12) Public and environmental receptors within the distance;
    (13) Passive mitigation considered; and
    (14) Active mitigation considered (alternative releases only);

[61 FR 31726, June 20, 1996, as amended at 64 FR 980, Jan. 6, 1999]



Sec. 68.168  Five-year accident history.

    The owner or operator shall submit in the RMP the information 
provided in Sec. 68.42(b) on each accident covered by 
Sec. 68.42(a).



Sec. 68.170  Prevention program/Program 2.

    (a) For each Program 2 process, the owner or operator shall provide 
in the RMP the information indicated in paragraphs (b) through (k) of 
this section. If the same information applies to more than one covered 
process, the owner or operator may provide the information only once, 
but shall indicate to which processes the information applies.
    (b) The five- or six-digit NAICS code that most closely corresponds 
to the process.
    (c) The name(s) of the chemical(s) covered.
    (d) The date of the most recent review or revision of the safety 
information and a list of Federal or state regulations or industry-
specific design codes and standards used to demonstrate compliance with 
the safety information requirement.
    (e) The date of completion of the most recent hazard review or 
update.
    (1) The expected date of completion of any changes resulting from 
the hazard review;
    (2) Major hazards identified;
    (3) Process controls in use;
    (4) Mitigation systems in use;
    (5) Monitoring and detection systems in use; and
    (6) Changes since the last hazard review.
    (f) The date of the most recent review or revision of operating 
procedures.
    (g) The date of the most recent review or revision of training 
programs;
    (1) The type of training provided - classroom, 
classroom plus on the job, on the job; and
    (2) The type of competency testing used.
    (h) The date of the most recent review or revision of maintenance 
procedures and the date of the most recent equipment inspection or test 
and the equipment inspected or tested.
    (i) The date of the most recent compliance audit and the expected 
date of

[[Page 188]]

completion of any changes resulting from the compliance audit.
    (j) The date of the most recent incident investigation and the 
expected date of completion of any changes resulting from the 
investigation.
    (k) The date of the most recent change that triggered a review or 
revision of safety information, the hazard review, operating or 
maintenance procedures, or training.

[61 FR 31726, June 20, 1996, as amended at 64 FR 980, Jan. 6, 1999]



Sec. 68.175  Prevention program/Program 3.

    (a) For each Program 3 process, the owner or operator shall provide 
the information indicated in paragraphs (b) through (p) of this section. 
If the same information applies to more than one covered process, the 
owner or operator may provide the information only once, but shall 
indicate to which processes the information applies.
    (b) The five- or six-digit NAICS code that most closely corresponds 
to the process.
    (c) The name(s) of the substance(s) covered.
    (d) The date on which the safety information was last reviewed or 
revised.
    (e) The date of completion of the most recent PHA or update and the 
technique used.
    (1) The expected date of completion of any changes resulting from 
the PHA;
    (2) Major hazards identified;
    (3) Process controls in use;
    (4) Mitigation systems in use;
    (5) Monitoring and detection systems in use; and
    (6) Changes since the last PHA.
    (f) The date of the most recent review or revision of operating 
procedures.
    (g) The date of the most recent review or revision of training 
programs;
    (1) The type of training provided - classroom, 
classroom plus on the job, on the job; and
    (2) The type of competency testing used.
    (h) The date of the most recent review or revision of maintenance 
procedures and the date of the most recent equipment inspection or test 
and the equipment inspected or tested.
    (i) The date of the most recent change that triggered management of 
change procedures and the date of the most recent review or revision of 
management of change procedures.
    (j) The date of the most recent pre-startup review.
    (k) The date of the most recent compliance audit and the expected 
date of completion of any changes resulting from the compliance audit;
    (l) The date of the most recent incident investigation and the 
expected date of completion of any changes resulting from the 
investigation;
    (m) The date of the most recent review or revision of employee 
participation plans;
    (n) The date of the most recent review or revision of hot work 
permit procedures;
    (o) The date of the most recent review or revision of contractor 
safety procedures; and
    (p) The date of the most recent evaluation of contractor safety 
performance.

[61 FR 31726, June 20, 1996, as amended at 64 FR 980, Jan. 6, 1999]



Sec. 68.180  Emergency response program.

    (a) The owner or operator shall provide in the RMP the following 
information:
    (1) Do you have a written emergency response plan?
    (2) Does the plan include specific actions to be taken in response 
to an accidental releases of a regulated substance?
    (3) Does the plan include procedures for informing the public and 
local agencies responsible for responding to accidental releases?
    (4) Does the plan include information on emergency health care?
    (5) The date of the most recent review or update of the emergency 
response plan;
    (6) The date of the most recent emergency response training for 
employees.
    (b) The owner or operator shall provide the name and telephone 
number of the local agency with which emergency response activities and 
the emergency response plan is coordinated.
    (c) The owner or operator shall list other Federal or state 
emergency plan

[[Page 189]]

requirements to which the stationary source is subject.

[61 FR 31726, June 20, 1996, as amended at 64 FR 980, Jan. 6, 1999]



Sec. 68.185  Certification.

    (a) For Program 1 processes, the owner or operator shall submit in 
the RMP the certification statement provided in Sec. 
68.12(b)(4).
    (b) For all other covered processes, the owner or operator shall 
submit in the RMP a single certification that, to the best of the 
signer's knowledge, information, and belief formed after reasonable 
inquiry, the information submitted is true, accurate, and complete.



Sec. 68.190  Updates.

    (a) The owner or operator shall review and update the RMP as 
specified in paragraph (b) of this section and submit it in a method and 
format to a central point specified by EPA prior to June 21, 1999.
    (b) The owner or operator of a stationary source shall revise and 
update the RMP submitted under Sec. 68.150 as follows:
    (1) Within five years of its initial submission or most recent 
update required by paragraphs (b)(2) through (b)(7) of this section, 
whichever is later.
    (2) No later than three years after a newly regulated substance is 
first listed by EPA;
    (3) No later than the date on which a new regulated substance is 
first present in an already covered process above a threshold quantity;
    (4) No later than the date on which a regulated substance is first 
present above a threshold quantity in a new process;
    (5) Within six months of a change that requires a revised PHA or 
hazard review;
    (6) Within six months of a change that requires a revised offsite 
consequence analysis as provided in Sec. 68.36; and
    (7) Within six months of a change that alters the Program level that 
applied to any covered process.
    (c) If a stationary source is no longer subject to this part, the 
owner or operator shall submit a revised registration to EPA within six 
months indicating that the stationary source is no longer covered.



                   Subpart H - Other Requirements

    Source: 61 FR 31728, June 20, 1996, unless otherwise noted.



Sec. 68.200  Recordkeeping.

    The owner or operator shall maintain records supporting the 
implementation of this part for five years unless otherwise provided in 
subpart D of this part.



Sec. 68.210  Availability of information to the public.

    (a) The RMP required under subpart G of this part shall be available 
to the public under 42 U.S.C. 7414(c).
    (b) The disclosure of classified information by the Department of 
Defense or other Federal agencies or contractors of such agencies shall 
be controlled by applicable laws, regulations, or executive orders 
concerning the release of classified information.



Sec. 68.215  Permit content and air permitting authority or designated agency requirements.

    (a) These requirements apply to any stationary source subject to 
this part 68 and parts 70 or 71 of this chapter. The 40 CFR part 70 or 
part 71 permit for the stationary source shall contain:
    (1) A statement listing this part as an applicable requirement;
    (2) Conditions that require the source owner or operator to submit:
    (i) A compliance schedule for meeting the requirements of this part 
by the date provided in Sec. 68.10(a) or;
    (ii) As part of the compliance certification submitted under 40 CFR 
70.6(c)(5), a certification statement that the source is in compliance 
with all requirements of this part, including the registration and 
submission of the RMP.
    (b) The owner or operator shall submit any additional relevant 
information requested by the air permitting authority or designated 
agency.
    (c) For 40 CFR part 70 or part 71 permits issued prior to the 
deadline for registering and submitting the RMP and which do not contain 
permit conditions described in paragraph (a) of this section, the owner 
or operator or air

[[Page 190]]

permitting authority shall initiate permit revision or reopening 
according to the procedures of 40 CFR 70.7 or 71.7 to incorporate the 
terms and conditions consistent with paragraph (a) of this section.
    (d) The state may delegate the authority to implement and enforce 
the requirements of paragraph (e) of this section to a state or local 
agency or agencies other than the air permitting authority. An up-to-
date copy of any delegation instrument shall be maintained by the air 
permitting authority. The state may enter a written agreement with the 
Administrator under which EPA will implement and enforce the 
requirements of paragraph (e) of this section.
    (e) The air permitting authority or the agency designated by 
delegation or agreement under paragraph (d) of this section shall, at a 
minimum:
    (1) Verify that the source owner or operator has registered and 
submitted an RMP or a revised plan when required by this part;
    (2) Verify that the source owner or operator has submitted a source 
certification or in its absence has submitted a compliance schedule 
consistent with paragraph (a)(2) of this section;
    (3) For some or all of the sources subject to this section, use one 
or more mechanisms such as, but not limited to, a completeness check, 
source audits, record reviews, or facility inspections to ensure that 
permitted sources are in compliance with the requirements of this part; 
and
    (4) Initiate enforcement action based on paragraphs (e)(1) and 
(e)(2) of this section as appropriate.



Sec. 68.220  Audits.

    (a) In addition to inspections for the purpose of regulatory 
development and enforcement of the Act, the implementing agency shall 
periodically audit RMPs submitted under subpart G of this part to review 
the adequacy of such RMPs and require revisions of RMPs when necessary 
to ensure compliance with subpart G of this part.
    (b) The implementing agency shall select stationary sources for 
audits based on any of the following criteria:
    (1) Accident history of the stationary source;
    (2) Accident history of other stationary sources in the same 
industry;
    (3) Quantity of regulated substances present at the stationary 
source;
    (4) Location of the stationary source and its proximity to the 
public and environmental receptors;
    (5) The presence of specific regulated substances;
    (6) The hazards identified in the RMP; and
    (7) A plan providing for neutral, random oversight.
    (c) Exemption from audits. A stationary source with a Star or Merit 
ranking under OSHA's voluntary protection program shall be exempt from 
audits under paragraph (b)(2) and (b)(7) of this section.
    (d) The implementing agency shall have access to the stationary 
source, supporting documentation, and any area where an accidental 
release could occur.
    (e) Based on the audit, the implementing agency may issue the owner 
or operator of a stationary source a written preliminary determination 
of necessary revisions to the stationary source's RMP to ensure that the 
RMP meets the criteria of subpart G of this part. The preliminary 
determination shall include an explanation for the basis for the 
revisions, reflecting industry standards and guidelines (such as AIChE/
CCPS guidelines and ASME and API standards) to the extent that such 
standards and guidelines are applicable, and shall include a timetable 
for their implementation.
    (f) Written response to a preliminary determination. (1) The owner 
or operator shall respond in writing to a preliminary determination made 
in accordance with paragraph (e) of this section. The response shall 
state the owner or operator will implement the revisions contained in 
the preliminary determination in accordance with the timetable included 
in the preliminary determination or shall state that the owner or 
operator rejects the revisions in whole or in part. For each rejected 
revision, the owner or operator shall explain the basis for rejecting 
such revision. Such explanation may include substitute revisions.

[[Page 191]]

    (2) The written response under paragraph (f)(1) of this section 
shall be received by the implementing agency within 90 days of the issue 
of the preliminary determination or a shorter period of time as the 
implementing agency specifies in the preliminary determination as 
necessary to protect public health and the environment. Prior to the 
written response being due and upon written request from the owner or 
operator, the implementing agency may provide in writing additional time 
for the response to be received.
    (g) After providing the owner or operator an opportunity to respond 
under paragraph (f) of this section, the implementing agency may issue 
the owner or operator a written final determination of necessary 
revisions to the stationary source's RMP. The final determination may 
adopt or modify the revisions contained in the preliminary determination 
under paragraph (e) of this section or may adopt or modify the 
substitute revisions provided in the response under paragraph (f) of 
this section. A final determination that adopts a revision rejected by 
the owner or operator shall include an explanation of the basis for the 
revision. A final determination that fails to adopt a substitute 
revision provided under paragraph (f) of this section shall include an 
explanation of the basis for finding such substitute revision 
unreasonable.
    (h) Thirty days after completion of the actions detailed in the 
implementation schedule set in the final determination under paragraph 
(g) of this section, the owner or operator shall be in violation of 
subpart G of this part and this section unless the owner or operator 
revises the RMP prepared under subpart G of this part as required by the 
final determination, and submits the revised RMP as required under 
Sec. 68.150.
    (i) The public shall have access to the preliminary determinations, 
responses, and final determinations under this section in a manner 
consistent with Sec. 68.210.
    (j) Nothing in this section shall preclude, limit, or interfere in 
any way with the authority of EPA or the state to exercise its 
enforcement, investigatory, and information gathering authorities 
concerning this part under the Act.

     Appendix A to Part 68 - Table of Toxic Endpoints

            [As defined in Sec. 68.22 of this part]
------------------------------------------------------------------------
                                                                Toxic
          CAS No.                    Chemical name          endpoint (mg/
                                                                 L)
------------------------------------------------------------------------
107-02-8..................  Acrolein [2-Propenal].........       0.0011
107-13-1..................  Acrylonitrile [2-                    0.076
                             Propenenitrile].
814-68-6..................  Acrylyl chloride [2-Propenoyl        0.00090
                             chloride].
107-18-6..................  Allyl alcohol [2-Propen-1-ol].       0.036
107-11-9..................  Allylamine [2-Propen-1-amine].       0.0032
7664-41-7.................  Ammonia (anhydrous)...........       0.14
7664-41-7.................  Ammonia (conc 20% or greater).       0.14
7784-34-1.................  Arsenous trichloride..........       0.010
7784-42-1.................  Arsine........................       0.0019
10294-34-5................  Boron trichloride [Borane,           0.010
                             trichloro-].
7637-07-2.................  Boron trifluoride [Borane,           0.028
                             trifluoro-].
353-42-4..................  Boron trifluoride compound           0.023
                             with methyl ether (1:1)
                             [Boron,
                             trifluoro[oxybis[methane]]-,
                             T-4.
7726-95-6.................  Bromine.......................       0.0065
75-15-0...................  Carbon disulfide..............       0.16
7782-50-5.................  Chlorine......................       0.0087
10049-04-4................  Chlorine dioxide [Chlorine           0.0028
                             oxide (ClO2)].
67-66-3...................  Chloroform [Methane, trichloro-      0.49
                             ].
542-88-1..................  Chloromethyl ether [Methane,         0.00025
                             oxybis[chloro-].
107-30-2..................  Chloromethyl methyl ether            0.0018
                             [Methane, chloromethoxy-].
4170-30-3.................  Crotonaldehyde [2-Butenal]....       0.029
123-73-9..................  Crotonaldehyde, (E)-, [2-            0.029
                             Butenal, (E)-].
506-77-4..................  Cyanogen chloride.............       0.030
108-91-8..................  Cyclohexylamine                      0.16
                             [Cyclohexanamine].
19287-45-7................  Diborane......................       0.0011
75-78-5...................  Dimethyldichlorosilane               0.026
                             [Silane, dichlorodimethyl-].
57-14-7...................  1,1-Dimethylhydrazine                0.012
                             [Hydrazine, 1,1-dimethyl-].
106-89-8..................  Epichlorohydrin [Oxirane,            0.076
                             (chloromethyl)-].
107-15-3..................  Ethylenediamine [1,2-                0.49
                             Ethanediamine].

[[Page 192]]

 
151-56-4..................  Ethyleneimine [Aziridine].....       0.018
75-21-8...................  Ethylene oxide [Oxirane]......       0.090
7782-41-4.................  Fluorine......................       0.0039
50-00-0...................  Formaldehyde (solution).......       0.012
110-00-9..................  Furan.........................       0.0012
302-01-2..................  Hydrazine.....................       0.011
7647-01-0.................  Hydrochloric acid (conc 37% or       0.030
                             greater).
74-90-8...................  Hydrocyanic acid..............       0.011
7647-01-0.................  Hydrogen chloride (anhydrous)        0.030
                             [Hydrochloric acid].
7664-39-3.................  Hydrogen fluoride/Hydrofluoric       0.016
                             acid (conc 50% or greater)
                             [Hydrofluoric acid].
7783-07-5.................  Hydrogen selenide.............       0.00066
7783-06-4.................  Hydrogen sulfide..............       0.042
13463-40-6................  Iron, pentacarbonyl- [Iron           0.00044
                             carbonyl (Fe(CO)5), (TB-5-11)-
                             ].
78-82-0...................  Isobutyronitrile                     0.14
                             [Propanenitrile, 2-methyl-].
108-23-6..................  Isopropyl chloroformate              0.10
                             [Carbonochloride acid, 1-
                             methylethyl ester].
126-98-7..................  Methacrylonitrile [2-                0.0027
                             Propenenitrile, 2-methyl-].
74-87-3...................  Methyl chloride [Methane,            0.82
                             chloro-].
79-22-1...................  Methyl chloroformate                 0.0019
                             [Carbonochloridic acid,
                             methylester].
60-34-4...................  Methyl hydrazine [Hydrazine,         0.0094
                             methyl-].
624-83-9..................  Methyl isocyanate [Methane,          0.0012
                             isocyanato-].
74-93-1...................  Methyl mercaptan                     0.049
                             [Methanethiol].
556-64-9..................  Methyl thiocyanate [Thiocyanic       0.085
                             acid, methyl ester].
75-79-6...................  Methyltrichlorosilane [Silane,       0.018
                             trichloromethyl-].
13463-39-3................  Nickel carbonyl...............       0.00067
7697-37-2.................  Nitric acid (conc 80% or             0.026
                             greater).
10102-43-9................  Nitric oxide [Nitrogen oxide         0.031
                             (NO)].
8014-95-7.................  Oleum (Fuming Sulfuric acid)         0.010
                             [Sulfuric acid, mixture with
                             sulfur trioxide].
79-21-0...................  Peracetic acid [Ethaneperoxoic       0.0045
                             acid].
594-42-3..................  Perchloromethylmercaptan             0.0076
                             [Methanesulfenyl chloride,
                             trichloro-].
75-44-5...................  Phosgene [Carbonic dichloride]       0.00081
7803-51-2.................  Phosphine.....................       0.0035
10025-87-3................  Phosphorus oxychloride               0.0030
                             [Phosphoryl chloride].
7719-12-2.................  Phosphorus trichloride               0.028
                             [Phosphorous trichloride].
110-89-4..................  Piperidine....................       0.022
107-12-0..................  Propionitrile [Propanenitrile]       0.0037
109-61-5..................  Propyl chloroformate                 0.010
                             [Carbonochloridic acid,
                             propylester].
75-55-8...................  Propyleneimine [Aziridine, 2-        0.12
                             methyl-].
75-56-9...................  Propylene oxide [Oxirane,            0.59
                             methyl-].
7446-09-5.................  Sulfur dioxide (anhydrous)....       0.0078
7783-60-0.................  Sulfur tetrafluoride [Sulfur         0.0092
                             fluoride (SF4), (T-4)-].
7446-11-9.................  Sulfur trioxide...............       0.010
75-74-1...................  Tetramethyllead [Plumbane,           0.0040
                             tetramethyl-].
509-14-8..................  Tetranitromethane [Methane,          0.0040
                             tetranitro-].
7750-45-0.................  Titanium tetrachloride               0.020
                             [Titanium chloride (TiCl4) (T-
                             4)-].
584-84-9..................  Toluene 2,4-diisocyanate             0.0070
                             [Benzene, 2,4-diisocyanato-1-
                             methyl-].
91-08-7...................  Toluene 2,6-diisocyanate             0.0070
                             [Benzene, 1,3-diisocyanato-2-
                             methyl-].
26471-62-5................  Toluene diisocyanate                 0.0070
                             (unspecified isomer)
                             [Benzene, 1,3-
                             diisocyanatomethyl-].
75-77-4...................  Trimethylchlorosilane [Silane,       0.050
                             chlorotrimethyl-].
108-05-4..................  Vinyl acetate monomer [Acetic        0.26
                             acid ethenyl ester].
------------------------------------------------------------------------


[61 FR 31729, June 20, 1996, as amended at 62 FR 45132, Aug. 25, 1997]



PART 69 - SPECIAL EXEMPTIONS FROM REQUIREMENTS OF THE CLEAN AIR ACT--Table of Contents




                          Subpart A - Guam

Sec.
69.11 New exemptions.
69.12 Continuing exemptions.
69.13 Title V conditional exemption.

                     Subpart B - American Samoa

69.21 New exemptions. [Reserved]
69.22 Title V conditional exemption.

      Subpart C - Commonwealth of the Northern Mariana Islands

69.31 New exemptions. [Reserved]
69.32 Title V conditional exemption.

                Subpart D - The U.S. Virgin Islands

69.41 New exemptions.

                         Subpart E - Alaska

69.51 Motor vehicle diesel fuel.


[[Page 193]]


    Authority: 42 U.S.C. 7545(c), (g) and (i), and 7625-1.

    Source: 50 FR 25577, June 20, 1985, unless otherwise noted.



                          Subpart A - Guam



Sec. 69.11  New exemptions.

    (a) Pursuant to section 325(a) of the Clean Air Act 
(``CAA'') and a petition submitted by the 
Governor of Guam (``Petition''), the 
Administrator of the Environmental Protection Agency 
(``EPA'') conditionally exempts electric 
generating units on Guam from certain CAA requirements.
    (1) A waiver of the requirement to obtain a prevention of 
significant deterioration (``PSD'') permit 
prior to construction is granted for the electric generating units 
identified in the Petition as Cabras Diesel No. 1, the Tenjo project, 
and three 6-megawatt diesel generators to be constructed at Orote, with 
the following conditions:
    (i) Each electric generating unit shall not be operated until a 
final PSD permit is issued for that unit;
    (ii) Each electric generating unit shall not be operated until that 
unit complies with all requirements of its PSD permit, including, if 
necessary, retrofitting with the best available control technology 
(``BACT'');
    (iii) The PSD application for each electric generating unit shall be 
deemed complete without the submittal of the required one year of on-
site meteorological data, however, EPA will not issue a PSD permit to 
such a unit prior to submission of such data or data which the EPA finds 
to be an equivalent and acceptable substitute; and
    (iv) If any electric generating unit covered by this paragraph is 
operated either prior to the issuance of a final PSD permit or without 
BACT equipment, that electric generating unit shall be deemed in 
violation of this waiver and the CAA beginning on the date of 
commencement of construction of that unit.
    (2) A waiver of the three nonattainment area requirements (a 
construction ban, the use of lowest achievable emission rate control 
equipment, and emission offset requirements) currently applicable to the 
Cabras-Piti area is granted for electric generating units with the 
following conditions:
    (i) A tower and meteorological station shall be constructed in the 
Cabras-Piti area by May 1, 1993;
    (ii) Meteorological data shall be collected from the Cabras-Piti 
station which is sufficient to run air quality models both to 
demonstrate no current exceedences of the primary national ambient air 
quality standard for sulfur dioxide (``sulfur dioxide 
NAAQS''), as set forth at 40 CFR 50.4, and sufficient to 
submit a complete request for redesignation of the area to attainment;
    (iii) Ambient sulfur dioxide monitors shall be installed and 
operated in accordance with the procedures set forth at 40 CFR part 58, 
the PSD air monitoring requirements, and any additional monitoring 
requested by EPA to verify the efficacy of the intermittent control 
strategy (``ICS'') of fuel switching;
    (iv) Within three years from the effective date of this waiver, the 
Governor of Guam shall submit to the EPA a complete request that the 
Cabras-Piti area be redesignated to attainment for the sulfur dioxide 
NAAQS;
    (v) Electric generating units to be constructed in the Cabras-Piti 
area must submit applications for PSD permits as though the area had 
been redesignated to attainment for the sulfur dioxide NAAQS;
    (vi) The Cabras-Piti area electric generating units shall comply 
with the fuel switching ICS described in paragraph (a)(3)(i) of this 
section;
    (vii) If the collected data and air quality analysis does not 
demonstrate to the EPA's satisfaction that there are no current or 
likely future exceedences of the sulfur dioxide NAAQS, the EPA will so 
notify the Governor of Guam;
    (viii) Within six months of such notification, the Governor of Guam 
shall submit to the EPA an implementation plan which includes a schedule 
of emission reductions and/or control measures that will ensure 
achievement of the sulfur dioxide NAAQS within one year of submission of 
the implementation plan; and
    (ix) If the Governor of Guam fails to submit an implementation plan 
in a timely fashion, or if EPA disapproves

[[Page 194]]

that implementation plan, all electric generating units subject to the 
fuel switching ICS described in paragraph (a)(3)(i) of this section 
shall be fueled exclusively with low sulfur fuel.
    (3) A waiver of the prohibition on the use of the ICS of fuel 
switching is granted for electric generating units with the following 
conditions:
    (i) The protocol to be followed for the ICS of fuel switching for 
electric generating units shall be the one set forth in a separate EPA 
document entitled Cabras-Piti Area Intermittent Control Strategy; and
    (ii) This protocol may be modified by the EPA to protect against 
exceedences of the sulfur dioxide NAAQS and to accommodate additional 
electric generating units.
    (b) The waiver will be periodically reviewed (at intervals no longer 
than three years) and, as deemed appropriate by the Administrator, can 
be modified or terminated at any time through rulemaking procedures.
    (c) Pursuant to Section 325(a) of the CAA and a petition submitted 
by the Governor of Guam on July 14, 1995 (``1995 
Petition''), the Administrator of EPA conditionally 
exempts Guam Power Authority (``GPA'') from 
certain CAA requirements.
    (1) A waiver of the requirement to obtain a PSD permit prior to 
construction is granted for the electric generating unit identified in 
the 1995 Petition as Cabras Unit No. 4, with the following conditions:
    (i) Cabras Unit No. 4 shall not operate until a final PSD permit is 
received by GPA for this unit;
    (ii) Cabras Unit No. 4 shall not operate until it complies with all 
requirements of its PSD permit, including, if necessary, retrofitting 
with BACT;
    (iii) If Cabras Unit No. 4 operates either prior to the issuance of 
a final PSD permit or without BACT equipment, Cabras Unit No. 4 shall be 
deemed in violation of this waiver and the CAA beginning on the date of 
commencement of construction of the unit.
    (2) A waiver of the requirement to obtain a PSD permit prior to the 
operation of the unit identified in the 1995 Petition as Cabras Unit No. 
3 is granted subject to the following conditions:
    (i) The protocol to be followed for the ICS of fuel switching for 
electric generating units shall be modified to require the use of fuel 
oil with a sulfur content of 2.00 percent or less during offshore wind 
conditions. This fuel shall be fired in Cabras Power Plant Units Nos. 1 
through 3 and in Piti Power Plant Units Nos. 4 and 5.
    (ii) Cabras Unit No. 3 shall operate in compliance with all 
applicable requirements in its permits to construct and to operate as 
issued by Guam Environmental Protection Agency.
    (iii) The waiver provisions allowing Cabras Unit No. 3 to operate 
prior to issuance of a PSD permit shall expire on August 15, 1996, or 
upon the receipt by GPA of a PSD permit for Cabras Unit No. 3, whichever 
event occurs first.
    (3) On or before October 15, 1995, GPA shall submit to EPA, Region 
IX, a report concerning the operation of Cabras Unit No. 3 and the 
construction of Cabras Unit No. 4. The report shall contain:
    (i) A summary of GPA's conclusions from its wind tunnel study;
    (ii) A description of the alternatives available to assure 
compliance with all air quality requirements, including PSD 
requirements, during the operation of Cabras Units Nos. 3 and 4;
    (iii) A description of the alternative GPA chooses to assure 
compliance with all air quality requirements, including PSD 
requirements, during the operation of Cabras Units Nos. 3 and 4; and
    (iv) A plan of implementation by GPA.
    (d)(1) Pursuant to Section 325(a) of the CAA and a petition 
submitted by the Governor of Guam on February 11, 1997 
(``1997 Petition''), the Administrator of 
EPA conditionally exempts Piti Power Plant Units No. 8 and No. 9 from 
certain CAA requirements.
    (2) A waiver of the requirement to obtain a PSD permit prior to 
construction is granted for the electric generating units identified in 
the 1997 Petition as Piti Units No. 8 and No. 9 (two 45 megawatt 
baseload diesel electric generators and associated waste heat recovery 
boilers with a steam generator), with the following conditions:

[[Page 195]]

    (i) Piti Units No. 8 and No. 9 shall not operate until final PSD 
permits are received for these units;
    (ii) Piti Units No. 8 and No. 9 shall not operate until they comply 
with all requirements of their PSD permits, including, if necessary, 
retrofitting with BACT;
    (iii) If either Piti Units No. 8 or No. 9 operate either prior to 
the issuance of a final PSD permit or without BACT equipment, the Piti 
Unit(s) shall be deemed in violation of this waiver and the CAA 
beginning on the date of commencement of construction of the unit(s).

