United States
Environmental Protection
Agency
Office of Air Quality
Planning and Standards
Research Triangle Park, NC 27111
EPA/456-B-00-001
November 2000
www.epa.gov/ttn/uatw/petrefine/petrefpg.html
Petroleum Refinery
MACT Standard
Guidance
(Revised to include Rule Amendments)
Revised Document
November 2000

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EPA-456/B-00-001
Petroleum Refinery MACT
Standard Guidance
(Revised to include Rule Amendments)
Prepared for:
Office of Air Quality Planning and Standards
US Environmental Protection Agency
Research Triangle Park, NC 27711
Prepared by:
Eastern Research Group
November, 2000
Revised Document

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Petroleum Refinery MACT Standard Guidance
Notice
The statements in this document are intended solely as
guidance. This document is not intended, nor can it be relied
on, to create any rights enforceable by any party in litigation
with the United States. EPA and State officials may decide to
follow the guidance provided in this document, or to act at
variance with the guidance, based on an analysis of specific
site circumstances. This guidance may be revised without
public notice to reflect changes in EPA's policy.
Mentions of trade names or commercial products in this
document or associated references does not constitute an
endorsement or recommendation for use.

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Petroleum Refinery MACT Standard Guidance
ACKNOWLEDGMENTS
The Petroleum Refinery MACT Standard Guidance document was originally prepared by
Science Applications International Corporation under the direction of Rafael Sanchez of
EPA's Office of Enforcement and Compliance Assurance, under EPA contract number
68-C4-0072. This document has now been updated to include rule amendments as of
November, 2000, see below*
The US Environmental Protection Agency's Manufacturing, Energy and Transportation
Division in the Office of Enforcement and Compliance Assurance would like to express
thanks and appreciation to everyone who helped make the Petroleum Refinery MACT
Standard Guidance possible.
Special thanks to the Petroleum Refinery MACT Review Members: Fred Weeks, EPA
Region 1; Harish Patel, EPA Region 2; Paul Dressel, EPA Region 3; Mirza Baig, EPA
Region 4; Kathy Keith, EPA Region 5; Martin Brittain, EPA Region 6; Bill Peterson, EPA
Region 7; Scott Whitmore, EPA Region 8; John Kim, EPA Region 9; Doug Hardesty &
Andrea Longhouse, EPA Region 10; Jim Durham and Larry Brockman, EPA OAQPS, and
Mary Lalley, ERG, Inc.
* This updated document was prepared by the Environmental Research Group Inc. under
the direction of Larry Brockman of EPA's Office of Air Quality Planning and Standards,
under Task Order 68-D6-011.
ii

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Petroleum Refinery MACT Standard Guidance
How to Download this Document Electronically
from the Internet
This document is electronically available through the EPA Public Access server at the
following Web site: http://www.epa.gov/envirosense/oeca/metd/ref.html or from EPA's
Unified Air Toxics Website's Petroleum Refinery webpage:
http://www.epa.gov/ttn/uatw/petrefine/petrefpg.html
Additional Resources
• Applicability Determination Index (ADI):
http://134.67.104.12/cfdocs/adiwww/adiwww.html-ssi
Additional information and guidance on the applicability of the MACT standard can
be obtained through the EPA's Applicability Determination Index (ADI). The ADI is
a database that contains memoranda issued by EPA on the applicability and
compliance issues associated with the New Source Performance Standards
(NSPS), National Emissions Standards for Hazardous Air Pollutants (with
categories for both NESHAP, Part 61, and MACT, Part 63), and
chlorofluorocarbons (CFC). Recently issued determinations are added to the
database on a quarterly basis.
The National Compliance Assistance Clearinghouse is your guide to
compliance information on the Internet. It provides quick access to
compliance tools, contacts, and planned activities from across EPA as well
as other compliance assistance providers. To find out more about the
Clearinghouse, go towww.epa.gov/clearinghouse
Contact List
EPA Regional Contact List (see Appendix H)
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Petroleum Refinery MACT Standard Guidance
Table of Contents
Page
1.	Introduction 	1-1
2.	The Petroleum Refinery MACT Standard: An Overview	2-1
2.1	Applicability of the Rule	2-2
2.2	How Does a Facility Determine the Emission Points to Which
the Control Requirements Apply?	2-3
2.3	What Are the Control Requirements? 	2-5
2.4	When Must A Facility Comply?	2-5
2.5	Conclusions 	2-13
3.	General Standards 	3-1
3.1	What are the Performance Testing Requirements That Must Be
Met By All Regulated Emission Points? 	3-1
3.2	What are the Monitoring Requirements For All Regulated
Emission Points?	3-1
3.3	What are the Reporting Requirements For All Regulated Emission
Points? 	3-2
3.3.1	What are the Requirements For Permit Applications? 	3-2
3.3.2	What are the Requirements for Applications for Approval of
Construction or Reconstruction? 	3-3
3.3.3	What are the Requirements for Notification of Compliance
Status (NCS)? 	3-3
3.3.4	What are Periodic Reports, and When Are They Required? 	3-4
3.3.5	What are the Requirements for Startup, Shutdown, and
Malfunction Plan and Reports?	3-5
3.3.6	What are Reports Required for Special Situations? 	3-5
3.3.7	When can Facilities Submit Requests for Extension of
Compliance? 	3-6
3.3.8	What are the Requirements for Applications for a Performance
Test Waiver?	3-6
3.4	What are the Recordkeeping Requirements? 	3-7
3.5	Conclusions 	3-7
4.	Emission Points Subject to the Regulation 	4-1
4.1 What are the Requirements for Miscellaneous Process Vents? 	4-1
4.1.1	What are the Control Requirements for Miscellaneous
Process Vents? 	4-1
4.1.2	What are the Testing Requirements for Miscellaneous
Process Vents? 	4-2
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Petroleum Refinery MACT Standard Guidance
Page
4.1.3	What are the Monitoring Requirements for Miscellaneous
Process Vents? 	4-4
4.1.4	What are the Reporting Requirements for Miscellaneous
Process Vents? 	4-6
4.1.5	What are the Recordkeeping Requirements for Miscellaneous
Process Vents? 	4-10
4.2	What are the Requirements for Storage Vessels?	4-11
4.2.1	What are the Control Requirements for Storage Vessels?	4-11
4.2.2	What are the Testing Requirements for Storage Vessels?	4-12
4.2.3	What are the Monitoring and Inspection Requirements for
Storage Vessels? 	4-13
4.2.4	What are the Reporting Requirements for Storage
Vessels? 	4-15
4.2.5	What are the Recordkeeping Requirements for Storage
Vessels?	4-18
4.3	What are the Requirements for Wastewater Streams?	4-19
4.3.1	What are the Control Requirements for Wastewater
Streams?	4-20
4.3.2	What are the Testing Requirements for Wastewater
Streams? 	4-20
4.3.3	What are the Monitoring Requirements for Wastewater
Streams?	4-20
4.3.4	What are the Reporting and Recordkeeping Requirements
for Wastewater Streams?	4-20
4.4	What are the Requirements for Gasoline Loading Racks?	4-21
4.4.1	What are the Control Requirements for Gasoline Loading
Racks? 	4-21
4.4.2	What are the Testing and Monitoring Requirements for
Gasoline Loading Racks?	4-21
4.4.3	What are the Reporting and Recordkeeping Requirements
for Gasoline Loading Racks?	4-23
4.5	What are the Requirements for Marine Tank Vessel Loading? 	4-23
4.5.1	What are the Control Requirements for Marine Tank
Vessel Loading? 	4-24
4.5.2	What are the Testing and Monitoring Requirements for
Marine Tank Vessel Loading?	4-24
4.5.3	What are the Reporting and Recordkeeping Requirements
for Marine Tank Vessel Loading? 	4-24
4.6	What are the Requirements for Equipment Leaks?	4-24
4.6.1	What are the Control Requirements for Equipment Leaks?	4-25
4.6.2	What are the Testing, Inspection, and Monitoring
Requirements for Equipment Leaks? 	4-25
4.6.3	What are the Reporting and Recordkeeping Requirements
for Equipment Leaks?	4-25
v

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Petroleum Refinery MACT Standard Guidance
Page
4.7 Emissions Averaging	4-25
4.7.1	Emissions Averaging Applicability	4-26
4.7.2	Emissions Averaging Credit/Debit System 	4-26
4.7.3	Approval of Emissions Averaging Plan	4-28
4.7.4	Testing, Monitoring, Reporting, and Recordkeeping for
Emissions Averaging	4-28
4.7.5	Recordkeeping for Emissions Averaging	4-28
4.8 Conclusions 	4-29
5. Interrelationship of the Petroleum Refinery MACT Standard with
Other Regulations	5-1
TABLES
Table 2-1 Applicability of the Petroleum Refinery MACT Standard	2-3
Table 2-2 Control Applicability Criteria for Emission Points 	2-4
Table 2-3 Control Requirements for Process Units/Emission Points 	2-6
Table 4-1 Monitoring Requirements for Combustion Devices	4-5
Table 4-2 Monitoring Requirements for Miscellaneous Process
Vents with Bypass Lines	4-6
Table 4-3 40 CFR Part 63, Subpart CC, Table 10 Parameters	4-8
Table 4-4 Additional Recordkeeping Requirements	4-10
Table 5-1 Overlap of the Petroleum Refinery MACT Standard
(40 CFR 63 Subpart CC) with Existing Regulations 	5-4
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Petroleum Refinery MACT Standard Guidance
Page
FIGURES
Figure 2-1	Emission Points within an Affected Source 	2-2
Figure 2-2	Determination of Applicability for Miscellaneous Process Vents	2-7
Figure 2-3	Determination of Applicability for Storage Vessels	2-8
Figure 2-4	Determination of Applicability for Wastewater Streams 	2-9
Figure 2-5	Determination of Applicability for Gasoline Loading Racks	2-10
Figure 2-6	Determination of Applicability for Marine Tank Vessel Loading	2-11
Figure 2-7	Determination of Applicability for Equipment Leaks 	2-12
APPENDICES
Appendix A. Hazardous Air Pollutants	 A-1
Appendix B. Organic Hazardous Air Pollutants 	 B-1
Appendix C. U.S. Petroleum Refineries Affected by the Petroleum Refinery
Standards	 C-1
Appendix D. Additional Resources for Petroleum Refining MACT Standard
Guidance Document 	 D-1
Appendix E. Definitions	 E-1
Appendix F. Compliance Checklist for the Petroleum Refinery MACT
Standard (40 CFR Part 63, Subpart CC) 	F-1
Appendix G. Recent Changes to the MACT Standard	 G-1
Appendix H. EPA Regions and Regional Contacts For the Petroleum Refinery
MACT Standard Implementation 	 H-1
Technical Report Data
vii

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Petroleum Refinery MACT Standard Guidance
I. INTRODUCTION
In August 1995, the United States Environmental Protection Agency (EPA) promulgated
the National Standards for Hazardous Air Pollutants (NESHAP) for petroleum refineries
that were originally proposed in July 1992. These standards require petroleum refineries,
that are major sources of Hazardous Air Pollutants (HAPs), to meet emission standards
reflecting the application of the maximum achievable control technology (MACT). The
affected sources at petroleum refineries are defined to include all process vents, storage
vessels, marine tank vessel loading operations, gasoline rack operations, equipment
leaks, and wastewater treatment systems located at the refinery. This manual was
developed to assist refineries in determining the applicability of these new standards to
their operations, and to provide guidance to assist facilities in achieving and maintaining
compliance.
The manual is presented in five chapters. Chapter 1 states the purpose, scope, and layout
of the document. Chapter 2 summarizes the major parts of the regulation, applicability of
the regulation to specific process units, applicable control requirements, and processes
not covered under the new rule. Chapter 3 discusses general standards applicable to all
process units. Chapter 4 builds on the general requirements, and discusses requirements
specific to each type of process unit and for facilities that use emissions averaging.
Finally, Chapter 5 shows where the new Petroleum Refinery MACT standard overlaps with
existing regulations.
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Petroleum Refinery MACT Standard Guidance
2. THE PETROLEUM REFINERY MACT STANDARD:
An Overview
The maximum achievable control technology (MACT) standard for petroleum refineries
stems from the Clean Air Act Amendments (the Act) of 1990. Under the Act, EPA is
required to regulate emissions of 188 listed hazardous air pollutants (HAPs), also known
as air toxics. On July 16, 1992, EPA published a list of source categories (industry
groups) that emit one or more of these HAPs. For listed categories of "major" sources
(those that emit 10 tons annually or more of a listed pollutant or 25 tons or more of a
combination of pollutants annually- see Appendix I of this document for additional
information on "major sources), the Act requires EPA to develop standards that will require
the application of maximum achievable control technology.
The list of industry groups to be regulated includes petroleum refineries, because they are
a major source of HAP emissions. Consequently, the MACT standard was developed to
help control this source of emissions.
The Petroleum Refinery MACT standard applies to petroleum refining process units and
related emission points. The standard MACT includes testing, monitoring, reporting,
recordkeeping, and control requirements. Requirements in the MACT standard include
control of HAP emissions from the following emission points within petroleum refining
process units: process vents, storage vessel loading, wastewater collection and treatment
systems, gasoline loading racks, marine tank vessel loading, and equipment leaks. There
are two general approaches to comply with the MACT standard's control requirements:
(1)	Implement controls on all emission points that meet the criteria for control in the rule; or
(2)	Use a method called emissions averaging.
This method allows the facilities flexibility to
choose certain emission points for control in
order to achieve the required emissions
reductions in the most cost-effective manner. In
some situations, facilities may find it more cost-
effective to overcontrol certain emission points
and undercontrol others, so that the overall result
would be greater emissions reductions at less
control cost. The MACT standard spells out how
facilities may use emissions averaging and which
emission points may be included. This approach
can only be used for existing sources. A
detailed explanation of emissions averaging is
found in Chapter 4 of this manual.
Who Will Be Affected By The
Petroleum Refinery MACT
Standard?
There are approximately 165
petroleum refineries as of
January 1, 1997 in the United
States, all of which are
anticipated to be major
sources of HAPs, and
therefore, may be subject to
this regulation.
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Petroleum Refinery MACT Standard Guidance
H Under the Petroleum Refinery MACT standard, the term "source" refers to the
entire refinery, whereas under New Source Performance Standards (NSPS)
and State Implementation Plans (SIPs), sources are most commonly process
units. The MACT standard applies only to major sources. Under the MACT
standard, there are different requirements depending on whether the facility is an existing
source or a new source. The MACT Standard defines existing and new sources as
follows:
Existing sources - sources that commenced construction on or before July 14, 1994;
New sources - sources that commenced construction after July 14, 1994. A process unit
constructed at an existing source is subject to new source requirements if the new unit has
the potential to emit 10 tons per year (tpy) or more of any one HAP or 25 tpy or more of
total HAPs. Otherwise it is subject to the requirements applicable to existing sources. A
change to an existing source or an addition of an emission point is subject to existing
source standards, unless it is a reconstructed source, which is subject to new source
standards.
This chapter provides an overview of the major elements of the rule, including general
applicability, control requirements, and compliance deadlines. General information on
testing, monitoring, reporting, and recordkeeping is given in Chapter 3 and a detailed
discussion of individual emission points is found in Chapter 4.
2.1 Applicability of the Rule
The affected source is the combination of all the emission points located at a refinery, and
each point is considered part of the single affected source. The MACT standard also
applies only to major sources as defined by Section 112(a) of the Clean Air Act with the
potential to emit hazardous air pollutants. For clarification on whether a source is a major
source, see Appendix E. Figure 2-1 gives an example of each of the emission points
FIGURE 2-1. Emission Points Within an Affected Source
Flare
Finished Product
Storage Vessels
Marine Tank
Vessel Loading
Miscellaneous
Process^,
Vents
Gasoline
Loading
Rack
Raw Material
Storage Vessel
Processing
Finished Product
Storage Vessel
Wastewater
Streams
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Petroleum Refinery MACT Standard Guidance
within an affected source. TABLE 2-1 presents the emission points to which the
Petroleum Refinery MACT standard applies. If any of the points in TABLE 2-1 is not
located at the refinery, the MACT standard does not apply.
TABLE 2-1. Applicability of the Petroleum Refinery MACT Standard
The Rule Applies To
The Rules Does Not Apply To
• Refineries that are major HAP sources under
•
Refineries that are not major HAP sources
either of the following definitions:

Equipment that does not emit or contain
•
- Potential to emit > 10 tons per year (tpy) of

any of the HAPs in Appendix B of this
any of the 188 HAPs in Appendix A of this

manual
manual; or
•
Catalytic cracking and reforming catalyst
- Potential to emit > 25 tpy of total HAPs

regeneration vents
• Refining process units at refineries that are
•
Sulfur recovery plant vents
major sources and emit or contain any of the

Research and development facilities
28 HAPs in Appendix B of this manual

• The following emission points within
•
Units processing natural gas
petroleum refining process units at major
•
Units for recycling discarded oil
sources:
•
Shale oil extraction units
- Miscellaneous process vents that contain >

Ethylene processes
20 ppmv total organic HAP
•

•
Units subject to the hazardous organic
- Storage vessels (pressure vessels and
vessels < 40 m3 are exempt)

NESHAP (HON) [40 CFR 63 Subparts F,
G, H, and I]
- Wastewater streams and treatment

operations
•
Storm water from segregated storm water
- Equipment containing or contacting a fluid is

sewers
> 5% by weight total organic HAPs.
•
Spills
• The following emission points if located at
•
Equipment in organic HAP service < 300
refineries that are major sources:

hours during the calendar year.
- Marine vessel loading operations


- Gasoline loading racks in SIC 2911


- Storage vessels and equipment leaks


associated with bulk gasoline terminals in SIC


2911.