[58 FR 43043, Aug. 12, 1993, as amended at 60 FR 48038, Sept. 18, 1995; 
62 FR 44416, Aug. 21, 1997]



Sec. 69.12  Continuing exemptions.

    (a) Effective on the expiration date of the initial eighteen month 
exemption provided under section 325(b) of ``the 
Act'', the Administrator of the Environmental Protection 
Agency (EPA) exempts the Guam Power Authority's two sixty-six megawatt 
oil-fired steam units which comprise the Cabras Power Plant from sulfur 
dioxide requirements associated with New Source Performance Standards 
(NSPS) under section 111 of the Clean Air Act and from the related NSPS 
limitation on sulfur dioxide emissions contained in the Guam SIP.
    (b) The exemption will be reviewed at intervals and upon occasions 
to be specified by EPA (not longer than 2 years), allowing EPA to 
determine whether the factual circumstances upon which it is based, 
including commitments made by GPA in the application for extension and 
the continuing attainment of the National Ambient Air Quality Standards 
(NAAQS) for Sulfur Dioxide, have changed. The commitments include 
reporting requirements specified by the Guam Environmental Protection 
Agency (GEPA), including but not limited to strict implementation of 
both the monitoring (wind direction and ambient SO2 
concentration) and fuel switching portions of the control strategy, 
reporting to GEPA of all applications of the strategy, and reporting to 
GEPA of laboratory analyses of percent sulfur in all new fuel stocks 
acquired GPA. A finding by EPA that the source is not in compliance with 
the terms of the exemption will be grounds for enforcement of the terms 
of the exemption under section 113. A finding by EPA that factual 
circumstances have changed will be grounds for revocation of the 
exemption and enforcement of the underlying Clean Air Act requirements.
    (c) It is a condition of this action that GPA provide to EPA a copy 
of any GPA application for rate changes or for commercial credit for 
construction or replacement of capital assets, simultaneously with 
submission of such application to the rate making authority or 
commercial credit institution. No later than the 90th day after a 
finding by EPA that the circumstances upon which the determination for 
continuing the exemption was originally made have changed, this 
exemption shall terminate unless within that time GPA submits 
information that it is taking all practicable steps to comply with NSPS 
and SIP requirements related to SO2. EPA shall review such 
information under the procedures it has established and shall, as 
appropriate, extend or terminate the exemption.



Sec. 69.13  Title V conditional exemption.

    (a) Conditional exemption. In response to a petition submitted by 
the Governor of Guam and pursuant to section 325(a) of the Clean Air Act 
(Act), the Administrator of the United States EPA (EPA) grants the 
following conditional exemptions:
    (1) Guam is exempted from the requirement to develop, submit for 
approval, and implement an operating permit program under title V of the 
Clean Air Act on the condition that Guam meets the requirements of 
paragraph (b) of this section and subject to the provisions of 
paragraphs (c) through (e) of this section.
    (2) Except for sources listed under paragraph (a)(4) of this 
section, owners or operators of sources located in Guam subject to the 
operating permit requirements of title V of the Clean Air Act are exempt 
from the requirement to apply for and obtain a title V operating permit, 
on the condition that the owner or operator of each such source

[[Page 196]]

must apply for and obtain an operating permit under an EPA approved 
alternate program that meets the requirements of paragraph (b) of this 
section and subject to the provisions of paragraphs (c) through (e) of 
this section. The owner or operator of each such source shall apply for 
and obtain a permit under the alternate operating permit program by the 
deadlines set forth in the approved program, but in any event shall 
obtain a permit no later than January 13, 2003. If the owner or operator 
of any source has not obtained an operating permit under an alternate 
operating program approved by EPA for Guam by January 13, 2003, the 
exemption for such source shall expire and the owner or operator of such 
source shall become subject to the permitting requirements of 40 CFR 
part 71 on that date, consistent with paragraph (d)(4) of this section.
    (3) Upon EPA approval of an alternate operating permit program 
adopted by Guam in accordance with this Sec. 69.13, a person 
shall not violate any permit condition or term in a permit that has been 
issued under such alternate permit program.
    (4) This exemption does not apply to owners or operators of major 
sources of hazardous air pollutants (HAPs) as defined under section 112 
of the Clean Air Act or to owners or operators of solid waste 
incinerators subject to the title V requirements of section 129(e) of 
the Act. Owners or operators of major sources of HAPs or solid waste 
incinerators shall be subject to the requirements of 40 CFR part 71 and 
shall apply for and obtain a part 71 permit by the deadlines specified 
in 40 CFR part 71. Any owner or operator of a major source of HAPs 
subject to 40 CFR part 63, subpart B, shall submit a timely part 71 
permit application as required by 40 CFR part 71 and 40 CFR part 63, 
subpart B, requesting a case-by-case section 112(g) or 112(j) Maximum 
Achievable Control Technology (MACT) determination.
    (b) Requirements for the alternate operating program. Guam shall 
develop and submit an alternate operating permit program (the program) 
to EPA for approval. Upon approval by EPA, Guam shall implement the 
program. The program, including the necessary statutory and regulatory 
authority, must be submitted by January 13, 1999 for approval. The 
submittal shall include the following elements:
    (1) The program must contain regulations that ensure that:
    (i) The permits shall include emission limits and standards, and 
other terms or conditions necessary to ensure compliance with all 
applicable federal requirements, as defined under 40 CFR 70.2.
    (ii) The limitations, controls, and requirements in the permits 
shall be permanent, quantifiable, and otherwise enforceable as a 
practical matter.
    (iii) Permits shall contain monitoring, recordkeeping and reporting 
requirements sufficient to ensure compliance with applicable federal 
requirements during the reporting period.
    (iv) The program shall require that the owner or operator of each 
source submit permit applications with compliance certifications 
describing the source's compliance status with all applicable 
requirements. The program shall also provide that each permit contain a 
requirement that the owner or operator of a source submit annual 
compliance certifications. The compliance certification shall contain a 
compliance plan, and shall contain a schedule for expeditiously 
achieving compliance if the source is not in compliance with all 
applicable requirements. The program must provide that approval of a 
permit with a compliance plan and schedule does not sanction 
noncompliance.
    (2) The program shall provide for the collection of fees from 
permitted sources or other revenues in an amount that will pay for the 
cost of operation of such a program and ensure that these funds are used 
solely to support the program.
    (3) The program shall provide for public notice and a public comment 
period of at least 30 days for each permit, significant permit 
modification, and permit renewal, and shall include submittal to EPA of 
each permit, significant permit modification, and permit renewal.
    (4) The program shall provide EPA at least 45 days from receipt of a 
permit, modification, or renewal for EPA review and objection prior to 
issuance.

[[Page 197]]

The program shall provide that if EPA objects to a permit sent to EPA 
for review, Guam cannot issue such permit until the permit is revised in 
a manner that resolves EPA's objections. The program shall provide that 
Guam will have no more than 180 days to resolve EPA's objections and 
that if the objections are not resolved within that time period, EPA 
shall issue the permit under 40 CFR part 71.
    (5) The program shall provide that all documents other than 
confidential business information will be made available to the public.
    (6) The program shall provide Guam with the authority to enforce 
permits, including the authority to assess civil and criminal penalties 
up to $10,000 per day per violation and to enjoin activities that are in 
violation of the permit, the program, or the Act without first revoking 
the permit.
    (7) The program shall require that owners or operators of nonmajor 
sources of hazardous air pollutants that are required to obtain title V 
permits, and owners or operators of major sources of all other air 
pollutants as defined at 40 CFR 70.2 that are exempted from 40 CFR part 
71 under paragraph (a) of this section, obtain an operating permit under 
the approved program. The program shall include a schedule for issuing 
permits to all subject sources within three years of EPA approval of the 
program.
    (8) The program shall include a system of regular inspections of 
permitted sources, a system to identify any unpermitted major sources, 
and guidelines for appropriate responses to violations.
    (9) The program shall provide for the issuance of permits with a 
fixed term that shall not exceed five years.
    (10) The program shall allow Guam or the EPA to reopen a permit for 
cause. The program shall provide that if EPA provides Guam with written 
notice that a permit must be reopened for cause, Guam shall issue a 
revised permit within 180 days (including public notice and comment) 
that sufficiently addresses EPA's concerns. The program shall provide 
that if Guam fails to issue a permit that resolves EPA's concerns within 
180 days, then EPA will terminate, modify, or revoke and reissue the 
permit under part 71 after providing the permittee and the public with 
notice and opportunity for comment.
    (c) State Implementation Plan (SIP) submittal. In conjunction with 
the submittal of the alternative operating permit program, Guam shall, 
no later than January 13, 1999 submit a revision to its SIP that 
provides that a person shall not violate a permit condition or term in 
an operating permit that has been issued under an EPA approved alternate 
operating permit program adopted by Guam pursuant to the exemption 
authorized in this Sec. 69.13.
    (d) Expiration and revocation of the exemption. This exemption shall 
expire or may be revoked under the following circumstances:
    (1) If Guam fails to submit an alternate operating permit program by 
January 13, 1999, the exemption shall automatically expire with no 
further rulemaking and 40 CFR part 71 shall become effective for all 
subject sources in Guam on that date.
    (2) In the event that EPA disapproves Guam's alternate operating 
permit program because the program does not meet the requirements set 
forth in paragraph (b) of this section, EPA will revoke the exemption by 
rulemaking.
    (3) If, by January 13, 2003, the owner or operator of any subject 
source has not obtained a federally enforceable operating permit under 
an EPA approved program, the exemption shall automatically expire for 
such source and such source shall be subject to the permitting 
requirements of 40 CFR part 71. Guam will work with EPA to identify such 
sources prior to expiration of the exemption under this paragraph (d).
    (4) EPA shall revoke the exemption in its entirety through 
rulemaking if Guam does not adequately administer and enforce an 
alternate operating permit program approved by EPA.
    (5) EPA shall revoke the exemption by rulemaking with respect to the 
owner or operator of any source if, during the 45-day review period, EPA 
objects to issuance of a permit and Guam fails to resolve EPA's 
objections within 180 days. EPA shall also revoke the exemption by 
rulemaking for the owner or operator of any source in the event

[[Page 198]]

that EPA reopens a permit for cause and Guam does not issue a permit 
that resolves the concerns as set forth in EPA's notice to reopen within 
180 days.
    (6) EPA reserves its authority to revoke or modify this exemption in 
whole or in part.
    (e) Scope of the exemption. This exemption applies solely to the 
requirement that an owner or operator obtain an operating permit under 
title V of the Clean Air Act and the requirement that Guam implement a 
title V permit program. In addition, this exemption does not apply to 
owners or operators of sources set forth in paragraph (a)(4) of this 
section. Owners and operators of air pollutant sources are required to 
comply with all other applicable requirements of the Clean Air Act. For 
purposes of complying with any applicable requirement that is triggered 
or implemented by the approval of a title V permit program, the approval 
date for owners or operators to which this exemption applies shall be 
the date that EPA approves the alternate program for each territory or, 
for owners or operators of sources that are subject to 40 CFR part 71, 
the approval date shall be the effective date of 40 CFR part 71, which 
is July 31, 1996.
    (f) Interim approval of alternate permit program.
    (1) The following sections of Guam's Air Pollution Control Standards 
and Regulations are granted interim approval as Guam's alternate permit 
program:

1101.1(a) Administrator
1101.1(d) Air pollutant
1101.1(e) Air pollution
1101.1(i) Air pollution emission source
1101.1(r) CFR
1101.1(s) Clean Air Act
1101.1(t) Commenced
1101.1(v) Compliance Plan
1101.1(aa) Emission
1101.1(cc) Emissions unit
1101.1(ii) Fugitive Emissions
1101.1(jj) GEPA
1101.1(kk) Hazardous air pollutant
1101.1(xx) Owner or operator
1101.1(zz) Permit
1101.1(bbb) Person
1101.1(eee) Potential to emit
1101.1(iii) Regulated air pollutant
1101.1(jjj) Responsible official
1101.1(ooo) Source
1101.1(uuu) USEPA
1101.1(vvv) USEPA Administrator
1102.3 Certification
1102.7 Public Access to Information
1102.9 Prompt Reporting of Deviations
1104.1 Definitions
(a) Administrative Permit Amendment
(b) AP-42
(c) Applicable requirement
(d) Federal oversight source
(e) Insignificant source
(f) Insignificant sources - Type I
(g) Insignificant sources - Type II
(h) Major source
(i) Minor source
(j) Modification
(k) Pollution prevention
(l) Significant modification
(m) Transition period
1104.2 Applicability
1104.3 General conditions for considering applications
1104.4 Holding and transfer of permit
1104.5(a) Cancellation of Air Pollution Control Permit
1104.6 Air Pollution Control Permit Application
1104.7 Duty to Supplement or Correct Permit Applications
1104.8 Compliance Plan
1104.9 Compliance Certification of Air Pollution Emission Sources
1104.10 Transition Period and Deadlines to Submit First Applications
1104.11 Permit Term
1104.12 Permit Content
1104.13 Inspections
1104.14 Federally-Enforceable Permit Terms and Conditions
1104.15 Transmission of Information to USEPA
1104.16 USEPA Oversight
1104.17 Emergency Provision
1104.18 Permit Termination, Suspension, Reopening, and Amendment
1104.19 Public Participation
1104.20 Administrative Permit Amendment
1104.21 General Fee Provisions
1104.22 Air Pollution Control Special Fund
1104.23 Application Fees for Air Pollution Emission Sources
1104.24 Annual Fees for Air Pollution Emission Sources
1104.25 Penalties and Remedies
1106 Standards of Performance for Air Pollution Emission Sources

    (2)(i) If Guam does not submit a revised alternate operating permit 
program within 18 months of April 9, 2003, then interim approval of the 
alternate permit program shall expire with no further rulemaking and 40 
CFR part 71 shall become effective for all subject sources in Guam.
    (ii) If Guam submits revisions within 18 months of April 9, 2003, 
the interim

[[Page 199]]

approval will continue for an additional 6 months while EPA reviews the 
amended program to determine if it qualifies for full approval. Unless 
EPA approves the amended program, the interim approval will expire with 
no further rulemaking two years after April 9, 2003. EPA will approve 
the amended program and provide notice of the approval in the Federal 
Register if the amended program meets all the conditions of the 
exemption.
    (3) SIP Revision. Guam shall adopt, pursuant to required procedures, 
and submit to EPA a revision to Guam's SIP that provides that a person 
shall not violate a permit condition or term in an operating permit that 
has been issued under an EPA approved alternate operating permit program 
adopted by Guam pursuant the exemption authorized in this Sec. 
69.13.

[61 FR 58289, Nov. 13, 1996; 61 FR 66077, Dec. 16, 1996, as amended at 
68 FR 1167, Jan. 9, 2003]



                     Subpart B - American Samoa



Sec. 69.21  New exemptions. [Reserved]



Sec. 69.22  Title V conditional exemption.

    (a) Conditional exemption. In response to a petition submitted by 
the Governor of American Samoa (American Samoa) and pursuant to section 
325(a) of the Clean Air Act (Act), the Administrator of the United 
States EPA (EPA) grants the following conditional exemptions:
    (1) American Samoa is exempted from the requirement to develop, 
submit for approval, and implement an operating permit program under 
title V of the Clean Air Act on the condition that American Samoa meets 
the requirements of paragraph (b) of this section and subject to the 
provisions of paragraphs (c) through (f) of this section.
    (2) Except for sources listed under paragraph (a)(4) of this 
section, owners or operators of sources located in American Samoa 
subject to the operating permit requirements of title V of the Clean Air 
Act are exempt from the requirement to apply for and obtain a title V 
operating permit, on the condition that the owner or operator of each 
such source must apply for and obtain an operating permit under an EPA 
approved alternate program that meets the requirements of paragraph (b) 
of this section and subject to the provisions of paragraphs (c) through 
(f) of this section. The owner or operator of each such source shall 
apply for and obtain a permit under the alternate operating permit 
program by the deadlines set forth in the approved program, but in any 
event shall obtain a permit no later than January 13, 2003. If the owner 
or operator of any source has not obtained an operating permit under an 
alternate operating program approved by EPA for American Samoa by 
January 13, 2003, the exemption for such source shall expire and the 
owner or operator of such source shall become subject to the permitting 
requirements of 40 CFR part 71 on that date, consistent with paragraph 
(e)(4) of this section.
    (3) Upon EPA approval of an alternate operating permit program 
adopted by American Samoa in accordance with this Sec. 69.22, 
a person shall not violate any permit condition or term in a permit that 
has been issued under such alternate permit program.
    (4) This exemption does not apply to owners or operators of major 
sources of hazardous air pollutants (HAPs) as defined under section 112 
of the Clean Air Act or to owners or operators of solid waste 
incinerators subject to the title V requirements of section 129(e) of 
the Act. Owners or operators of major sources of HAPs or solid waste 
incinerators shall be subject to the requirements of 40 CFR part 71 and 
shall apply for and obtain a part 71 permit by the deadlines specified 
in 40 CFR part 71. Any owner or operator of a major source of HAPs 
subject to 40 CFR part 63, subpart B, shall submit a timely part 71 
permit application as required by 40 CFR part 71 and 40 CFR part 63, 
subpart B, requesting a case-by-case 112(g) or 112(j) Maximum Achievable 
Control Technology (MACT) determination.
    (b) Requirements for the alternate operating program. American Samoa 
shall develop and submit an alternate operating permit program (the 
program) to EPA for approval. Upon approval by

[[Page 200]]

EPA, American Samoa shall implement the program. The program, including 
the necessary statutory and regulatory authority, must be submitted by 
January 13, 1999 for approval. The submittal shall include the following 
elements:
    (1) The program must contain regulations that ensure that:
    (i) The permits shall include emission limits and standards, and 
other terms or conditions necessary to ensure compliance with all 
applicable federal requirements, as defined under 40 CFR 70.2.
    (ii) The limitations, controls, and requirements in the permits 
shall be permanent, quantifiable, and otherwise enforceable as a 
practical matter.
    (iii) Permits shall contain monitoring, recordkeeping and reporting 
requirements sufficient to ensure compliance with applicable federal 
requirements during the reporting period.
    (iv) The program shall require that the owner or operator of each 
source submit permit applications with compliance certifications 
describing the source's compliance status with all applicable 
requirements. The program shall also provide that each permit contain a 
requirement that the owner or operator of a source submit annual 
compliance certifications. The compliance certification shall contain a 
compliance plan, and shall contain a schedule for expeditiously 
achieving compliance if the source is not in compliance with all 
applicable requirements. The program must provide that approval of a 
permit with a compliance plan and schedule does not sanction 
noncompliance.
    (2) The program shall provide for the collection of fees from 
permitted sources or other revenues in an amount that will pay for the 
cost of operation of such a program and ensure that these funds are used 
solely to support the program.
    (3) The program shall provide for public notice and a public comment 
period of at least 30 days for each permit, significant permit 
modification, and permit renewal, and shall include submittal to EPA of 
each permit, significant permit modification, and permit renewal.
    (4) The program shall provide EPA at least 45 days from receipt of a 
permit, modification, or renewal for EPA review and objection prior to 
issuance. The program shall provide that if EPA objects to a permit sent 
to EPA for review, American Samoa cannot issue such permit until the 
permit is revised in a manner that resolves EPA's objections. The 
program will provide that American Samoa will have no more than 180 days 
to resolve EPA's objections and that if the objections are not resolved 
within that time period, EPA shall issue the permit under 40 CFR part 
71.
    (5) The program shall provide that all documents other than 
confidential business information will be made available to the public.
    (6) The program shall provide American Samoa with the authority to 
enforce permits, including the authority to assess civil and criminal 
penalties up to $10,000 per day per violation and to enjoin activities 
that are in violation of the permit, the program, or the Act without 
first revoking the permit.
    (7) The program shall require that owners or operators of nonmajor 
sources of hazardous air pollutants that are required to obtain title V 
permits, and owners or operators of major sources of all other air 
pollutants as defined in 40 CFR 70.2 that are exempted from 40 CFR part 
71 under paragraph (a) of this section, obtain an operating permit under 
the approved program. The program shall include a schedule for issuing 
permits to all subject sources within three years of EPA approval of the 
program.
    (8) The program shall include a system of regular inspections of 
permitted sources, a system to identify any unpermitted major sources, 
and guidelines for appropriate responses to violations.
    (9) The program shall provide for the issuance of permits with a 
fixed term that shall not exceed five years.
    (10) The program shall allow American Samoa or the EPA to reopen a 
permit for cause. The program shall provide that if EPA provides 
American Samoa with written notice that a permit must be reopened for 
cause, American Samoa shall issue a revised permit within 180 days 
(including public notice

[[Page 201]]

and comment) that sufficiently addresses EPA's concerns. The program 
shall provide that if American Samoa fails to issue a permit that 
resolves EPA's concerns within 180 days, then EPA will terminate, 
modify, or revoke and reissue the permit under part 71 after providing 
the permittee and the public with notice and opportunity for comment.
    (c) Ambient air quality program. American Samoa shall implement the 
following program to address the National Ambient Air Quality Standards 
(NAAQS) as a condition of the waiver:
    (1) American Samoa shall collect complete meteorological data and 
complete refined air quality modeling for the Pago Pago Harbor and 
submit such data and modeling results to EPA by January 13, 1999.
    (2) American Samoa shall address any NAAQS exceedances demonstrated 
through the modeling results with revisions to its SIP that shall be 
submitted by January 13, 2000. The plan shall ensure compliance with the 
NAAQS is achieved by January 14, 2002.
    (d) State Implementation Plan (SIP) submittal. In conjunction with 
the submittal of the alternative operating permit program, American 
Samoa shall, no later than January 13, 1999, submit a revision to its 
SIP that provides that a person shall not violate a permit condition or 
term in an operating permit that has been issued under an EPA approved 
alternate operating permit program adopted by American Samoa pursuant to 
the exemption authorized in this Sec. 69.22.
    (e) Expiration and revocation of the exemption. This exemption shall 
expire or may be revoked under the following circumstances:
    (1) If American Samoa fails to submit the required alternate 
operating permit program or modeling (and supporting data) by March 15, 
1999, the exemption shall automatically expire with no further 
rulemaking and 40 CFR part 71 shall become effective for all subject 
sources in American Samoa on that date. The exemption will also expire 
with no further rulemaking in the event that American Samoa fails to 
submit a SIP revision by January 13, 2000, consistent with paragraph 
(c)(2) of this section.
    (2) In the event that EPA disapproves American Samoa's alternate 
operating permit program because the program does not meet the 
requirements set forth in paragraph (b) of this section, EPA will revoke 
the exemption by rulemaking.
    (3) If, by March 14, 2003, the owner or operator of any subject 
source has not obtained a federally enforceable operating permit under 
an EPA approved program, the exemption shall automatically expire for 
such source and such source shall be subject to the permitting 
requirements of 40 CFR part 71. American Samoa will work with EPA to 
identify such sources prior to expiration of the exemption under this 
paragraph (d).
    (4) EPA shall revoke the exemption in its entirety through 
rulemaking if American Samoa does not adequately administer and enforce 
an alternate operating permit program approved by EPA.
    (5) EPA shall revoke the exemption by rulemaking with respect to the 
owner or operator of any source if, during the 45-day review period, EPA 
objects to issuance of a permit and American Samoa fails to resolve 
EPA's objections within 180 days. EPA shall also revoke the exemption by 
rulemaking for the owner or operator of any source in the event that EPA 
reopens a permit for cause and American Samoa does not issue a permit 
that resolves the concerns as set forth in EPA's notice to reopen within 
180 days.
    (6) EPA reserves its authority to revoke or modify this exemption in 
whole or in part.
    (f) Scope of the exemption. This exemption applies solely to the 
requirement that an owner or operator obtain an operating permit under 
title V of the Clean Air Act and the requirement that American Samoa 
implement a title V permit program. In addition, this exemption does not 
apply to owners or operators of sources set forth in paragraph (a)(4) of 
this section. Owners and operators of air pollutant sources are required 
to comply with all other applicable requirements of the Clean Air Act. 
For purposes of complying with any applicable requirement that is 
triggered or implemented by the approval of a title V permit program, 
the

[[Page 202]]

approval date for owners or operators to which this exemption applies 
shall be the date that EPA approves the alternate program for each 
territory or, for owners or operators of sources that are subject to 40 
CFR part 71, the approval date shall be the effective date of 40 CFR 
part 71, which is July 31, 1996.