2.2 How Does A Facility Determine the Emission
Points to Which the Control Requirements
Apply?
The introduction to this chapter presented how a facility determines if it is classified as an
existing or newsource. Once this determination has been made, a facility must assess
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Petroleum Refinery MACT Standard Guidance
whether it meets the criteria for requiring controls on its emission points. TABLE 2-2
presents the control applicability criteria for each type of emission point. Emission points
that meet these criteria are called Group 1 emission points, while all other emission points
are called Group 2 emission points. Group 1 emission points are subject to all applicable
requirements of the MACT standard. Group 2 emission points are not subject to the
control or monitoring requirements of the MACT standard. However, Group 2
emission points are subject to certain recordkeeping requirements.
TABLE 2-2. Control Applicability Criteria for Emission Points
Emission
points
For Existing Sources, Controls Must
Be Used If:
For New Sources, Controls Must Be
Used If:
Miscellaneous
Process
Vents
(1)	Organic HAP concentration > 20
ppmv, and
(2)	Total VOC emissions > 33 kg/day.
(1)	Organic HAP concentration > 20
ppmv, and
(2)	Total VOC emissions > 6.8 kg/day.
Storage
Vessels
(1)	Capacity > 177 m3, and
(2)	Vapor pressure > 10.4 kPa
(maximum) and > 8.3 kPa (annual
average), and
(3)	Organic liquid HAP concentration >
4% by weight (annual average).
(1)	Capacity> 151 m3, and
(2)	Vapor pressure > 3.4 kPa
(maximum), and
(3)	Organic liquid HAP concentration >
2% by weight (annual average).
OR
(1)	Capacity > 76 and < 151 m3, and
(2)	Vapor pressure > 77 kPa (maximum),
and
(3)	Organic liquid HAP concentration >
2% by weight (annual average).
Wastewater
Streams
(1)	Total annual benzene loading > 10
megagrams per year, and
(2)	Flow rate > .02 liters per minute, and
(3)	Benzene concentration > 10 ppm by
weight, and
(4)	Not exempt from controls under 40
CFR61 Subpart FF.
(1)	Total annual benzene loading > 10
megagrams per year, and
(2)	Flow rate > .02 liters per minute, and
(3)	Benzene concentration > 10 ppm by
weight, and
(4)	Not exempt from controls under 40
CFR 61 Subpart FF.
Gasoline
Loading
Racks
Part of bulk gasoline terminal located at
facilities designated under SIC 2911 with
gasoline throughput > 75,700 liters per
day.
Part of bulk gasoline terminal located at
facilities designated under SIC 2911 with
gasoline throughput > 75,700 liters per
day.
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Petroleum Refinery MACT Standard Guidance
Emission
points
For Existing Sources, Controls Must
Be Used If:
For New Sources, Controls Must Be
Used If:
Marine Tank
Vessel
Loading
(1)	Vapor pressure of liquid loaded >
10.3 kPa, and
(2)	Emission > 9.1 megagrams of any
HAP or > 22.7 megagrams of total
HAP per year after August 18, 1999.
(1)	Vapor pressure of liquid loaded > 10.3
kPa
(2)	No parallel emission rate cutoffs for
new sources.
Equipment
Leaks
Equipment containing or contacting fluid
that is 5% by weight total organic HAPs.
Equipment containing or contacting fluid
that is 5% by weight total organic HAPs.
Included at the end of this chapter in Figure 2-2 through 2-6 are decision flowcharts which
show how a facility can determine first if it is subject to the MACT standard, and second if
Group 1 or Group 2 requirements apply. Decision flowcharts have been included for each
emission point that is potentially subject to the MACT standard (i.e., miscellaneous
process vents, storage vessels, wastewater streams, gasoline loading racks, marine tank
vessel loading, and equipment leaks).
2.3	What Are the Control Requirements?
TABLE 2-3 summarizes the control requirements for emission points meeting the criteria
in TABLE 2-2. Please note that while TABLE 2-3 provides an inclusive (as of
September 1997) summary of the control requirements for these emissions points,
specific requirements can be found in the referenced section of the Code of
Federal Regulations.
2.4	When Must A Facility Comply?
The MACT standard specifies the dates by which each emission point at new and existing
sources must be in compliance with the control requirements. All emission
points at new sources must be in compliance at startup or by August 18, 1995, whichever
is later.
There is a specific compliance date for each emission point at existing sources.
Miscellaneous process vents and gasoline loading racks have a compliance date of
August 18, 1998. Wastewater streams also have a compliance date of August 18, 1998,
and sources should be in compliance with the benzene waste operations NESHAP found
in 40 CFR 61 Subpart FF.
Fixed roof storage vessels must be in compliance by August 18, 1998 as well; however,
the preamble suggests compliance by August 18, 1999 if the tank must be replaced.
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Petroleum Refinery MACT Standard Guidance
TABLE 2-3. Control Requirements for Process Units/Emission Points
Emission points
Control Requirements
Miscellaneous Process
Vents
Reduce organic HAPs by 98% orto 20 ppmv using incinerators,
boilers, process heaters, or other devices; or
Use a flare.
Storage Vessels
• Comply with storage vessel NESHAP [40 CFR 63 Subpart G],
which requires:
Internal floating roofwith specified seals; or
External floating roofwith specified seals; or
External floating roof converted to internal floating roofwith
specified seals; or
Closed vent system with 95% efficient control device.
Wastewater Streams
Comply with benzene waste operations NESHAP [40 CFR 61 Subpart
FF], which requires:
Reducing benzene mass emissions by 99% using suppression
followed by another treatment process (e.g., steam stripping or
biotreatment); and
Reducing emissions from vents from stream strippers, other waste
management, or treatment units by 95% with a control device orto
20 ppmv at the outlet of the control device.
Gasoline Loading Racks
Comply with gasoline distribution NESHAP [40 CFR 63 Subpart R],
which requires:
Reducing emissions of total organic compounds to 10 milligrams
per liter of gasoline loaded; and
Loading only in vapor tight cargo tanks that have been tested to
assure vapor tightness.
Marine Tank Vessel
Loading
Comply with marine tank vessel loading NESHAP [40 CFR 63 Subpart
Y], which requires:
Reducing HAP by 97% for existing sources
Reducing HAP by 98% for new sources.
Equipment Leaks
Comply with equipment leak rules [40 CFR 63 Subpart H or 40 CFR 60
Subpart VV] for existing sources and [40 CFR 63 Subpart H] for new
sources, which require:
Leak detection and repair with specified leak definitions and
monitoring frequencies
Equipment specifications for some types of equipment.
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Petroleum Refinery MACT Standard Guidance
FIGURE 2-2. Determination of Applicability for Miscellaneous Process Vents
Oows th« v««i| ecnfeln « ₯tr#» m yrfih 20 Cpm by j*}lwTO organic HAP and is il
continuously or periodically discharged during norma operations?
No
1 r
NS
NO
Group 2 raseeltaoous
process vent*
Group 1 rtti&eelianeoi]!
process venr1
Group 2 misoallenaous
process vent'
GrtS-up 1 Tiisrallaneous
processor)!'
Is vsnt associated with an editing ar new source?
Is (jrefiniij HAF concsnrrafioo >20 ppntv. and
total YOG mr,isikmi s 33 kg/Va/?
, . Existing Sojtcs:
fe ifgamc MAP cmssntmtion > 20 ppmv, anrf total
VOC smisa/crM: > B.BiQASay?
Note: The absva list gives axamples of v/here vent or gas streams may orfginete and may not ha aB inclasiva.
Does the va.it or gas siraero como from: cauafc wash a<3pymw(8ftws, f/isSSatKO h w ecjietensera/'
acci/mumters, Jtasn/blOCfaMr drums., fe&tiCf v#SS6fe, scrubber ovBrfjestfs. stipper overheads. vacuum
aeeumutefora, btov/dovm cnndenssrs/aocumulaioiS; and dBtsyesS poker vents?
Note: The above Sstghres examples of vent or gas streams and may rcpf t>a glt.:imfri$sve.
-	directly discfisrgBd Jd the atmosphere or
¦ rtsutefii to a GQittiot cfci/ice prior to discharge to vie vtntQSphcre or
-	di'/erted to a prvduot recover/prior to control or discharge flo the atms}8ph$r°?
Isth3 ventres stream:
-	Gas streams ftwtGd to 3 ft/ar gas SyStert
-	Relief vshw rfedjsrges
-	Leafts from «jufprt#rrf re$i JjrtCfSf 40 CTR 51 #40
-	Episodic or nonmutsne releases such as maintenance or upsets
-	Sn svftf sarttjfifi'djj systems ifemiwwi wfyt&rs)
-	Cafafytfc cracking ur.it catalyst regeneration vents
¦ Cats Wo reformer regeflewton verts
-	SaJferpftrtf VBrtfS
-	V'en/s from ranfraf devices
-	VertlS BlDtft arty StfipnitiQ O.oeraf/GfiS HflOteo' ffl comply with ffta wsstsumiBrprchfisbns of 40 CFR
63 Subpart CC, -3, a' FF
-	Catfrif j/n# y-snS ssKwrafed v,ith w*e drum cfejwessmiig af arftetaw a coHs drum outlet pressure
of f 5 pounds per squara inch pSup, daftead^jp, draining, or dacaki.ig (coke cutting) or pressure
tasting attar dacoking
-	vents from storage vessels
-	Emissions fmm wastewater coilaitbn and conveyance attorns?
Does tt10 vent or gas stream coma fcwnr
* See Chapter a for applicable requirement for Grouo 1 ar>d Groufl 2 ernjsaon poirils.
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Petroleum Refinery MACT Standard Guidance
FIGURE 2-3. Determination of Applicability for Storage Vessels
No-
Yes
Yes
No
Yes
No
Yes
No
Yes
No
Yes
No
Existing
New-
¦Yes-
No-
¦Yes-
No-
Storage vessels
provision does
not apply
Group 1 storage
vessel*
Group 2 storage
vessel*
Group 1 storage
vessel*
Group 2 storage
vessel*
Is tank associated with an
existing or new source?
Is it used as a wastewater
storage tank?
Is it used as a bottoms receiver
tank?
Does it have a capacity less than
40 cubic meters?
Storage
vessels
provision
does
not
apply
Is it permanently attached to a
motor vehicle such as a truck,
railcar, barge or ship?
Is it a tank or other vessel that is used to
store organic liquids? (i.e., is this a storage
vessel "as described in the rule"?)
Is it a pressure vessel designed to operate
in excess of 204.9 kilopascals and without
emission to the atmosphere?
Is capacity > 177 m3 and vapor pressures 10.4
kPa (maximum) and > 8.3 kPa (annual average),
and liquid HAP content > 4% by weight
(annual average)?
Existing Source:
Is capacity> 151 m3 and vapor pressure^ 3.4 kPa
(maximum), and liquid HAP content > 2% by weight
(annual average)?
OR
Is capacity between 76and 151 m3, and vapor
pressures 77 kPa (maximum), and liquid HAP >2%
by weight (annual average)?
New Source:
* See Chapter 4 for applicable requirements for Group 1 and Group 2 emission points.
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Petroleum Refinery MACT Standard Guidance
FIGURE 2-4. Determination of Applicability for Wastewater Streams
	No-
Applicability
criteria (tie
same for
existing and
new sources
Group 1 wastewater
si team'
Group 2 wastewater
stream*
Wastewater provision
(foes not apply
Is discharged Into any individual drain
system?
la tt water or wastewater that, during production or processing:
Cows into direct contact with or results
Item the producfion or use of any raw
material, intermediate product, finished
product, byproduct, or waste product?
Does refinery have a total annual benzene
loading > 10 megagrams per year, and a
flew rate >0,02 liters per minute, and
benzene concentration * 10 pprn by
weight, and subject to control requirements
tintter 40 CFR 61 Subpart FF?
[Examples. of wastewater are; feed tank drawdown; water farmed during a chemical reaction or used as a
reacterit; water used to wash impurities from organic products or r&actante; water used to cool or quendi
organic vapor streams through direct contact; and condensed eteam from jet ejector systems pulling vacuum
on vassals containing or panics.]
* See Chapter 4 tor applicable requirements fc>r Group 1 and Croup 2 emission points.
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Petroleum Refinery MACT Standard Guidance
FIGURE 2-5. Determination of Applicability for Gasoline Loading Racks
Is it any of the following:
loading arms, pumps, meters, shutoff va|/es,
relief valves, or
other piping and valves necessary to f
gasoline cargo tanks?
Yes
1
r
Is it a gasoline loading rack
classified under SIC 2911?
No ^



f
Gasoline loading rack
provision does not app
Yes

r
Does it have a gasoline throughput:
75,700 liters (20,000 gallons) per da}

	No		
Applicability \
criteria are the \
same for \
existing and /
new sources /
^ Yeo 1	No ^
Group 1 gasoline
loading rack*
Group 2 gasoline
loading rack*
* See Chapter 4 for applicable requirements for Group 1 and Group 2 emission points.
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Petroleum Refinery MACT Standard Guidance
FIGURE 2-6. Determination of Applicability for Marine Tank Vessel Loading
	No-
Yes
Existing-
¦New-
¦Yes-
No-
-Yes-
No-
Group 2 marine tank
vessel loading*
Group 1 marine tank
vessel loading*
Group 1 marine tank
vessel loading*
Group 2 marine tank
vessel loading*
Marine tank vessel
loading provision
does not apply
Is it a land- or sea-based terminal or
structure that loads liquid commodities in
bulk onto marine tank vessels?
Is marine tank vessel loading associated
with an existing or new source?
Is vapor pressure of liquid loaded> 10.3 kPa?
New Source:
Is vapor pressure of liquid loaded> 10.3 kPa and
emissions > 9.1 megagrams of any one HAP or >
22.7 megagrams of total HAP per year?
Existing Source:
* See Chapter 4 for applicable requirements for Group 1 and Group 2 emission points.
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Petroleum Refinery MACT Standard Guidance
FIGURE 2-7. Determination of Applicability for Equipment Leaks
Yes1
i k
No
Yes
Equipment
leaks
provision
does not
apply
Equipment leaks provision applies
Is it a vent from a wastewater system
drain, tank mixer or sample valve on a
storage tank?
Is it an emission of organic hazardous air
pollutants from a pump, compressor,
pressure relief device, sampling connection
system, open-ended valve or line, valve,
or instrumentation system "in organic
hazardous air pollutant service" (equipmenl
containing or contacting fluich 5% by
weight total organic HAP)?
* See Chapter 4 for applicable requirements for Group 1 and Group 2 emission points.
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Petroleum Refinery MACT Standard Guidance
Floating roof storage vessels have a compliance date of August 18, 2005, or the next
scheduled maintenance and degassing after August 18, 1998, whichever is first.
Marine tank vessel loading must be in compliance by August 18, 1999, unless used in
emissions averaging. If used to generate credit in an emissions average, it must comply
by August 18, 1998, unless a case-by-case 1-year extension is granted.
A compliance date of August 18, 1998 is set for equipment leaks. Sources have the
option of complying with 40 CFR 60 Subpart W or 40 CFR 63 Subpart H, which allows for
3 phases of emissions reductions. (See Chapter 4 for more detailed information on
compliance dates for equipment leaks.)
2.5 Conclusions
Chapter 2 provided an overview of the MACT Standard answering the questions of which
facilities must comply; what facilities must do to comply, and when must they comply. The
overview defined the applicability of the MACT Standard to affected sources, and the
various types of emission points associated with the affected sources. Chapter 2 also
defined the control requirements applicable to the various emission points, noting which
points are required to maintain control equipment, and the types of control or associated
emission limit. Finally, Chapter 2 provided compliance deadlines for each category of
emission point. After reviewing the applicability determination flow charts in Chapter 2, a
facility should be able to determine whether the general requirements to be discussed in
Chapter 3, or the specific requirements in Chapter 4 will apply.
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Petroleum Refinery MACT Standard Guidance
3. General Standards
Once the refinery has determined which of its emission points are required to comply with
the Petroleum Refinery MACT standard (MACT standard), the refinery must determine the
specific requirements applicable to each emission point. While the control requirements
are specific to each type of emission point at the refinery, the MACT standard also
contains general provisions that are applicable to
all emission points. These general requirements
include performance testing, monitoring, reporting,
and recordkeeping. In addition, some reporting
requirements apply only to refineries conducting
certain activities.
Chapter 3 discusses the general requirements
applicable to all emission points at refineries.
Chapter 4 describes the control requirements
applicable only to specific emission points, as well
as emissions averaging - an alternative method to controlling emissions.
3.1	What are the Performance Testing Requirements
That Must Be Met By All Regulated Emission
points?
All facilities are required to conduct an initial performance test of certain pollution control
equipment. (No performance tests are required for floating roofs or process heaters > 44
MWwith vent introduced into the flame zone.) These initial performance tests must be
approved by EPA. To conduct the test, the facility must:
•	Notify regulatory authority 30 days prior to conducting a performance test [40 CFR
63.642(d)(2)]
•	Conduct tests at maximum representative operating capacity, with controls operating at
either maximum or minimum representative operating conditions for monitored
parameters, whichever result in lower emission reduction [40 CFR 63.642 (d)(3)],
3.2	What are the Monitoring Requirements For All
Regulated Emission points?
Monitoring is required for some Group 1 emission points. Requirements range from once
an hour for miscellaneous process vents routed to a flare, to no monitoring requirements
General requirements for all
emission points include:
performance testing, monitoring,
reporting (including permit
applications and notifications of
compliance status), and
recordkeeping.
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Petroleum Refinery MACT Standard Guidance
for Group 1 storage vessels equipped with an external floating roof. Specific monitoring
requirements for each process unit are presented in Chapter 4.
3.3 What are the Reporting Requirements For All
Regulated Emission Points?
Reporting requirements range from permit applications, and initial notification of
compliance status, to those requesting compliance extensions. With the exception of
periodic reports, all reports are one-time submittals, or one time per incident submittals.
The following types of information/reports must be submitted, where applicable, for each
emission point to the appropriate EPA Regional Office [40 CFR 63.13](See Appendix H
for a list of EPA Regional Offices):
•	Permit Applications
•	Applications for Approval of Construction or Reconstruction
•	Notification of Compliance Status
•	Periodic Reports
•	Startup, Shutdown, and Malfunction Reports
•	Reports Required for Special Situations
•	Requests for Extension of Compliance
•	Applications for a Performance Test Waiver.
Each of these requirements is presented in the following subsections.
3.3.1 What are the Requirements
For Permit Applications?
All owners or operators of a source subject to the
rule are required to apply for a one-time Part 70 or
Part 71 operating permit from the appropriate
authority. A source may apply for the permit from
either EPA or its State authority, depending on
whether EPA has approved a State operating
permit program. [40 CFR 63.642(a)]
The source must apply for a permit
from its state if EPA has approved
a State operating permit program
under Part 70. The source must
apply for a permit from its EPA
Regional Office if the State does
not have an EPA operating permit
program under Part 71.
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Petroleum Refinery MACT Standard Guidance
3.3.2	What are the
Requirements for
Applications for
Approval of
Construction or
Reconstruction?
All new or reconstructed sources are
required to submit an application for
approval of construction or reconstruction.
Existing sources are not required to submit
the application, unless new construction or
reconstruction occurs at the source.
General application requirements include
[40 CFR 63.5(d)]:
•	Applicant's name and address
•	Notification of intent to construct a new
major affected source
•	Source description and address
•	Identification of relevant standard that is the basis of the application
•	Expected commencement and completion dates of construction or reconstruction
•	Anticipated date of startup
•	Determination of rule applicability for each process unit (e.g., distillation units, storage
vessels, flexible operation units)
•	Actual or expected type and quantity of HAPs emitted
•	Additional relevant information as requested by the Administrator.
3.3.3	What are the Requirements for Notification of
Compliance Status (NCS)?
All refineries are required to inform EPA of their compliance status with respect to the
MACT standard. Facilities must submit a NCS report within 150 days after each
Construction means the on-site
fabrication, erection, or installation of an
affected source.
Reconstruction means the
replacement of components of an
affected or a previously unaffected
stationary source to the extent that:
(1)	The fixed capital cost of the new
component exceeds 50 percent of
the fixed capital cost that would be
required to construct a comparable
new source; and
(2)	It is technologically and economically
feasible for the reconstructed source
to meet the relevant standard(s)
established by the Administrator (or
a state) pursuant to section 112 of
the Clean Air Act.
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Petroleum Refinery MACT Standard Guidance
applicable compliance deadline. (See Section 2.4 of this manual for compliance dates.)
There are two exceptions: When a new Group 1 emission point is added or a floating roof
storage vessel is brought into compliance, the NCS may be included in the next periodic
report.1 The report must identify each emission point and method of compliance. This
information may be included as a separate report, as an operating permit application, or in
an amendment to an operating permit application. [40 CFR 63.654(f)] NCS report
requirements include the following:
•	Determination of rule applicability to flexible operation units and storage vessels and
distillation units for which use varies from year to year [40 CFR 63.654(h)(6)]1
•	Information on individual emission points to demonstrate compliance, such as range of
monitored parameters. [40 CFR 63.654(f)(1) and (f)(3)]
•	Results of continuous monitoring system performance evaluations. [40 CFR
63.654(f)(4)]
•	If initial performance tests are required, one example complete test report for each test
method used must be submitted. For additional tests using the same method, only the
results must be submitted. [40 CFR 63.654 (f)(2)]
3.3.4 What are Periodic Reports, and When are They
Required?
Periodic reports are required only if compliance exceptions occur within any 6-month
reporting period. If compliance exceptions do occur, periodic reports must be submitted.
The reports must be submitted within 60 days after the end of each 6- month period. If
facilities use emissions averaging, reports must be submitted quarterly. [40 CFR
63.654(g)]
Periodic reports must include information on compliance exceptions, such as a description
and cause of the exception and corrective action taken. (See Chapter 4 for each type of
emission point.) If a performance test is done for an emission point that is added or
changed from Group 2 to Group 1, include the results, such as percent emissions
reduction or concentration, in the next periodic report. [40 CFR 63.654(g)(7)]
-1
This requirement reflects an amendment to 40 CFR Part 63 Subpart CC made on August 18,
1998. For more information, see Appendix G.
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Petroleum Refinery MACT Standard Guidance
3.3.5 What are the Requirements for
Startup, Shutdown, and
Malfunction Plan and Reports?
All refineries must develop and implement a startup,
shutdown, and malfunction plan (SSMP) for the entire
facility, with the exception of wastewater stream
management units. An SSMP is not required for
wastewater stream management units unless they
receive streams subject to 40 CFR Part 63 Subpart G.
The malfunction plan must describe procedures for
operating and maintaining the source during periods
of startup, shutdown, and malfunction. In addition, the
plan must include a program of corrective action for malfunction of process and air
pollution control equipment used to comply with the relevant standard. EPA typically
defines malfunctions as rare, unforeseeable occurrences and does not allow for facilities
to operate in malfunction for extended periods of time.
If corrective actions to address the malfunction are consistent with the startup, shutdown,
and malfunction plan, submit a statement to this effect in the semi-annual report. [40 CFR
63.10(d)(5)(l)]
If a malfunction occurs and corrective actions are not consistent with the startup, shutdown,
and malfunction plan, this must be reported in the next periodic report.1
If a malfunction does not occur during a reporting period, a startup, shutdown, and
malfunction report is not required.
3.3.6 What are Reports Required for Special Situations?
The MACT standard has detailed requirements for testing, monitoring, and recordkeeping.
However, the rule allows for flexibility in meeting these requirements. If facilities intend to
use alternative procedures or devices, additional reports and approvals are required. For
these facilities, the following information must be submitted 18 months before the
compliance date for existing sources, or with the application for approval of construction
for new sources:
A Startup, Shutdown, and
Malfunction Report is
required to document:
•	The start of operation of a
process unit for production
•	The cessation of a process
unit for maintenance,
repair, or equipment
replacement
•	Any malfunction of a
process unit.
-1
This requirement reflects an amendment to 40 CFR Part 63 Subpart CC made on August 18,
1998. For more information, see Appendix G.
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Petroleum Refinery MACT Standard Guidance
•	Request for approval to monitor an alternative control device operating parameter, with
supporting justification [40 CFR 63.654(h)(4)]
•	Request for approval to use data compression systems instead of keeping hourly
records, with supporting information [40 CFR 63.654(h)(5)]
•	Request to use other alternative monitoring methods, with supporting justification [40
CFR 63.654(h)(5)(iv) and 63.8(f)(4)(ii)]
•	Request to establish an alternative emission standard, with a test plan or results of
testing and monitoring. [40 CFR 63.6(g)(2)] (If EPA finds the alternative standard
equivalent to the MACT standard, EPA will request public comment and publish a
Federal Register notice allowing its use.)
3.3.7	When Can Facilities Submit Requests for Extension of
Compliance?
An extension of compliance may be requested if emission reductions have been achieved
early, or if the source is unable to comply with the relevant standard. Requests for
extension of compliance are allowed only for existing sources and must be submitted at
least 12 months before the compliance date, or 18 months prior if emissions averaging is
used. [40 CFR 63.6(l)(2-3)] (See Chapter 2, Section 2.4 for compliance dates.)
Requests must include the following:
•	Description of controls to be installed
•	Compliance schedule
•	Interim emission control steps.
3.3.8	What are the Requirements for Applications for a
Performance Test Waiver?
If a facility is unable to conduct a performance test for reasons such as technical or
economic infeasibility, an extension of compliance has been requested, or other reasons,
the facility must submit an application for waiver of a performance test to the Administrator.
The application must include information justifying the request and detailing the
infeasibility. [40 CFR 63.7(h)(3)(iii)]
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Petroleum Refinery MACT Standard Guidance
3.4	What are the Recordkeeping Requirements?
All refineries are required to keep records of reports submitted, monitoring results, and
other records for at least 5 years. [40 CFR 63.642(e) and 63.654(l)(4)] In addition,
records must be kept so that they are accessible within 24 hours of request in either hard
copy or computer-readable form. If acceptable to the Administrator, reports may be
submitted on electronic media. [40 CFR 63.642(e)] The following records must be
maintained on site:
•	Records of the occurrence and duration of each startup, shutdown, or malfunction of
operation and air pollution control equipment [40 CFR 63.10(b)(2)(l-ii)]
•	Records of actions that are consistent and inconsistent with the startup, shutdown, and
malfunction plan [40 CFR 63.10(b)(2)(iv-v)]
•	Records of continuous monitoring system calibration checks (if continuous monitoring
is required) [40 CFR 63.10(b)(x)]
•	Records for storage vessels [40 CFR 63.654(l)(1)]
•	Complete test reports and reported results for any required performance tests
[64.654(l)(2)]
•	Values of continuously monitored parameters [40 CFR 63.654(l)(3)]
•	Any additional records required by permit.
3.5	Conclusions
Chapter 3 discussed the general requirements of the MACT Standard (i.e., those
requirements applicable to all regulated emission points). The chapter presented the
requirements for performance testing, monitoring, reporting, and recordkeeping that apply
to all regulated emission points. For each of these requirements, Chapter 3 discussed
only those requirements that apply to every emission point. Additional requirements
applicable to individual emission points are discussed in Chapter 4.
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Petroleum Refinery MACT Standard Guidance
4. EMISSION POINTS SUBJECT TO THE REGULATION
This chapter summarizes the detailed testing, monitoring, reporting and recordkeeping
requirements specific to each emission point regulated by the MACT standard. In
addition, control requirements for each emission point are described. Unless otherwise
noted, the requirements in Chapter 4 apply only to Group 1 emissions points. With few
exceptions, Group 2 emissions points are subject only to record keeping requirements.
Chapter 4 discusses each of the regulated emission points (i.e., miscellaneous process
vents, storage vessels, wastewater streams, gasoline loading racks, marine tank vessel
loading, and equipment leaks) presenting the applicable requirements. Chapter 4
concludes with a discussion emissions averaging and how this technique can be used by
existing sources in lieu of complying with the applicable control requirements for the
individual emission points. Please note that this chapter does not discuss the
details of all of the MACT Standard requirements for each of these regulated
emissions points. In particular, in the discussion of storage vessels, wastewater
streams, gasoline loading racks, marine tank vessels and equipment leaks this chapter
references other sections of the federal code of regulations to which the refinery may be
required to comply. For further detail on the referenced sections, see the
appropriate section of the Code of Federal Regulations.
4.1 What are the Requirements for Miscellaneous
Process Vents?
Once the refinery has determined which process vents are subject to the MACT standard,
the refinery must then determine the requirements applicable to each vent. These
requirements include controls, monitoring, reporting, and recordkeeping. To determine if a
process vent is subject to the MACT standard, refer to the applicability flowchart for
miscellaneous process vents in Chapter 2.
4.1.1 What are the Control Requirements for Miscellaneous
Process Vents?
If a vent meets the applicability criteria, it must be controlled by:
•	Using a flare; or
•	Reducing organic HAPs by 98% or to 20 ppmv using incinerators, boilers, process
heaters, or other devices; or
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Petroleum Refinery MACT Standard Guidance
• If a boiler or process heater is used, the vent stream must be introduced into the
flame zone of the control device, or in a location such that the required percent
reduction or concentration is achieved.
The following sections discuss the applicable testing, monitoring, reporting and
recordkeeping requirements associated with each of these control methods.
4.1.2 What are the Testing Requirements for Miscellaneous
Process Vents?
The MACT standard requires that
miscellaneous process vents be controlled by
routing the vents to a flare, incinerator, boiler,
process heater, other approved device, or
bypass lines. Some control devices for
miscellaneous process vents are required to
be tested during a one-time initial
performance test, and in follow-up tests in the
event of process changes. This performance
test must confirm that control equipment is
operating properly, and that emissions are
within specified limits. While some of the
components of the test are similar for all
miscellaneous process vents, the MACT
standard also applies testing requirements based on the control device as described
below.
Initial Performance Tests
Initial performance tests are required
approved control devices. When
performance tests are required, the
test measures whether equipment is
operating according to manufacturer
specifications, or whether equipment
is meeting a specified emissions
reduction. Vents routed to a flare
have testing requirements designed
to measure whether equipment is
operating properly, while other
categories of process vents must
have more sophisticated equipment
that measures the level of emissions
Miscellaneous Process Vents are
to be Controlled if:
•	It is an existing source, and the
vent contains 20 ppmv or more
of organic HAPs, and emits 33
kg/day or more of VOCs
•	It is a new source, and the vent
contains 20 ppmv or more of
organic HAPs, and emits 6.8
kg/day or more of VOCs.
for vents routed to a flare and vents using other
Performance tests are not required for:
•	Vents routed to a boiler or process
heater > 44 MW(150 MMBtu/hr)
•	Vent streams that are introduced into the
flame zone of the boiler or process
heater
•	A control device for which a
performance test was conducted for
determination of compliance with an
NSPS if no process changes have been
made.
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Petroleum Refinery MACT Standard Guidance
from each controlled vent. Performance tests are not required to determine percent
reduction when a flare is used.
For vents routed to a flare, the initial performance test must show that the flare is operating
properly, and that the emission rate does not exceed the capacity of the flame to control
the emissions. Based on these criteria, the initial performance test is required to measure
the following:
•	Emissions visibility (There should be no visible emissions.)
•	Net heat value of combusted gas.
•	Flow rate of gases being combusted.
For vents routed to an incinerator or a boiler or process heater < 44 Megawatts (MW) (150
MMBtu/hr) where the vent streams are not introduced into the flame zone of the boiler or
process heater, the initial performance test must show compliance with the requirement to
reduce organic HAPs by 98% or to 20 ppmv. [40 CFR 63.645 and 63.116 except (d) and
(e)]. The organic HAP concentration and percent reduction may be measured either as
total organic HAP or as total organic compounds (TOC) minus methane and ethane. The
sampling point varies depending on whether the facility is measuring total organic HAP or
TOC.
Determining Compliance Using Total Organic HAP
Sample sites must be located at both the inlet and
outlet of the control device, but the inlet sampling site
must be located after the final product recovery
device. If a process vent stream is introduced with
the combustion air or as a secondary fuel into a
boiler or process heater with a design capacity < 44
MW, selection of the location of the inlet sampling
site is required to ensure the measurement of total
organic HAP or TOC (minus methane and ethane)
concentrations in all process vent streams and
primary and secondary fuels introduced into the
boiler or process heater.
Determining Compliance Using TOC
As noted above, for vents that must show organic
HAP reduction, owners and operators can measure
that reduction either as total organic HAP or as TOC
minus methane and ethane. To measure the
Calculating the TOC
Emissions Rate:
TOC can be calculated using
Method 18 or Method 25A of
40 CFR 60 Appendix A, or any
other method or data validated
according to the protocol in
Method 301 of 40 CFR 63
Appendix A. When selecting
the sampling site, refineries are
required to use Test Methods 1
or 1 A of 40 CFR 60 Appendix
A, as appropriate. Additional
guidance on using these
methods can be found in 40
CFR 63(f), (g), and (h).
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Petroleum Refinery MACT Standard Guidance
reduction as TOC minus methane and ethane, the refinery first must determine TOC
according to the procedures specified below.
Samples must be taken:
•	After the last product recovery device, but
•	Prior to the inlet of any control device, and
•	Prior to any dilution of the process vent stream and release to the atmosphere.
Test Method 1 describes appropriate testing for sample and velocity traverses for
stationary sources. Test Method 1A describes appropriate testing for sample and velocity
traverses for stationary sources with small stacks or ducts. Traverse site selection
methods are not needed for vents smaller than 0.10 meter in diameter.
Follow-up Tests to Process
Changes
For Group 2 process vents, whenever the
refinery conducts a process change, the TOC
emission rate must be recalculated to determine
whether the vent remains a Group 2 process
vent or becomes a Group 1 process vent.
Recalculation may be based on vent stream flow
rate and TOC measurements as specified for
initial performance tests or best engineering
assessment practices.
4.1.3 What are the Monitoring
Requirements for
Miscellaneous Process
Vents?
Monitoring devices are not required for boilers or process heaters > 44MW or in which all
vent streams are introduced into the flame zone. The type and frequency of monitoring
depends on the type of combustion device. All continuous monitoring devices must be
installed, calibrated, maintained, and operated according to manufacturer specifications.
Table 4-1 lists the type of monitoring required for each combustion device. Refineries with
Group 1 miscellaneous process vents may request approval to monitor parameters other
than those listed in Table 4-1 if the refinery uses a control device other than an incinerator,
boiler, process heater, or flare, or wants to monitor a parameter other than those specified
What Constitutes a Process
Change?
Process changes include, but are
not limited to, changes in production
capacity, production rate, or catalyst
type; whenever there is replacement,
removal, or addition of recovery
equipment; and debottlenecking
activities.
Process changes do not include
process upsets, unintentional,
temporary process changes, or
changes that are within the range on
which the original calculation was
based.
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Petroleum Refinery MACT Standard Guidance
in the table. Refineries that use a vent system with bypass lines have separate
requirements that are described in Table 4-2.
For facilities using other approved control devices, or requesting to monitor other
parameters, a site-specific determination can be requested from the permitting authority.
TABLE 4-1. Monitoring Requirements for Combustion Devices
Combustion Device
Type of Monitoring Required
Monitoring Location
Flare
Device capable of continuously
detecting the presence of a pilot
flame (including, but not limited
to a thermocouple, an ultraviolet
beam sensor, or an infrared
sensor)
Not specified
Incinerators other than catalytic
incinerators
Temperature monitoring device
with a continuous recorder
In the firebox or in the duct
work immediately downstream
of the firebox in a position
before any substantial heat
exchange occurs
Catalytic incinerators
Temperature monitoring device
with a continuous recorder
In the gas stream immediately
before and after the catalyst
bed
Boiler or process heater with a
design heat input capacity > 44
megawatts, or any boiler or
process heater in which all vent
streams are introduced into the
flame zone
No monitoring required
Not applicable
Boiler or process heater with a
design heat input capacity < 44
megawatts where the vent
streams are riot introduced into
the flame zone
Temperature monitoring device
with a continuous recorder
In the firebox
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Petroleum Refinery MACT Standard Guidance
TABLE 4-2. Monitoring Requirements for Miscellaneous Process Vents
with Bypass Lines
Type of Bypass Line Control
Type of Monitoring Required
Monitoring Location
Refineries that use a vent system
with bypass line valves that have
not been sealed or secured
Flow indicator that determines at
least every hour whether a vent
stream flow is present
At the entrance to any
bypass line that could divert
the vent stream away from
the control device to the
atmosphere
Refineries that use a vent system
with bypass lines, where the
valves have been secured in the
closed position with a car-seal or
a lock-and key-type configuration
Visual inspection at least every
other month to ensure that the
valve is maintained in the closed
position and the vent stream is
not diverted through the bypass
line
At the valve
4.1.4 What are the Reporting Requirements for
Miscellaneous Process Vents?
Reporting requirements for miscellaneous process vents include some requirements
applicable to all control devices, and additional
reporting based on the specific control device.
This section discusses the two reports with
specific requirements for miscellaneous
process vents: Notice of Compliance Status
reports, and Periodic reports.
Notice of Compliance Status
Report
As noted in Chapter 3, all refineries are required
to submit a Notice of Compliance Status report.
The NCS may be submitted in an operating
permit application, an amendment to an
operating permit application, a separate
submittal, or any combination of the three. If the
required information has been submitted at an
earlier date, or at different times, and/or in
different submittals, later submittals may refer to
earlier submittals instead of duplicating and
resubmitting previously submitted information.
When Are NCS Reports
Required?
Notice of Compliance Status reports
are required at startup, or within 150
days of an applicable compliance
deadline. If the refinery submits an
NCS report prior to the compliance
deadline, it does not need to submit
an additional report within 150 days
of the deadline. It does, however,
need to send a letter to the
Administrator referencing the earlier
notification.
For example, if a new facility submits
an NCS report at startup in 1995, it
is required to submit a letter referring
to the NCS (and noting that no
process changes have occurred)
when an applicable 1998
compliance deadline occurs.
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Information required to be included in the NCS depends on the type of emission point. For
all miscellaneous process vents, the NCS must identify each vent, whether the process
vent is Group 1 or Group 2, and, for each Group 1 vent that is not included in an emissions
average, the method of compliance (e.g., use of a flare or other control device meeting the
requirements of the MACT standard). [40 CFR 63.643(a)]
In addition, miscellaneous process vents with control devices required to be tested under
the MACT standard must submit information on each testing method, and results of the
performance test since there are different requirements for each test and test method
used. Supporting information required for each test method used is indicated in the box
below. Test results must include the following information:
•	The percentage reduction of organic
HAPs or TOC or the outlet
concentration of organic HAPs or TOC
(ppm by volume on a dry basis
corrected to 3 percent oxygen),
determined as specified in 40 CFR
63.116(c)
•	For vents controlled by flares, all visible
emission readings, heat content
determinations, flow rate
measurements, and exit velocity
determinations made during the
compliance determination [40 CFR
63.654(f)(1)(iv)(A)]
•	For vents controlled by flares, a
statement of whether a flame was
present at the pilot light over the full
period of the compliance determination
[40 CFR 63.654(f)(1)(iv)(B)]
• The value of the monitored parameter
specified in 40 CFR 63 Subpart CC, Table 10 (shown in Table 4-3), or a site
specific parameter approved by the permitting authority, averaged over the full
period of the performance test.
Results of a prior performance test can be used if that test was conducted using the
methods specified in 40 CFR 63.645 and test conditions were representative of current
operating conditions.
Required Supporting Information
For Each Test Method Used:
1)
Sampling site description
2)
Description of sampling and