[61 FR 58291, Nov. 13, 1996; 61 FR 66077, Dec. 16, 1996]



      Subpart C - Commonwealth of the Northern Mariana Islands



Sec. 69.31  New exemptions. [Reserved]



Sec. 69.32  Title V conditional exemption.

    (a) Conditional exemption. In response to a petition submitted by 
the Governor of The Commonwealth of the Northern Mariana Islands (CNMI) 
and pursuant to section 325(a) of the Clean Air Act (Act), the 
Administrator of the United States EPA (EPA) grants the following 
conditional exemptions:
    (1) CNMI is exempted from the requirement to develop, submit for 
approval, and implement an operating permit program under title V of the 
Clean Air Act on the condition that CNMI meets the requirements of 
paragraph (b) of this section and subject to the provisions of 
paragraphs (c) through (f) of this section.
    (2) Except for sources listed under paragraph (a)(4) of this 
section, owners or operators of sources located in CNMI subject to the 
operating permit requirements of title V of the Clean Air Act are exempt 
from the requirement to apply for and obtain a title V operating permit, 
on the condition that the owner or operator of each such source must 
apply for and obtain an operating permit under an EPA approved alternate 
program that meets the requirements of paragraph (b) of this section and 
subject to the provisions of paragraphs (c) through (f) of this section. 
The owner or operator of each such source shall apply for and obtain a 
permit under the alternate operating permit program by the deadlines set 
forth in the approved program, but in any event shall obtain a permit no 
later than January 13, 2003. If the owner or operator of any source has 
not obtained an operating permit under an alternate operating program 
approved by EPA for CNMI by January 13, 2003, the exemption for such 
source shall expire and the owner or operator of such source shall 
become subject to the permitting requirements of 40 CFR part 71 on that 
date, consistent with paragraph (e)(3) of this section.
    (3) Upon EPA approval of an alternate operating permit program 
adopted by CNMI in accordance with this Sec. 69.32, a person 
shall not violate any permit condition or term in a permit that has been 
issued under such alternate permit program.
    (4) This exemption does not apply to owners or operators of major 
sources of hazardous air pollutants (HAPs) as defined under section 112 
of the Clean Air Act or to owners or operators of solid waste 
incinerators subject to the title V requirements of section 129(e) of 
the Act. Owners or operators of major sources of HAPs or solid waste 
incinerators shall be subject to the requirements of 40 CFR part 71 and 
shall apply for and obtain a part 71 permit by the deadlines specified 
in 40 CFR part 71. Any owner or operator of a major source of HAPs 
subject to 40 CFR part 63, subpart B, shall submit a timely part 71 
permit application as required by 40 CFR part 71 and 40 CFR part 63, 
subpart B, requesting a case-by-case section 112(g) or 112(j) Maximum 
Achievable Control Technology (MACT) determination.
    (b) Requirements for the alternate operating program. CNMI shall 
develop and submit an alternate operating permit program (the program) 
to EPA for approval. Upon approval by EPA, CNMI shall implement the 
program. The program, including the necessary statutory and regulatory 
authority, must be submitted by January 13, 1999 for approval. The 
submittal shall include the following elements:
    (1) The program must contain regulations that ensure that:
    (i) The permits shall include emission limits and standards, and 
other terms or conditions necessary to ensure compliance with all 
applicable federal requirements, as defined under 40 CFR 70.2.
    (ii) The limitations, controls, and requirements in the permits 
shall be permanent, quantifiable, and otherwise enforceable as a 
practical matter.

[[Page 203]]

    (iii) Permits shall contain monitoring, recordkeeping and reporting 
requirements sufficient to ensure compliance with applicable federal 
requirements during the reporting period.
    (iv) The program shall require that the owner or operator of each 
source submit permit applications with compliance certifications 
describing the source's compliance status with all applicable 
requirements. The program shall also provide that each permit contain a 
requirement that the owner or operator of a source submit annual 
compliance certifications. The compliance certification shall contain a 
compliance plan, and shall contain a schedule for expeditiously 
achieving compliance if the source is not in compliance with all 
applicable requirements. The program must provide that approval of a 
permit with a compliance plan and schedule does not sanction 
noncompliance.
    (2) The program shall provide for the collection of fees from 
permitted sources or other revenues in an amount that will pay for the 
cost of operation of such a program and ensure that these funds are used 
solely to support the program.
    (3) The program shall provide for public notice and a public comment 
period of at least 30 days for each permit, significant permit 
modification, and permit renewal, and shall include submittal to EPA of 
each permit, significant permit modification, and permit renewal.
    (4) The program shall provide EPA at least 45 days from receipt of a 
permit, modification, or renewal for EPA review and objection prior to 
issuance. The program shall provide that if EPA objects to a permit sent 
to EPA for review, CNMI cannot issue such permit until the permit is 
revised in a manner that resolves EPA's objections. The program will 
provide that CNMI will have no more than 180 days to resolve EPA's 
objections and that if the objections are not resolved within that time 
period, EPA shall issue the permit under 40 CFR part 71.
    (5) The program shall provide that all documents other than 
confidential business information will be made available to the public.
    (6) The program shall provide CNMI with the authority to enforce 
permits, including the authority to assess civil and criminal penalties 
up to $10,000 per day per violation and to enjoin activities that are in 
violation of the permit, the program, or the Act without first revoking 
the permit.
    (7) The program shall require that owners or operators of nonmajor 
sources of hazardous air pollutants that are required to obtain title V 
permits, and owners or operators of major sources of all other air 
pollutants as defined at 40 CFR 70.2 that are exempted from 40 CFR part 
71 under paragraph (a) of this section, obtain an operating permit under 
the approved program. The program shall include a schedule for issuing 
permits to all subject sources within three years of EPA approval of the 
program.
    (8) The program shall include a system of regular inspections of 
permitted sources, a system to identify any unpermitted major sources, 
and guidelines for appropriate responses to violations.
    (9) The program shall provide for the issuance of permits with a 
fixed term that shall not exceed five years.
    (10) The program shall allow CNMI or the EPA to reopen a permit for 
cause. The program shall provide that if EPA provides CNMI with written 
notice that a permit must be reopened for cause, CNMI shall issue a 
revised permit within 180 days (including public notice and comment) 
that sufficiently addresses EPA's concerns. The program shall provide 
that if CNMI fails to issue a permit that resolves EPA's concerns within 
180 days, then EPA will terminate, modify, or revoke and reissue the 
permit under part 71 after providing the permittee and the public with 
notice and opportunity for comment.
    (c) Ambient air quality program. CNMI shall implement the following 
program to protect attainment of National Ambient Air Quality Standards 
(NAAQS) as a condition of the waiver:
    (1) CNMI shall enforce its January 19, 1987 Air Pollution Control 
(APC) regulations, including the requirement that all new or modified 
sources comply with the NAAQS and Prevention of Significant 
Deterioration (PSD) increments.

[[Page 204]]

    (2) CNMI may conduct air emissions modeling, using EPA guidelines, 
for power plants located on Saipan to assess EPA's preliminary 
determination of non-compliance with the NAAQS for sulfur dioxide 
(SO2). CNMI shall complete and submit any additional modeling 
to EPA by January 13, 1998 to determine whether existing power plants 
cause or contribute to violation of the NAAQS and PSD increments in the 
APC regulations and 40 CFR 52.21.
    (3) If CNMI's additional modeling, based on EPA guidelines, predicts 
exceedances of the NAAQS for SO2, or if CNMI elects to accept 
EPA's preliminary determination that the NAAQS for SO2 have 
been exceeded, CNMI shall submit a revised SIP that ensures compliance 
with the NAAQS for SO2. CNMI shall submit the proposed 
revision to the SIP by January 13, 1998 or, if CNMI elects to conduct 
additional modeling, by January 13, 1999. CNMI shall take appropriate 
corrective actions through the SIP to demonstrate compliance with the 
NAAQS for SO2 by January 15, 2001.
    (d) State Implementation Plan (SIP) submittal. In conjunction with 
the submittal of the alternative operating permit program, CNMI shall, 
no later than January 13, 1999 submit a revision to its SIP that 
provides that a person shall not violate a permit condition or term in 
an operating permit that has been issued under an EPA approved alternate 
operating permit program adopted by CNMI pursuant to the exemption 
authorized in this Sec. 69.32.
    (e) Expiration and revocation of the exemption. This exemption shall 
expire or may be revoked under the following circumstances:
    (1) If CNMI fails to submit the required alternate operating permit 
program or any required SIP revision by January 13, 1999, the exemption 
shall automatically expire with no further rulemaking and 40 CFR part 71 
shall become effective for all subject sources in CNMI on that date, 
consistent with paragraph (c)(3) of this section.
    (2) In the event that EPA disapproves CNMI's alternate operating 
permit program because the program does not meet the requirements set 
forth in paragraph (b) of this section, EPA will revoke the exemption by 
rulemaking.
    (3) If, by January 13, 2003, the owner or operator of any subject 
source has not obtained a federally enforceable operating permit under 
an EPA approved program, the exemption shall automatically expire for 
such source and such source shall be subject to the permitting 
requirements of 40 CFR part 71. CNMI will work with EPA to identify such 
sources prior to expiration of the exemption under this paragraph (e).
    (4) EPA shall revoke the exemption in its entirety through 
rulemaking if CNMI does not adequately administer and enforce an 
alternate operating permit program approved by EPA.
    (5) EPA shall revoke the exemption by rulemaking with respect to the 
owner or operator of any source if, during the 45-day review period, EPA 
objects to issuance of a permit and CNMI fails to resolve EPA's 
objections within 180 days. EPA shall also revoke the exemption by 
rulemaking for the owner or operator of any source in the event that EPA 
reopens a permit for cause and CNMI does not issue a permit that 
resolves the concerns as set forth in EPA's notice to reopen within 180 
days.
    (6) EPA reserves its authority to revoke or modify this exemption in 
whole or in part.
    (f) Scope of the exemption. This exemption applies solely to the 
requirement that an owner or operator obtain an operating permit under 
title V of the Clean Air Act and the requirement that CNMI implement a 
title V permit program. In addition, this exemption does not apply to 
owners or operators of sources set forth in paragraph (a)(4) of this 
section. Owners and operators of air pollutant sources are required to 
comply with all other applicable requirements of the Clean Air Act. For 
purposes of complying with any applicable requirement that is triggered 
or implemented by the approval of a title V permit program, the approval 
date for owners or operators to which this exemption applies shall be 
the date that EPA approves the alternate program for each territory or, 
for owners or operators of sources that are subject to 40 CFR part 71, 
the approval date

[[Page 205]]

shall be the effective date of 40 CFR part 71, which is July 31, 1996.

[61 FR 58292, Nov. 13, 1996; 61 FR 66077, Dec. 16, 1996]



                Subpart D - The U.S. Virgin Islands



Sec. 69.41  New exemptions.

    (a) Pursuant to section 325(a) of the Clean Air Act and a petition 
submitted by the Governor of the Virgin Islands, an exemption to section 
123 of the Clean Air Act is granted to the Hess Oil Virgin Islands 
Corporation (HOVIC) at the St. Croix refinery. Specifically, the 
exemption waives the prohibition on the implementation of an 
Intermittent Control Strategy (ICS) based upon atmospheric conditions in 
order to set emission limitations. The emission limitations shall depend 
upon the sulfur content in the residual oil burned at the refinery.
    (b) The protocol to be followed for the ICS shall be set forth in a 
Prevention of Significant Deterioration of Air Quality (PSD) permit 
issued to HOVIC; and shall include as a minimum, the conditions listed 
in paragraphs (b)(1), (b)(2), (b)(3), and (b)(4) of this section.
    (1) HOVIC shall maintain a meteorological tower on its property for 
the purpose of the ICS which meets the required EPA QA/QC operating 
specifications. At a minimum, the wind direction data will be monitored, 
collected and reported as 1-hour averages, starting on the hour. If the 
average wind direction for a given hour is from within the designated 
sector, the wind will be deemed to have flowed from within the sector 
for that hour. Each ``day'' or 
``block period'', for these purposes will 
start at midnight and end the following midnight.
    (2) HOVIC shall maintain SO2 ambient monitors and collect ambient 
SO2 concentration data for the purpose of implementing the ICS at nearby 
locations approved by EPA and specified in the PSD permit. The ambient 
monitors must follow the required EPA QA/QC operating specifications. At 
a minimum, the data will be collected according to EPA approved State 
and Local Ambient Monitoring Stations procedures found at 40 CFR 58.20, 
but will, for these purposes, be averaged by the hour, starting on the 
hour.
    (3) The switch to a lower sulfur fuel (0.5%) will take place when 
paragraphs (b)(3)(i) or (b)(3)(ii) of this section are met.
    (i) The winds blow from a 45 degree sector defined as 143 to 187 
degrees inclusive, where zero degrees is due north, for at least 6 
consecutive hours during a 24-hour block period or any 12 non-
consecutive hours during a 24 hour block period.
    (ii) One of HOVIC's ICS monitors measures an average ambient SO2 
concentration that is 75% of the 24-hour NAAQS during any rolling 24-
hour average. (75% of the 24-hour NAAQS = 274 ug/m3 or 0.105 ppm).
    (4) The switch back to the higher sulfur fuel (1.0%) may occur if 
the conditions in paragraphs (b)(4)(i), (b)(4)(ii), and (b)(4)(iii) of 
this section are met.
    (i) If the ICS was triggered by paragraph (b)(3)(i) of this section, 
the switch back may occur when the winds blow outside the sector listed 
in paragraph (b)(3)(i) of this section for at least 3 consecutive hours 
following the period during which the winds were blowing inside the 
sector.
    (ii) If the ICS was triggered by paragraph (b)(3)(ii) of this 
section, the switch back may occur after all of HOVIC's ICS ambient 
monitors measure a 24-hour average concentration which is less than 75% 
of the NAAQS for at least one 24-hour block period following any 
occurrence when the monitor measured the concentration which was 75% of 
the NAAQS.
    (iii) If the ICS was triggered by both paragraphs (b)(3)(i) and 
(b)(3)(ii) of this section, the switch back may occur when both of the 
conditions in paragraphs (b)(4)(i) and (b)(4)(ii) of this section are 
met.
    (c) The protocol may be modified by EPA to protect against 
exceedances of the sulfur dioxide NAAQS.
    (d) In the event that there is an exceedance of the NAAQS, HOVIC 
will report the exceedance to EPA and recommend corrective action as 
well as amendments to the protocol to ensure the protection of the 
NAAQS.
    (e) HOVIC must comply with all fuel switching requirements, 
contained in HOVIC's PSD permit.

[[Page 206]]

    (f) This exemption shall take effect only in the event that a final 
PSD permit modification becomes effective.
    (g) The Administrator may terminate the exemption through rulemaking 
procedures upon determining that HOVIC's use of the ICS is causing or 
contributing to an exceedance of the NAAQS.

[62 FR 61205, Nov. 14, 1997]



                         Subpart E - Alaska



Sec. 69.51  Motor vehicle diesel fuel.

    (a) Diesel fuel that is designated for use only in Alaska and is 
used only in Alaska, is exempt from the sulfur standard of 40 CFR 
80.29(a)(1) and the dye provisions of 40 CFR 80.29(a)(3) and 40 CFR 
80.29(b) until the implementation dates of 40 CFR 80.500, provided that:
    (1) The fuel is segregated from non-exempt diesel fuel from the 
point of such designation; and
    (2) On each occasion that any person transfers custody or title to 
the fuel, except when it is dispensed at a retail outlet or wholesale 
purchaser-consumer facility, the transferor must provide to the 
transferee a product transfer document stating:

    This diesel fuel is for use only in Alaska. It is exempt from the 
federal low sulfur standards applicable to highway diesel fuel and red 
dye requirements applicable to non-highway diesel fuel only if it is 
used in Alaska.

    (b) Beginning on the implementation dates in 40 CFR 80.500, diesel 
fuel that is designated for use in Alaska or is used in Alaska, is 
subject to the applicable provisions of 40 CFR Part 80, Subpart I, 
except as provided under paragraph (c) of this section. The Governor of 
Alaska may submit for EPA approval, by April 1, 2002, a plan for 
implementing the sulfur standard in Alaska as an alternative to the 
temporary compliance option provided under Sec.Sec. 
80.530-80.532. If EPA approves an alternative plan, the provisions as 
approved by EPA under that plan shall apply to the diesel fuel subject 
to this paragraph (b).
    (c) If such diesel fuel is designated as fuel that does not comply 
with the standards and requirements for motor vehicle diesel fuel under 
40 CFR Part 80, Subpart I, it is exempt from the dye presumption of 40 
CFR 80.520(b)(2) provided that:
    (1) The fuel is segregated from all motor vehicle diesel fuel.
    (2) On each occasion that any person transfers custody or title to 
the fuel, except when it is dispensed at a retail outlet or wholesale 
purchaser-consumer facility, the transferor must provide to the 
transferee a product transfer document complying with the requirements 
of 40 CFR 80.590(a) through (d) and (g), and stating:

    This diesel fuel is for use only in Alaska and is not for use in 
highway vehicles. It is exempt from the red dye requirement applicable 
to non-highway diesel fuel only if it is used in Alaska.

    (3) Any pump dispensing the fuel must comply with the labeling 
requirements in 40 CFR 80.570(c).

[66 FR 5134, Jan. 18, 2001]



PART 70 - STATE OPERATING PERMIT PROGRAMS--Table of Contents




Sec.
70.1 Program overview.
70.2 Definitions.
70.3 Applicability.
70.4 State program submittals and transition.
70.5 Permit applications.
70.6 Permit content.
70.7 Permit issuance, renewal, reopenings, and revisions.
70.8 Permit review by EPA and affected States.
70.9 Fee determination and certification.
70.10 Federal oversight and sanctions.
70.11 Requirements for enforcement authority.

Appendix A to Part 70 - Approval Status of State and Local 
          Operating Permits Programs

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

    Source: 57 FR 32295, July 21, 1992, unless otherwise noted.



Sec. 70.1  Program overview.

    (a) The regulations in this part provide for the establishment of 
comprehensive State air quality permitting systems consistent with the 
requirements of title V of the Clean Air Act (Act) (42 U.S.C. 7401, et 
seq.). These regulations define the minimum elements required by the Act 
for State operating

[[Page 207]]

permit programs and the corresponding standards and procedures by which 
the Administrator will approve, oversee, and withdraw approval of State 
operating permit programs.
    (b) All sources subject to these regulations shall have a permit to 
operate that assures compliance by the source with all applicable 
requirements. While title V does not impose substantive new 
requirements, it does require that fees be imposed on sources and that 
certain procedural measures be adopted especially with respect to 
compliance.
    (c) Nothing in this part shall prevent a State, or interstate 
permitting authority, from establishing additional or more stringent 
requirements not inconsistent with this Act. The EPA will approve State 
program submittals to the extent that they are not inconsistent with the 
Act and these regulations. No permit, however, can be less stringent 
than necessary to meet all applicable requirements. In the case of 
Federal intervention in the permit process, the Administrator reserves 
the right to implement the State operating permit program, in whole or 
in part, or the Federal program contained in regulations promulgated 
under title V of the Act.
    (d) The requirements of part 70, including provisions regarding 
schedules for submission and approval or disapproval of permit 
applications, shall apply to the permitting of affected sources under 
the acid rain program, except as provided herein or modified in 
regulations promulgated under title IV of the Act (acid rain program).
    (e) Issuance of State permits under this part may be coordinated 
with issuance of permits under the Resource Conservation and Recovery 
Act and under the Clean Water Act, whether issued by the State, the U.S. 
Environmental Protection Agency (EPA), or the U.S. Army Corps of 
Engineers.



Sec. 70.2  Definitions.

    The following definitions apply to part 70. Except as specifically 
provided in this section, terms used in this part retain the meaning 
accorded them under the applicable requirements of the Act.
    Act means the Clean Air Act, as amended, 42 U.S.C. 7401, et seq.
    Affected source shall have the meaning given to it in the 
regulations promulgated under title IV of the Act.
    Affected States are all States:
    (1) Whose air quality may be affected and that are contiguous to the 
State in which a part 70 permit, permit modification or permit renewal 
is being proposed; or
    (2) That are within 50 miles of the permitted source.
    Affected unit shall have the meaning given to it in the regulations 
promulgated under title IV of the Act.
    Applicable requirement means all of the following as they apply to 
emissions units in a part 70 source (including requirements that have 
been promulgated or approved by EPA through rulemaking at the time of 
issuance but have future-effective compliance dates):
    (1) Any standard or other requirement provided for in the applicable 
implementation plan approved or promulgated by EPA through rulemaking 
under title I of the Act that implements the relevant requirements of 
the Act, including any revisions to that plan promulgated in part 52 of 
this chapter;
    (2) Any term or condition of any preconstruction permits issued 
pursuant to regulations approved or promulgated through rulemaking under 
title I, including parts C or D, of the Act;
    (3) Any standard or other requirement under section 111 of the Act, 
including section 111(d);
    (4) Any standard or other requirement under section 112 of the Act, 
including any requirement concerning accident prevention under section 
112(r)(7) of the Act;
    (5) Any standard or other requirement of the acid rain program under 
title IV of the Act or the regulations promulgated thereunder;
    (6) Any requirements established pursuant to section 504(b) or 
section 114(a)(3) of the Act;
    (7) Any standard or other requirement governing solid waste 
incineration, under section 129 of the Act;
    (8) Any standard or other requirement for consumer and commercial

[[Page 208]]

products, under section 183(e) of the Act;
    (9) Any standard or other requirement for tank vessels under section 
183(f) of the Act;
    (10) Any standard or other requirement of the program to control air 
pollution from outer continental shelf sources, under section 328 of the 
Act;
    (11) Any standard or other requirement of the regulations 
promulgated to protect stratospheric ozone under title VI of the Act, 
unless the Administrator has determined that such requirements need not 
be contained in a title V permit; and
    (12) Any national ambient air quality standard or increment or 
visibility requirement under part C of title I of the Act, but only as 
it would apply to temporary sources permitted pursuant to section 504(e) 
of the Act.
    Designated representative shall have the meaning given to it in 
section 402(26) of the Act and the regulations promulgated thereunder.
    Draft permit means the version of a permit for which the permitting 
authority offers public participation under Sec. 70.7(h) or 
affected State review under Sec. 70.8 of this part.
    Emissions allowable under the permit means a federally enforceable 
permit term or condition determined at issuance to be required by an 
applicable requirement that establishes an emissions limit (including a 
work practice standard) or a federally enforceable emissions cap that 
the source has assumed to avoid an applicable requirement to which the 
source would otherwise be subject.
    Emissions unit means any part or activity of a stationary source 
that emits or has the potential to emit any regulated air pollutant or 
any pollutant listed under section 112(b) of the Act. This term is not 
meant to alter or affect the definition of the term 
``unit'' for purposes of title IV of the 
Act.
    The EPA or the Administrator means the Administrator of the EPA or 
his designee.
    Final permit means the version of a part 70 permit issued by the 
permitting authority that has completed all review procedures required 
by Sec.Sec. 70.7 and 70.8 of this part.
    Fugitive emissions are those emissions which could not reasonably 
pass through a stack, chimney, vent, or other functionally-equivalent 
opening.
    General permit means a part 70 permit that meets the requirements of 
Sec. 70.6(d).
    Major source means any stationary source (or any group of stationary 
sources that are located on one or more contiguous or adjacent 
properties, and are under common control of the same person (or persons 
under common control)) belonging to a single major industrial grouping 
and that are described in paragraph (1), (2), or (3) of this definition. 
For the purposes of defining ``major 
source,'' a stationary source or group of stationary 
sources shall be considered part of a single industrial grouping if all 
of the pollutant emitting activities at such source or group of sources 
on contiguous or adjacent properties belong to the same Major Group 
(i.e., all have the same two-digit code) as described in the Standard 
Industrial Classification Manual, 1987.
    (1) A major source under section 112 of the Act, which is defined 
as:
    (i) For pollutants other than radionuclides, any stationary source 
or group of stationary sources located within a contiguous area and 
under common control that emits or has the potential to emit, in the 
aggregate, 10 tons per year (tpy) or more of any hazardous air pollutant 
which has been listed pursuant to section 112(b) of the Act, 25 tpy or 
more of any combination of such hazardous air pollutants, or such lesser 
quantity as the Administrator may establish by rule. Notwithstanding the 
preceding sentence, emissions from any oil or gas exploration or 
production well (with its associated equipment) and emissions from any 
pipeline compressor or pump station shall not be aggregated with 
emissions from other similar units, whether or not such units are in a 
contiguous area or under common control, to determine whether such units 
or stations are major sources; or
    (ii) For radionuclides, ``major source'' 
shall have the meaning specified by the Administrator by rule.
    (2) A major stationary source of air pollutants, as defined in 
section 302 of

[[Page 209]]

the Act, that directly emits or has the potential to emit, 100 tpy or 
more of any air pollutant (including any major source of fugitive 
emissions of any such pollutant, as determined by rule by the 
Administrator). The fugitive emissions of a stationary source shall not 
be considered in determining whether it is a major stationary source for 
the purposes of section 302(j) of the Act, unless the source belongs to 
one of the following categories of stationary source:
    (i) Coal cleaning plants (with thermal dryers);
    (ii) Kraft pulp mills;
    (iii) Portland cement plants;
    (iv) Primary zinc smelters;
    (v) Iron and steel mills;
    (vi) Primary aluminum ore reduction plants;
    (vii) Primary copper smelters;
    (viii) Municipal incinerators capable of charging more than 250 tons 
of refuse per day;
    (ix) Hydrofluoric, sulfuric, or nitric acid plants;
    (x) Petroleum refineries;
    (xi) Lime plants;
    (xii) Phosphate rock processing plants;
    (xiii) Coke oven batteries;
    (xiv) Sulfur recovery plants;
    (xv) Carbon black plants (furnace process);
    (xvi) Primary lead smelters;
    (xvii) Fuel conversion plants;
    (xviii) Sintering plants;
    (xix) Secondary metal production plants;
    (xx) Chemical process plants;
    (xxi) Fossil-fuel boilers (or combination thereof) totaling more 
than 250 million British thermal units per hour heat input;
    (xxii) Petroleum storage and transfer units with a total storage 
capacity exceeding 300,000 barrels;
    (xxiii) Taconite ore processing plants;
    (xxiv) Glass fiber processing plants;
    (xxv) Charcoal production plants;
    (xxvi) Fossil-fuel-fired steam electric plants of more than 250 
million British thermal units per hour heat input; or
    (xxvii) Any other stationary source category, which as of August 7, 
1980 is being regulated under section 111 or 112 of the Act.
    (3) A major stationary source as defined in part D of title I of the 
Act, including:
    (i) For ozone nonattainment areas, sources with the potential to 
emit 100 tpy or more of volatile organic compounds or oxides of nitrogen 
in areas classified as ``marginal'' or 
``moderate,'' 50 tpy or more in areas 
classified as ``serious,'' 25 tpy or more in 
areas classified as ``severe,'' and 10 tpy 
or more in areas classified as ``extreme''; 
except that the references in this paragraph to 100, 50, 25 and 10 tpy 
of nitrogen oxides shall not apply with respect to any source for which 
the Administrator has made a finding, under section 182(f) (1) or (2) of 
the Act, that requirements under section 182(f) of the Act do not apply;
    (ii) For ozone transport regions established pursuant to section 184 
of the Act, sources with the potential to emit 50 tpy or more of 
volatile organic compounds;
    (iii) For carbon monoxide nonattainment areas:
    (A) That are classified as ``serious,'' 
and
    (B) in which stationary sources contribute significantly to carbon 
monoxide levels as determined under rules issued by the Administrator, 
sources with the potential to emit 50 tpy or more of carbon monoxide; 
and
    (iv) For particulate matter (PM-10) nonattainment areas classified 
as ``serious,'' sources with the potential 
to emit 70 tpy or more of PM-10.
    Part 70 permit or permit (unless the context suggests otherwise) 
means any permit or group of permits covering a part 70 source that is 
issued, renewed, amended, or revised pursuant to this part.
    Part 70 program or State program means a program approved by the 
Administrator under this part.
    Part 70 source means any source subject to the permitting 
requirements of this part, as provided in Sec. Sec. 
70.3(a) and 70.3(b) of this part.
    Permit modification means a revision to a part 70 permit that meets 
the requirements of Sec. 70.7(e) of this part.
    Permit program costs means all reasonable (direct and indirect) 
costs required to develop and administer a permit program, as set forth 
in Sec. 70.9(b) of this

[[Page 210]]

part (whether such costs are incurred by the permitting authority or 
other State or local agencies that do not issue permits directly, but 
that support permit issuance or administration).
    Permit revision means any permit modification or administrative 
permit amendment.
    Permitting authority means either of the following:
    (1) The Administrator, in the case of EPA-implemented programs; or
    (2) 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 this part.
    Potential to emit means the maximum capacity of a stationary source 
to emit any air pollutant under its physical and operational design. Any 
physical or operational limitation on the capacity of a source to emit 
an air pollutant, including air pollution control equipment and 
restrictions on hours of operation or on the type or amount of material 
combusted, stored, or processed, shall be treated as part of its design 
if the limitation is enforceable by the Administrator. This term does 
not alter or affect the use of this term for any other purposes under 
the Act, or the term ``capacity factor'' as 
used in title IV of the Act or the regulations promulgated thereunder.
    Proposed permit means the version of a permit that the permitting 
authority proposes to issue and forwards to the Administrator for review 
in compliance with Sec. 70.8.
    Regulated air pollutant means the following:
    (1) Nitrogen oxides or any volatile organic compounds;
    (2) Any pollutant for which a national ambient air quality standard 
has been promulgated;
    (3) Any pollutant that is subject to any standard promulgated under 
section 111 of the Act;
    (4) Any Class I or II substance subject to a standard promulgated 
under or established by title VI of the Act; or
    (5) Any pollutant subject to a standard promulgated under section 
112 or other requirements established under section 112 of the Act, 
including sections 112(g), (j), and (r) of the Act, including the 
following:
    (i) Any pollutant subject to requirements under section 112(j) of 
the Act. If the Administrator fails to promulgate a standard by the date 
established pursuant to section 112(e) of the Act, any pollutant for 
which a subject source would be major shall be considered to be 
regulated on the date 18 months after the applicable date established 
pursuant to section 112(e) of the Act; and
    (ii) Any pollutant for which the requirements of section 112(g)(2) 
of the Act have been met, but only with respect to the individual source 
subject to section 112(g)(2) requirement.
    Regulated pollutant (for presumptive fee calculation), which is used 
only for purposes of Sec. 70.9(b)(2), means any 
``regulated air pollutant'' except the 
following:
    (1) Carbon monoxide;
    (2) Any pollutant that is a regulated air pollutant solely because 
it is a Class I or II substance to a standard promulgated under or 
established by title VI of the Act; or
    (3) Any pollutant that is a regulated air pollutant solely because 
it is subject to a standard or regulation under section 112(r) of the 
Act.
    Renewal means the process by which a permit is reissued at the end 
of its term.
    Responsible official means one of the following:
    (1) For a corporation: a president, secretary, treasurer, or vice-
president of the corporation in charge of a principal business function, 
or any other person who performs similar policy or decision-making 
functions for the corporation, or a duly authorized representative of 
such person if the representative is responsible for the overall 
operation of one or more manufacturing, production, or operating 
facilities applying for or subject to a permit and either:
    (i) The facilities employ more than 250 persons or have gross annual 
sales or expenditures exceeding $25 million (in second quarter 1980 
dollars); or
    (ii) The delegation of authority to such representatives is approved 
in advance by the permitting authority;
    (2) For a partnership or sole proprietorship: a general partner or 
the proprietor, respectively;

[[Page 211]]

    (3) For a municipality, State, Federal, or other public agency: 
Either a principal executive officer or ranking elected official. For 
the purposes of this part, a principal executive officer of a Federal 
agency includes the chief executive officer having responsibility for 
the overall operations of a principal geographic unit of the agency 
(e.g., a Regional Administrator of EPA); or
    (4) For affected sources:
    (i) The designated representative in so far as actions, standards, 
requirements, or prohibitions under title IV of the Act or the 
regulations promulgated thereunder are concerned; and
    (ii) The designated representative for any other purposes under part 
70.
    Section 502(b)(10) changes are changes that contravene an express 
permit term. Such changes do not include changes that would violate 
applicable requirements or contravene federally enforceable permit terms 
and conditions that are monitoring (including test methods), 
recordkeeping, reporting, or compliance certification requirements.
    State means any non-Federal permitting authority, including any 
local agency, interstate association, or statewide program. The term 
``State'' also includes the District of 
Columbia, the Commonwealth of Puerto Rico, the Virgin Islands, Guam, 
American Samoa, and the Commonwealth of the Northern Mariana Islands. 
Where such meaning is clear from the context, 
``State'' shall have its conventional 
meaning. For purposes of the acid rain program, the term 
``State'' shall be limited to authorities 
within the 48 contiguous States and the District of Columbia as provided 
in section 402(14) of the Act.
    Stationary source means any building, structure, facility, or 
installation that emits or may emit any regulated air pollutant or any 
pollutant listed under section 112(b) of the Act.
    Whole program means a part 70 permit program, or any combination of 
partial programs, that meet all the requirements of these regulations 
and cover all the part 70 sources in the entire State. For the purposes 
of this definition, the term ``State'' does 
not include local permitting authorities, but refers only to the entire 
State, Commonwealth, or Territory.

[57 FR 32295, July 21, 1992, as amended at 66 FR 59166, Nov. 27, 2001]



Sec. 70.3  Applicability.

    (a) Part 70 sources. A State program with whole or partial approval 
under this part must provide for permitting of at least the following 
sources:
    (1) Any major source;
    (2) Any source, including an area source, subject to a standard, 
limitation, or other requirement under section 111 of the Act;
    (3) Any source, including an area source, subject to a standard or 
other requirement under section 112 of the Act, except that a source is 
not required to obtain a permit solely because it is subject to 
regulations or requirements under section 112(r) of this Act;
    (4) Any affected source; and
    (5) Any source in a source category designated by the Administrator 
pursuant to this section.
    (b) Source category exemptions. (1) All sources listed in paragraph 
(a) of this section that are not major sources, affected sources, or 
solid waste incineration units required to obtain a permit pursuant to 
section 129(e) of the Act, may be exempted by the State from the 
obligation to obtain a part 70 permit until such time as the 
Administrator completes a rulemaking to determine how the program should 
be structured for nonmajor sources and the appropriateness of any 
permanent exemptions in addition to those provided for in paragraph 
(b)(4) of this section.
    (2) In the case of nonmajor sources subject to a standard or other 
requirement under either section 111 or section 112 of the Act after 
July 21, 1992 publication, the Administrator will determine whether to 
exempt any or all such applicable sources from the requirement to obtain 
a part 70 permit at the time that the new standard is promulgated.
    (3) Any source listed in paragraph (a) of this section exempt from 
the requirement to obtain a permit under this section may opt to apply 
for a permit under a part 70 program.
    (4) Unless otherwise required by the State to obtain a part 70 
permit, the

[[Page 212]]

following source categories are exempted from the obligation to obtain a 
part 70 permit:
    (i) All sources and source categories that would be required to 
obtain a permit solely because they are subject to part 60, subpart 
AAA - Standards of Performance for New Residential Wood 
Heaters; and
    (ii) All sources and source categories that would be required to 
obtain a permit solely because they are subject to part 61, subpart 
M - National Emission Standard for Hazardous Air Pollutants 
for Asbestos, Sec. 61.145, Standard for Demolition and 
Renovation.
    (c) Emissions units and part 70 sources. (1) For major sources, the 
permitting authority shall include in the permit all applicable 
requirements for all relevant emissions units in the major source.
    (2) For any nonmajor source subject to the part 70 program under 
paragraph (a) or (b) of this section, the permitting authority shall 
include in the permit all applicable requirements applicable to 
emissions units that cause the source to be subject to the part 70 
program.
    (d) Fugitive emissions. Fugitive emissions from a part 70 source 
shall be included in the permit application and the part 70 permit in 
the same manner as stack emissions, regardless of whether the source 
category in question is included in the list of sources contained in the 
definition of major source.



Sec. 70.4  State program submittals and transition.

    (a) Date for submittal. Not later than November 15, 1993, the 
Governor of each State shall submit to the Administrator for approval a 
proposed part 70 program, under State law or under an interstate 
compact, meeting the requirements of this part. If part 70 is 
subsequently revised such that the Administrator determines that it is 
necessary to require a change to an approved State program, the required 
revisions to the program shall be submitted within 12 months of the 
final changes to part 70 or within such other period as authorized by 
the Administrator.
    (b) Elements of the initial program submission. Any State that seeks 
to administer a program under this part shall submit to the 
Administrator a letter of submittal from the Governor or his designee 
requesting EPA approval of the program and at least three copies of a 
program submission. The submission shall contain the following:
    (1) A complete program description describing how the State intends 
to carry out its responsibilities under this part.
    (2) The regulations that comprise the permitting program, reasonably 
available evidence of their procedurally correct adoption, (including 
any notice of public comment and any significant comments received on 
the proposed part 70 program as requested by the Administrator), and 
copies of all applicable State or local statutes and regulations 
including those governing State administrative procedures that either 
authorize the part 70 program or restrict its implementation. The State 
shall include with the regulations any criteria used to determine 
insignificant activities or emission levels for purposes of determining 
complete applications consistent with Sec. 70.5(c) of this 
part.
    (3) A legal opinion from the Attorney General for the State, or the 
attorney for those State, local, or interstate air pollution control 
agencies that have independent legal counsel, stating that the laws of 
the State, locality, or interstate compact provide adequate authority to 
carry out all aspects of the program. This statement shall include 
citations to the specific states, administrative regulations, and, where 
appropriate, judicial decisions that demonstrate adequate authority. 
State statutes and regulations cited by the State Attorney General or 
independent legal counsel shall be in the form of lawfully adopted State 
states and regulations at the time the statement is signed and shall be 
fully effective by the time the program is approved. To qualify as 
``independent legal counsel,'' the attorney 
signing the statement required by this section shall have full authority 
to independently represent the State agency in court on all matters 
pertaining to the State program. The legal opinion shall also include a

[[Page 213]]

demonstration of adequate legal authority to carry out the requirements 
of this part, including authority to carry out each of the following:
    (i) Issue permits and assure compliance with each applicable 
requirement and requirement of this part by all part 70 sources.
    (ii) Incorporate monitoring, recordkeeping, reporting, and 
compliance certification requirements into part 70 permits consistent 
with Sec. 70.6.
    (iii) Issue permits for a fixed term of 5 years in the case of 
permits with acid rain provisions and issue all other permits for a 
period not to exceed 5 years, except for permits issued for solid waste 
incineration units combusting municipal waste subject to standards under 
section 129(e) of the Act.
    (iv) Issue permits for solid waste incineration units combusting 
municipal waste subject to standards under section 129(e) of the Act for 
a period not to exceed 12 years and review such permits at least every 5 
years. No permit for a solid waste incineration unit may be issued by an 
agency, instrumentality or person that is also responsible, in whole or 
in part, for the design and construction or operation of the unit.
    (v) Incorporate into permits all applicable requirements and 
requirements of this part.
    (vi) Terminate, modify, or revoke and reissue permits for cause.
    (vii) Enforce permits, permit fee requirements, and the requirement 
to obtain a permit, as specified in Sec. 70.11.
    (viii) Make available to the public any permit application, 
compliance plan, permit, and monitoring and compliance, certification 
report pursuant to section 503(e) of the Act, except for information 
entitled to confidential treatment pursuant to section 114(c) of the 
Act. The contents of a part 70 permit shall not be entitled to 
protection under section 115(c) of the Act.
    (ix) Not issue a permit if the Administrator timely objects to its 
issuance pursuant to Sec. 70.8(c) of this part or, if the 
permit has not already been issued, to Sec. 70.8(d) of this 
part.
    (x) Provide an opportunity for judicial review in State court of the 
final permit action by the applicant, any person who participated in the 
public participation process provided pursuant to Sec. 70.7(h) 
of this part, and any other person who could obtain judicial review of 
such actions under State laws.
    (xi) Provide that, solely for the purposes of obtaining judicial 
review in State court for failure to take final action, final permit 
action shall include the failure of the permitting authority to take 
final action on an application for a permit, permit renewal, or permit 
revision within the time specified in the State program. If the State 
program allows sources to make changes subject to post hoc review [as 
set forth in Sec.Sec. 70.7(e)(2) and (3) of this 
part], the permitting authority's failure to take final action within 90 
days of receipt of an application requesting minor permit modification 
procedures (or 180 days for modifications subject to group processing 
requirements) must be subject to judicial review in State court.
    (xii) Provide that the opportunity for judicial review described in 
paragraph (b)(3)(x) of this section shall be the exclusive means for 
obtaining judicial review of the terms and conditions of permits, and 
require that such petitions for judicial review must be filed no later 
than 90 days after the final permit action, or such shorter time as the 
State shall designate. Notwithstanding the preceding requirement, 
petitions for judicial review of final permit actions can be filed after 
the deadline designated by the State, only if they are based solely on 
grounds arising after the deadline for judicial review. Such petitions 
shall be filed no later than 90 days after the new grounds for review 
arise or such shorter time as the State shall designate. If the final 
permit action being challenged is the permitting authority's failure to 
take final action, a petition for judicial review may be filed any time 
before the permitting authority denies the permit or issues the final 
permit.
    (xiii) Ensure that the authority of the State/local permitting 
Agency is not used to modify the acid rain program requirements.
    (4) Relevant permitting program documentation not contained in the 
State regulations, including the following:

[[Page 214]]

    (i) Copies of the permit form(s), application form(s), and reporting 
form(s) the State intends to employ in its program; and
    (ii) Relevant guidance issued by the State to assist in the 
implementation of its permitting program, including criteria for 
monitoring source compliance (e.g., inspection strategies).
    (5) A complete description of the State's compliance tracking and 
enforcement program or reference to any agreement the State has with EPA 
that provides this information.
    (6) A showing of adequate authority and procedures to determine 
within 60 days of receipt whether applications (including renewal 
applications) are complete, to request such other information as needed 
to process the application, and to take final action on complete 
applications within 18 months of the date of their submittal, except for 
initial permit applications, for which the permitting authority may take 
up to 3 years from the effective date of the program to take final 
action on the application, as provided for in the transition plan.
    (7) A demonstration, consistent with Sec. 70.9, that the 
permit fees required by the State program are sufficient to cover permit 
program costs.
    (8) A statement that adequate personnel and funding have been made 
available to develop, administer, and enforce the program. This 
statement shall include the following:
    (i) A description in narrative form of the scope, structure, 
coverage, and processes of the State program.
    (ii) A description of the organization and structure of the agency 
or agencies that will have responsibility for administering the program, 
including the information specified in this paragraph. If more than one 
agency is responsible for administration of a program, the 
responsibilities of each agency must be delineated, their procedures for 
coordination must be set forth, and an agency shall be designated as a 
``lead agency'' to facilitate communications 
between EPA and the other agencies having program responsibility.
    (iii) A description of the agency staff who will carry out the State 
program, including the number, occupation, and general duties of the 
employees. The State need not submit complete job descriptions for every 
employee carrying out the State program.
    (iv) A description of applicable State procedures, including 
permitting procedures and any State administrative or judicial review 
procedures.
    (v) An estimate of the permit program costs for the first 4 years 
after approval, and a description of how the State plans to cover those 
costs.
    (9) A commitment from the State to submit, at least annually to the 
Administrator, information regarding the State's enforcement activities 
including, but not limited to, the number of criminal and civil, 
judicial and administrative enforcement actions either commenced or 
concluded; the penalties, fines, and sentences obtained in those 
actions; and the number of administrative orders issued.
    (10) A requirement under State law that, if a timely and complete 
application for a permit renewal is submitted, consistent with 
Sec. 70.5(a)(2), but the State has failed to issue or deny the 
renewal permit before the end of the term of the previous permit, then:
    (i) The permit shall not expire until the renewal permit has been 
issued or denied and any permit shield that may be granted pursuant to 
Sec. 70.6(f) may extend beyond the original permit term until 
renewal; or
    (ii) All the terms and conditions of the permit including any permit 
shield that may be granted pursuant to Sec. 70.6(f) shall 
remain in effect until the renewal permit has been issued or denied.
    (11) A transition plan providing a schedule for submittal and final 
action on initial permit applications for all part 70 sources. This plan 
shall provide that:
    (i) Submittal of permit applications by all part 70 sources 
(including any sources subject to a partial or interim program) shall 
occur within 1 year after the effective date of the permit program;
    (ii) Final action shall be taken on at least one-third of such 
applications annually over a period not to exceed 3 years after such 
effective date;
    (iii) Any complete permit application containing an early reduction 
demonstration under section 112(i)(5) of the

[[Page 215]]

Act shall be acted on within 9 months of receipt of the complete 
application; and
    (iv) Submittal of permit applications and the permitting of affected 
sources shall occur in accordance with the deadlines in title IV of the 
Act and the regulations promulgated thereunder.
    (12) Provisions consistent with paragraphs (b)(12)(i) through (iii) 
of this section to allow changes within a permitted facility without 
requiring a permit revision, if the changes are not modifications under 
any provision of title I of the Act and the changes do not exceed the 
emissions allowable under the permit (whether expressed therein as a 
rate of emissions or in the terms of total emissions): Provided, That 
the facility provides the Administrator and the permitting authority 
with written notification as required below in advance of the proposed 
changes, which shall be a minimum of 7 days, unless the permitting 
authority provides in its regulations a different time frame for 
emergencies. The source, permitting authority, and EPA shall attach each 
such notice to their copy of the relevant permit. The following 
provisions implement this requirement of an approvable part 70 permit 
program:
    (i) The program shall allow permitted sources to make section 
502(b)(10) changes without requiring a permit revision, if the changes 
are not modifications under any provision of title I of the Act and the 
changes do not exceed the emissions allowable under the permit (whether 
expressed therein as a rate of emissions or in terms of total 
emissions).
    (A) For each such change, the written notification required above 
shall include a brief description of the change within the permitted 
facility, the date on which the change will occur, any change in 
emissions, and any permit term or condition that is no longer applicable 
as a result of the change.
    (B) The permit shield described in Sec. 70.6(f) of this 
part shall not apply to any change made pursuant to this paragraph 
(b)(12)(i) of this section.
    (ii) The program may provide for permitted sources to trade 
increases and decreases in emissions in the permitted facility, where 
the applicable implementation plan provides for such emissions trades 
without requiring a permit revision and based on the 7-day notice 
prescribed in this paragraph (b)(12)(ii) of this section. This provision 
is available in those cases where the permit does not already provide 
for such emissions trading.
    (A) Under this paragraph (b)(12)(ii) of this section, the written 
notification required above shall include such information as may be 
required by the provision in the applicable implementation plan 
authorizing the emissions trade, including at a minimum, when the 
proposed change will occur, a description of each such change, any 
change in emissions, the permit requirements with which the source will 
comply using the emissions trading provisions of the applicable 
implementation plan, and the pollutants emitted subject to the emissions 
trade. The notice shall also refer to the provisions with which the 
source will comply in the applicable implementation plan and that 
provide for the emissions trade.
    (B) The permit shield described in Sec. 70.6(f) of this 
part shall not extend to any change made under this paragraph 
(b)(12)(ii) of this section. Compliance with the permit requirements 
that the source will meet using the emissions trade shall be determined 
according to requirements of the applicable implementation plan 
authorizing the emissions trade.
    (iii) The program shall require the permitting authority, if a 
permit applicant requests it, to issue permits that contain terms and 
conditions, including all terms required under Sec. 70.6 (a) 
and (c) of this part to determine compliance, allowing for the trading 
of emissions increases and decreases in the permitted facility solely 
for the purpose of complying with a federally-enforceable emissions cap 
that is established in the permit independent of otherwise applicable 
requirements. The permit applicant shall include in its application 
proposed replicable procedures and permit terms that ensure the 
emissions trades are quantifiable and enforceable. The permitting 
authority shall not be required to include in the