analysis procedures, and any

modifications to standard

procedures
3)
Quality assurance procedures
4)
Record of operating conditions

during the test
5)
Record of preparation of

standards
6)
Record of calibrations
7)
Raw data sheets for field

sampling
8)
Raw data sheets for field and

laboratory analyses
9)
Documentation of calculations
10)
Any other information required

by the test method.
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TABLE 4-3. 40 CFR Part 63, Subpart CC, Table 10 Parameters
Control Device
Parameters to be Monitored
Thermal incinerators
Firebox temperature
Catalytic incinerators
Temperature upstream and downstream of the catalyst bed
Boiler or process heater with a design
heat capacity < 44 MW where the vent
stream is not introduced into the flame
zone
Firebox temperature
Flare
Presence of a flame at the pilot light
All Control Devices
Presence of flow diverted to the atmosphere from the control
device, or monthly inspections of sealed valves
Specific NCS Reports For Vents Controlled By a Flare
In addition to the above requirements, vents controlled by a flare are required to include
performance test results applicable to the specific testing of the flare. For vents routed to a
flare, the NCS report must include the following performance test information:
•	All visible readings
•	Heat content determinations
•	Flow rate measurements
•	Exit velocity determinations
•	A statement of whether a flame was present at
the pilot light over the full period of the
compliance determination
•	If a parameter other than the presence of a
pilot flame is monitored, the acceptable range
for the parameter and the rationale (including
any supporting data or calculations) for the
range.
Specific NCS Reports For Vents Routed to an
Incinerator or Boiler or Process Heater < 44
MW Where the Vent Streams are NOT
Introduced Into the Flame Zone.
Do NCS Reports Have to be
Submitted If the Same Test is
Conducted for Multiple
Emission points?
Vents for which initial performance
tests are required must also submit
one complete test report for each
test method used for each emission
point. If the refinery uses the same
method for additional tests, the
additional test results must be
submitted, but additional complete
test reports are not required.
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In addition to the above requirements, vents routed to an incinerator or boiler or process
heater < 44 MW where the vent streams are not introduced into the flame zone must
include the following in the NCS report:
•	Average firebox temperature (or gas stream temperature for catalytic incinerators)
over the duration of the performance test
•	Acceptable range for the daily average firebox temperature and rationale for the
range
•	Times at which an operating day begins and ends.
Periodic Reports
When Are Periodic Reports Required?
Periodic reports are required only if the refinery experiences any compliance exceptions or
periods of excess emissions. Periods of excess emissions are defined as shown in the
box on the following page. Compliance exceptions include any of the exceptions
described in Section 3.3. Compliance exceptions and periods of excess emissions do
not include periods of startup, shutdown, malfunction, performance testing and monitoring
system calibration.
If Periodic Reports Are Required, When Must They Be Submitted?
Periodic reports must be submitted no later than 60 days after the end of each 6-month
period when any compliance exceptions occur. (The first 6-month period begins on the
date the NCS report is required to be submitted.) Quarterly reporting is required if the
refinery uses emissions averaging, which is discussed in Section 4.7 below.
What Must Be Included In Periodic Reports?
General contents of periodic reports are described in Chapter 3. For miscellaneous
process vents, periodic reports must also include excess emissions for the operating
parameters applicable to the vents (either parameters in Table 4-4 of this manual, or
others specified by the permitting authority).
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What is a Period of Excess Emissions?
1)	An operating day when the daily average value of a monitored parameter, except presence
of a flare or pilot flame, is outside the range specified in the NCS.
2)	For each vent routed to a flare, operating days when all pilot flames of a flare are absent.
3)	An operating day when monitoring data required to be recorded (see section 4.1.6) is
available for less than 75% of the operating hours.
4)	For approved data compressions systems, an operating day when the monitor operated for
less than 75% of the operating hours or a day when less than 18 monitoring values were
recorded.
4.1.5 What are the Recordkeeping Requirements for
Miscellaneous Process Vents?
As with the reporting requirements for miscellaneous process vents, there are also
overlapping recordkeeping requirements for the various control devices, as well as some
recordkeeping requirements specific to individual control devices. For all control devices,
it is necessary to retain for 5 years all information that must be reported.
In addition to information that must be reported, refineries may be required to maintain
records applicable to specific process vents as shown in Table 4-4.
TABLE 4-4. Additional Recordkeeping Requirements
Control Device
Required Records
Control devices for which an initial
performance test is required (flare,
incinerator, and boiler or process
heater < 44 MW where the vent
streams are not introduced into the
flame zone)
•	Complete test report for initial performance test results
•	Times and duration of periods when monitoring devices
are not operating
Vents routed to a flare
• Record of each pilot flame determination (or alternate
parameter upon request and approval)
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Petroleum Refinery MACT Standard Guidance
Vents routed to an incinerator or
• Record of each firebox temperature value or a block
boiler or process heater < 44 MW
average of values for periods of one hour or less
where the vent streams are not

introduced into the flame zone
• Record of the daily average of firebox temperature.