[[Page 216]]

emissions trading provisions any emissions units for which emissions are 
not quantifiable or for which there are no replicable procedures to 
enforce the emissions trades. The permit shall also require compliance 
with all applicable requirements.
    (A) Under this paragraph (b)(12)(iii) of this section, the written 
notification required above shall state when the change will occur and 
shall describe the changes in emissions that will result and how these 
increases and decreases in emissions will comply with the terms and 
conditions of the permit.
    (B) The permit shield described in Sec. 70.6(f) of this 
part may extend to terms and conditions that allow such increases and 
decreases in emissions.
    (13) Provisions for adequate, streamlined, and reasonable procedures 
for expeditious review of permit revisions or modifications. The program 
may meet this requirement by using procedures that meet the requirements 
of Sec. 70.7(e) or that are substantially equivalent to those 
provided in Sec. 70.7(e) of this part.
    (14) If a State allows changes that are not addressed or prohibited 
by the permit, other than those described in paragraph (b)(15) of this 
section, to be made without a permit revision, provisions meeting the 
requirements of paragraphs (b)(14) (i) through (iii) of this section. 
Although a State may, as a matter of State law, prohibit sources from 
making such changes without a permit revision, any such prohibition 
shall not be enforceable by the Administrator or by citizens under the 
Act unless the prohibition is required by an applicable requirement. Any 
State procedures implementing such a State law prohibition must include 
the requirements of paragraphs (b)(14) (i) through (iii) of this 
section.
    (i) Each such change shall meet all applicable requirements and 
shall not violate any existing permit term or condition.
    (ii) Sources must provide contemporaneous written notice to the 
permitting authority and EPA of each such change, except for changes 
that qualify as insignificant under the provisions adopted pursuant to 
Sec. 70.5(c) of this part. Such written notice shall describe 
each such change, including the date, any change in emissions, 
pollutants emitted, and any applicable requirement that would apply as a 
result of the change.
    (iii) The change shall not qualify for the shield under 
Sec. 70.6(f) of this part.
    (iv) The permittee shall keep a record describing changes made at 
the source that result in emissions of a regulated air pollutant subject 
to an applicable requirement, but not otherwise regulated under the 
permit, and the emissions resulting from those changes.
    (15) Provisions prohibiting sources from making, without a permit 
revision, changes that are not addressed or prohibited by the part 70 
permit, if such changes are subject to any requirements under title IV 
of the Act or are modifications under any provision of title I of the 
Act.
    (16) Provisions requiring the permitting authority to implement the 
requirements of Sec.Sec. 70.6 and 70.7 of this part.
    (c) Partial programs. (1) The EPA may approve a partial program that 
applies to all part 70 sources within a limited geographic area (e.g., a 
local agency program covering all sources within the agency's 
jurisdiction). To be approvable, any partial program must, at a minimum, 
ensure compliance with all of the following applicable requirements, as 
they apply to the sources covered by the partial program:
    (i) All requirements of title V of the Act and of part 70;
    (ii) All applicable requirements of title IV of the Act and 
regulations promulgated thereunder which apply to affected sources; and
    (iii) All applicable requirements of title I of the Act, including 
those established under sections 111 and 112 of the Act.
    (2) Any partial permitting program, such as that of a local air 
pollution control agency, providing for the issuance of permits by a 
permitting authority other than the State, shall be consistent with all 
the elements required in paragraphs (b) (1) through (16) of this 
section.
    (3) Approval of any partial program does not relieve the State from 
its obligation to submit a whole program or from application of any 
sanctions for

[[Page 217]]

failure to submit a fully-approvable whole program.
    (4) Any partial program may obtain interim approval under paragraph 
(d) of this section if it substantially meets the requirements of this 
paragraph (c) of this section.
    (d) Interim approval. (1) If a program (including a partial permit 
program) submitted under this part substantially meets the requirements 
of this part, but is not fully approvable, the Administrator may be rule 
grant the program interim approval.
    (2) Interim approval shall expire on a date set by the Administrator 
(but not later than 2 years after such approval), and may not be 
renewed. Sources shall become subject to the program according to the 
schedule approved in the State program. Permits granted under an interim 
approval shall expire at the end of their fixed term, unless renewed 
under a part 70 program.
    (3) The EPA may grant interim approval to any program if it meets 
each of the following minimum requirements and otherwise substantially 
meets the requirements of this part:
    (i) Adequate fees. The program must provide for collecting permit 
fees adequate for it to meet the requirements of Sec. 70.9 of 
this part.
    (ii) Applicable requirements. (A) The program must provide for 
adequate authority to issue permits that assure compliance with the 
requirements of paragraph (c)(1) of this section for those major sources 
covered by the program.
    (B) Notwithstanding paragraph (d)(3)(ii)(A) of this section, where a 
State or local permitting authority lacks adequate authority to issue or 
revise permits that assure compliance with applicable requirements 
established exclusively through an EPA-approved minor NSR program, EPA 
may grant interim approval to the program upon a showing by the 
permitting authority of compelling reasons which support the interim 
approval.
    (C) Any part 70 permit issued during an interim approval granted 
under paragraph (d)(3)(ii)(B) of this section that does not incorporate 
minor NSR requirements shall:
    (1) Note this fact in the permit;
    (2) Indicate how citizens may obtain access to excluded minor NSR 
permits;
    (3) Provide a cross reference, such as a listing of the permit 
number, for each minor NSR permit containing an excluded minor NSR term; 
and
    (4) State that the minor NSR requirements which are excluded are not 
eligible for the permit shield under Sec. 70.6(f).
    (D) A program receiving interim approval for the reason specified in 
(d)(3)(ii)(B) of this section must, upon or before granting of full 
approval, institute proceedings to reopen part 70 permits to incorporate 
excluded minor NSR permits as terms of the part 70 permits, as required 
by Sec. 70.7(f)(1)(iv). Such reopening need not follow full 
permit issuance procedures nor the notice requirement of Sec. 
70.7(f)(3), but may instead follow the permit revision procedure in 
effect under the State's approved part 70 program for incorporation of 
minor NSR permits.
    (iii) Fixed term. The program must provide for fixed permit terms, 
consistent with paragraphs (b)(3) (iii) and (iv) of this section.
    (iv) Public participation. The program must provide for adequate 
public notice of and an opportunity for public comment and a hearing on 
draft permits and revisions, except for modifications qualifying for 
minor permit modification procedures under Sec. 70.7(e) of 
this part.
    (v) EPA and affected State review. The program must allow EPA an 
opportunity to review each proposed permit, including permit revisions, 
and to object to its issuance consistent with Sec. 70.8(c) of 
this part. The program must provide for affected State review consistent 
with Sec. 70.8(b) of this part.
    (vi) Permit issuance. The program must provide that the proposed 
permit will not be issued if EPA objects to its issuance.
    (vii) Enforcement. The program must contain authority to enforce 
permits, including the authority to assess penalties against sources 
that do not comply with their permits or with the requirement to obtain 
a permit.
    (viii) Operational flexibility. The program must allow changes 
within a permitted facility without requiring a permit revision, if the 
changes are not modifications under any provision of

[[Page 218]]

title I of the act and the changes do not exceed the emissions allowable 
under the permit, consistent with paragraph (b)(12) of this section.
    (ix) Streamlined procedures. The program must provide for 
streamlined procedures for issuing and revising permits and determining 
expeditiously after receipt of a permit application or application for a 
permit revision whether such application is complete.
    (x) Permit application. The program submittal must include copies of 
the permit application and reporting form(s) that the State will use in 
implementing the interim program.
    (xi) Alternative scenarios. The program submittal must include 
provisions to insure that alternate scenarios requested by the source 
are included in the part 70 permit pursuant to Sec. 70.6(a)(9) 
of this part.
    (e) EPA review of permit program submittals. Within 1 year after 
receiving a program submittal, the Administrator shall approve or 
disapprove the program, in whole or in part, by publishing a notice in 
the Federal Register. Prior to such notice, the Administrator shall 
provide an opportunity for public comment on such approval or 
disapproval. Any EPA action disapproving a program, in whole or in part, 
shall include a statement of the revisions or modifications necessary to 
obtain full approval. The Administrator shall approve State programs 
that conform to the requirements of this part.
    (1) Within 60 days of receipt by EPA of a State program submission, 
EPA will notify the State whether its submission is complete enough to 
warrant review by EPA for either full, partial, or interim approval. If 
EPA finds that a State's submission is complete, the 1-year review 
period (i.e., the period of time allotted for formal EPA review of a 
proposed State program) shall be deemed to have begun on the date of 
receipt of the State's submission. If EPA finds that a State's 
submission is incomplete, the 1-year review period shall not begin until 
all the necessary information is received by EPA.
    (2) If the State's submission is materially changed during the 1-
year review period, the Administrator may extend the review period for 
no more than 1 year following receipt of the revised submission.
    (3) In any notice granting interim or partial approval, the 
Administrator shall specify the changes or additions that must be made 
before the program can receive full approval and the conditions for 
implementation of the program until that time.
    (f) State response to EPA review of program - (1) Disapproval. 
The State shall submit to EPA program revisions or modifications 
required by the Administrator's action disapproving the program, or any 
part thereof, within 180 days of receiving notification of the 
disapproval.
    (2) Interim approval. The State shall submit to EPA changes to the 
program addressing the deficiencies specified in the interim approval no 
later than 6 months prior to the expiration of the interim approval.
    (g) Effective date. The effective date of a part 70 program, 
including any partial or interim program approved under this part, shall 
be the effective date of approval by the Administrator.
    (h) Individual permit transition. Upon approval of a State program, 
the Administrator shall suspend the issuance of Federal permits for 
those activities subject to the approved State program, except that the 
Administrator will continue to issue phase I acid rain permits. After 
program approval, EPA shall retain jurisdiction over any permit 
(including any general permit) that it has issued unless arrangements 
have been made with the State to assume responsibility for these 
permits. Where EPA retains jurisdiction, it will continue to process 
permit appeals and modification requests, to conduct inspections, and to 
receive and review monitoring reports. If any permit appeal or 
modification request is not finally resolved when the federally-issued 
permit expires, EPA may, with the consent of the State, retain 
jurisdiction until the matter is resolved. Upon request by a State, the 
Administrator may delegate authority to implement all or part of a 
permit issued by EPA, if a part 70 program has been approved for the 
State. The delegation may include authorization for the State to collect 
appropriate fees, consistent with Sec. 70.9 of this part.

[[Page 219]]

    (i) Program revisions. Either EPA or a State with an approved 
program may initiate a program revision. Program revision may be 
necessary when the relevant Federal or State statutes or regulations are 
modified or supplemented. The State shall keep EPA apprised of any 
proposed modifications to its basic statutory or regulatory authority or 
procedures.
    (1) If the Administrator determines pursuant to Sec. 70.10 
of this part that a State is not adequately administering the 
requirements of this part, or that the State's permit program is 
inadequate in any other way, the State shall revise the program or its 
means of implementation to correct the inadequacy. The program shall be 
revised within 180 days, or such other period as the Administrator may 
specify, following notification by the Administrator, or within 2 years 
if the State demonstrates that additional legal authority is necessary 
to make the program revision.
    (2) Revision of a State program shall be accomplished as follows:
    (i) The State shall submit a modified program description, Attorney 
General's statement, or such other documents as EPA determines to be 
necessary.
    (ii) After EPA receives a proposed program revision, it will publish 
in the Federal Register a public notice summarizing the proposed change 
and provide a public comment period of at least 30 days.
    (iii) The Administrator shall approve or disapprove program 
revisions based on the requirements of this part and of the Act.
    (iv) A program revision shall become effective upon the approval of 
the Administrator. Notice of approval of any substantial revision shall 
be published in the Federal Register. Notice of approval of 
nonsubstantial program revisions may be given by a letter from the 
Administrator to the Governor or a designee.
    (v) The Governor of any State with an approved part 70 program shall 
notify EPA whenever the Governor proposes to transfer all or part of the 
program to any other agency, and shall identify any new division of 
responsibilities among the agencies involved. The new agency is not 
authorized to administer the program until the revision has been 
approved by the Administrator under this paragraph.
    (3) Whenever the Administrator has reason to believe that 
circumstances have changed with respect to a State program, he may 
request, and the State shall provide, a supplemental Attorney General's 
statement, program description, or such other documents or information 
as he determines are necessary.
    (j) Sharing of information. (1) Any information obtained or used in 
the administration of a State program shall be available to EPA upon 
request without restriction and in a form specified by the 
Administrator, including computer-readable files to the extent 
practicable. If the information has been submitted to the State under a 
claim of confidentiality, the State may require the source to submit 
this information to the Administrator directly. Where the State submits 
information to the Administrator under a claim of confidentiality, the 
State shall submit that claim to EPA when providing information to EPA 
under this section. Any information obtained from a State or part 70 
source accompanied by a claim of confidentiality will be treated in 
accordance with the regulations in part 2 of this chapter.
    (2) The EPA will furnish to States with approved programs the 
information in its files that the State needs to implement its approved 
program. Any such information submitted to EPA under a claim of 
confidentiality will be subject to the regulations in part 2 of this 
chapter.
    (k) Administration and enforcement. Any State that fails to adopt a 
complete, approvable part 70 program, or that EPA determines is not 
adequately administering or enforcing such program shall be subject to 
certain Federal sanctions as set forth in Sec. 70.10 of this 
part.

[57 FR 32295, July 21, 1992, as amended at 61 FR 31448, June 20, 1996; 
61 FR 56370, Oct. 31, 1996; 66 FR 27010, May 15, 2001]



Sec. 70.5  Permit applications.

    (a) Duty to apply. For each part 70 source, the owner or operator 
shall submit a timely and complete permit

[[Page 220]]

application in accordance with this section.
    (1) Timely application. (i) A timely application for a source 
applying for a part 70 permit for the first time is one that is 
submitted within 12 months after the source becomes subject to the 
permit program or on or before such earlier date as the permitting 
authority may establish.
    (ii) Part 70 sources required to meet the requirements under section 
112(g) of the Act, or to have a permit under the preconstruction review 
program approved into the applicable implementation plan under part C or 
D of title I of the Act, shall file a complete application to obtain the 
part 70 permit or permit revision within 12 months after commencing 
operation or on or before such earlier date as the permitting authority 
may establish. Where an existing part 70 permit would prohibit such 
construction or change in operation, the source must obtain a permit 
revision before commencing operation.
    (iii) For purposes of permit renewal, a timely application is one 
that is submitted at least 6 months prior to the date of permit 
expiration, or such other longer time as may be approved by the 
Administrator that ensures that the term of the permit will not expire 
before the permit is renewed. In no event shall this time be greater 
than 18 months.
    (iv) Applications for initial phase II acid rain permits shall be 
submitted to the permitting authority by January 1, 1996 for sulfur 
dioxide, and by January 1, 1998 for nitrogen oxides.
    (2) Complete application. The program shall provide criteria and 
procedures for determining in a timely fashion when applications are 
complete. To be deemed complete, an application must provide all 
information required pursuant to paragraph (c) of this section, except 
that applications for permit revision need supply such information only 
if it is related to the proposed change. Information required under 
paragraph (c) of this section must be sufficient to evaluate the subject 
source and its application and to determine all applicable requirements. 
The program shall require that a responsible official certify the 
submitted information consistent with paragraph (d) of this section. 
Unless the permitting authority determines that an application is not 
complete within 60 days of receipt of the application, such application 
shall be deemed to be complete, except as otherwise provided in 
Sec. 70.7(a)(4) of this part. If, while processing an 
application that has been determined or deemed to be complete, the 
permitting authority determines that additional information is necessary 
to evaluate or take final action on that application, it may request 
such information in writing and set a reasonable deadline for a 
response. The source's ability to operate without a permit, as set forth 
in Sec. 70.7(b) of this part, shall be in effect from the date 
the application is determined or deemed to be complete until the final 
permit is issued, provided that the applicant submits any requested 
additional information by the deadline specified by the permitting 
authority.
    (3) Confidential information. In the case where a source has 
submitted information to the State under a claim of confidentiality, the 
permitting authority may also require the source to submit a copy of 
such information directly to the Administrator.
    (b) Duty to supplement or correct application. Any applicant who 
fails to submit any relevant facts or who has submitted incorrect 
information in a permit application shall, upon becoming aware of such 
failure or incorrect submittal, promptly submit such supplementary facts 
or corrected information. In addition, an applicant shall provide 
additional information as necessary to address any requirements that 
become applicable to the source after the date it filed a complete 
application but prior to release of a draft permit.
    (c) Standard application form and required information. The State 
program under this part shall provide for a standard application form or 
forms. Information as described below for each emissions unit at a part 
70 source shall be included in the application. The Administrator may 
approve as part of a State program a list of insignificant activities 
and emissions levels which need not be included in permit applications. 
However, for insignificant activities which are exempted because of size

[[Page 221]]

or production rate, a list of such insignificant activities must be 
included in the application. An application may not omit information 
needed to determine the applicability of, or to impose, any applicable 
requirement, or to evaluate the fee amount required under the schedule 
approved pursuant to Sec. 70.9 of this part. The permitting 
authority may use discretion in developing application forms that best 
meet program needs and administrative efficiency. The forms and 
attachments chosen, however, shall include the elements specified below:
    (1) Identifying information, including company name and address (or 
plant name and address if different from the company name), owner's name 
and agent, and telephone number and names of plant site manager/contact.
    (2) A description of the source's processes and products (by 
Standard Industrial Classification Code) including any associated with 
alternate scenario identified by the source.
    (3) The following emission-related information:
    (i) All emissions of pollutants for which the source is major, and 
all emissions of regulated air pollutants. A permit application shall 
describe all emissions of regulated air pollutants emitted from any 
emissions unit, except where such units are exempted under this 
paragraph (c) of this section. The permitting authority shall require 
additional information related to the emissions of air pollutants 
sufficient to verify which requirements are applicable to the source, 
and other information necessary to collect any permit fees owed under 
the fee schedule approved pursuant to Sec. 70.9(b) of this 
part.
    (ii) Identification and description of all points of emissions 
described in paragraph (c)(3)(i) of this section in sufficient detail to 
establish the basis for fees and applicability of requirements of the 
Act.
    (iii) Emissions rate in tpy and in such terms as are necessary to 
establish compliance consistent with the applicable standard reference 
test method.
    (iv) The following information to the extent it is needed to 
determine or regulate emissions: Fuels, fuel use, raw materials, 
production rates, and operating schedules.
    (v) Identification and description of air pollution control 
equipment and compliance monitoring devices or activities.
    (vi) Limitations on source operation affecting emissions or any work 
practice standards, where applicable, for all regulated pollutants at 
the part 70 source.
    (vii) Other information required by any applicable requirement 
(including information related to stack height limitations developed 
pursuant to section 123 of the Act).
    (viii) Calculations on which the information in paragraphs (c)(3 (i) 
through (vii) of this section is based.
    (4) The following air pollution control requirements:
    (i) Citation and description of all applicable requirements, and
    (ii) Description of or reference to any applicable test method for 
determining compliance with each applicable requirement.
    (5) Other specific information that may be necessary to implement 
and enforce other applicable requirements of the Act or of this part or 
to determine the applicability of such requirements.
    (6) An explanation of any proposed exemptions from otherwise 
applicable requirements.
    (7) Additional information as determined to be necessary by the 
permitting authority to define alternative operating scenarios 
identified by the source pursuant to Sec. 70.6(a)(9) of this 
part or to define permit terms and conditions implementing 
Sec. 70.4 (b) (12) or Sec. 70.6 (a) (10) of this 
part.
    (8) A compliance plan for all part 70 sources that contains all the 
following:
    (i) A description of the compliance status of the source with 
respect to all applicable requirements.
    (ii) A description as follows:
    (A) For applicable requirements with which the source is in 
compliance, a statement that the source will continue to comply with 
such requirements.
    (B) For applicable requirements that will become effective during 
the permit term, a statement that the source will meet such requirements 
on a timely basis.

[[Page 222]]

    (C) For requirements for which the source is not in compliance at 
the time or permit issuance, a narrative description of how the source 
will achieve compliance with such requirements.
    (iii) A compliance schedule as follows:
    (A) For applicable requirements with which the source is in 
compliance, a statement that the source will continue to comply with 
such requirements.
    (B) For applicable requirements that will become effective during 
the permit term, a statement that the source will meet such requirements 
on a timely basis. A statement that the source will meet in a timely 
manner applicable requirements that become effective during the permit 
term shall satisfy this provision, unless a more detailed schedule is 
expressly required by the applicable requirement.
    (C) A schedule of compliance for sources that are not in compliance 
with all applicable requirements at the time of permit issuance. Such a 
schedule shall include a schedule of remedial measures, including an 
enforceable sequence of actions with milestones, leading to compliance 
with any applicable requirements for which the source will be in 
noncompliance at the time of permit issuance. This compliance schedule 
shall resemble and be at least as stringent as that contained in any 
judicial consent decree or administrative order to which the source is 
subject. Any such schedule of compliance shall be supplemental to, and 
shall not sanction noncompliance with, the applicable requirements on 
which it is based.
    (iv) A schedule for submission of certified progress reports no less 
frequently than every 6 months for sources required to have a schedule 
of compliance to remedy a violation.
    (v) The compliance plan content requirements specified in this 
paragraph shall apply and be included in the acid rain portion of a 
compliance plan for an affected source, except as specifically 
superseded by regulations promulgated under title IV of the Act with 
regard to the schedule and method(s) the source will use to achieve 
compliance with the acid rain emissions limitations.
    (9) Requirements for compliance certification, including the 
following:
    (i) A certification of compliance with all applicable requirements 
by a responsible official consistent with paragraph (d) of this section 
and section 114(a)(3) of the Act;
    (ii) A statement of methods used for determining compliance, 
including a description of monitoring, recordkeeping, and reporting 
requirements and test methods;
    (iii) A schedule for submission of compliance certifications during 
the permit term, to be submitted no less frequently than annually, or 
more frequently if specified by the underlying applicable requirement or 
by the permitting authority; and
    (iv) A statement indicating the source's compliance status with any 
applicable enhanced monitoring and compliance certification requirements 
of the Act.
    (10) The use of nationally-standardized forms for acid rain portions 
of permit applications and compliance plans, as required by regulations 
promulgated under title IV of the Act.
    (d) Any application form, report, or compliance certification 
submitted pursuant to these regulations shall contain certification by a 
responsible official of truth, accuracy, and completeness. This 
certification and any other certification required under this part shall 
state that, based on information and belief formed after reasonable 
inquiry, the statements and information in the document are true, 
accurate, and complete.



Sec. 70.6  Permit content.

    (a) Standard permit requirements. Each permit issued under this part 
shall include the following elements:
    (1) Emission limitations and standards, including those operational 
requirements and limitations that assure compliance with all applicable 
requirements at the time of permit issuance.
    (i) The permit shall specify and reference the origin of and 
authority for each term or condition, and identify any difference in 
form as compared to the applicable requirement upon which the term or 
condition is based.
    (ii) The permit shall state that, where an applicable requirement of 
the

[[Page 223]]

Act is more stringent than an applicable requirement of regulations 
promulgated under title IV of the Act, both provisions shall be 
incorporated into the permit and shall be enforceable by the 
Administrator.
    (iii) If an applicable implementation plan allows a determination of 
an alternative emission limit at a part 70 source, equivalent to that 
contained in the plan, to be made in the permit issuance, renewal, or 
significant modification process, and the State elects to use such 
process, any permit containing such equivalency determination shall 
contain provisions to ensure that any resulting emissions limit has been 
demonstrated to be quantifiable, accountable, enforceable, and based on 
replicable procedures.
    (2) Permit duration. The permitting authority shall issue permits 
for a fixed term of 5 years in the case of affected sources, and for a 
term not to exceed 5 years in the case of all other sources. 
Notwithstanding this requirement, the permitting authority shall issue 
permits for solid waste incineration units combusting municipal waste 
subject to standards under section 129(e) of the Act for a period not to 
exceed 12 years and shall review such permits at least every 5 years.
    (3) Monitoring and related recordkeeping and reporting requirements. 
(i) Each permit shall contain the following requirements with respect to 
monitoring:
    (A) All monitoring and analysis procedures or test methods required 
under applicable monitoring and testing requirements, including part 64 
of this chapter and any other procedures and methods that may be 
promulgated pursuant to sections 114(a)(3) or 504(b) of the Act. If more 
than one monitoring or testing requirement applies, the permit may 
specify a streamlined set of monitoring or testing provisions provided 
the specified monitoring or testing is adequate to assure compliance at 
least to the same extent as the monitoring or testing applicable 
requirements that are not included in the permit as a result of such 
streamlining;
    (B) Where the applicable requirement does not require periodic 
testing or instrumental or noninstrumental monitoring (which may consist 
of recordkeeping designed to serve as monitoring), periodic monitoring 
sufficient to yield reliable data from the relevant time period that are 
representative of the source's compliance with the permit, as reported 
pursuant to paragraph (a)(3)(iii) of this section. Such monitoring 
requirements shall assure use of terms, test methods, units, averaging 
periods, and other statistical conventions consistent with the 
applicable requirement. Recordkeeping provisions may be sufficient to 
meet the requirements of this paragraph (a)(3)(i)(B) of this section; 
and
    (C) As necessary, requirements concerning the use, maintenance, and, 
where appropriate, installation of monitoring equipment or methods.
    (ii) With respect to recordkeeping, the permit shall incorporate all 
applicable recordkeeping requirements and require, where applicable, the 
following:
    (A) Records of required monitoring information that include the 
following:
    (1) The date, place as defined in the permit, and time of sampling 
or measurements;
    (2) The date(s) analyses were performed;
    (3) The company or entity that performed the analyses;
    (4) The analytical techniques or methods used;
    (5) The results of such analyses; and
    (6) The operating conditions as existing at the time of sampling or 
measurement;
    (B) Retention of records of all required monitoring data and support 
information for a period of at least 5 years from the date of the 
monitoring sample, measurement, report, or application. Support 
information includes all calibration and maintenance records and all 
original strip-chart recordings for continuous monitoring 
instrumentation, and copies of all reports required by the permit.
    (iii) With respect to reporting, the permit shall incorporate all 
applicable reporting requirements and require the following:
    (A) Submittal of reports of any required monitoring at least every 6 
months. All instances of deviations from permit requirements must be 
clearly identified in such reports. All

[[Page 224]]

required reports must be certified by a responsible official consistent 
with Sec. 70.5(d) of this part.
    (B) Prompt reporting of deviations from permit requirements, 
including those attributable to upset conditions as defined in the 
permit, the probable cause of such deviations, and any corrective 
actions or preventive measures taken. The permitting authority shall 
define ``prompt'' in relation to the degree 
and type of deviation likely to occur and the applicable requirements.
    (4) A permit condition prohibiting emissions exceeding any 
allowances that the source lawfully holds under title IV of the Act or 
the regulations promulgated thereunder.
    (i) No permit revision shall be required for increases in emissions 
that are authorized by allowances acquired pursuant to the acid rain 
program, provided that such increases do not require a permit revision 
under any other applicable requirement.
    (ii) No limit shall be placed on the number of allowances held by 
the source. The source may not, however, use allowances as a defense to 
noncompliance with any other applicable requirement.
    (iii) Any such allowance shall be accounted for according to the 
procedures established in regulations promulgated under title IV of the 
Act.
    (5) A severability clause to ensure the continued validity of the 
various permit requirements in the event of a challenge to any portions 
of the permit.
    (6) Provisions stating the following:
    (i) The permittee must comply with all conditions of the part 70 
permit. Any permit noncompliance constitutes a violation of the Act and 
is grounds for enforcement action; for permit termination, revocation 
and reissuance, or modification; or for denial of a permit renewal 
application.
    (ii) Need to halt or reduce activity not a defense. It shall not be 
a defense for a permittee in an enforcement action that it would have 
been necessary to halt or reduce the permitted activity in order to 
maintain compliance with the conditions of this permit.
    (iii) The permit may be modified, revoked, reopened, and reissued, 
or terminated for cause. The filing of a request by the permittee for a 
permit modification, revocation and reissuance, or termination, or of a 
notification of planned changes or anticipated noncompliance does not 
stay any permit condition.
    (iv) The permit does not convey any property rights of any sort, or 
any exclusive privilege.
    (v) The permittee shall furnish to the permitting authority, within 
a reasonable time, any information that the permitting authority may 
request in writing to determine whether cause exists for modifying, 
revoking and reissuing, or terminating the permit or to determine 
compliance with the permit. Upon request, the permittee shall also 
furnish to the permitting authority copies of records required to be 
kept by the permit or, for information claimed to be confidential, the 
permittee may furnish such records directly to the Administrator along 
with a claim of confidentiality.
    (7) A provision to ensure that a part 70 source pays fees to the 
permitting authority consistent with the fee schedule approved pursuant 
to Sec. 70.9 of this part.
    (8) Emissions trading. A provision stating that no permit revision 
shall be required, under any approved economic incentives, marketable 
permits, emissions trading and other similar programs or processes for 
changes that are provided for in the permit.
    (9) Terms and conditions for reasonably anticipated operating 
scenarios identified by the source in its application as approved by the 
permitting authority. Such terms and conditions:
    (i) Shall require the source, contemporaneously with making a change 
from one operating scenario to another, to record in a log at the 
permitted facility a record of the scenario under which it is operating;
    (ii) May extend the permit shield described in paragraph (f) of this 
section to all terms and conditions under each such operating scenario; 
and
    (iii) Must ensure that the terms and conditions of each such 
alternative scenario meet all applicable requirements and the 
requirements of this part.
    (10) Terms and conditions, if the permit applicant requests them, 
for the

[[Page 225]]

trading of emissions increases and decreases in the permitted facility, 
to the extent that the applicable requirements provide for trading such 
increases and decreases without a case-by-case approval of each 
emissions trade. Such terms and conditions:
    (i) Shall include all terms required under paragraphs (a) and (c) of 
this section to determine compliance;
    (ii) May extend the permit shield described in paragraph (f) of this 
section to all terms and conditions that allow such increases and 
decreases in emissions; and
    (iii) Must meet all applicable requirements and requirements of this 
part.
    (b) Federally-enforceable requirements. (1) All terms and conditions 
in a part 70 permit, including any provisions designed to limit a 
source's potential to emit, are enforceable by the Administrator and 
citizens under the Act.
    (2) Notwithstanding paragraph (b)(1) of this section, the permitting 
authority shall specifically designate as not being federally 
enforceable under the Act any terms and conditions included in the 
permit that are not required under the Act or under any of its 
applicable requirements. Terms and conditions so designated are not 
subject to the requirements of Sec.Sec. 70.7, 70.8, 
or of this part, other than those contained in this paragraph (b) of 
this section.
    (c) Compliance requirements. All part 70 permits shall contain the 
following elements with respect to compliance:
    (1) Consistent with paragraph (a)(3) of this section, compliance 
certification, testing, monitoring, reporting, and recordkeeping 
requirements sufficient to assure compliance with the terms and 
conditions of the permit. Any document (including reports) required by a 
part 70 permit shall contain a certification by a responsible official 
that meets the requirements of Sec. 70.5(d) for this part.
    (2) Inspection and entry requirements that require that, upon 
presentation of credentials and other documents as may be required by 
law, the permittee shall allow the permitting authority or an authorized 
representative to perform the following:
    (i) Enter upon the permittee's premises where a part 70 source is 
located or emissions-related activity is conducted, or where records 
must be kept under the conditions of the permit;
    (ii) Have access to and copy, at reasonable times, any records that 
must be kept under the conditions of the permit;
    (iii) Inspect at reasonable times any facilities, equipment 
(including monitoring and air pollution control equipment), practices, 
or operations regulated or required under the permit; and
    (iv) As authorized by the Act, sample or monitor at reasonable times 
substances or parameters for the purpose of assuring compliance with the 
permit or applicable requirements.
    (3) A schedule of compliance consistent with Sec. 
70.5(c)(8) of this part.
    (4) Progress reports consistent with an applicable schedule of 
compliance and Sec. 70.5(c)(8) of this part to be submitted at 
least semiannually, or at a more frequent period if specified in the 
applicable requirement or by the permitting authority. Such progress 
reports shall contain the following:
    (i) Dates for achieving the activities, milestones, or compliance 
required in the schedule of compliance, and dates when such activities, 
milestones or compliance were achieved; and
    (ii) An explanation of why any dates in the schedule of compliance 
were not or will not be met, and any preventive or corrective measures 
adopted.
    (5) Requirements for compliance certification with terms and 
conditions contained in the permit, including emission limitations, 
standards, or work practices. Permits shall include each of the 
following:
    (i) The frequency (not less than annually or such more frequent 
periods as specified in the applicable requirement or by the permitting 
authority) of submissions of compliance certifications;
    (ii) In accordance with Sec. 70.6(a)(3) of this part, a 
means for monitoring the compliance of the source with its emissions 
limitations, standards, and work practices;
    (iii) A requirement that the compliance certification include all of 
the following (provided that the identification of applicable 
information may cross-reference the permit or previous reports, as 
applicable):

[[Page 226]]

    (A) The identification of each term or condition of the permit that 
is the basis of the certification;
    (B) The identification of the method(s) or other means used by the 
owner or operator for determining the compliance status with each term 
and condition during the certification period. Such methods and other 
means shall include, at a minimum, the methods and means required under 
paragraph (a)(3) of this section;
    (C) The status of compliance with the terms and conditions of the 
permit for the period covered by the certification, including whether 
compliance during the period was continuous or intermittent. The 
certification shall be based on the method or means designated in 
paragraph (c)(5)(iii)(B) of this section. The certification shall 
identify each deviation and take it into account in the compliance 
certification. The certification shall also identify as possible 
exceptions to compliance any periods during which compliance is required 
and in which an excursion or exceedance as defined under part 64 of this 
chapter occurred; and
    (D) Such other facts as the permitting authority may require to 
determine the compliance status of the source.
    (iv) A requirement that all compliance certifications be submitted 
to the Administrator as well as to the permitting authority.
    (6) Such other provisions as the permitting authority may require.
    (d) General permits. (1) The permitting authority may, after notice 
and opportunity for public participation provided under Sec. 
70.7(h) of this part, issue a general permit covering numerous similar 
sources. Any general permit shall comply with all requirements 
applicable to other part 70 permits and shall identify criteria by which 
sources may qualify for the general permit. To sources that qualify, the 
permitting authority shall grant the conditions and terms of the general 
permit. Notwithstanding the shield provisions of paragraph (f) of this 
section, the source shall be subject to enforcement action for operation 
without a part 70 permit if the source is later determined not to 
qualify for the conditions and terms of the general permit. General 
permits shall not be authorized for affected sources under the acid rain 
program unless otherwise provided in regulations promulgated under title 
IV of the Act.
    (2) Part 70 sources that would qualify for a general permit must 
apply to the permitting authority for coverage under the terms of the 
general permit or must apply for a part 70 permit consistent with 
Sec. 70.5 of this part. The permitting authority may, in the 
general permit, provide for applications which deviate from the 
requirements of Sec. 70.5 of this part, provided that such 
applications meet the requirements of title V of the Act, and include 
all information necessary to determine qualification for, and to assure 
compliance with, the general permit. Without repeating the public 
participation procedures required under Sec. 70.7(h) of this 
part, the permitting authority may grant a source's request for 
authorization to operate under a general permit, but such a grant shall 
not be a final permit action for purposes of judicial review.
    (e) Temporary sources. The permitting authority may issue a single 
permit authorizing emissions from similar operations by the same source 
owner or operator at multiple temporary locations. The operation must be 
temporary and involve at least one change of location during the term of 
the permit. No affected source shall be permitted as a temporary source. 
Permits for temporary sources shall include the following:
    (1) Conditions that will assure compliance with all applicable 
requirements at all authorized locations;
    (2) Requirements that the owner or operator notify the permitting 
authority at least 10 days in advance of each change in location; and
    (3) Conditions that assure compliance with all other provisions of 
this section.
    (f) Permit shield. (1) Except as provided in this part, the 
permitting authority may expressly include in a part 70 permit a 
provision stating that compliance with the conditions of the permit 
shall be deemed compliance with any applicable requirements as of the 
date of permit issuance, provided that:

[[Page 227]]

    (i) Such applicable requirements are included and are specifically 
identified in the permit; or
    (ii) The permitting authority, in acting on the permit application 
or revision, determines in writing that other requirements specifically 
identified are not applicable to the source, and the permit includes the 
determination or a concise summary thereof.
    (2) A part 70 permit that does not expressly state that a permit 
shield exists shall be presumed not to provide such a shield.
    (3) Nothing in this paragraph or in any part 70 permit shall alter 
or affect the following:
    (i) The provisions of section 303 of the Act (emergency orders), 
including the authority of the Administrator under that section;
    (ii) The liability of an owner or operator of a source for any 
violation of applicable requirements prior to or at the time of permit 
issuance;
    (iii) The applicable requirements of the acid rain program, 
consistent with section 408(a) of the Act; or
    (iv) The ability of EPA to obtain information from a source pursuant 
to section 114 of the Act.
    (g) Emergency provision - (1) Definition. An 
``emergency'' means any situation arising 
from sudden and reasonably unforeseeable events beyond the control of 
the source, including acts of God, which situation requires immediate 
corrective action to restore normal operation, and that causes the 
source to exceed a technology-based emission limitation under the 
permit, due to unavoidable increases in emissions attributable to the 
emergency. An emergency shall not include noncompliance to the extent 
caused by improperly designed equipment, lack of preventative 
maintenance, careless or improper operation, or operator error.
    (2) Effect of an emergency. An emergency constitutes an affirmative 
defense to an action brought for noncompliance with such technology-
based emission limitations if the conditions of paragraph (g)(3) of this 
section are met.
    (3) The affirmative defense of emergency shall be demonstrated 
through properly signed, contemporaneous operating logs, or other 
relevant evidence that:
    (i) An emergency occurred and that the permittee can identify the 
cause(s) of the emergency;
    (ii) The permitted facility was at the time being properly operated;
    (iii) During the period of the emergency the permittee took all 
reasonable steps to minimize levels of emissions that exceeded the 
emission standards, or other requirements in the permit; and
    (iv) The permittee submitted notice of the emergency to the 
permitting authority within 2 working days of the time when emission 
limitations were exceeded due to the emergency. This notice fulfills the 
requirement of paragraph (a)(3)(iii)(B) of this section. This notice 
must contain a description of the emergency, any steps taken to mitigate 
emissions, and corrective actions taken.
    (4) In any enforcement proceeding, the permittee seeking to 
establish the occurrence of an emergency has the burden of proof.
    (5) This provision is in addition to any emergency or upset 
provision contained in any applicable requirement.

[57 FR 32295, July 21, 1992, as amended at 62 FR 54946, Oct. 22, 1997; 
66 FR 12876, Mar. 1, 2001; 66 FR 55884, Nov. 5, 2001; 68 FR 38523, June 
27, 2003]



Sec. 70.7  Permit issuance, renewal, reopenings, and revisions.

    (a) Action on application. (1) A permit, permit modification, or 
renewal may be issued only if all of the following condition have been 
met:
    (i) The permitting authority has received a complete application for 
a permit, permit modification, or permit renewal, except that a complete 
application need not be received before issuance of a general permit 
under Sec. 70.6(d) of this part;
    (ii) Except for modifications qualifying for minor permit 
modification procedures under paragraphs (e) (2) and (3) of this 
section, the permitting authority has complied with the requirements for 
public participation under paragraph (h) of this section;

[[Page 228]]

    (iii) The permitting authority has complied with the requirements 
for notifying and responding to affected States under Sec. 
70.8(b) of this part;
    (iv) The conditions of the permit provide for compliance with all 
applicable requirements and the requirements of this part; and
    (v) The Administrator has received a copy of the proposed permit and 
any notices required under Sec.Sec. 70.8(a) and 
70.8(b) of this part, and has not objected to issuance of the permit 
under Sec. 70.8(c) of this part within the time period 
specified therein.
    (2) Except as provided under the initial transition plan provided 
for under Sec. 70.4(b)(11) of this part or under regulations 
promulgated under title IV of title V of the Act for the permitting of 
affected sources under the acid rain program, the program shall provide 
that the permitting authority take final action on each permit 
application (including a request for permit modification or renewal) 
within 18 months, or such lesser time approved by the Administrator, 
after receiving a complete application.
    (3) The program shall also contain reasonable procedures to ensure 
priority is given to taking action on applications for construction or 
modification under title I, parts C and D of the Act.
    (4) The permitting authority shall promptly provide notice to the 
applicant of whether the application is complete. Unless the permitting 
authority requests additional information or otherwise notifies the 
applicant of incompleteness within 60 days of receipt of an application, 
the application shall be deemed complete. For modifications processed 
through minor permit modification procedures, such as those in 
paragraphs (e) (2) and (3) of this section, the State program need not 
require a completeness determination.
    (5) The permitting authority shall provide a statement that sets 
forth the legal and factual basis for the draft permit conditions 
(including references to the applicable statutory or regulatory 
provisions). The permitting authority shall send this statement to EPA 
and to any other person who requests it.
    (6) The submittal of a complete application shall not affect the 
requirement that any source have a preconstruction permit under title I 
of the Act.
    (b) Requirement for a permit. Except as provided in the following 
sentence, Sec. 70.4(b)(12)(i), and paragraphs (e) (2)(v) and 
(3)(v) of this section, no part 70 source may operate after the time 
that it is required to submit a timely and complete application under an 
approved permit program, except in compliance with a permit issued under 
a part 70 program. The program shall provide that, if a part 70 source 
submits a timely and complete application for permit issuance (including 
for renewal), the source's failure to have a part 70 permit is not a 
violation of this part until the permitting authority takes final action 
on the permit application, except as noted in this section. This 
protection shall cease to apply if, subsequent to the completeness 
determination made pursuant to paragraph (a)(4) of this section, and as 
required by Sec. 70.5(a)(2) of this part, the applicant fails 
to submit by the deadline specified in writing by the permitting 
authority any additional information identified as being needed to 
process the application.
    (c) Permit renewal and expiration. (1) The program shall provide 
that:
    (i) Permits being renewed are subject to the same procedural 
requirements, including those for public participation, affected State 
and EPA review, that apply to initial permit issuance; and
    (ii) Permit expiration terminates the source's right to operate 
unless a timely and complete renewal application has been submitted 
consistent with paragraph (b) of this section and Sec. 
70.5(a)(1)(iii) of this part.
    (2) If the permitting authority fails to act in a timely way on a 
permit renewal, EPA may invoke its authority under section 505(e) of the 
Act to terminate or revoke and reissue the permit.
    (d) Administrative permit amendments. (1) An 
``administrative permit amendment'' is a 
permit revision that:
    (i) Corrects typographical errors;
    (ii) Identifies a change in the name, address, or phone number of 
any person identified in the permit, or provides a

[[Page 229]]

similar minor administrative change at the source;
    (iii) Requires more frequent monitoring or reporting by the 
permittee;
    (iv) Allows for a change in ownership or operational control of a 
source where the permitting authority determines that no other change in 
the permit is necessary, provided that a written agreement containing a 
specific date for transfer of permit responsibility, coverage, and 
liability between the current and new permittee has been submitted to 
the permitting authority;
    (v) Incorporates into the part 70 permit the requirements from 
pre[chyph]con[chyph]struc[chyph]tion review permits authorized under an 
EPA-approved program, provided that such a program meets procedural 
requirements substantially equivalent to the requirements of 
Sec.Sec. 70.7 and 70.8 of this part that would be 
applicable to the change if it were subject to review as a permit 
modification, and compliance requirements substantially equivalent to 
those contained in Sec. 70.6 of this part; or
    (vi) Incorporates any other type of change which the Administrator 
has determined as part of the approved part 70 program to be similar to 
those in paragraphs (d)(1) (i) through (iv) of this section.
    (2) Administrative permit amendments for purposes of the acid rain 
portion of the permit shall be governed by regulations promulgated under 
title IV of the Act.
    (3) Administrative permit amendment procedures. An administrative 
permit amendment may be made by the permitting authority consistent with 
the following:
    (i) The permitting authority shall take no more than 60 days from 
receipt of a request for an administrative permit amendment to take 
final action on such request, and may incorporate such changes without 
providing notice to the public or affected States provided that it 
designates any such permit revisions as having been made pursuant to 
this paragraph.
    (ii) The permitting authority shall submit a copy of the revised 
permit to the Administrator.
    (iii) The source may implement the changes addressed in the request 
for an administrative amendment immediately upon submittal of the 
request.
    (4) The permitting authority may, upon taking final action granting 
a request for an administrative permit amendment, allow coverage by the 
permit shield in Sec. 70.6(f) for administrative permit 
amendments made pursuant to paragraph (d)(1)(v) of this section which 
meet the relevant requirements of Sec.Sec. 70.6, 
70.7, and 70.8 for significant permit modifications.
    (e) Permit modification. A permit modification is any revision to a 
part 70 permit that cannot be accomplished under the program's 
provisions for administrative permit amendments under paragraph (d) of 
this section. A permit modification for purposes of the acid rain 
portion of the permit shall be governed by regulations promulgated under 
title IV of the Act.
    (1) Program description. The State shall provide adequate, 
streamlined, and reasonable procedures for expeditiously processing 
permit modifications. The State may meet this obligation by adopting the 
procedures set forth below or ones substantially equivalent. The State 
may also develop different procedures for different types of 
modifications depending on the significance and complexity of the 
requested modification, but EPA will not approve a part 70 program that 
has modification procedures that provide for less permitting authority, 
EPA, or affected State review or public participation than is provided 
for in this part.
    (2) Minor permit modification procedures - (i) 
Criteria. (A) Minor permit modification procedures may be used only for 
those permit modifications that:
    (1) Do not violate any applicable requirement;
    (2) Do not involve significant changes to existing monitoring, 
reporting, or recordkeeping requirements in the permit;
    (3) Do not require or change a case-by-case determination of an 
emission limitation or other standard, or a source-specific 
determination for temporary sources of ambient impacts, or a visibility 
or increment analysis;
    (4) Do not seek to establish or change a permit term or condition 
for which there is no corresponding underlying

[[Page 230]]

applicable requirement and that the source has assumed to avoid an 
applicable requirement to which the source would otherwise be subject. 
Such terms and conditions include:
    (A) A federally enforceable emissions cap assumed to avoid 
classification as a modification under any provision of title I; and
    (B) An alternative emissions limit approved pursuant to regulations 
promulgated under section 112(i)(5) of the Act;
    (5) Are not modifications under any provision of title I of the Act; 
and
    (6) Are not required by the State program to be processed as a 
significant modification.
    (B) Notwithstanding paragraphs (e)(2)(i)(A) and (e)(3)(i) of this 
section, minor permit modification procedures may be used for permit 
modifications involving the use of economic incentives, marketable 
permits, emissions trading, and other similar approaches, to the extent 
that such minor permit modification procedures are explicitly provided 
for in an applicable implementation plan or in applicable requirements 
promulgated by EPA.
    (ii) Application. An application requesting the use of minor permit 
modification procedures shall meet the requirements of Sec. 
70.5(c) of this part and shall include the following:
    (A) A description of the change, the emissions resulting from the 
change, and any new applicable requirements that will apply if the 
change occurs;
    (B) The source's suggested draft permit;
    (C) Certification by a responsible official, consistent with 
Sec. 70.5(d), that the proposed modification meets the 
criteria for use of minor permit modification procedures and a request 
that such procedures be used; and
    (D) Completed forms for the permitting authority to use to notify 
the Administrator and affected States as required under Sec. 
70.8.
    (iii) EPA and affected State notification. Within 5 working days of 
receipt of a complete permit modification application, the permitting 
authority shall meet its obligation under Sec. 70.8 (a)(1) and 
(b)(1) to notify the Administrator and affected States of the requested 
permit modification. The permitting authority promptly shall send any 
notice required under Sec. 70.8(b)(2) to the Administrator.
    (iv) Timetable for issuance. The permitting authority may not issue 
a final permit modification until after EPA's 45-day review period or 
until EPA has notified the permitting authority that EPA will not object 
to issuance of the permit modification, whichever is first, although the 
permitting authority can approve the permit modification prior to that 
time. Within 90 days of the permitting authority's receipt of an 
application under minor permit modification procedures or 15 days after 
the end of the Administrator's 45-day review period under Sec. 
70.8(c), whichever is later, the permitting authority shall:
    (A) Issue the permit modification as proposed;
    (B) Deny the permit modification application;
    (C) Determine that the requested modification does not meet the 
minor permit modification criteria and should be reviewed under the 
significant modification procedures; or
    (D) Revise the draft permit modification and transmit to the 
Administrator the new proposed permit modification as required by 
Sec. 70.8(a) of this part.
    (v) Source's ability to make change. The State program may allow the 
source to make the change proposed in its minor permit modification 
application immediately after it files such application. After the 
source makes the change allowed by the preceding sentence, and until the 
permitting authority takes any of the actions specified in paragraphs 
(e)(2)(v) (A) through (C) of this section, the source must comply with 
both the applicable requirements governing the change and the proposed 
permit terms and conditions. During this time period, the source need 
not comply with the existing permit terms and conditions it seeks to 
modify. However, if the source fails to comply with its proposed permit 
terms and conditions during this time period, the existing permit terms 
and conditions it seeks to modify may be enforced against it.
    (vi) Permit shield. The permit shield under Sec. 70.6(f) 
of this part may not extend to minor permit modifications.