However, if all hourly temperature values are within the

range reported in the NCS, the facility may record that

all values are within the range instead of daily average

values.
For additional information on general recordkeeping requirements applicable to
miscellaneous process vents and all other process units, refer to Section 3.4 of this
manual.
4.2 What are the Requirements for Storage Vessels?
Group 1 storage vessels covered by the MACT standard include vessels storing organic
liquids that contain organic HAPs. In order to determine if a storage vessel is subject to the
MACT standard, refer to the applicability flowchart for storage vessels in Chapter 2.
The HAP weight percent criteria may be determined using engineering judgement or test
results. The vapor pressure criteria may be determined by using one of the following:
•	Information in standard reference texts
•	Methods described in API publication 2517 (Evaporative Loss from External Floating-
Roof Tanks)
•	Tests conducted using ASTM Method D2879-83
•	Any other approved method.
4.2.1 What are the Control Requirements for Storage
Vessels?
Storage vessels, that store a liquid with a maximum true vapor pressure of total organic
HAPs < 76.6 kPa, must be controlled by one of the following control methods [40 CFR
63.119(a)(1)]:
Floating Roofs
(1)	Internal floating roof with specified seals; or
(2)	External floating roof with specified seals; or
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Petroleum Refinery MACT Standard Guidance
(3)	External floating roof converted to internal floating roof with specified seals; (i.e., fixed
roof installed above the external floating roof)
Closed Vent Systems
(4)	Closed vent system routed to a flare or other control device that reduces HAP
emissions by 95% or to 20 ppmv.
Storage vessels that store a liquid with a maximum true vapor pressure of total organic
HAPs > 76.6 kPa must be controlled by a closed vent system and control device. [40 CFR
63.119(a)(2)] In addition, work practices, as specified in 40 CFR 63.119(b) through (e),
must be followed for each of the control methods.
The above control methods apply to both existing and new sources. For storage vessels
at new sources, deck fitting controls, as specified in 40 CFR 63.119(c)(2)(l) through (xii),
must be installed on all floating roof tanks. In addition, the control requirements of 40 CFR
63.119(b)(5) and (b)(6) also apply.
As indicated above, the four control methods for storage vessels generally fit into two
categories for testing, monitoring, reporting, and recordkeeping requirements. The first
three methods fall under the category of floating roofs, while the last item is in the category
of closed vent systems with control device. Although some of the requirements described
below are specific to individual control methods within the two categories, most of the
requirements apply to all control methods within each of the two categories.
4.2.2 What are the Testing Requirements for Storage Vessels?
As with other emission points, certain storage vessels are required to be tested during an
initial performance test, and follow-up tests in the event of process changes. This initial
test is required to ensure that the control equipment is operating properly, and that
emissions are within specified limits.
For storage vessels equipped with a closed vent system routed to control device, an initial
performance test must be performed. However, there are no testing requirements for
storage vessels equipped with a floating roof.
Initial Performance Tests
Closed Vent System Routed to a Flare
For storage vessels equipped with a closed vent system routed to a flare, testing
requirements include an initial performance test or compliance determination, as specified
in 40 CFR 63.11 (b), to ensure compliance with the control requirement to reduce total
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Petroleum Refinery MACT Standard Guidance
organic HAP emissions by 95% or to 20 ppmv. The test must include the
measurement/determination of the following:
•	Emissions visibility
•	Net heat value of combusted gas
•	Flow rate of gases being combusted
•	Exit velocity.
Closed Vent System Routed to a Control Device Other Than a Flare
For storage vessels equipped with a closed vent system routed to a control device other
than a flare, testing requirements include either an initial design evaluation, as specified in
40 CFR 63.120(d)(1 )(l), or an initial performance test, as specified in 40 CFR
63.120(d)(1)(ii).
4.2.3 What are the Monitoring and Inspection Requirements
for Storage Vessels?
For storage vessels that must apply controls, there are monitoring and inspection
requirements to ensure continuing compliance with the control requirements. The
requirements vary according to the control method used, with similarities for all closed vent
systems and similarities for all floating roofs.
Monitoring Requirements
For storage vessels equipped with a closed vent system, the facility must monitor the
parameters proposed in the Notice of Compliance Status report to ensure that the control
device is being properly operated and maintained. There are no monitoring requirements
for storage vessels equipped with floating roofs.
Inspection Requirements
Closed Vent Systems
Inspections of control equipment are also required periodically to demonstrate compliance
with the control requirements. For a closed vent system routed to a control device, the
facility must inspect the closed vent system, as specified in 40 CFR 63.148, every 12
months.
Floating Roofs
Storage vessels with floating roofs may have a single-seal system or a double-seal
system. For vessels with a double seal, the requirements for the secondary (outer) seal do
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Petroleum Refinery MACT Standard Guidance
not apply when gaps in the primary (inner) seal are being measured. For storage vessels
equipped with a fixed roof and an internal floating roof or an external floating roof converted
to an internal floating roof, the following inspection requirements apply for each type of seal
system:
Single-Seal System
/ Visually inspect the internal floating roof and primary seal through manholes and
roof hatches at least once every 12 months after initial fill, or at least every 12
months after the compliance date.
/ Visually inspect the internal floating roof and primary seal each time the storage
vessel is emptied and degassed and at least once every 10 years after the
compliance date.
/ Visually inspect gaskets, slotted membranes, and sleeve seal (if any) each time
the storage vessel is emptied and degassed and at least once every 10 years after
the compliance date (new source only).
Double-Seal System
/ Visually inspect the internal floating roof, primary seal, and secondary seal each
time the vessel is emptied and degassed and at least once every 5 years after the
compliance date; or
/ Visually inspect the internal floating roof and the secondary seal through manholes
and roof hatches at least once every 12 months after initial fill, or at least every 12
months after the compliance date; and
/ Visually inspect the internal floating roof, primary seal, and secondary seal each
time the vessel is emptied and degassed and at least once every 10 years after the
compliance date.
For storage vessels equipped with an external floating roof, the facility must visually inspect
the external floating roof, the primary and secondary seals, and fittings each time the
vessel is emptied and degassed. In addition, the following inspection requirements apply
for each type of seal system:
Single-Seal System
/ Measure the gaps between the vessel wall and the primary seal by the compliance
date and at least once a year, until a secondary seal is installed. When a
secondary seal is installed, measure gaps between the vessel wall and both the
primary and secondary seal within 90 calendar days of installation, and then comply
with the double-seal inspection requirements below. [40 CFR 63.120(b)(1 )(ii)]
Double-Seal System
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Petroleum Refinery MACT Standard Guidance
/ Measure the gaps between the vessel wall and the primary seal during hydrostatic
testing or by the compliance date and at least once every 5 years thereafter
/ Measure the gaps between the vessel wall and the secondary seal by the
compliance date and at least once a year.
4.2.4 What are the Reporting Requirements for Storage
Vessels?
Reporting requirements for storage vessels include Notice of Compliance Status reports,
periodic reports, and internal inspection notification. As with testing and monitoring,
reporting requirements for storage vessels include some requirements applicable to all
four control methods, some requirements applicable to the two general control categories
(i.e., closed vent systems and floating roofs), and some requirements specific to individual
control methods. The following subsections discuss the specific information required for
storage vessels in each of these reports.
Notice of Compliance Status Report
Section 3.3.3 of this manual lays out the basic requirements for a NCS report. The MACT
standard sets out additional NCS requirements for storage vessels equipped with closed
vent systems, but not for storage vessels with floating roofs.
Closed Vent System Routed to a Flare
For storage vessels equipped with a closed vent system routed to a flare, the NCS must
also contain the results of the initial performance test, including:
•	Flare design, such as steam-assisted, air-assisted, or non-assisted
•	Visible emissions readings
•	Heat content determinations
•	Flow rate measurements
•	Exit velocity determinations
•	Periods during the compliance determination when the pilot flame is absent.
Closed Vent System Routed to a Control Device Other Than a Flare
For storage vessels equipped with a closed vent system routed to a control device other
than a flare, the NCS must also include:
•	Description of the parameter(s) to be monitored to ensure proper operation and
maintenance of the control device
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•	Explanation of the parameter selection
•	Frequency of monitoring
•	Design evaluation documentation, as specified in 40 CFR 63.120(d)(1 )(l), or
results of the initial performance test including identification of emission points
sharing the control device.
Periodic Reports
As mentioned previously in this section and in Chapter 3, periodic reports are only
required if compliance exceptions occur. The information required in periodic reports falls
into the 2 general categories of control methods: closed vent systems and floating roofs,
with a few additional requirements for external floating roofs.
Closed Vent Systems
Routed To Any Control
Device
For storage vessels equipped
with a closed vent system
routed to a control device,
periodic reports must include a
description of the following:
•	Routine maintenance
for the control device
that was performed
during the previous 6
months
•	Routine maintenance
anticipated for the
control device for the
next 6 months
•	For a control device
that is a flare, each
occurrence and cause
when the requirements
specified in 40 CFR
63.11(b) are not met
What Are Compliance Exceptions For Storage
Vessels?
Compliance exceptions refer to the following failures
or defects in the control equipment:
• Floating roof not resting on the surface of the liquid
inside the vessel and not resting on the leg
supports
•	Liquid floating on the floating roof
•	Seal detached from the floating roof
•	Holes, tears, or other openings in the seal or
seal fabric
•	Visible gaps between the seal and the wall of
the vessel
•	Gaskets no longer close off the liquid surface
from the atmosphere
•	Slotted membrane has more than a 10% open
area (new source only).
Compliance exceptions also include occurrences
when monitored parameters are outside the
parameters established in the NCS.
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•	For a control device other than a flare, each occurrence and cause of monitored
parameters being outside the ranges documented in the NCS.
Floating Roofs
For storage vessels equipped with any type of floating roof, periodic reports must contain
the results of each inspection in which a failure was detected. Periodic reports must
include the following information:
•	Date of inspection
•	Identification of the storage vessel
•	Description of the failure
•	Nature and date of repair or date the vessel was emptied.
If a failure or defect is detected during inspection, the facility must repair or empty and
remove the vessel from service within 45 days. If the vessel cannot be repaired or emptied
within 45 days, the facility may utilize up to 2 extensions of up to 30 additional days each. If
an extension is used, periodic reports must also include the following information:
•	Description of the failure
•	Statement that alternate storage capacity is unavailable
•	Schedule of actions that will ensure that the control equipment will be repaired or
the vessel will be emptied as soon as possible.
Additional reporting requirements for storage vessels equipped with an external floating
roof include notifying the Administrator 30 days in advance of any gap measurement.
Results of each gap measurement in which the requirements of 40 CFR 63.120(b)(3), (4),
(5), or (6) are not met must also be reported in the periodic reports. Such results must
include the following information:
•	Date of seal gap measurement
•	Raw data and calculations described in 63.120(b)(5) or (6)
•	Description of seal conditions that are not met
•	Nature and date of repair or date the vessel was emptied.
Periodic reports should also include a Notification of Compliance Status (NCS) report if a
floating roof storage vessel is brought into compliance during the reporting period.1
The NCS must include the following information:
•	The method of compliance for each storage vessel brought into compliance.
-1
This requirement reflects an amendment to 40 CFR Part 63 Subpart CC made on August 18,
1998. For more information, see Appendix G.
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•	The expected compliance date for all floating roof storage vessels subject to control
requirements that are not yet in compliance (floating roof storage vessels have until
August 15, 2005 or the next scheduled emptying and degassing to be brought into
compliance).
•	For floating roof vessels that are in compliance, the actual compliance date.
Internal Inspection Notification
The third category of reporting directly applicable to storage vessels is notifying the
Administrator of scheduled internal inspections and refilling of empty storage vessels with
organic HAPs. Refineries are required to notify the Administrator at least 30 calendar
days prior to filling or refilling each storage vessel with organic HAPs. The 30-day
notification is required except if:
•	The internal inspection required by 40 CFR 1209(a)(2), 63.1299(a)(3), or
63.120(b)(10) is not planned, and
•	The owner/operator of the refinery could not have known about the inspection 30
calendar days in advance of refilling the vessel with organic HAPs.
If the inspection is not planned and the owner/operator could not have known about it in
advance, the Administrator must be notified at least 7 calendar days prior to refilling the
storage vessel. Notification may be made by telephone and immediately followed by
written documentation demonstrating why the inspection was unplanned. The notification
may also be made in writing provided that it is received by the Administrator at least 7
calendar days prior to the refilling.
If the State or local permitting authority has received delegation of the Refinery MACT (not
all states have as of August 1997), they can waive the notification requirements for all or
some storage vessels at petroleum refineries. The State or local permitting authority may
also grant permission to refill storage vessels sooner than 30 days after submitting the
required notification under 40 CFR 64.654(h)(2)(i)(A) or sooner than 7 days after
submitting the notification under 40 CFR 64.654(h)(2)(i)(B) on a case-by-case basis.
4.2.5 What are the Recordkeeping Requirements for Storage
Vessels?
There are recordkeeping requirements common to all storage vessels, as well as some
recordkeeping requirements specific to the different control methods. For all storage
vessels, it is necessary to maintain records of Group 1 or Group 2 determinations, vessel
dimensions, and analysis of capacity. In addition, all information required to be reported
must be retained for 5 years.
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Closed Vent Systems Routed To Any Control Device
For storage vessels equipped with a closed vent system routed to a control device,
additional recordkeeping requirements include:
•	Complete test report for initial performance test results
•	Measured values of monitored parameters
•	Planned routine maintenance performed, including:
-	The first time of day and date the control requirements are not met at the beginning
of the planned routine maintenance, and
-	The first time of day and date the control requirements are met at the conclusion of
the planned routine maintenance.
Floating Roofs
For storage vessels equipped with any type of floating roof, recordkeeping requirements
include retaining records of each inspection performed. [40 CFR 63.123(c) and (e)] For
storage vessels equipped with an external floating roof, additional requirements involve
retaining records of each seal gap measurement, including date, raw data obtained in the
measurement, and the calculations described in 40 CFR 63.120(b)(3) and (4).
4.3 What are the Requirements for Wastewater
Streams?
In order to determine if a wastewater stream is subject to the MACT Standard, refer to the
applicability flowchart for wastewater streams in Chapter 2. Refineries in compliance with
the benzene waste NESHAP [40 CFR 61 Subpart FF] are considered to be in compliance
with the refinery MACT standard. Provisions of the benzene waste NESHAP apply to the
following wastewater streams at petroleum refineries:
(1)	Total benzene loading > 10 Mg per year, and
(2)	Flow rate > .02 liters per minute, and
(3)	Benzene concentration > 10 ppm by weight, and
(4)	Not exempt from controls under the benzene waste NESHAP.
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4.3.1	What are the Control Requirements for Wastewater
Streams?
Wastewater streams meeting the applicability criteria above are required to comply with
the control requirements of the benzene waste NESHAP [40 CFR 61 Subpart FF], These
control requirements include the following:
•	Wastewater streams must reduce benzene mass emissions by 99% by using
suppression followed by steam stripping, biotreatment, or other treatment process.
•	Vents from steam strippers and other waste management or treatment units must
have a control device that achieves 95% emission reduction or 20 ppmv at the
outlet of the control device.
4.3.2	What are the Testing Requirements for Wastewater
Streams?
All wastewater streams must comply with the testing requirements of the benzene waste
NESHAP found in 40 CFR 61.340 through 61.355. These sections also specify the
frequency for which testing must be done. If required, periodic measurements of benzene
concentration in the wastewater must be performed.
4.3.3	What are the Monitoring Requirements for
Wastewater Streams?
All wastewater streams must also comply with the monitoring requirements of the benzene
waste NESHAP found in 40 CFR 61.340 through 61.355. If required, monitoring of the
process or control device operating parameters must be performed.
4.3.4	What are the Reporting and Recordkeeping
Requirements for Wastewater Streams?
All wastewater streams must comply with the reporting requirements of the benzene waste
NESHAP found in 40 CFR 61.356 and 61.357. [40 CFR 63.654(a)] In addition, all
information required to be reported must be retained for 5 years. [40 CFR 63.654(l)(4)]
Since affected sources should already be in compliance with 40 CFR 61 Subpart FF, they
will not need to make any changes to their current reporting and recordkeeping
procedures.
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4.4 What are the Requirements for Gasoline Loading
Racks?
In order to determine if a gasoline loading rack is subject to the MACT standard, refer to
the applicability flowchart for gasoline loading racks in Chapter 2.
4.4.1 What are the Control Requirements for Gasoline
Loading Racks?
Gasoline loading racks that are subject to the MACT standard must be in compliance with
the gasoline distribution facilities NESHAP found in 40 CFR 63 Subpart R, which requires
the following:
(1)	Reduce emissions of total
organic compounds (TOC) to 10
milligrams per liter of gasoline
loaded; and
(2)	Load gasoline only in vapor tight
cargo tanks that have been tested
to assure vapor tightness.
4.4.2 What are the
Testing and
Monitoring
Requirements for
Gasoline Loading
Racks?
For all gasoline loading racks subject
to the MACT standard, the facility
must comply with the testing and
monitoring requirements of the
gasoline distribution facilities
NESHAP. These tests are found in
40 CFR 63.425(a) through (c)
(performance tests), 63.425(e)
(annual certification), 63.425(f) (leak
detection tests), 63.425(g) (nitrogen
Procedure For Initial Performance Testing
of Gasoline Loading Racks:
Initial performance tests must determine a
monitored operating parameter value for the
vapor processing system using the following
procedure:
1)	During the performance test, continuously
record the operating parameters under 40
CFR 63.427.
2)	Determine an operating parameter value
based on the parameter data monitored
during the performance test, supplemented
by engineering assessments and the
manufacturer's recommendations, and
3)	Provide for the Administrator's approval the
rationale for the selected operating
parameter value, and monitoring frequency
and averaging time. This includes data and
calculations used to develop the value and a
description why the value, monitoring
frequency, and averaging time demonstrate
continuous compliance with the emission
standard in 40 CFR 63.422(b) or
60.112b(a)(3)(ii).
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pressure decay field tests), 63.425(h) (continuous performance pressure decay test) and
63.427 (continuous monitoring).
Initial Performance Test
The initial performance test is required to be conducted according to the test methods and
procedures in 40 CFR 60.503, except a reading of 500 ppm must be used to determine
the level of leaks to be repaired under 40 CFR 60.503.
For follow-up tests (required to be conducted following process changes), the refinery is
required to document the reasons for any change in the operating parameter value since
the previous test.
What If A Closed Vent System Is Used To Control Emissions?
If a closed vent system and control device, as specified in 40 CFR 60.112b(a)(3), is
required to comply with the control requirements for gasoline loading racks, initial
performance tests are required. [40 CFR 63.423]
What If a Flare Is Used To Control Emissions?
If a flare is used, and emissions from the gasoline loading rack cannot be measured using
the methods specified in 40 CFR 60.503, the refinery is required to comply with the
provisions of 40 CFR 63.11 (b).
Annual Certification Tests
In addition to the initial performance test, gasoline cargo tanks are required to be tested
annually to certify that emissions controls are functioning properly. The annual
performance test must be conducted according to the vacuum and pressure tests
described in Method 27 of 40 CFR 60 Appendix A.
Leak Detection Tests
During loading operations, the facility is required to conduct a leak detection test for
gasoline cargo tanks according to Method 21 of 40
CFR 60 Appendix A. The tests are required to be
conducted on each compartment during the loading
of that compartment, or while the compartment is still
under pressure. In addition to Method 21, the
following additional requirements for the test apply
[40 CFR 63.425]:
How Are Leaks Defined
for gasoline cargo tanks?
A leak is defined as a
reading of 21,000 ppm or
more propane.
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Petroleum Refinery MACT Standard Guidance
•	To eliminate a positive instrument drift, the dwell time for each leak detection may
not exceed two times the instrument response time. The instrument must be purged
with ambient air between each leak detection, and the duration of the purge must
be in excess of two instrument response times.
•	The facility must attempt to block the wind from the area being monitored, and
record the highest detector reading and location for each leak.
Additional Testing Requirements
Cargo tanks with manifolded product lines are required to conduct a nitrogen pressure
decay field test on each compartment of each tank. This test is described in 40 CFR
63.425(g). A continuous performance pressure decay test, as described in 40 CFR
63.425 (h), is also required.
Continuous Monitoring
Gasoline loading racks are required to be in compliance with the continuous monitoring
requirements of 40 CFR 63.427(a) and (b). The continuous monitoring system must be
installed, calibrated, certified, operated and maintained according to manufacturer
specifications. The location where the continuous monitoring system must be installed
depends on the type of system used (e.g., carbon adsorption, refrigeration condenser,
thermal oxidation, or flare).
4.4.3 What are the Reporting and Recordkeeping
Requirements for Gasoline Loading Racks?
For gasoline loading racks, the facility must comply with the reporting and recordkeeping
requirements of the gasoline distribution facilities NESHAP found in 40 CFR 63.428(b),
(c), (g)(1), and (h)(1) through (h)(3). The initial notification report under 40 CFR 63.428(a)
is to be submitted with the initial NCS for the refinery, 150 days after the compliance date.1
All required records must be retained for 5 years.
4.5 What are the Requirements for Marine tank vessel
LOADING?
-1
This requirement reflects an amendment to 40 CFR Part 63 Subpart CC made on August 18,
1998. For more information, see Appendix G.
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Petroleum Refinery MACT Standard Guidance
In order to determine if marine tank vessel loading is subject to the MACT standard, refer
to the applicability flowchart for marine tank vessel loading in Chapter 2.
4.5.1	What are the Control Requirements for Marine tank
VESSEL LOADING?
Marine tank vessel loading operations that are subject to the MACT standard must be in
compliance with the marine tank loading NESHAP found in 40 CFR 63 Subpart Y, which
requires the following:
Existing Sources: • Collect vapors discharged during loading
•	Load only in vapor tight vessels
•	Reduce collected HAP emissions by 97% or use vapor
balancing.
New Sources:	• Same as existing sources, except reduce collected HAP
by 98% or use vapor balancing.
4.5.2	What are the Testing and Monitoring Requirements for
Marine Tank Vessel Loading?
For all marine tank vessel loading operations subject to the MACT Standard, the refinery
must comply with the testing and monitoring requirements of the marine tank loading
NESHAP found in 40 CFR 63.560 through 63.567.
4.5.3 What are the Reporting and Recordkeeping
Requirements for Marine tank vessel loading?
For all marine tank vessel loading subject to the MACT standard, the refinery must comply
with the reporting and recordkeeping requirements of the marine tank loading NESHAP
found in 40 CFR 63.566, 63.567(a) and (c) through (I). The Initial Notification Report under
40 CFR 63.567(b) is not required. All required records must be retained for 5 years.
4.6 What are the Requirements for Equipment Leaks?
In order to determine if an equipment leak is subject to the MACT standard control
requirements, refer to the applicability flowchart for equipment leaks in Chapter 2. The 5%
HAP service criterion is determined using test methods and procedures specified in 40
CFR 63.180.
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Petroleum Refinery MACT Standard Guidance
4.6.1	What are the Control Requirements for Equipment
Leaks?
For equipment leaks at existing sources, the facility must comply with either of the
following equipment leaks provisions:
(1)	40 CFR 60 Subpart W (synthetic organic chemical manufacturing industry (SOCMI)
equipment leaks NSPS), or
(2)	Modified 40 CFR 63 Subpart H (hazardous organic NESHAP (HON) negotiated
regulation).
For equipment leaks at new sources, the facility must comply with modified 40 CFR 63
Subpart H.
4.6.2	What are the Testing, Inspection, and Monitoring
Requirements for Equipment Leaks?
For all equipment leaks subject to the MACT standard, the refinery must comply with the
testing, inspection, and monitoring requirements for equipment leaks in 40 CFR 60.1046
and 60.1047 (40 CFR 60 Subpart W), or 40 CFR 63.162 through 63.180 (40 CFR 63
Subpart H).
4.6.3	What are the Reporting and Recordkeeping
Requirements for Equipment Leaks?
For all equipment leaks subject to the MACT Standard, the refinery must comply with the
reporting and recordkeeping requirements for equipment leaks found in 40 CFR 60.1048
and 60.1049 (40 CFR 60 Subpart W) (except that the name rather than the signature of
the person deciding to delay repair must be recorded)1 , or 40 CFR 63.181 and 63.182
(40 CFR 63 Subpart H) (except for 63.182(b), (c)(2), and (c)(4)).
4.7 Emissions Averaging
The Petroleum Refinery NESHAP [40 CFR 63 Subpart CC] is stated as a source-wide
emissions allowance, as represented by the equation in 40 CFR 63.642. As mentioned in
Chapter 2, there are 2 general approaches for petroleum refineries to comply with the
MACT standard's control requirements for achieving the emissions allowance:
-1
This requirement reflects an amendment to 40 CFR Part 63 Subpart CC made on August 18,
1998. For more information, see Appendix G.
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Petroleum Refinery MACT Standard Guidance
(1)	Implement controls on all emission points, as discussed in the previous sections of this
chapter; or
(2)	Use a method called emissions averaging, which allows flexibility in applying controls.
Emissions averaging allows facilities to overcontrol some emission points and
undercontrol others in order to achieve the required emissions reductions in the most cost-
effective manner. Additional flexibility is provided by permitting the use of emissions
averaging among petroleum refineries, gasoline distribution facilities, and marine terminal
loading operations located at the same site. Emissions averaging can only be used for
existing sources.
4.7.1	Emissions Averaging Applicability
Emissions averaging is allowed for miscellaneous process vents, storage vessels,
wastewater streams, gasoline loading racks, and marine tank vessel loading operations in
SIC 2911 at a refinery. Emissions averaging is not allowed across sources, such as
across different plant sites or between refinery and HON sources (i.e., units having a
hazardous organic air pollutant as its primary product) at the same plant site. In addition,
an emissions estimation is only required for points included in emissions averages, not for
all points in the source.
A limitation on the emissions averaging provision is that States have the authority to
disallow emission averaging and require the application of standard control requirements
to all emission points.
4.7.2	Emissions Averaging Credit/Debit System
Emissions averaging provides a credit/debit system for calculating emissions to comply
with the overall emissions allowance. Facilities receive credits for overcontrol of emission
points - control above what is required in Subpart CC, and debits for undercontrol of
emission points - control below what is required in Subpart CC. Emission credits and
debits are calculated on a mass basis using equations in 40 CFR 63.652(g) and (h) to
estimate emissions based on actual operations. Credits calculated must be greater than
or equal to debits calculated on an annual basis. [40 CFR 63.652(e)(3)] In addition,
debits may not exceed credits by more than 30% in any one quarter. [40 CFR 652(e)(4)]
The following emission points can be used to generate emissions averaging credits [40
CFR 63.652(c)(1) through (3)]:
•	Group 2 emission points
•	Group 1 emission points controlled by technology with a higher nominal efficiency
than the reference control technology
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Petroleum Refinery MACT Standard Guidance
•	Emission points from which emissions are reduced by pollution reduction
measures, alone or in conjunction with other controls, that get more emission
reduction than required
The following emission points cannot be used to generate emissions averaging credits [40
CFR 63.652(d)]:
•	Emission points already controlled on or before November 15, 1990, unless the
level of control was increased after November 15, 1990. If so, credit is allowed for
the increase only
•	Group 1 emission points that are controlled by a reference control technology,
unless the technology has been approved for use in a different manner and a higher
nominal efficiency has been assigned. For example, it is not allowable to claim that
an internal floating roof meeting only the specifications stated in the reference
control technology definition in 40 CFR 63.641 applied to a storage vessel is
achieving greater than 95 percent control
•	Emission points on shutdown process units
•	Emission points controlled to comply with a State or other Federal rule, unless the
level of control has been increased after November 15, 1990 above what is
required by the State or other Federal rule. If so, credit is allowed for the increase
only.
Debits are generated if the required level of control of a Group 1 emission point, such as
98% for miscellaneous process vents and 95% for storage vessels, is not achieved. [40
CFR 63.652(g)] (See Table 2.3 for required level of control.) Debits and credits are
calculated using formulas found in 40 CFR 63.652(g) and (h). Calculations may not
include emissions from the following:
•	Wastewater that is not process wastewater or wastewater streams treated in
biological treatment units. Group 1 wastewater streams cannot be left
undercontrolled or uncontrolled to generate debits [40 CFR 63.652(d)(4)]
•	More than 20 individual emission points in addition to those controlled by pollution
prevention measures. Where pollution prevention measures are used, no more
than 25 emission points total may be included in the average [40 CFR 63.652(f)(1)]
•	Emission points during periods of startup, shutdown, and malfunction [40 CFR
63.652(f)(2)]
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Petroleum Refinery MACT Standard Guidance
• Emission points for which continuous monitors are used and excess emissions
occur. [40 CFR 63.652(f)(3)] For these periods, the monthly credits and debits will
be adjusted as specified in 40 CFR 63.652(f)(3)(l) through (iii).
4.7.3	Approval of Emissions Averaging Plan
Facilities that wish to use emissions averaging to comply with the source-wide emissions
allowance, must submit for approval an emissions averaging plan in the Implementation
Plan or Operating Permit Application. The plan must demonstrate that the credits will be
sufficient to offset the debits under representative operating conditions. [40 CFR
63.652(e)(3)(l)] The plan may include use of innovative technologies, different from the
reference control technology, provided that the innovative technologies achieve greater
than the level of control required for a Group 1 emission point. In addition, the facility must
include a risk assessment in the plan of any hazards or risks of the plan, such as the risk
from one large emission point versus the risk from combined emission points. Such
hazards and risks must be reviewed and compared to point-by-point compliance.
4.7.4	Testing, Monitoring, Reporting, and Recordkeeping for
Emissions Averaging
For each emission point included in an emissions average, facilities must perform testing,
monitoring, reporting, and recordkeeping equivalent to the requirements for Group 1
emission points that are not included in emissions averaging. [40 CFR 63.653(a)] See
Chapter 3 for general requirements and previous sections in this chapter for emission
point specific requirements. One additional requirement is to maintain the monthly
calculations of debits and credits.
4.7.5	Recordkeeping for Emissions Averaging
Requirements for emissions averaging include maintaining the following:
•	Initial performance test results (if applicable)
•	Monthly debits, credits, and calculations using EPA-specified calculation
procedures
•	Operating parameter monitoring results.
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Petroleum Refinery MACT Standard Guidance
4.8 Conclusions
Chapter 4 completed the discussion of requirements of the MACT standard by detailing
requirements that are specific to each emission point, and discussed the alternative
compliance method of emissions averaging. This chapter explained the requirements for
emissions from miscellaneous process vents, storage vessels, wastewater streams,
gasoline loading racks, marine tank vessel loading, and equipment leaks. For each type
of emission point, the chapter discussed control requirements, followed by an explanation
of testing, monitoring, reporting and record keeping requirements. The chapter concluded
by discussing how a facility could use emissions averaging to meet the requirements of the
standard, rather than control each emission point.
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Petroleum Refinery MACT Standard Guidance
5. INTERRELATIONSHIP OF THE PETROLEUM
Refinery MACT Standard with Other
Regulations
This chapter summarizes the interrelationship between the MACT standard and other
regulations. As described in previous chapters, the MACT standard requires that HAP
emissions be controlled from various emission points within the petroleum refinery. Some
of these emission points may also be subject to other existing regulations including the
New Source Performance Standards (NSPS) or other NESHAPs. It was not EPA's intent
to have redundant regulations that put an undue burden on the owner/operator of a
petroleum refinery, but to allow sources to comply with only the most stringent regulation
which will demonstrate compliance with all applicable regulations.
The applicability of 40 CFR 63 Subpart CC versus 40 CFR 63 Subpart G, hazardous
organic NESHAP (HON), or some other MACT standard, to an emission point is
determined by the primary product produced at the unit. The primary product is that
produced in the greatest mass or volume by the unit. For instance, if the unit produces a
hazardous organic as the primary product, then it is subject to the HON. If a unit is integral
to the petroleum refinery's operations, and produces hazardous organics in small
quantities, it is subject to the petroleum refining MACT standard.
EPA has also included a SIC code reference for petroleum refining (SIC 2911) in the
MACT Standard in order to clarify the applicability of the rule and reduce the potential
confusion of regulatory overlap.
The following describes the relationship of the MACT standard to existing regulations for
each process unit and related emission points:
Miscellaneous Process Vents: There are no existing regulations governing
miscellaneous process vents. Both Group 1 and Group 2 have to comply with the MACT
standard.
Storage Vessels: For storage vessels, there is an overlap between the MACT standard
and the following NSPS:
• 40 CFR 60 Subpart K, performance standards for petroleum liquid storage vessels
that were built or have undergone some kind of modification after June 11, 1973,
but before May 19, 1978
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Petroleum Refinery MACT Standard Guidance
•	40 CFR 60 Subpart Ka, performance standards for petroleum liquid storage
vessels that were built or have undergone some kind of modification after May 18,
1978, but before July 7, 1984
•	40 CFR 60 Subpart Kb, performance standards for volatile organic storage vessels
that have been modified after July 23, 1984.
The control requirements in the MACT standard reference the storage vessel provisions in
40 CFR 63 Subpart G. The MACT standard is applicable to all new Group 1 storage
vessels and to existing facilities not governed by 40 CFR 60 Subpart Kb. For Group 2
storage vessels, if the control requirements of Subparts K, Ka or Kb do not apply, the
vessel is subject to Subpart CC. All units that are not subject to Subparts K, Ka or Kb are
subject to the MACT Standard.
Owners/operators of internal floating roof or external floating roof tanks are allowed to
defer upgrading their seals to meet the NESHAP requirements until the next scheduled
inspection and maintenance activity or within 10 years, whichever comes first.
Wastewater Streams: For wastewater streams, the following regulations are cross-
referenced in the MACT standard:
•	40 CFR 60 Subpart QQQ, performance standards for VOC emissions from
petroleum refinery wastewater systems
•	40 CFR 61 Subpart FF, benzene waste operations NESHAP (BWON)
•	40 CFR 63 Subpart G, synthetic organic chemical manufacturing industry (SOCMI)
NESHAP (Subpart G).
New and existing sources in compliance with BWON are in compliance with the MACT
standard. The MACT standard is applicable only to Group 1 streams that are subject to 40
CFR 60 Subpart QQQ. For wastewater stream management units that receive streams
subject to the BWON and streams subject to 40 CFR Part 63 Subpart G, the MACT
standard clarifies which provisions of the BWON and which provisions of Subpart G must
be complied with. The specific provisions of each regulation that apply are specified in
§63.640(o)(2). Alternately, the owner/operator may comply with all of the requirements of
Subpart G only.1
Gasoline Storage Racks: Existing sources are governed by 40 CFR 63 Subpart R,
gasoline distribution facilities NESHAP, which is referenced in the MACT standard. New
sources are subject to 40 CFR Part 60 Subpart XX, but are required to comply only with
the requirements of the MACT standard.1
-1
This requirement reflects an amendment to 40 CFR Part 63 Subpart CC made on August 18,
1998. For more information, see Appendix G.
5.2