[[Page 231]]

    (3) Group processing of minor permit modifications. Consistent with 
this paragraph, the permitting authority may modify the procedure 
outlined in paragraph (e)(2) of this section to process groups of a 
source's applications for certain modifications eligible for minor 
permit modification processing.
    (i) Criteria. Group processing of modifications may be used only for 
those permit modifications:
    (A) That meet the criteria for minor permit modification procedures 
under paragraph (e)(2)(i)(A) of this section; and
    (B) That collectively are below the threshold level approved by the 
Administrator as part of the approved program. Unless the State sets an 
alternative threshold consistent with the criteria set forth in 
paragraphs (e)(3)(i)(B) (1) and (2) of this section, this threshold 
shall be 10 percent of the emissions allowed by the permit for the 
emissions unit for which the change is requested, 20 percent of the 
applicable definition of major source in Sec. 70.2 of this 
part, or 5 tons per year, whichever is least. In establishing any 
alternative threshold, the State shall consider:
    (1) Whether group processing of amounts below the threshold levels 
reasonably alleviates severe administrative burdens that would be 
imposed by immediate permit modification review, and
    (2) Whether individual processing of changes below the threshold 
levels would result in trivial environmental benefits.
    (ii) Application. An application requesting the use of group 
processing procedures shall meet the requirements of Sec. 
70.5(c) of this part and shall include the following:
    (A) A description of the change, the emissions resulting from the 
change, and any new applicable requirements that will apply if the 
change occurs.
    (B) The source's suggested draft permit.
    (C) Certification by a responsible official, consistent with 
Sec. 70.5(d) of this part, that the proposed modification 
meets the criteria for use of group processing procedures and a request 
that such procedures be used.
    (D) A list of the source's other pending applications awaiting group 
processing, and a determination of whether the requested modification, 
aggregated with these other applications, equals or exceeds the 
threshold set under paragraph (e)(3)(i)(B) of this section.
    (E) Certification, consistent with Sec. 70.5(d) of this 
part, that the source has notified EPA of the proposed modification. 
Such notification need only contain a brief description of the requested 
modification.
    (F) Completed forms for the permitting authority to use to notify 
the Administrator and affected States as required under Sec. 
70.8 of this part.
    (iii) EPA and affected State notification. On a quarterly basis or 
within 5 business days of receipt of an application demonstrating that 
the aggregate of a source's pending applications equals or exceeds the 
threshold level set under paragraph (e)(3)(i)(B) of this section, 
whichever is earlier, the permitting authority promptly shall meet its 
obligations under Sec.Sec. 70.8 (a)(1) and (b)(1) to 
notify the Administrator and affected States of the requested permit 
modifications. The permitting authority shall send any notice required 
under Sec. 70.8(b)(2) of this part to the Administrator.
    (iv) Timetable for issuance. The provisions of paragraph (e)(2)(iv) 
of this section shall apply to modifications eligible for group 
processing, except that the permitting authority shall take one of the 
actions specified in paragraphs (e)(2)(iv) (A) through (D) of this 
section within 180 days of receipt of the application or 15 days after 
the end of the Administrator's 45-day review period under Sec. 
70.8(c) of this part, whichever is later.
    (v) Source's ability to make change. The provisions of paragraph 
(e)(2)(v) of this section shall apply to modifications eligible for 
group processing.
    (vi) Permit shield. The provisions of paragraph (e)(2)(vi) of this 
section shall also apply to modifications eligible for group processing.
    (4) Significant modification procedures - (i) Criteria. 
Significant modification procedures shall be used for applications 
requesting permit modifications that do not qualify as minor permit 
modifications or as administrative amendments. The State

[[Page 232]]

program shall contain criteria for determining whether a change is 
significant. At a minimum, every significant change in existing 
monitoring permit terms or conditions and every relaxation of reporting 
or recordkeeping permit terms or conditions shall be considered 
significant. Nothing herein shall be construed to preclude the permittee 
from making changes consistent with this part that would render existing 
permit compliance terms and conditions irrelevant.
    (ii) The State program shall provide that significant permit 
modifications shall meet all requirements of this part, including those 
for applications, public participation, review by affected States, and 
review by EPA, as they apply to permit issuance and permit renewal. The 
permitting authority shall design and implement this review process to 
complete review on the majority of significant permit modifications 
within 9 months after receipt of a complete application.
    (f) Reopening for cause. (1) Each issued permit shall include 
provisions specifying the conditions under which the permit will be 
reopened prior to the expiration of the permit. A permit shall be 
reopened and revised under any of the following circumstances:
    (i) Additional applicable requirements under the Act become 
applicable to a major part 70 source with a remaining permit term of 3 
or more years. Such a reopening shall be completed not later than 18 
months after promulgation of the applicable requirement. No such 
reopening is required if the effective date of the requirement is later 
than the date on which the permit is due to expire, unless the original 
permit or any of its terms and conditions has been extended pursuant to 
Sec. 70.4(b)(10) (i) or (ii) of this part.
    (ii) Additional requirements (including excess emissions 
requirements) become applicable to an affected source under the acid 
rain program. Upon approval by the Administrator, excess emissions 
offset plans shall be deemed to be incorporated into the permit.
    (iii) The permitting authority or EPA determines that the permit 
contains a material mistake or that inaccurate statements were made in 
establishing the emissions standards or other terms or conditions of the 
permit.
    (iv) The Administrator or the permitting authority determines that 
the permit must be revised or revoked to assure compliance with the 
applicable requirements.
    (2) Proceedings to reopen and issue a permit shall follow the same 
procedures as apply to initial permit issuance and shall affect only 
those parts of the permit for which cause to reopen exists. Such 
reopening shall be made as expeditiously as practicable.
    (3) Reopenings under paragraph (f)(1) of this section shall not be 
initiated before a notice of such intent is provided to the part 70 
source by the permitting authority at least 30 days in advance of the 
date that the permit is to be reopened, except that the permitting 
authority may provide a shorter time period in the case of an emergency.
    (g) Reopenings for cause by EPA. (1) If the Administrator finds that 
cause exists to terminate, modify, or revoke and reissue a permit 
pursuant to paragraph (f) of this section, the Administrator will notify 
the permitting authority and the permittee of such finding in writing.
    (2) The permitting authority shall, within 90 days after receipt of 
such notification, forward to EPA a proposed determination of 
termination, modification, or revocation and reissuance, as appropriate. 
The Administrator may extend this 90-day period for an additional 90 
days if he finds that a new or revised permit application is necessary 
or that the permitting authority must require the permittee to submit 
additional information.
    (3) The Administrator will review the proposed determination from 
the permitting authority within 90 days of receipt.
    (4) The permitting authority shall have 90 days from receipt of an 
EPA objection to resolve any objection that EPA makes and to terminate, 
modify, or revoke and reissue the permit in accordance with the 
Administrator's objection.
    (5) If the permitting authority fails to submit a proposed 
determination pursuant to paragraph (g)(2) of this section or fails to 
resolve any objection

[[Page 233]]

pursuant to paragraph (g)(4) of this section, the Administrator will 
terminate, modify, or revoke and reissue the permit after taking the 
following actions:
    (i) Providing at least 30 days' notice to the 
permittee in writing of the reasons for any such action. This notice may 
be given during the procedures in paragraphs (g) (1) through (4) of this 
section.
    (ii) Providing the permittee an opportunity for comment on the 
Administrator's proposed action and an opportunity for a hearing.
    (h) Public participation. Except for modifications qualifying for 
minor permit modification procedures, all permit proceedings, including 
initial permit issuance, significant modifications, and renewals, shall 
provide adequate procedures for public notice including offering an 
opportunity for public comment and a hearing on the draft permit. These 
procedures shall include the following:
    (1) Notice shall be given: by publication in a newspaper of general 
circulation in the area where the source is located or in a State 
publication designed to give general public notice; to persons on a 
mailing list developed by the permitting authority, including those who 
request in writing to be on the list; and by other means if necessary to 
assure adequate notice to the affected public;
    (2) The notice shall identify the affected facility; the name and 
address of the permittee; the name and address of the permitting 
authority processing the permit; the activity or activities involved in 
the permit action; the emissions change involved in any permit 
modification; the name, address, and telephone number of a person from 
whom interested persons may obtain additional information, including 
copies of the permit draft, the application, all relevant supporting 
materials, including those set forth in Sec. 70.4(b)(3)(viii) 
of this part, and all other materials available to the permitting 
authority that are relevant to the permit decision; a brief description 
of the comment procedures required by this part; and the time and place 
of any hearing that may be held, including a statement of procedures to 
request a hearing (unless a hearing has already been scheduled);
    (3) The permitting authority shall provide such notice and 
opportunity for participation by affected States as is provided for by 
Sec. 70.8 of this part;
    (4) Timing. The permitting authority shall provide at least 30 days 
for public comment and shall give notice of any public hearing at least 
30 days in advance of the hearing.
    (5) The permitting authority shall keep a record of the commenters 
and also of the issues raised during the public participation process so 
that the Administrator may fulfill his obligation under section 
505(b)(2) of the Act to determine whether a citizen petition may be 
granted, and such records shall be available to the public.



Sec. 70.8  Permit review by EPA and affected States.

    (a) Transmission of information to the Administrator. (1) The permit 
program shall require that the permitting authority provide to the 
Administrator a copy of each permit application (including any 
application for permit modification), each proposed permit, and each 
final part 70 permit. The applicant may be required by the permitting 
authority to provide a copy of the permit application (including the 
compliance plan) directly to the Administrator. Upon agreement with the 
Administrator, the permitting authority may submit to the Administrator 
a permit application summary form and any relevant portion of the permit 
application and compliance plan, in place of the complete permit 
application and compliance plan. To the extent practicable, the 
preceding information shall be provided in computer-readable format 
compatible with EPA's national database management system.
    (2) The Administrator may waive the requirements of paragraphs 
(a)(1) and (b)(1) of this section for any category of sources (including 
any class, type, or size within such category) other than major sources 
according to the following:
    (i) By regulation for a category of sources nationwide, or

[[Page 234]]

    (ii) At the time of approval of a State program for a category of 
sources covered by an individual permitting program.
    (3) Each State permitting authority shall keep for 5 years such 
records and submit to the Administrator such information as the 
Administrator may reasonably require to ascertain whether the State 
program complies with the requirements of the Act or of this part.
    (b) Review by affected States. (1) The permit program shall provide 
that the permitting authority give notice of each draft permit to any 
affected State on or before the time that the permitting authority 
provides this notice to the public under Sec. 70.7(h) of this 
part, except to the extent Sec. 70.7(e) (2) or (3) of this 
part requires the timing of the notice to be different.
    (2) The permit program shall provide that the permitting authority, 
as part of the submittal of the proposed permit to the Administrator [or 
as soon as possible after the submittal for minor permit modification 
procedures allowed under Sec. 70.7(e) (2) or (3) of this 
part], shall notify the Administrator and any affected State in writing 
of any refusal by the permitting authority to accept all recommendations 
for the proposed permit that the affected State submitted during the 
public or affected State review period. The notice shall include the 
permitting authority's reasons for not accepting any such 
recommendation. The permitting authority is not required to accept 
recommendations that are not based on applicable requirements or the 
requirements of this part.
    (c) EPA objection. (1) The Administrator will object to the issuance 
of any proposed permit determined by the Administrator not to be in 
compliance with applicable requirements or requirements under this part. 
No permit for which an application must be transmitted to the 
Administrator under paragraph (a) of this section shall be issued if the 
Administrator objects to its issuance in writing within 45 days of 
receipt of the proposed permit and all necessary supporting information.
    (2) Any EPA objection under paragraph (c)(1) of this section shall 
include a statement of the Administrator's reasons for objection and a 
description of the terms and conditions that the permit must include to 
respond to the objections. The Administrator will provide the permit 
applicant a copy of the objection.
    (3) Failure of the permitting authority to do any of the following 
also shall constitute grounds for an objection:
    (i) Comply with paragraphs (a) or (b) of this section;
    (ii) Submit any information necessary to review adequately the 
proposed permit; or
    (iii) Process the permit under the procedures approved to meet 
Sec. 70.7(h) of this part except for minor permit 
modifications.
    (4) If the permitting authority fails, within 90 days after the date 
of an objection under paragraph (c)(1) of this section, to revise and 
submit a proposed permit in response to the objection, the Administrator 
will issue or deny the permit in accordance with the requirements of the 
Federal program promulgated under title V of this Act.
    (d) Public petitions to the Administrator. The program shall provide 
that, if the Administrator does not object in writing under paragraph 
(c) of this section, any person may petition the Administrator within 60 
days after the expiration of the Administrator's 45-day review period to 
make such objection. Any such petition shall be based only on objections 
to the permit that were raised with reasonable specificity during the 
public comment period provided for in Sec. 70.7(h) of this 
part, unless the petitioner demonstrates that it was impracticable to 
raise such objections within such period, or unless the grounds for such 
objection arose after such period. If the Administrator objects to the 
permit as a result of a petition filed under this paragraph, the 
permitting authority shall not issue the permit until EPA's objection 
has been resolved, except that a petition for review does not stay the 
effectiveness of a permit or its requirements if the permit was issued 
after the end of the 45-day review period and prior to an EPA objection. 
If the permitting authority has issued a permit prior to receipt of an 
EPA objection under this paragraph, the Administrator will modify, 
terminate, or revoke such permit, and shall do so consistent with the

[[Page 235]]

procedures in Sec. 70.7(g) (4) or (5) (i) and (ii) of this 
part except in unusual circumstances, and the permitting authority may 
thereafter issue only a revised permit that satisfies EPA's objection. 
In any case, the source will not be in violation of the requirement to 
have submitted a timely and complete application.
    (e) Prohibition on default issuance. Consistent with Sec. 
70.4(b)(3)(ix) of this part, for the purposes of Federal law and title V 
of the Act, no State program may provide that a part 70 permit 
(including a permit renewal or modification) will issue until affected 
States and EPA have had an opportunity to review the proposed permit as 
required under this section. When the program is submitted for EPA 
review, the State Attorney General or independent legal counsel shall 
certify that no applicable provision of State law requires that a part 
70 permit or renewal be issued after a certain time if the permitting 
authority has failed to take action on the application (or includes any 
other similar provision providing for default issuance of a permit), 
unless EPA has waived such review for EPA and affected States.



Sec. 70.9  Fee determination and certification.

    (a) Fee Requirement. The State program shall require that the owners 
or operators of part 70 sources pay annual fees, or the equivalent over 
some other period, that are sufficient to cover the permit program costs 
and shall ensure that any fee required by this section will be used 
solely for permit program costs.
    (b) Fee schedule adequacy. (1) The State program shall establish a 
fee schedule that results in the collection and retention of revenues 
sufficient to cover the permit program costs. These costs include, but 
are not limited to, the costs of the following activities as they relate 
to the operating permit program for stationary sources:
    (i) Preparing generally applicable regulations or guidance regarding 
the permit program or its implementation or enforcement;
    (ii) Reviewing and acting on any application for a permit, permit 
revision, or permit renewal, including the development of an applicable 
requirement as part of the processing of a permit, or permit revision or 
renewal;
    (iii) General administrative costs of running the permit program, 
including the supporting and tracking of permit applications, compliance 
certification, and related data entry;
    (iv) Implementing and enforcing the terms of any part 70 permit (not 
including any court costs or other costs associated with an enforcement 
action), including adequate resources to determine which sources are 
subject to the program;
    (v) Emissions and ambient monitoring;
    (vi) Modeling, analyses, or demonstrations;
    (vii) Preparing inventories and tracking emissions; and
    (viii) Providing direct and indirect support to sources under the 
Small Business Stationary Source Technical and Environmental Compliance 
Assistance Program contained in section 507 of the Act in determining 
and meeting their obligations under this part.
    (2)(i) The Administrator will presume that the fee schedule meets 
the requirements of paragraph (b)(1) of this section if it would result 
in the collection and retention of an amount not less than $25 per year 
[as adjusted pursuant to the criteria set forth in paragraph (b)(2)(iv) 
of this section] times the total tons of the actual emissions of each 
regulated pollutant (for presumptive fee calculation) emitted from part 
70 sources.
    (ii) The State may exclude from such calculation:
    (A) The actual emissions of sources for which no fee is required 
under paragraph (b)(4) of this section;
    (B) The amount of a part 70 source's actual emissions of each 
regulated pollutant (for presumptive fee calculation) that the source 
emits in excess of four thousand (4,000) tpy;
    (C) A part 70 source's actual emissions of any regulated pollutant 
(for presumptive fee calculation), the emissions of which are already 
included in the minimum fees calculation; or
    (D) The insignificant quantities of actual emissions not required in 
a permit application pursuant to Sec. 70.5(c).

[[Page 236]]

    (iii) ``Actual emissions'' means the 
actual rate of emissions in tons per year of any regulated pollutant 
(for presumptive fee calculation) emitted from a part 70 source over the 
preceding calendar year or any other period determined by the permitting 
authority to be representative of normal source operation and consistent 
with the fee schedule approved pursuant to this section. Actual 
emissions shall be calculated using the unit's actual operating hours, 
production rates, and in-place control equipment, types of materials 
processed, stored, or combusted during the preceding calendar year or 
such other time period established by the permitting authority pursuant 
to the preceding sentence.
    (iv) The program shall provide that the $25 per ton per year used to 
calculate the presumptive minimum amount to be collected by the fee 
schedule, as described in paragraph (b)(2)(i) of this section, shall be 
increased each year by the percentage, if any, by which the Consumer 
Price Index for the most recent calendar year ending before the 
beginning of such year exceeds the Consumer Price Index for the calendar 
year 1989.
    (A) The Consumer Price Index for any calendar year is the average of 
the Consumer Price Index for all-urban consumers published by the 
Department of Labor, as of the close of the 12-month period ending on 
August 31 of each calendar year.
    (B) The revision of the Consumer Price Index which is most 
consistent with the Consumer Price Index for the calendar year 1989 
shall be used.
    (3) The State program's fee schedule may include emissions fees, 
application fees, service-based fees or other types of fees, or any 
combination thereof, to meet the requirements of paragraph (b)(1) or 
(b)(2) of this section. Nothing in the provisions of this section shall 
require a permitting authority to calculate fees on any particular basis 
or in the same manner for all part 70 sources, all classes or categories 
of part 70 sources, or all regulated air pollutants, provided that the 
permitting authority collects a total amount of fees sufficient to meet 
the program support requirements of paragraph (b)(1) of this section.
    (4) Notwithstanding any other provision of this section, during the 
years 1995 through 1999 inclusive, no fee for purposes of title V shall 
be required to be paid with respect to emissions from any affected unit 
under section 404 of the Act.
    (5) The State shall provide a detailed accounting that its fee 
schedule meets the requirements of paragraph (b)(1) of this section if:
    (i) The State sets a fee schedule that would result in the 
collection and retention of an amount less than that presumed to be 
adequate under paragraph (b)(2) of this section; or
    (ii) The Administrator determines, based on comments rebutting the 
presumption in paragraph (b)(2) of this section or on his own 
initiative, that there are serious questions regarding whether the fee 
schedule is sufficient to cover the permit program costs.
    (c) Fee demonstration. The permitting authority shall provide a 
demonstration that the fee schedule selected will result in the 
collection and retention of fees in an amount sufficient to meet the 
requirements of this section.
    (d) Use of Required Fee Revenue. The Administrator will not approve 
a demonstration as meeting the requirements of this section, unless it 
contains an initial accounting (and periodic updates as required by the 
Administrator) of how required fee revenues are used solely to cover the 
costs of meeting the various functions of the permitting program.



Sec. 70.10  Federal oversight and sanctions.

    (a) Failure to submit an approvable program. (1) If a State fails to 
submit a fully-approvable whole part 70 program, or a required revision 
thereto, in conformance with the provisions of Sec. 70.4, or 
if an interim approval expires and the Administrator has not approved a 
whole part 70 program:
    (i) At any time the Administrator may apply any one of the sanctions 
specified in section 179(b) of the Act; and
    (ii) Eighteen months after the date required for submittal or the 
date of disapproval by the Administrator, the Administrator will apply 
such sanctions in the same manner and with the

[[Page 237]]

same conditions as are applicable in the case of a determination, 
disapproval, or finding under section 179(a) of the Act.
    (2) If full approval of a whole part 70 program has not taken place 
within 2 years after the date required for such submission, the 
Administrator will promulgate, administer, and enforce a whole program 
or a partial program as appropriate for such State.
    (b) State failure to administer or enforce. Any State program 
approved by the Administrator shall at all times be conducted in 
accordance with the requirements of this part and of any agreement 
between the State and the Administrator concerning operation of the 
program.
    (1) Whenever the Administrator makes a determination that a 
permitting authority is not adequately administering or enforcing a part 
70 program, or any portion thereof, the Administrator will notify the 
permitting authority of the determination and the reasons therefore. The 
Administrator will publish such notice in the Federal Register.
    (2) If, 90 days after issuing the notice under paragraph (c)(1) of 
this section, the permitting authority fails to take significant action 
to assure adequate administration and enforcement of the program, the 
Administrator may take one or more of the following actions:
    (i) Withdraw approval of the program or portion thereof using 
procedures consistent with Sec. 70.4(e) of this part;
    (ii) Apply any of the sanctions specified in section 179(b) of the 
Act;
    (iii) Promulgate, administer, or enforce a Federal program under 
title V of the Act.
    (3) Whenever the Administrator has made the finding and issued the 
notice under paragraph (c)(1) of this section, the Administrator will 
apply the sanctions under section 179(b) of the Act 18 months after that 
notice. These sanctions will be applied in the same manner and subject 
to the same deadlines and other conditions as are applicable in the case 
of a determination, disapproval, or finding under section 179(a) of the 
Act.
    (4) Whenever the Administrator has made the finding and issued the 
notice under paragraph (c)(1) of this section, the Administrator will, 
unless the State has corrected such deficiency within 18 months after 
the date of such finding, promulgate, administer, and enforce, a whole 
or partial program 2 years after the date of such finding.
    (5) Nothing in this section shall limit the Administrator's 
authority to take any enforcement action against a source for violations 
of the Act or of a permit issued under rules adopted pursuant to this 
section in a State that has been delegated responsibility by EPA to 
implement a Federal program promulgated under title V of the Act.
    (6) Where a whole State program consists of an aggregate of partial 
programs, and one or more partial programs fails to be fully approved or 
implemented, the Administrator may apply sanctions only in those areas 
for which the State failed to submit or implement an approvable program.
    (c) Criteria for withdrawal of State programs. (1) The Administrator 
may, in accordance with the procedures of paragraph (c) of this section, 
withdraw program approval in whole or in part whenever the approved 
program no longer complies with the requirements of this part, and the 
permitting authority fails to take corrective action. Such 
circumstances, in whole or in part, include any of the following:
    (i) Where the permitting authority's legal authority no longer meets 
the requirements of this part, including the following:
    (A) The permitting authority fails to promulgate or enact new 
authorities when necessary; or
    (B) The State legislature or a court strikes down or limits State 
authorities to administer or enforce the State program.
    (ii) Where the operation of the State program fails to comply with 
the requirements of this part, including the following:
    (A) Failure to exercise control over activities required to be 
regulated under this part, including failure to issue permits;
    (B) Repeated issuance of permits that do not conform to the 
requirements of this part;
    (C) Failure to comply with the public participation requirements of 
Sec. 70.7(h) of this part;

[[Page 238]]

    (D) Failure to collect, retain, or allocate fee revenue consistent 
with Sec. 70.9 of this part; or
    (E) Failure in a timely way to act on any applications for permits 
including renewals and revisions.
    (iii) Where the State fails to enforce the part 70 program 
consistent with the requirements of this part, including the following:
    (A) Failure to act on violations of permits or other program 
requirements;
    (B) Failure to seek adequate enforcement penalties and fines and 
collect all assessed penalties and fines; or
    (C) Failure to inspect and monitor activities subject to regulation.
    (d) Federal collection of fees. If the Administrator determines that 
the fee provisions of a part 70 program do not meet the requirements of 
Sec. 70.9 of this part, or if the Administrator makes a 
determination under paragraph (c)(1) of this section that the permitting 
authority is not adequately administering or enforcing an approved fee 
program, the Administrator may, in addition to taking any other action 
authorized under title V of the Act, collect reasonable fees to cover 
the Administrator's costs of administering the provisions of the 
permitting program promulgated by the Administrator, without regard to 
the requirements of Sec. 70.9 of this part.



Sec. 70.11  Requirements for enforcement authority.

    All programs to be approved under this part must contain the 
following provisions:
    (a) Enforcement authority. Any agency administering a program shall 
have the following enforcement authority to address violations of 
program requirements by part 70 sources:
    (1) To restrain or enjoin immediately and effectively any person by 
order or by suit in court from engaging in any activity in violation of 
a permit that is presenting an imminent and substantial endangerment to 
the public health or welfare, or the environment.
    (2) To seek injunctive relief in court to enjoin any violation of 
any program requirement, including permit conditions, without the 
necessity of a prior revocation of the permit.
    (3) To assess or sue to recover in court civil penalties and to seek 
criminal remedies, including fines, according to the following:
    (i) Civil penalties shall be recoverable for the violation of any 
applicable requirement; any permit condition; any fee or filing 
requirement; any duty to allow or carry out inspection, entry or 
monitoring activities or, any regulation or orders issued by the 
permitting authority. These penalties shall be recoverable in a maximum 
amount of not less than $10,000 per day per violation. State law shall 
not include mental state as an element of proof for civil violations.
    (ii) Criminal fines shall be recoverable against any person who 
knowingly violates any applicable requirement; any permit condition; or 
any fee or filing requirement. These fines shall be recoverable in a 
maximum amount of not less than $10,000 per day per violation.
    (iii) Criminal fines shall be recoverable against any person who 
knowingly makes any false material statement, representation or 
certification in any form, in any notice or report required by a permit, 
or who knowingly renders inaccurate any required monitoring device or 
method. These fines shall be recoverable in a maximum amount of not less 
than $10,000 per day per violation.
    (b) Burden of proof. The burden of proof and degree of knowledge or 
intent required under State law for establishing violations under 
paragraph (a)(3) of this section shall be no greater than the burden of 
proof or degree of knowledge or intent required under the Act.
    (c) Appropriateness of penalties and fines. A civil penalty or 
criminal fine assessed, sought, or agreed upon by the permitting 
authority under paragraph (a)(3) of this section shall be appropriate to 
the violation.