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Petroleum Refinery MACT Standard Guidance
Marine Tank Vessel Loading: These sources are subject to 40 CFR 63 Subpart Y,
marine tank loading NESHAP, which is referenced in the MACT standard.
Equipment Leaks: For equipment leaks, the following regulations are cross-referenced
in the MACT standard:
•	40 CFR 60 Subpart W, performance standards for equipment leaks from SOCMI
process units
•	Modified 40 CFR 63 Subpart H, HON negotiated equipment leak standard.
There are no group designations for equipment leaks. New sources must comply with the
40 CFR 63 Subpart H at startup, whereas existing sources can choose to comply with
either 40 CFR 60 Subpart W or 40 CFR 63 Subpart H. Also, the MACT standard does
not apply to units that are also subject to provisions of the HON.
Table 5-1 presents a summary of the existing regulations that may be applicable to each
emission point controlled under the MACT standard.
Conclusions
Chapter 5 discussed the relationship between the MACT Standard and existing
regulations. As was indicated in this chapter, the MACT Standard overlaps with certain
requirements for storage vessels, wastewater streams, gasoline storage racks, marine
tank vessel loading, and equipment leaks. Miscellaneous process vents are the one type
of emission point for which there are no existing requirements, and thus no overlap. This
chapter also described other federal standards with which refineries are required to
comply that are referenced in the MACT standard.
5.3

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TABLE 5-1. Overlap of the Petroleum Refinery MACT Standard (40 CFR 63 Subpart CC)
with Existing Regulations
cn
Source
Category
Source
Type
Source
Group
Existing Regulation
Must Comply With
Comments
Miscellaneous
Process
Vents
New/
Existing
1 / 2
N/A
40 CFR 63 Subpart CC:
NESHAP for petroleum refineries
No existing regulation
Storage
Vessels
Existing
1
40 CFR 60 Subpart K or Ka:
NSPS for petroleum liquids
40 CFR 63 Subpart CC:
NESHAP for petroleum refineries,
which references 40 CFR 63
Subpart G




40 CFR 60 Subpart Kb: nsps
forvolatile organic liquids
40 CFR 60 Subpart Kb: nsps
for volatile organic liquids



2
40 CFR 60 Subpart K or Ka:
NSPS for petroleum liquid
storage
40 CFR 60 Subpart K or Ka:
NSPS for petroleum liquids
If subject to control
requirements of 40 CFR 60
Subpart K or Ka



40 CFR 60 Subpart Kb: NSPS
forvolatile organic liquids
40 CFR 60 Subpart Kb: NSPS
forvolatile organic liquids


New
1
40 CFR 60 Subpart K or Ka:
NSPS for petroleum liquids
40 CFR 63 Subpart CC:
NESHAP for petroleum refineries,




40 CFR 60 Subpart Kb: nsps
forvolatile organic liquids
which references 40 CFR 63
Subpart G



2
40 CFR 60 Subpart K or Ka:
NSPS for petroleum liquids
40 CFR 60 Subpart K or Ka:
NSPS for petroleum liquids


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TABLE 5-1. Overlap of the Petroleum Refinery MACT Standard (40 CFR 63 Subpart CC)
with Existing Regulations (continued)
cn
cn
Source
Category
Source
Type
Source
Group
Existing Regulation
Must Comply With
Comments
Wastewater
Streams
New/
Existing
1
40 CFR 61 Subpart FF:
benzene waste operations
NESHAP (BWON)
40 CFR 61 Subpart FF:
benzene waste operations
NESHAP (BWON)




40 CFR 60 Subpart QQQ:
NSPS for VOC emissions from
petroleum refinery wastewater
systems only
40 CFR 63 Subpart CC:
NESHAP for petroleum refineries



2
40 CFR 60 Subpart QQQ:
NSPS for VOC emissions from
petroleum refinery wastewater
systems
40 CFR 60 Subpart QQQ:
NSPS for VOC emissions from
petroleum refinery wastewater
systems



1 / 2
40 CFR 63 Subpart G:
NESHAP for SOCMI process
vents, storage vessels, transfer
40 CFR 63 Subpart G: 53 133 .
63.137 &63.140
For equipment used in
storage and conveyance of
wastewater streams



operations, and wastewater
40 CFR 61 Subpart FF and
40 CFR 63 Subpart G: 53 -| 33 -
63.139
For treatment and control of
wastewater streams




40 CFR 63 Subpart G: 53 143 .
63.148
For monitoring and
inspection of equipment,
reporting, and
recordkeeping requirements




OR





40 CFR 63 Subpart G: 63.133-
63.148 &63.151 -63.152
Alternately, comply with
only the requirements of
Subpart G.1

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TABLE 5-1. Overlap of the Petroleum Refinery MACT Standard (40 CFR 63 Subpart CC)
with Existing Regulations (continued)
Source
Category
Source
Type
Source
Group
Existing Regulation
Must Comply With
Comments
Gasoline
Loading
Racks
New/
Existing
N/A
40 CFR 63 Subpart R:
gasoline distribution facilities
NESHAP
40 CFR 63 Subpart CC:
NESHAP for petroleum refineries,
which references 40 CFR 63
Subpart R


New
N/A
40 CFR 60 Subpart XX: n6vv
Source Standard for Bulk
Gasoline Terminals
40 CFR 63 Subpart CC:
NESHAP for petroleum refineries,
which references 40 CFR 63
Subpart R1

Equipment
Leaks
Existing
N/A
40 CFR 60 Subpart W: NSPS
for equipment leaks
OR
40 CFR 63 Subpart H: HON
equipment leaks
40 CFR 63 Subpart CC:
NESHAP for petroleum refineries,
which references 40 CFR 63
Subpart H
40 CFR 60 Subpart W: nsps
for equipment leaks
The new petroleum refinery
NESHAP allows owners
and operators of existing
sources to choose between
the two regulations.

New
N/A
40 CFR 63 Subpart H: HON
equipment leaks
40 CFR 63 Subpart CC:
NESHAP for petroleum refineries,
which references 40 CFR 63
Subpart H
New sources do not have a
choice like existing
sources.
cn
b)
1 This requirement reflects an amendment to 40 CFR Part 63 Subpart CC made on August 18, 1998. For more information, see
Appendix G.

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Petroleum Refinery MACT Standard Guidance
APPENDIX A. HAZARDOUS AIR POLLUTANTS (HAPS)
Chemical Name
CAS Number
Acetaldehyde
75070
Acetamide
60355
Acetonitrile
75058
Acetophenone
98862
2-Acetylam inofluorene
53963
Acrolein
107028
Aery lam ide
79061
Acrylic acid
79107
Acrylonitrile
107131
Allyl chloride
107051
4-Aminobiphenyl
92671
Aniline
62533
o-Anisidine
90040
Asbestos
1332214
Benzene (including benzene from gasoline)
71432
Benzidine
92875
Benzotrichloride
98077
Benzyl chloride
100447
Biphenyl
92524
Bis(2-ethylhexyl)phthalate (DEHP)
117817
Bis(chloromethyl)ether
542881
Bromoform
75252
1,3-Butadiene
106990
Calcium cyanamide
156627
Captan
133062
Carbaryl
63252
A.1

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Petroleum Refinery MACT Standard Guidance
Chemical Name
CAS Number
Carbon disulfide
75150
Carbon tetrachloride
56235
Carbonyl sulfide
463581
Catechol
120809
Chloramben
133904
Chlordane
57749
Chlorine
7782505
Chloroacetic acid
79118
2-Chloroacetophenone
532274
Chlorobenzene
108907
Chlorobenzilate
510156
Chloroform
67663
Chloromethyl methyl ether
107302
Chloroprene
126998
Cresols/Cresylic acid (isomers and mixture)
1319773
o-Cresol
95487
m-Cresol
108394
p-Cresol
106445
Cumene
98828
2,4-D, salts and esters
94757
DDE
3547044
Diazomethane
334883
Dibenzofurans
132649
1,2-Dibromo-3-chloropropane
96128
Dibutylphthalate
84742
1,4-Dichlorobenzene(p)
106467
3,3-Dichlorobenzidene
91941
Dichloroethyl ether (Bis(2-chloroethyl)ether)
111444
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Petroleum Refinery MACT Standard Guidance
Chemical Name
CAS Number
1,3-Dichloropropene
542756
Dichlorvos
62737
Diethanolamine
111422
N,N-Diethyl aniline (N,N-Dimethylaniline)
121697
Diethyl sulfate
64675
3,3-Dimethoxybenzidine
119904
Dimethyl aminoazobenzene
60117
3,3-Dimethyl benzidine
119937
Dimethyl carbamoyl chloride
79447
Dimethyl formamide
68122
1,1-Dimethyl hydrazine
57147
Dimethyl phthalate
131113
Dimethyl sulfate
77781
4,6-Dinitro-o-cresol, and salts
534521
2,4-Dinitrophenol
51285
2,4-Dinitrotoluene
121142
1,4-Dioxane (1,4-Diethyleneoxide)
123911
1,2-Diphenylhydrazine
122667
Epichlorohydrin (l-Chloro-2,3-epoxypropane)
106898
1,2-Epoxybutane
106887
Ethyl acrylate
140885
Ethyl benzene
100414
Ethyl carbamate (Urethane)
51796
Ethyl chloride (Chloroethane)
75003
Ethylene dibromide (Dibromoethane)
106934
Ethylene dichloride (1,2-Dichloroethane)
107062
Ethylene glycol
107211
Ethylene imine (Aziridine)
151564
A.3

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Petroleum Refinery MACT Standard Guidance
Chemical Name
CAS Number
Ethylene oxide
75218
Ethylene thiourea
96457
Ethylidene dichloride (1,1-Dichloroethane)
75343
Formaldehyde
50000
Heptachlor
76448
Hexachlorobenzene
118741
Hexachlorobutadiene
87683
Hexachlorocyclopentadiene
77474
Hexachloroethane
67721
Hexamethylene-1,6-diisocyanate
822060
Hexamethylphosphoram ide
680319
Hexane
110543
Hydrazine
302012
Hydrochloric acid
7647010
Hydrogen fluoride (Hydrofluoric acid)
7664393
Hydroquinone
123319
Isophorone
78591
Lindane (all isomers)
58899
Maleic anhydride
108316
Methanol
67561
Methoxychlor
72435
Methyl bromide (Bromomethane)
74839
Methyl chloride (Chloromethane)
74873
Methyl chloroform (1,1,1-Trichloroethane)
71556
Methyl ethyl ketone (2-Butanone)
78933
Methyl hydrazine
60344
Methyl iodide (lodomethane)
74884
Methyl isobutyl ketone (Hexone)
108101
A.4

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Petroleum Refinery MACT Standard Guidance
Chemical Name
CAS Number
Methyl isocyanate
624839
Methyl methacrylate
80626
Methyl tert butyl ether
1634044
4,4-Methylene bis(2-chloroaniline)
101144
Methylene chloride (Dichloromethane)
75092
Methylene diphenyl diisocyanate (MDI)
101688
4,4-Methylenedianiline
101779
Naphthalene
91203
Nitrobenzene
98953
4-Nitrobiphenyl
92933
4-Nitrophenol
100027
2-Nitropropane
79469
N-Nitroso-N-methylurea
684935
N-Nitrosodimethylamine
62759
N-Nitrosomorpholine
59892
Parathion
56382
Pentachloronitrobenzene (Quintobenzene)
82688
Pentachlorophenol
87865
Phenol
108952
p-Phenylenediamine
106503
Phosgene
75445
Phosphine
7803512
Phosphorus
7723140
Phthalic anhydride
85449
Polychlorinated biphenyls (Aroclors)
1336363
1,3-Propane sultone
1120714
beta-Propiolactone
57578
Propionaldehyde
123386
A.5

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Petroleum Refinery MACT Standard Guidance
Chemical Name
CAS Number
Propoxur(Baygon)
114261
Propylene dichloride (1,2-Dichloropropane)
78875
Propylene oxide
75569
1,2-Propylenimine (2-Methyl aziridine)
75558
Quinoline
91225
Quinone
106514
Styrene
100425
Styrene oxide
96093
2,3,7,8-Tetrachlorodibenzo-p-dioxin
1746016
1,1,2,2-Tetrachloroethane
79345
Tetrachloroethylene (Perchloroethylene)
127184
Titanium tetrachloride
7550450
Toluene
108883
2,4-Toluene diamine
95807
2,4-Toluene diisocyanate
584849
o-Toluidine
95534
Toxaphene (chlorinated camphene)
8001352
1,2,4-Trichlorobenzene
120821
1,1,2-T richloroethane
79005
Trichloroethylene
79016
2,4,5-Trichlorophenol
95954
2,4,6-T richlorophenol
88062
Triethylamine
121448
Trifluralin
1582098
2,2,4-T rimethylpentane
540841
Vinyl acetate
108054
Vinyl bromide
593602
Vinyl chloride
75014
A.6

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Petroleum Refinery MACT Standard Guidance
Chemical Name
CAS Number
Vinylidene chloride (1,1-Dichloroethylene)
75354
Xylenes (isomers and mixture)
1330207
o-Xylenes
95476
m-Xylenes
108383
p-Xylenes
106423
Antimony Compounds
0
Arsenic Compounds (inorganic including arsine)
0
Beryllium Compounds
0
Cadmium Compounds
0
Chromium Compounds
0
Cobalt Compounds
0
Coke Oven Emissions
0
Cyanide Compounds1
0
Glycol ethers2
0
Lead Compounds
0
Manganese Compounds
0
Mercury Compounds
0
Fine mineral fibers3
0
Nickel Compounds
0
Polycylic Organic Matter4
0
Radionuclides (including radon)5
0
Selenium Compounds
0
Note: For all listings above which contain the word 'compounds' and for glycol ethers, the following applies: Unless
otherwise specified, these listings are defined as including any unique chemical substance that contains the name chemical
(i.e., antimony, arsenic, etc.) as part of that chemical's infrastructure.
1
X'CN where X=H' or any other group where a formal dissociation may occur. For example KCN or Ca(CN)2.
2	Includes mono- and di-ehters or ethylene glycol, diethylene glycol, and triethylene glycol
A. 7

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Petroleum Refinery MACT Standard Guidance
R-(OCH2CH2)n-OR' where n=1,2, or 3; R=alkyl or aryl groups; R'=R, H, or groups which, when removed, yield glycol
ethers with the structure: R-(OCH2CH)n-OH. Polymers are excluded from the glycol category.
Includes mineral fiber emissions from facilities manufacturing or processing glass, rock, or slag fibers (or ther mineral
derived fibers) of average diameter 1 micrometer or less.
Includes organic compounds with more than one benzene ring, and which have a boiling point greater than or equal to
100°C.
A type of atom which spontaneously undergoes radioactive decay.
A. 8

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Petroleum Refinery MACT Standard Guidance
Appendix B. Organic Hazardous Air pollutants
(Organic haps)
Chemical Name
CAS Number
Benzene
71432
Biphenyl
92524
Butadiene (1,3)
10990
Carbon disulfide
75150
Carbonyl sulfide
463581
Cresol (mixed isomers)
1319773
Cresol (m-)
108394
Cresol (o-)
95487
Cresol (p-)
106445
Cumene
98828
Dibromoethane (1,2) (ethylene debromide)
106934
Dichloroethane (1,2)
107062
Diethanolamine
111422
Ethylbenzene
100414
Ethylene glycol
107211
Hexane
110543
Methanol
67561
Methyl ethyl ketone (2-butanone)
78933
Methyl isobutyl ketone (hexone)
108101
Methyl tert butyl ether
1634044
Naphthalene
91203
Phenol
108952
Toluene
108883
Trimethylpentane (2,2,4)
540841
B.1

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Petroleum Refinery MACT Standard Guidance
Chemical Name
CAS Number
Xylene (mixed isomers)
1330207
Xylene (m-)
108383
Xylene (o-)
95476
Xylene (p-)
106423
B.2

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Petroleum Refinery MACT Standard Guidance
APPENDIX C. U.S. PETROLEUM REFINERIES AFFECTED BY
THE PETROLEUM REFINERY STANDARDS
Facility Name
City
State
1994 Capacity
Units*
Tesoro Alaska Petroleum
Kenai
AK
72,000
Arco Alaska Inc.
Kuparuk
AK
12,000
Mapco Inc.
North Pole
AK
128,200
Petro Star Inc.
North Pole
AK
10,000
Arco Alaska Inc.
Prudhoe Bay
AK
15,000
Petro Star Inc.
Valdez
AK
26,300
Coastal Mobile Refining Co.
Chickasaw/Mobile Bay
AL
16,500
Shell Oil Products Co.1
Saraland
AL
76,000+
Hunt Refining Company Inc.
Tuscaloosa
AL
33,500
Lion Oil Co. Inc.
El Dorado
AR
51,000
Cross Oil & Refining Co. Inc.
Smackover
AR
6,200
Berry Petroleum Co.
Stephens
AR
6,700
Anchor Refining Co.
McKittirck
CA
10,000+
Kern Oil & Refining Co.
Bakersfield
CA
21,400
San Joaquin Refining Co. Inc.
Bakersfield
CA
24,300
Sunland Refining Corp.
Bakersfield
CA
12,000
Texaco Refining and Marketing Inc.
Bakersfield
CA
56,000
Exxon Corporation
Benecia
CA
128,000
Huntway Refining Co.
Benecia
CA
8,600
Chevron USA Products Co.
ElSegundo
CA
230,000
Atlantic Richfield Co.
Carson
CA
255,000+
Unocal Corp.
Los Angeles/Wilmington
CA
118,750+
Shell Martinez Refining Co.
Martinez
CA
148,900
c 1

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Petroleum Refinery MACT Standard Guidance
Facility Name
City
State
1994 Capacity
Units*
Tosco Corporation
Martinez
CA
160,000
Witco Corporation
Oildale
CA
0
Tenby Inc.
Oxnard
CA
4,000
Paramount Petroleum Corp.
Paramount
CA
46,500
Chevron USA Products Co.
Richmond
CA
230,000
Santa Maria Refining Co.2
Santa Maria
CA
10,000+
Unocal Corp.
San Francisco/Santa Maria
CA
103,645+
Lunday Thagard Co.
South Gate
CA
8,100
Mobile Oil Corp.
Torrance
CA
130,000
Huntway Refining Co.
Wilmington
CA
5,500
Texaco Refining and Marketing
Wilimington
CA
64,000
Ultramar Inc.
Wilmington
CA
68,000
Conoco Inc.
Commerce City
CO
57,500
Total Petroleum Inc.3
Denver
CO
28,000+
Star Enterprise
Delaware City
DE
140,000
Young Refining Corporation
Douglasville
GA
5,540
Citgo Asphalt Refining Co.
Savannah
GA
28,000
BHP Hawaii Inc.
Kapolei
HI
93,500
Chevron USA Products Co.
Barbers Point
HI
54,000
Clark Oil & Refining Corp.
Blue Island
IL
80,515
Clark Oil & Refining Corp.
Hartford
IL
62,500
Mobil Oil Corporation
Joliet
IL
188,000
Indian Refining Partnership
Lawrenceville
IL
80,750
Uno-Ven Company
Lemont
IL
147,000
Marathon Oil Company
Robinson
IL
175,000
Shell Wood River Refining Co.4
Wood River
IL
271,000+
Laketon Refining Corp.
Laketon
IN
11,100
C.2

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Petroleum Refinery MACT Standard Guidance
Facility Name
City
State
1994 Capacity
Units*
Countrymark Cooperative Inc.
Mount Vernon
IN
22,000
Amoco Oil Co.
Whiting
IN
410,000
Farmland Industries Inc.
Coffeyville
KS
68,600
Texaco Refining and Marketing Inc.
El Dorado
KS
94,600
National Coop Refinery Assoc.
Mc Pherson
KS
75,600
Ashland Petroleum Co.
Russell/Catlettsburg
KY
213,400
Somerset Refinery Inc.
Somerset
KY
5,500
Exxon Corporation
Baton Rouge
LA
424,000
BP Exploration & Oil Inc.
Belle Chasse
LA
231,500
Mobil Oil Corporation
Chalmette
LA
170,000
Canal Refining Co.
Church Point
LA
9,500
Star Enterprise
Convent
LA
225,000
Calumet Lubricants Co.
Cotton Valley
LA
7,800
Marathon Oil Company
Garyville
LA
255,000
Basis Petroleum, Inc.5
Krotz Springs
LA
67,100+
Calcasieu Refining Co.
Lake Charles
LA
12,500
Citgo Petroleum Corporation
Lake Charles
LA
305,000
American International Refining Inc.6
Lake Charles
LA
27,600+
Cit-Con Oil Corp.
Lake Charles
LA
7,350
Murphy Oil USA Inc.
Meraux
LA
100,000
Shell Norco Refining Co.
Norco
LA
215,000
Placid Refining Co.
Port Allen
LA
48,500
Calumet Lubricants Co. Ltd.
Princeton
LA
8,200
Atlas Processing Co. Div. Of Pennzoil
Shreveport
LA
46,200
Shell Chemical Co.7
St. Rose
LA
40,000+
Conoco Inc.
Westlake
LA
191,000
Lakeside Refining Co.
Kalamazoo
Ml
5,600+
C.3

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Petroleum Refinery MACT Standard Guidance
Facility Name
City
State
1994 Capacity
Units*
Total Petroleum Inc.
Alma
Ml
45,600
Marathon Oil Company
Detroit
Ml
70,000
Koch Refining Company LP
Rosemount
MN
230,000
Ashland Petroleum Co.
Saint Paul Park
MN
67,100
Southland Oil Company
Lumberton
MS
5,800
Chevron USA Products Co.
Pascagoula
MS
295,000
Southland Oil Company
Sandersville
MS
11,000
Ergon Inc.
Vicksburg
MS
23,000
Conoco Inc.
Billings
MT
49,500
Exxon Co.
Billings
MT
44,000
Montana Refining Co.
Great Falls
MT
7,000
Cenex
Laurel
MT
41,450
Amoco Oil Co.
Mandan
ND
58,000
Tosco Refining Co.8
Linden
NJ
240,000+
Citgo Asphalt Refining Co.
Paulsboro
NJ
40,000
Mobil Oil Corp.
Paulsboro
NJ
126,000
Chevron USA Products Co.
Perth Amboy
NJ
80,000
Amerada Hess Corporation
Port Reading
NJ
0
Coastal Eagle Point Oil Co.
Westville
NJ
125,000
Navajo Refining Company
Artesia
NM
57,000
Giant Refining Co.9
Bloomfield
NM
16,800+
Giant Refining Co.
Gallup
NM
20,800
Petro Source Refining Partners
Eagle Springs
NV
7,000
Ashland Petroleum Co.
Canton
OH
66,000
BP Oil Co.
Lima
OH
161,000
BP Oil Co.
Toledo (Oregon)
OH
136,000
Sun Refining & Marketing Co.10
Toledo
OH
125,000+
C.4

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Petroleum Refinery MACT Standard Guidance
Facility Name
City
State
1994 Capacity
Units*
Total Petroleum Inc.
Ardmore
OK
68,000
Conoco Inc.
Ponca City
OK
140,000
Sinclair Oil Corporation
Tulsa
OK
54,000
Sun Refining & Marketing Co.
Tulsa
OK
85,000
Gary-Williams Co.11
Wynnewood
OK
45,000+
Chevron USA Products Co.12
Portland (Willbridge)
OR
15,000+
Witco Corporation
Bradford
PA
10,000
Sun Refining & Marketing Co.
Marcus Hook
PA
175,000
Sun Refining & Marketing Co.
Philadelphia-Girard Pt13
PA
177,000+
Sun Refining & Marketing Co.
Philadelphia-Pt. Breeze14
PA
130,000+
Pennzoil Products Company
Rouseville
PA
15,700
United Refining Inc.
Warren
PA
60,000
Mapco Petroleum Inc.
Memphis
TN
89,000
Pride Companies L P
Abilene
TX
42,750
Exxon Co. USA
Baytown
TX
396,000
Mobil Oil Corporation
Beaumont
TX
315,000
Fina Oil and Chemical Co.
Big Spring
TX
55,000
Phillips Petroleum Company
Borger
TX
110,000
Howell Hydrocarbons & Chemicals Inc.
Channelview
TX
1,400
Citgo Petroleum Corp.15
Corpus Christi
TX
130,000+
Coastal Refining & Marketing Inc.
Corpus Christi
TX
95,000
Koch Refining Company Inc.
Corpus Christi
TX
255,000
Neste Trifinery Petroleum Services
Corpus Christi
TX
27,000
Valero Refining Company
Corpus Christi
TX
29,900
Deer Park Refining Ltd. Partnership
Deer Park
TX
215,900
Chevron USA Products Co.
El Paso
TX
87,000
Basis Petroleum, Inc.16
Houston
TX
67,600+
C.5

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Petroleum Refinery MACT Standard Guidance
Facility Name
City
State
1994 Capacity
Units*
Lyondell-Citgo Refining Co.
Houston
TX
265,000
Shell Odessa Refining Co.
Odessa
TX
28,600
Crown Central Petroleum Corp.
Pasadena
TX
100,000
Clark Oil & Refining Corp.17
Port Arthur
TX
185,000+
Fina Oil and Chemical Co.
Port Arthur
TX
175,000
Star Enterprise
Port Arthur/Neches
TX
235,000
Age Refining & Marketing
San Antonio
TX
6,000
Diamond Shamrock Corp.
Three Rivers
TX

Diamond Shamrock Corp.
Sunray (Mckee)
TX
132,000
Phillips Petroleum Company
Sweeny
TX
185,000
Amoco Oil Company
Texas City
TX
433,000
Marathon Oil Company
Texas City
TX
70,000
Basis Petroleum Inc.18
Texas City
TX
125,400+
La Gloria Oil & Gas Co.
Tyler
TX
55,000
Big West Oil Company
Salt Lake City
UT
24,000
Amoco Oil Company
Salt Lake City
UT
44,000
Chevron USA Products Co.
Salt Lake City
UT
45,000
Crysen Refining Inc.
Woods Cross
UT
12,500
Phillips Petroleum Company
Woods Cross
UT
25,000
Amoco Oil Company
Yorktown
VA
53,000
Hess of Virgin Islands Corp.
St. Croix
VI
505,000
Shell Anacortes Refin Co.19
Anacortes
WA
108,200+
Texaco Refining and Marketing
Anacortes
WA
136,000
Atlantic Richfield Company
Ferndale
WA
189,000
Tosco Corporation
Ferndale
WA
95,000
Chevron USA Products Co.20
Seattle
WA
0+
Sound Refining Inc.
Tacoma
WA
11,900
C.6

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Petroleum Refinery MACT Standard Guidance
Facility Name
City
State
1994 Capacity
Units*
US Oil & Refining Co.
Tacoma
WA
32,400
Murphy Oil USA Inc.
Superior
Wl
33,200
Quaker State oil Refining Corp.
Newell
WV
11,500
Frontier Refining Inc.
Cheyenne
WY
38,670
Little America Refining Co.
Evansville/Casper
WY
24,500
Wyoming Refining Co.
Newcastle
WY
12,555
Sinclair Oil Corporation
Sinclair
WY
54,000
* Barrels/Calendar day (one barrel=42 U.S. Gallons). Data extracted from Report 1 —Comparative Profile Petroleum
Refining. EPA Regional or State Reviewers, Regional Review Draft. 10/25/96.
+ Charge Capacity, b/cd. Data extracted from Oil and Gas Journal. Dec. 23, 1996, pp. 85-94.
Endnotes:
1.	Formerly LL&E Petroleum Marketing
2.	Formerly Conoco
3.	Formerly Colorado Refining
4.	Possibly same refinery as Shell Oil Company in Roxana Wood River
5.	Formerly Phibro Energy USA Inc.
6.	Leases Gold Line Refining Ltd.
7.	Formerly St. Rose Refining Inc.
8.	Formerly Bayway Refining Company
9.	Formerly Bloomfield Refining Company
10.	Same as Sun Company Inc. (r &M)
11.	Same as Kerr-Mcgee Refining Corp.
12.	Same as Chevron U.S.A. Inc.
13.	Previously combined with Point Breeze Refinery
14.	Previously combined with Girard Point Refinery
15.	Same as Citgo Refining and Chemical Inc.
16.	Previously Phibro Energy USA Inc.
17.	Formerly Chevron USA Inc.
18.	Formerly Diamond Shamrock Corp. in Three Rivers, TX
19.	Formerly Shell Oil Company
20.	Same as Chevron USA Inc.
C.7

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Petroleum Refinery MACT Standard Guidance
Appendix D. Additional Resources for
Petroleum Refining MACT Standard
Guidance document
Documents/Reports available on the Internet:
Clean Air Act signed rules
134.67.104.12/html/caa/rules. htm
Includes compressed files of the Clean Air Act.
Sector Notebook: Profile of the Petroleum Refining Industry. EPA Office of
Compliance. September 1995.http://es.inel.gov/.
This sector notebook provides general information on the petroleum refining industry,
including: industrial processes, chemical releases and transfer profile, and pollution
prevention opportunities. The report also summarizes applicable federal statutes and
regulations, provides a compliance and enforcement history, and presents compliance
assurance and initiatives for the industry.
Air Toxics Regulations: Petroleum Refining. Final Air Toxics Rule for the
Petroleum Refining Industry. July 28,1995.
www. epa. gov/oar/oaqps/airtox/fsrefine. htm I
Document written following EPA's issuance of final regulation to reduce emissions of
air toxics from petroleum refineries. Discusses health and environmental benefits of
new rule and flexibility of rule for the industry. Provides background and cost of
information, discusses who will be affected, and includes a FACT sheet.
AIRS Facility Subsystem (AFS Data) - USA Emissions Ranking Report - VOC
www.epa.gov/airs/afsd-voc.html
This report ranks the 100 largest stationary sources of volatile organic compounds
(VOC) emissions in the United States, as of February 28, 1997.
AIRS Facility Subsystem (AFS Data) - USA Emissions Ranking Report - CO
www. epa. gov/airs/afsd-co. htm I
This report ranks the 100 largest stationary sources of carbon monoxide (CO)
emissions in the United States, as of February 28, 1997.
D.1

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Petroleum Refinery MACT Standard Guidance
D.2

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Petroleum Refinery MACT Standard Guidance
National Ambient Air Quality Standards (NAAQS)
www.epa.gov/airs/criteria. htm I
Document lists EPA's national standards set for the six principal pollutants, called
"criteria" pollutants.
EPA Operating Permits Program -- Information
www.epa.gov/oar/oaqps/permits/
Provides a mechanism for gathering all the federal, state, and local requirements
applicable to air pollution sources. Answers questions like: What are the
requirements? What guidance has been prepared? Who are responsible for
implementing the permits programs? What is the approval status for each of the state
and local permitting authorities? What changes are coming?
Environment Canada
www.ns.doe.ca/soe/ch4-31 .html
State of the Environment in Atlantic Region report. Includes chapters describing
process releases from petroleum refining and presents data on air emissions from
refineries.
Center for Transportation and Analysis
www-cta.ornl.gov/data/tedb15/tab21 .htm
Includes the table Refinery Yield of Petroleum Products from a Barrel of Crude Oil,
1978-1993(a).
Websites
U.S. EPA Office of Air and Radiation (OAR):
OAR Homepage
www.epa.gov/oar/
Includes information on prevention and air toxics. Lists publications, regulations, and
resources. Provides search tool.
OAR Regulations
www. epa. gov/oar/oarregul. htm I
Contains information on Clean Air Act documents, Clean Air Act operating permits
program, ozone depletion regulations, OAQPS air regulations - schedule, air toxics
regulations - fact sheets, and other regulations, including the federal register online.
D.3

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Petroleum Refinery MACT Standard Guidance
OAR Resources
www.epa.gov/oar/oarrsrc. htm I
Lists various services, networks, webpages, databases, software, and contacts that
may be useful.
U.S. EPA Office of Air Quality Planning and Standards (OAQPS):
Transfer Technology Network 2000 (TTN 2000) Home Page
www.epa.gov/oar/ttn_bbs.html
Provides access to various electronic bulletin board systems containing information
about many areas of air pollution science, technology, regulation, measurement, and
prevention. Serves as a public forum for the exchange of technical information and
ideas among users and EPA staff. Includes tools to: 1) estimate air pollutant
emissions, 2) download computer code for regulatory models, 3) read summaries or
details of the Clean Air Act, 4) find a course offered by the Air Pollution Training
Institute, or 5) seek technical support in implementing air pollution programs.
Unified Air Toxics Website: Home Page
www.epa.gov/oar/oaqps/airtox/
Contains basic facts, summaries of EPA regulations, information on pollutants and
sources of pollutants, technical resources, EPA program and contacts, and state and
local programs.
Unified Air Toxics Website: Pollutants & Sources
www.epa.gov/oar/oaqps/airtox/pollsour.html
Provides a list of 188 toxic air pollutants to be regulated by EPA, defines the types of
sources of pollutants, and provides a list of 174 categories of industrial and
commercial sources that emit toxic air pollutants.
Unified Air Toxics Website: EPA Programs
www. epa. gov/oar/oaqps/airtox/epaprogs. htm I
Describes the following three programs: Hazardous Air Pollutants Strategic
Implementation Plan, National Emission Standards for Hazardous Air Pollutants
(NESHAP), and Maximum Achievable Control Technology (MACT) Standards.
Publications
www.epa.gov/oar/oaqps/publicat.html
Contains air quality and emissions trend reports, newsletters, fact sheets, and various
guides to evaluating exposure to air pollutants.
D.4