Appendix A to Part 70 - Approval Status of State and Local 
                       Operating Permits Programs

    This appendix provides information on the approval status of State 
and Local operating Permit Programs. An approved State part 70 program 
applies to all part 70 sources, as defined in that approved program, 
within such State, except for any source of air pollution

[[Page 239]]

over which a federally recognized Indian Tribe has jurisdiction.

                                 Alabama

    (a) Alabama Department of Environmental Management:
    (1) Submitted on December 15, 1993, and supplemented on March 3, 
1994; March 18, 1994; June 5, 1995; July 14, 1995; and August 28, 1995; 
interim approval effective on December 15, 1995; interim approval 
expires on December 1, 2001.
    (2) Revisions submitted on July 19, 1996; April 9, 1997; August 4, 
1999; January 10, 2000; and May 11, 2001. The rule revisions contained 
in the July 19, 1996; January 10, 2000; and May 11, 2001 submittals 
adequately addressed the conditions of the interim approval which 
expires on December 1, 2001. The State is hereby granted final full 
approval effective on November 28, 2001.
    (b) City of Huntsville Division of Natural Resources:
    (1) Submitted on November 15, 1993, and supplemented on July 20, 
1995; interim approval effective on December 15, 1995; interim approval 
expires on December 1, 2001.
    (2) Revisions submitted on March 21, 1997; July 21, 1999; December 
4, 2000; February 22, 2001; April 9, 2001; and September 18, 2001. The 
rule revisions contained in the March 21, 1997; April 9, 2001; and 
September 18, 2001 submittals adequately addressed the conditions of the 
interim approval which expires on December 1, 2001. The City is hereby 
granted final full approval effective on November 28, 2001.
    (c) Jefferson County Department of Health:
    (1) Submitted on December 14, 1993, and supplemented on July 14, 
1995; interim approval effective on December 15, 1995; interim approval 
expires on December 1, 2001.
    (2) Revisions submitted on February 5, 1998; September 20, 1999; 
August 8, 2000; March 30, 2001; May 18, 2001; and September 11, 2001. 
The rule revisions contained in the August 8, 2000; May 18, 2001; and 
September 11, 2001 submittals adequately addressed the conditions of the 
interim approval which expires on December 1, 2001. The County is hereby 
granted final full approval effective on November 28, 2001.

                                 Alaska

    (a) Alaska Department of Environmental Conservation: submitted on 
May 31, 1995, as supplemented by submittals on August 16, 1995, February 
6, 1996, February 27, 1996, July 5, 1996, August 2, 1996, and October 
17, 1996; interim approval effective on December 5, 1996; revisions 
submitted on June 5, 1996, October 3, 1996, August 25, 1998, and May 24, 
1999; full approval effective on November 30, 2001.
    (b) (Reserved)

                                 Arizona

    (a) Arizona Department of Environmental Quality:
    (1) Submitted on November 15, 1993 and amended on March 14, 1994; 
May 17, 1994; March 20, 1995; May 4, 1995; July 22, 1996; and August 12, 
1996; interim approval effective on November 29, 1996; interim approval 
expires December 1, 2001.
    (2) Revisions submitted on August 11, 1998, May 9, 2001 and 
September 7, 2001. Full approval is effective on November 30, 2001.
    (b) Maricopa County Environmental Services Department:
    (1) Submitted on November 15, 1993 and amended on December 15, 1993; 
January 13, 1994; March 9, 1994; and March 21, 1995; July 22, 1996; and 
August 12, 1996; interim approval effective on November 29, 1996; 
interim approval expires December 1, 2001.
    (2) Revisions submitted on September 7, 2001. Full approval is 
effective on November 30, 2001.
    (c) Pima County Department of Environmental Quality:
    (1) Submitted on November 15, 1993 and amended on December 15, 1993; 
January 27, 1994; April 6, 1994; April 8, 1994; August 14, 1995; July 
22, 1996; August 12, 1996; interim approval effective on November 29, 
1996; interim approval expires December 1, 2001.
    (2) Revisions submitted on January 14, 1997; February 26, 1997; July 
17, 1997; July 25, 1997; November 7, 1997; approval effective October 
23, 1998; interim approval expires December 1, 2001.
    (3) Revisions submitted on May 30, 1998 and November 9, 2001. Full 
approval is effective on November 30, 2001.
    (d) Pinal County Air Quality Control District:
    (1) submitted on November 15, 1993 and amended on August 16, 1994; 
August 15, 1995; July 22, 1996; and August 12, 1996; interim approval 
effective on November 29, 1996; interim approval expires December 1, 
2001.
    (2) revisions submitted on August 15, 1995; interim approval 
effective on December 30, 1996; interim approval expires December 1, 
2001.
    (3) revisions submitted on September 18, 2001. Full approval is 
effective on November 30, 2001.

                                Arkansas

    (a) The ADPCE submitted its Operating Permits program on November 9, 
1993, for approval. Interim approval is effective on October 10, 1995. 
Interim approval will expire December 1, 2001.
    (b) The Arkansas Department of Environmental Quality submitted 
program revisions on August 4, 2000. The rule revisions adequately 
addressed the conditions of the interim approval effective on October 
10, 1995, and which would expire on December 1, 2001.

[[Page 240]]

The State is hereby granted final full approval effective on December 
10, 2001.

                               California

    The following district programs were submitted by the California Air 
Resources Board on behalf of:
    (a) Amador County Air Pollution Control District (APCD):
    (1) Complete submittal received on September 30, 1994; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on April 10, 2001. Amador County Air 
Pollution Control District was granted final full approval effective on 
November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (b) Bay Area Air Quality Management District (AQMD):
    (1) Submitted on November 16, 1993, amended on October 27, 1994, and 
effective as an interim program on July 24, 1995. Revisions to interim 
program submitted on March 23, 1995, and effective on August 22, 1995, 
unless adverse or critical comments are received by July 24, 1995. 
Approval of interim program, including March 23, 1995, revisions, 
expires December 1, 2001.
    (2) Revisions were submitted on May 30, 2001. Bay Area Air Quality 
Management District was granted final full approval effective on 
November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (c) Butte County APCD:
    (1) Complete submittal received on December 16, 1993; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on May 17, 2001. Butte County APCD was 
granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (d) Calaveras County APCD:
    (1) Complete submittal received on October 31, 1994; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on July 27, 2001. Calaveras County APCD 
was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (e) Colusa County APCD:
    (1) Complete submittal received on February 24, 1994; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on August 22, 2001 and October 10, 
2001. Colusa County APCD was granted final full approval effective on 
November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (f) El Dorado County APCD:
    (1) Complete submittal received on November 16, 1993; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on August 16, 2001. El Dorado County 
APCD was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (g) Feather River AQMD:
    (1) Complete submittal received on December 27, 1993; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on May 22, 2001. Feather River AQMD was 
granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (h) Glenn County APCD:
    (1) Complete submittal received on December 27, 1993; interim 
approval effective on August 14, 1995; interim approval expires December 
1, 2001.
    (2) Revisions were submitted on September 13, 2001. Glenn County 
APCD was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (i) Great Basin Unified APCD:
    (1) Complete submittal received on January 12, 1994; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on May 18, 2001. Great Basin Unified 
APCD was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (j) Imperial County APCD:
    (1) Complete submittal received on March 24, 1994; interim approval 
effective on June 2, 1995; interim approval expires December 1, 2001.
    (2) Revisions were submitted on August 2, 2001. Imperial County APCD 
was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (k) Kern County APCD:

[[Page 241]]

    (1) Complete submittal received on November 16, 1993; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on May 24, 2001. Kern County APCD was 
granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (l) Lake County AQMD:
    (1) Complete submittal received on March 15, 1994; interim approval 
effective on August 14, 1995; interim approval expires December 1, 2001.
    (2) Revisions were submitted on June 1, 2001. Lake County AQMD was 
granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (m) Lassen County APCD:
    (1) Complete submittal received on January 12, 1994; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on August 2, 2001. Lassen County APCD 
was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (n) Mariposa County APCD:
    (1) Submitted on March 8, 1995; approval effective on February 5, 
1996 unless adverse or critical comments are received by January 8, 
1996. Interim approval expires on December 1, 2001.
    (2) Revisions were submitted on September 20, 2001. Mariposa County 
APCD was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (o) Mendocino County APCD:
    (1) Complete submittal received on December 27, 1993; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on April 13, 2001. Mendocino County 
APCD was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (p) Modoc County APCD:
    (1) Complete submittal received on December 27, 1993; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on September 12, 2001. Modoc County 
APCD was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (q) Mojave Desert AQMD:
    (1) Complete submittal received on March 10, 1995; interim approval 
effective on March 6, 1996; interim approval expires December 1, 2001.
    (2) Revisions were submitted on June 4, 2001 and July 11, 2001. 
Mojave Desert AQMD was granted final full approval effective on November 
30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (r) Monterey Bay Unified Air Pollution Control District:
    (1) Submitted on December 6, 1993, supplemented on February 2, 1994 
and April 7, 1994, and revised by the submittal made on October 13, 
1994; interim approval effective on November 6, 1995; interim approval 
expires December 1, 2001.
    (2) Revisions were submitted on May 9, 2001. Monterey Bay Unified 
Air Pollution Control District was granted final full approval effective 
on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (s) North Coast Unified AQMD:
    (1) Complete submittal received on February 24, 1994; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on May 24, 2001. North Coast Unified 
AQMD was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (t) Northern Sierra AQMD:
    (1) Complete submittal received on June 6, 1994; interim approval 
effective on June 2, 1995; interim approval expires December 1, 2001.
    (2) Revisions were submitted on May 24, 2001. Northern Sierra AQMD 
was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (u) Northern Sonoma County APCD:
    (1) Complete submittal received on January 12, 1994; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on May 21, 2001. Northern Sonoma APCD 
was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (v) Placer County APCD:

[[Page 242]]

    (1) Complete submittal received on December 27, 1993; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on May 4, 2001. Placer County APCD was 
granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (w) The Sacramento Metropolitan Air Quality Management District:
    (1) Complete submittal received on August 1, 1994; interim approval 
effective on September 5, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on June 1, 2001. The Sacramento 
Metropolitan Air Quality Management District was granted final full 
approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (x) San Diego County Air Pollution Control District:
    (1) Submitted on April 22, 1994 and amended on April 4, 1995 and 
October 10, 1995; approval effective on February 5, 1996, unless adverse 
or critical comments are received by January 8, 1996. Interim approval 
expires on December 1, 2001.
    (2) Revisions were submitted on June 4, 2001. The San Diego County 
Air Pollution Control District was granted final full approval effective 
on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (y) San Joaquin Valley Unified APCD:
    (1) Complete submittal received on July 5 and August 18, 1995; 
interim approval effective on May 24, 1996; interim approval expires May 
25, 1998. Interim approval expires on December 1, 2001.
    (2) Revisions were submitted on June 29, 2001. San Joaquin Valley 
Unified APCD was granted final full approval effective on November 30, 
2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (z) San Luis Obispo County APCD:
    (1) Complete submittal received on November 16, 1995; interim 
approval effective on December 1, 1995; interim approval expires 
December 1, 2001.
    (2) Revisions were submitted on May 18, 2001. San Luis Obispo County 
APCD was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (aa) Santa Barbara County APCD:
    (1) Submitted on November 15, 1993, as amended March 2, 1994, August 
8, 1994, December 8, 1994, June 15, 1995, and September 18, 1997; 
interim approval effective on December 1, 1995; interim approval expires 
on December 1, 2001.
    (2) Revisions were submitted on April 5, 2001. Santa Barbara County 
APCD was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (bb) Shasta County AQMD:
    (1) Complete submittal received on November 16, 1993; interim 
approval effective on August 14, 1995; interim approval expires December 
1, 2001.
    (2) Revisions were submitted on May 18, 2001. Shasta County AQMD was 
granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (cc) Siskiyou County APCD:
    (1) Complete submittal received on December 6, 1993; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on September 28, 2001. Siskiyou County 
APCD was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (dd) South Coast Air Quality Management District:
    (1) Submitted on December 27, 1993 and amended on March 6, 1995, 
April 11, 1995, September 26, 1995, April 24, 1996, May 6, 1996, May 23, 
1996, June 5, 1996 and July 29, 1996; approval effective on March 31, 
1997. Interim approval expires on December 1, 2001.
    (2) Revisions were submitted on August 2, 2001 and October 2, 2001. 
South Coast AQMD was granted final full approval effective on November 
30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (ee) Tehama County APCD:
    (1) Complete submittal received on December 6, 1993; interim 
approval effective on August 14, 1995; interim approval expires December 
1, 2001.
    (2) Revisions were submitted on June 4, 2001. Tehama County APCD was 
granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (ff) Tuolumne County APCD:
    (1) Complete submittal received on November 16, 1993; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on July 18, 2001. Tuolumne County APCD 
was granted

[[Page 243]]

final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (gg) Ventura County APCD:
    (1) Submitted on November 16, 1993, as amended December 6, 1993; 
interim approval effective on December 1, 1995; interim approval expires 
December 1, 2001.
    (2) Revisions were submitted on May 21, 2001. Ventura County APCD 
was granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.
    (hh) Yolo-Solano AQMD:
    (1) Complete submittal received on October 14, 1994; interim 
approval effective on June 2, 1995; interim approval expires December 1, 
2001.
    (2) Revisions were submitted on May 9, 2001. Yolo-Solano AQMD is 
hereby granted final full approval effective on November 30, 2001.
    (3) Approval is withdrawn for state-exempt major stationary 
agricultural sources, effective on November 14, 2002.

                                Colorado

    (a) Colorado Department Health-Air Pollution Control Division: 
submitted on November 5, 1993; effective on February 23, 1995; interim 
approval expires December 1, 2001.
    (b) The Colorado Department of Public Health and 
Environment - Air Pollution Control Division submitted an 
operating permits program on November 5, 1993; interim approval 
effective on February 23, 1995; revised June 24, 1997; full approval 
effective on October 16, 2000.

                               Connecticut

    (a) Department of Environmental Protection: submitted on September 
28, 1995; interim approval effective on April 23, 1997; revised program 
submitted on January 11, 2002; full approval effective May 31, 2002.
    (b) [Reserved]

                                Delaware

    (a) Department of Natural Resources and Environmental Control: 
submitted on November 15, 1993 and amended on November 22, 1993, 
February 9, 1994, May 15, 1995 and September 5, 1995; interim approval 
effective on January 3, 1996; interim approval expires December 1, 2001.
    (b) The Delaware Department of Natural Resources and Environmental 
Control submitted program amendments on November 14, 2000 and November 
20, 2000. The rule amendments contained in the November 14, 2000 and 
November 20, 2000 submittals adequately addressed the conditions of the 
interim approval effective on January 3, 1996. The State is hereby 
granted final full approval effective on November 19, 2001.

                          District of Columbia

    (a) Environmental Regulation Administration: submitted on January 
13, 1994 and March 11, 1994; interim approval effective on September 6, 
1995; interim approval expires December 1, 2001.
    (b) The District of Columbia Department of Health submitted 
operating permit program amendments on May 21, 2001, August 30, 2001, 
and September 26, 2001. The rule amendments contained in the May 21, 
2001, August 30, 2001, and September 26, 2001 submittals adequately 
addressed the conditions of the interim approval effective on September 
6, 1995. The District of Columbia is hereby granted final full approval 
effective on November 30, 2001.
    (c) The District of Columbia Department of Health submitted program 
amendments on April 4, 2003. The rule amendments contained in the April 
4, 2003 submittal adequately addressed the deficiency identified in the 
Notice of Deficiency effective on December 13, 2001. The District of 
Columbia hereby maintains final full approval effective on June 2, 2003.

                                 Florida

    (a) Florida Department of Environmental Protection: submitted on 
November 16, 1993, and supplemented on July 8, 1994, November 28, 1994, 
December 21, 1994, December 22, 1994, and January 11, 1995; interim 
approval effective on October 25, 1995; interim approval expires 
December 1, 2001.
    (b) The Florida Department of Environmental Protection submitted 
program revisions on April 29, 1996, February 11, 1998, June 11, 1998, 
April 9, 1999 (two submittals), July 1, 1999, and October 1, 1999. The 
rule revisions contained in the April 29, 1996, February 11, 1998, June 
11, 1998, April 9, 1999, July 1,1999, and October 1, 1999 submittals 
adequately addressed the conditions of the interim approval effective on 
October 25, 1995, and which would expire on December 1, 2001. The 
State's operating permits program is hereby granted final full approval 
effective on October 31, 2001.

                                 Georgia

    (a) The Georgia Department of Natural Resources submitted on 
November 12, 1993, and supplemented on June 24, 1994; November 14, 1994; 
and June 5, 1995; interim approval effective on December 22, 1995; 
interim approval expires December 1, 2001.
    (b) The Georgia Department of Natural Resources submitted program 
revisions on March 10, 1997, February 11, 1998, September 30, 1999, 
November 15, 1999, and January 11,

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2000. The rule revisions contained in the February 11, 1998 submittal 
adequately addressed the conditions of the interim approval effective on 
December 22, 1995, and which would expire on June 1, 2000. The State is 
hereby granted final full approval effective on August 7, 2000.

                                 Hawaii

    (a) Department of Health; submitted on December 20, 1993; effective 
on December 1, 1994; interim approval expires December 1, 2001.
    (b) Revisions were submitted on September 21, 2001. The rule 
amendments contained in the September 21, 2001 submittal adequately 
addressed the conditions of the interim approval effective on December 
1, 1994. The Department of Health, State of Hawaii, is hereby granted 
final full approval effective on November 30, 2001.

                                  Idaho

    (a) Idaho Division of Environmental Quality: submitted on January 
20, 1995, and supplemented on July 14, 1995, September 15, 1995, and 
January 12, 1996; interim approval effective on January 6, 1997; 
revisions submitted on July 9, 1998, May 25, 1999, and March 15, 2001; 
full approval effective on November 5, 2001.
    (b) Reserved.

                                Illinois

    (a) The Illinois Environmental Protection Agency: submitted on 
November 15, 1993; interim approval effective on March 7, 1995; interim 
approval expires December 1, 2001.
    (b) The Illinois Environmental Protection Agency: program revisions 
submitted on May 31, 2001; submittal adequately addressed the conditions 
of the interim approval which expires on December 1, 2001. Illinois is 
hereby granted final full approval effective November 30, 2001.

                                 Indiana

    (a) The Indiana Department of Environmental Management: submitted on 
August 10, 1994; interim approval effective on December 14, 1995; 
interim approval expires December 1, 2001.
    (b) The Indiana Department of Environmental Management: Program 
revisions submitted on May 22, 1996; submittal adequately addressed the 
conditions of the interim approval which expires on December 1, 2001. 
Indiana is hereby granted final full approval effective November 30, 
2001.
    (c) The Indiana Department of Environmental Management: program 
revisions submitted on February 7, 2002. These revisions are hereby 
granted final approval effective June 17, 2002.

                                  Iowa

    (a) The Iowa Department of Natural Resources submitted on November 
15, 1993, and supplemented by correspondence dated March 15, 1994; 
August 8, 1994; October 5, 1994; December 6, 1994; December 15, 1994; 
February 6, 1995; March 1, 1995; March 23, 1995; and May 26, 1995. 
Interim approval effective on October 2, 1995; interim approval expires 
October 1, 1998.
    (b) The Iowa Department of Natural Resources submitted a revised 
workload analysis dated April 3, 1997. This fulfills the final condition 
of the interim approval effective on October 2, 1995, and which would 
expire on October 1, 1997. The state is hereby granted final full 
approval effective September 12, 1997.
    (c) The Iowa Department of Natural Resources submitted for program 
approval rules 567-22.100 through 567-22.116 and 567-22.300 on August 7, 
2000, rules 567-22.201, 567-22.203, and 567-22.300 (except 
22.300(7)(``c'')) on January 29, 2001, and 
567-22.100 and 567-22.106 on July 18, 2001. These revisions to the Iowa 
program are approved effective May 3, 2002.
    (d) The Iowa Department of Natural Resources (IDNR) submitted 
amendments to Iowa Rule, 567 Iowa Administrative Code (IAC) 22.108(3), 
as a revision to the Iowa Title V operating permits program on August 
31, 2001, effective August 15, 2001. The amendments incorporate existing 
periodic monitoring guidance and adopt by reference compliance assurance 
monitoring requirements. The IDNR submitted a supplement regarding these 
amendments on November 7, 2001, clarifying IDNR's authority to establish 
periodic monitoring on a case-by-case basis. This revision to the Iowa 
program is effective April 15, 2002.
    (e) The Iowa Department of Natural Resources submitted for program 
approval rules ``567-22.100,'' 
``567-22.101,'' ``567-
22.201,'' and ``567-22.300'' 
on April 25, 2002. The state effective date of these rules is April 24, 
2002. These revisions to the Iowa program are approved effective May 6, 
2003.

                                 Kansas

    (a) The Kansas Department of Health and Environment program 
submitted on December 12, 1994; April 7 and 17, 1995; November 14, 1995; 
and December 13, 1995. Full approval effective on February 29, 1996.
    (b) [Reserved]

                                Kentucky

    (a)(1) Kentucky Natural Resources and Environmental Protection 
Cabinet: Submitted on December 27, 1993, and supplemented on November 
15, 1994, April 14, 1995, May 3, 1995, and May 22, 1995; interim 
approval expires on December 1, 2001.

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    (2) Revision submitted on February 13, 2001. Rule revisions 
contained in the February 13, 2001 submittal adequately addressed the 
conditions of the interim approval which expires on December 1, 2001. 
The Commonwealth is hereby granted final full approval effective on 
November 30, 2001.
    (b)(1) Air Pollution Control District of Jefferson County: submitted 
on January 31, 1994, and supplemented on March 9, 1994, June 15, 1994, 
July 15, 1994, July 14, 1995, August 9, 1995, August 10, 1995, and 
February 16, 1996; full approval effective on April 22, 1996.
    (2) Revisions submitted on February 20, 1998, January 11, 1999, 
September 30, 1999, March 17, 2000, March 21, 2001, and October 23, 
2001; full approval of revisions effective on April 22, 2002.

                                Louisiana

    (a) The Louisiana Department of Environmental Quality, Air Quality 
Division submitted an Operating Permits program on November 15, 1993, 
which was revised November 10, 1994, and became effective on October 12, 
1995.
    (b) [Reserved]

                                  Maine

    (a) Department of Environmental Protection: submitted on October 23, 
1995; source-category limited interim approval effective on March 24, 
1997; full approval effective December 17, 2001.
    (b) [Reserved]

                                Maryland

    (a) Maryland Department of the Environment: submitted on May 9, 
1995; interim approval effective on August 2, 1996; interim approval 
expires December 1, 2001.
    (b) The Maryland Department of Environmental Quality submitted 
operating permit program amendments on July 15, 2002. The program 
amendments contained in the July 15, 2002 submittal adequately addressed 
the conditions of the interim approval effective on August 2, 1996. The 
State is hereby granted final full approval effective on February 14, 
2003.

                              Massachusetts

    (a) Department of Environmental Protection: submitted on April 28, 
1995; interim approval effective on May 15, 1996; interim approval 
expires December 1, 2001.
    (b) The Massachusetts Department of Environmental Services submitted 
program revisions on November, 19, 1996 and May 11, 2001. EPA is hereby 
granting Massachusetts full approval effective on November 27, 2001.

                                Michigan

    (a)(1) Department of Environmental Quality: received on May 16, 
1995, July 20, 1995, October 6, 1995, November 7, 1995, and January 8, 
1996; interim approval effective on February 10, 1997; interim approval 
expires December 1, 2001.
    (2) Interim approval revised to provide for a 4 year initial permit 
issuance schedule under source category limited (SCL) interim approval, 
pursuant to the Department of Environmental Quality's request received 
on April 18, 1997. SCL interim approval effective on July 18, 1997.
    (3) Department of Environmental Quality: interim approval 
corrections submitted on June 1, 2001 and September 20, 2001; submittals 
adequately address the conditions of the interim approval which expires 
on December 1, 2001. Based on these corrections, Michigan is hereby 
granted final full approval effective on November 30, 2001.
    (b) (Reserved)

                                Minnesota

    (a) The Minnesota Pollution Control Agency: submitted on November 
15, 1993; interim approval effective on July 16, 1995; interim approval 
expires December 1, 2001.
    (b) The Minnesota Pollution Control Agency: Program revisions 
submitted on June 9, 2000, July 21, 2000, June 12, 2001; Rule revisions 
contained in the submittals adequately addressed the conditi