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Petroleum Refinery MACT Standard Guidance
American Petroleum Institute (API)
www.api.org/
Representing the Nation's oil and gas industries. Contains industry data, facts about
the petroleum industry, and publications such as: N0X Emissions from Petroleum
Industry Operations, October 1979; Petroleum Emission Factor Information Retrieval
System (PEFIRS), July 1993; The Cost Effectiveness of Carbon Dioxide from
Petroleum Sources, July 1991; and, Electric Exchange of Environmental Compliance
Information: A Proposed Approach, August 1995.
One of many documents available from API is the Summary of Question and Answer
Sessions for American Petroleum Institute's Refinery MACT Rule Workshop.
October 23-24, 1995.
D.5

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Petroleum Refinery MACT Standard Guidance
APPENDIX E. DEFINITIONS
Affected source means the combination of all emission points at a petroleum refinery.
Each point is considered part of the single affected source.
Boiler means any closed combustion device that extracts useful energy in the form of
steam and is not an incinerator.
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 and vapor from an emission point to a control device or back into the
process. If gas or vapor from regulated equipment is routed to a process (e.g., petroleum
refinery fuel gas system), the process is not considered a closed vent system and is not
subject to the closed vent system standards.
Combustion device means an individual unit of equipment such as a flare, incinerator,
process heater, or boiler used for the combustion of organic hazardous air pollutant (HAP)
vapors.
Construction means the on-site fabrication, erection, or installation of an affected source.
Control device means any equipment used for recovering, removing, or oxidizing
hazardous organic pollutants (HAPs). Such equipment includes, but is not limited to,
absorbers, carbon absorbers, condensers, incinerators, flares, boilers, and process
heaters.
Deck fitting controls means the fittings that pass through or are attached to the deck or
roof of a floating roof tank, and include hatches, gauge floats, and support columns.
Controls may be installed to minimize evaporative losses from the fittings.
Double-seal system means a floating roof having both primary and secondary seals.
Dwell time means the time feeds spend in a reactor (allowing for reactions to occur) or the
time feeds or products spend in a tank.
Emissions averaging means a method of complying with emission limitations, whereby
the affected source may create emission credits by reducing emissions from specific
points to a level below that required by the relevant standard, and those credits are used to
offset emissions from points that are not controlled to the level required by the relevant
standard.
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Petroleum Refinery MACT Standard Guidance
Emission point means an individual miscellaneous process vent, storage vessel,
wastewater stream, or equipment leak associated with a petroleum refining process unit;
an individual storage vessel or equipment leak associated with a bulk gasoline terminal or
pipeline breakout station classified under SIC 2911; a gasoline loading rack classified
under SIC 2911; or a marine tank vessel loading operation located at a petroleum refinery.
Existing source means a source that commenced construction on or before July 14,
1994.
External floating roof means a pontoon-type or double-deck-type cover that rests on the
liquid surface in a storage vessel or waste management unit with no fixed roof.
Firebox means a chamber (e.g., boiler) where fuels are burned.
Fixed roof means a cover that is mounted on a storage vessel or waste management unit
in a stationary manner and that does not move with fluctuations in liquid level.
Flame zone means the portion of a combustion chamber of a boiler or process heater
occupied by the flame envelope.
Flare means a device used in refineries to combust undesirable volatile gases (e.g.,
methane, ethane, hydrogen sulfide) from process units. Flares also take momentary
surges in gas manufacturing by burning the excess. When burned, these gases are
converted to more favorable compounds which can be emitted into the air.
Flow indicator means a device that indicates whether gas is flowing, or whether the valve
position would allow gas to flow, in a line.
Gasoline means any petroleum distillate or petroleum distillate/alcohol blend having a
Reid vapor pressure of 27.6 kilopascals or greater that is used as a fuel for internal
combustion engines.
Hazardous organic pollutant or HAP means one of the 188 chemicals listed in section
112(b) of the Clean Air Act, and listed in Appendix A of this manual.
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 is a separate section following the combustion section and
the two are joined by ducts or connections carrying flue gas.
Internal floating roof means a cover that rests or floats on the liquid surface (but not
necessarily in complete contact with it) inside a storage vessel or waste management unit
that has a permanently affixed roof.
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Petroleum Refinery MACT Standard Guidance
Major source means a source that has the potential to emit 10 tons per year or more
annually of any of the 188 listed hazardous air pollutants (HAPs), or 25 tons per year or
more annually of any combination of HAPs.
Malfunction means any sudden, infrequent, and not reasonably preventable failure of air
pollution control equipment, process equipment, or a process to operate in a normal or
usual manner. Failures that are caused in part by poor maintenance or careless operation
are not malfunctions.
Maximum achievable control technology or MACT means demonstrated technologies
which may be used to achieve acceptable air emissions limits for specific compounds.
Maximum true vapor pressure means the equilibrium partial pressure exerted by the
stored liquid at the temperature equal to the highest calendar-month average of the liquid
storage temperature for liquids stored above or below the ambient temperature or at the
local maximum monthly average temperature as reported by the National Weather Service
for liquids stored at the ambient temperature.
New source means a source that commenced construction after July 14, 1994.
Organic hazardous air pollutant or organic HAP means any of the 28 organic
chemicals listed in Appendix B of this manual.
Primary seal means the seal that slides against a wall of a floating roof tank as the roof is
raised and lowered. It closes the annular space between the roof and tank wall and can be
constructed of metal or polymer.
Process heater means an enclosed combustion device that primarily transfers heat
liberated by burning fuel directly to process streams or to heat transfer liquids other than
water.
Process unit means the equipment assembled and connected by pipes or ducts to
process raw and/or intermediate materials and to manufacture an intended product. A
process unit includes any associated storage vessels, and includes, but is not limited to,
chemical manufacturing process units and petroleum refining process units.
Reconstruction means the replacement of components of an affected or a previously
unaffected stationary source to the extent that:
(1)	The fixed capital cost of the new component exceeds 50 percent of the fixed capital
cost that would be required to construct a comparable new source; and
(2)	It is technologically and economically feasible for the reconstructed source to meet
the relevant standard(s) established by the Administrator (or a state) pursuant to
Section 112 of the Clean Air Act.
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Petroleum Refinery MACT Standard Guidance
Recovery device means an individual unit of equipment capable of and used for the
purpose of recovering chemicals for use, reuse, or sale. Recovery devices include, but are
not limited to, absorbers, carbon absorbers, and condensers.
Secondary seal means the seal that provides addition evaporative loss control. It is
mounted on the roof rim or tank wall over the primary seal.
Single-seal system means a floating roof having one continuous seal that completely
covers the space between the wall of the storage vessel and the edge of the floating roof.
Total organic compound or TOC means those compounds, excluding methane and
ethane, measured according to the procedures of method 18 of 40 CFR 60 Appendix A.
Method 25A may be used alone or in combination with Method 18 to measure TOC as
provided in 40 CFR 63.645.
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Petroleum Refinery MACT Standard Guidance
APPENDIX F. Compliance Checklist for the
Petroleum Refinery MACT Standard
40 CFR Part 63, Subpart CC
November, 2000
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Petroleum Refinery MACT Standard Guidance
Table of Contents
I.	GENERAL APPLICABILITY 	F-4
II.	APPLICABILITY FOR SPECIFIC EMISSION POINTS 	F-5
A Miscellaneous Process Vents 	F-5
B.	Storage Vessels 	F-7
C.	Wastewater Streams	F-8
D.	Gasoline Loading Racks 	F-8
E.	Marine Tank Vessel Loading 	F-8
F.	Equipment Leaks 	F-9
III.	COMPLIANCE DEADLINES 	F-9
A All new sources	F-9
B.	Existing Miscellaneous Process Vents and Gasoline Loading Racks 	F-9
C.	Existing Wastewater Streams 	F-9
D.	Existing Storage Vessels 	F-9
E.	Marine Tank Vessel Loading Operations 	F-10
F.	Equipment Leaks 	 F-10
IV.	GENERAL STANDARDS	 F-10
A Performance Testing 		F-10
B.	Operating Permits 		F-10
C.	Application for Approval of Construction or Reconstruction		F-10
D.	Notification of Compliance Status (NCS) Reports		F-11
E.	Periodic Reports		F-11
F.	Startup, Shutdown and Malfunction Plans and Reports 		F-12
G.	Reports Required for Special Situations 		F-12
H.	Requests for Extension of Compliance		F-13
I.	Applications for a Performance Test Waiver		F-14
J. Recordkeeping 		F-14
V.	REQUIREMENTS FOR MISCELLANEOUS PROCESS VENTS	 F-15
A Miscellaneous Process Vents Control Requirements 	 F-15
B.	Miscellaneous Process Vents Testing Requirements 	 F-15
C.	Miscellaneous Process Vents Monitoring Requirements 	 F-16
D.	Miscellaneous Process Vents Reporting Requirements	 F-18
VI.	REQUIREMENTS FOR STORAGE VESSELS	 F-21
A Control Requirements for Storage Vessels 	 F-21
B.	Testing Requirements for Storage Vessels		 F-22
C.	Monitoring and Inspection Requirements for Storage Vessels for Storage Vessels
Required to Apply Controls	 F-22
D.	Reporting Requirements for Storage Vessels Equipped with Closed
Vent Systems	 F-24
E.	Recordkeeping Requirements for Storage Vessels 	 F-28
VII.	REQUIREMENTS FOR WASTEWATER STREAMS	 F-29
A Control Requirements for Wastewater Streams 	 F-29
B.	Testing and Monitoring Requirements for Wastewater Streams 	 F-29
C.	Reporting and Recordkeeping Requirements for Wastewater Streams 	 F-29
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Petroleum Refinery MACT Standard Guidance
VIII.	REQUIREMENTS FOR GASOLINE LOADING RACKS	 F-30
A Control Requirements for Gasoline Loading Racks 	 F-30
B.	Testing and Monitoring Requirements for Gasoline Loading Racks	 F-30
C.	Reporting and Recordkeeping Requirements for Gasoline Loading Racks 	 F-31
IX.	REQUIREMENTS FOR MARINE TANK VESSEL LOADING	 F-32
A Control Requirements for Marine Tank Vessel Loading 	 F-32
B.	Testing and Monitoring Requirements for Marine Tank Vessel Loading 	 F-32
C.	Reporting and Recordkeeping Requirements for Marine Tank
Vessel Loading	 F-32
X REQUIREMENTS FOR EQUIPMENT LEAKS	 F-32
A Control Requirements for Equipment Leaks 	 F-33
B.	Testing, Inspection, and Monitoring Requirements for Equipment Leaks 	 F-33
C.	Reporting and Recordkeeping Requirements for Equipment Leaks 	 F-33
XI. EMISSIONS AVERAGING	 F-33
A Emissions Averaging Applicability 	 F-33
B.	Emissions Averaging Credit/Debit System 	 F-33
C.	Approval of Emissions Averaging Plan 	 F-35
D.	Testing, Monitoring, Reporting, and Recordkeeping for Emissions 	 F-35
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Petroleum Refinery MACT Standard Guidance
I. GENERAL APPLICABILITY
1. Is the refinery a major HAP source?
[ ] Potential to emit > 10 tons per year (tpy) of any of the 188 HAPs listed in §
112(b) of the Clean Air Act; or
[ ] Potential to emit > 25 tpy of total HAPs.
Yes[ ] No[
]
2. Do the refining process units at refineries that are major HAP sources emit or
contain any of the following 28 organic HAPs? Please check the substances
below that apply.
[ ] Benzene [ ] Ethylene glycol
[ ] Biphenyl [ ] Hexane
[ ] Butadiene (1,3) [ ] Methanol
[ ] Carbon disulfide [ ] Methyl ethyl ketone (2-butanone)
[ ] Carbonyl sulfide [ ] Methyl isobutyl ketone (hexone)
[ ] Cresol (mixed isomers) [ ] Methyl tert butyl ether
[ ] Cresol (m-) [ ] Naphthalene
[ ] Cresol (o-) [ ] Phenol
[ ] Cresol (p-) [ ] Toluene
[ ] Cumene [ ] Trimethylpentane (2,2,4)
[ ] Dibromoethane (1,2) [ ] Xylene (mixed isomers)
(ethylene dibromide) [ ] Xylene (m-)
[ ] Dichloroethane (1,2) [ ] Xylene (o-)
[ ] Diethanolamine [ ] Xylene (p-)
[ ] Ethylbenzene
Yes[ ] No[
]
3. Are any of the following emission points located within petroleum refining
process units? Please check the emission points below that apply.
[ ] Miscellaneous process vents that contain > 20 ppmv total organic HAP
[ ] Storage vessels (pressure vessels and vessels < m3 are exempt)
[ ] Wastewater streams and treatment operations
[ ] Equipment containing or contacting a fluid that is > 5% by weight total
organic HAPs
Yes[ ] No[
]
4. Are any of the following emission points located at a refinery that is a major
source? Please check the emission points below that apply.
[ ] Marine vessel loading operations
[ ] Gasoline loading racks in SIC 2911
[ ] Storage vessels and equipment leaks associated with bulk gasoline
terminals in SIC 2911
Yes[ ] No[
]
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Petroleum Refinery MACT Standard Guidance
II. APPLICABILITY FOR SPECIFIC EMISSION POINTS
A. Miscellaneous Process Vents
1. Does the vent contain a aas stream with > 20 dditiv oraanic HAP and is it
continuously or periodically discharaed durina normal operations?
Yes[ ] No[
]
2. Is the vent or gas stream any of the following? Please check the descriptions
below that apply.
r 1 Directlv discharaed to the atmosphere
r 1 Routed to a control device Drior to discharae to the atmosDhere
r 1 Diverted to a Droduct recoverv Drior to control or discharae to the
atmosphere
Note: The above list gives examples of vent or gas streams and may not be all
inclusive.
Yes[ ] No[
]
3. Does the vent or gas stream come from any of the following? Please check the
items below that apply.
[ ] Gas streams routed to a fuel gas system
[ ] Relief valve discharges
[ ] Leaks from equipment regulated under 40 CFR 63.648
[ ] Episodic or nonroutine releases such as maintenance or upsets
[ ] In situ sampling systems (on stream analyzers)
[ ] Catalytic cracking unit catalyst regeneration vents
[ ] Catalytic reformer regeneration vents
[ ] Sulfur plant vents
[ ] Vents from control devices
[ ] Vents from any stripping operations applied to comply with the wastewater
provisions of 40 CFR 63 Subpart CC, G, or FF
[ ] Coking unit vents associated with coke drum, depressuring at or below a
coke drum outlet pressure of 15 pounds per square inch gauge, deheading,
draining, or decoking (coke cutting) or pressure testing after decoking
[ ] Vents from storage vessels
[ ] Emissions from wastewater collection and conveyance systems
Note: If the answerto question 3 is "Yes", the miscellaneous process vents
provision does not apply.
Yes[ ] No[
]
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Petroleum Refinery MACT Standard Guidance
4. Does the vent or gas stream come from any of the following? Please check the
items below that apply.
Yes[ ] No[
[ ] Caustic wash accumulators [ ] Stripper overheads
[ ] Distillation lower condensers/ [ ] Vacuum accumulators
accumulators
[ ] Blowdown condenser/ [ ] Delayed coker vents
accumulators
[ ] Flash/knockout drums [ ] Reactor vessels
[ ] Scrubber overheads
J
Note: The above list gives examples of where vent or gas streams originate and
may not be all inclusive.

5. Is the vent associated with an existing or new source?

[ ] Existing source
[ ] New source

Existing sources - sources that commenced construction on or before July 14,
1994.

New sources - sources that commenced construction after July 14, 1994. A
process unit constructed at an existing source is subject to new source
requirements if the new unit has the potential to emit 10 tons per year (tpy) or more
of any one HAP or 25 tpy or more of total HAPs. Otherwise it is subject to existing
source standards. A change to an existing source or an addition of an emission
point is subject to existing source standards, unless it is a reconstructed source,
which is subject to new source standards.

For an existing source:

6. Is the organic HAP concentration > 20 ppmv, and total VOC emissions > 33
kg/day?
Yes[ ] No[
i
Note: If the answerto question 6 is "Yes", it is a Group 1 miscellaneous process
vent. If the answer is "No", it is a Group 2 miscellaneous process vent.
J
For a new source:

7. Is the organic HAP concentration > 20 ppmv, and total VOC emissions > 6.8
kg/day?
Yes[ ] No[
i
Note: If the answerto question 7 is "Yes", it is a Group 1 miscellaneous process
vent. If the answer is "No", it is a Group 2 miscellaneous process vent.
J
B. Storage Vessels

1. Is it a tank or other vessel used to store oraanic liauids?
Yes[ ] No[
]
2. Is it permanently attached to a motor vehicle such as a truck, railcar, barge, or
ship?
Yes[ ] No[
]
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Petroleum Refinery MACT Standard Guidance
3. Is it a pressure vessel designed to operate in excess of 204.9 kPa and without
emission to the atmosphere?
Yes [ ]
]
No [
4. Does it have a capacity less than 40 m3?
Yes [ ]
]
No [
5. Is it used as a bottoms receiver tank?
Yes [ ]
]
No [
6. Is it used as a wastewater storage tank?
Yes [ ]
]
No [
Note: If any of the answers to questions 2 through 6 is "Yes", the storage vessels provision does not
apply.
7. Is tank associated with an existing or new source?


[ ] Existing source
[ ] New source


Existing sources - sources that commenced construction on or before July 14,
1994;


New sources - sources that commenced construction after July 14, 1994. A
process unit constructed at an existing source is subject to new source
requirements if the new unit has the potential to emit 10 tons per year (tpy) or more
of any one HAP or 25 tpy or more of total HAPs. Otherwise it is subject to existing
source standards. A change to an existing source or an addition of an emission
point is subject to existing source standards, unless it is a reconstructed source,
which is subject to new source standards.


For an existing source:


8. Is the capacity > 177 m3 and vapor pressure >10.4 kPa (maximum) and > 8.3
kPa (annual average) and liquid HAP content > 4% by weight (annual average)?
Note: If the answerto question 8 is "Yes", it is a Group 1 storage vessel. If the
answer is "No", it is a Group 2 storage vessel.
Yes [ ]
]
No [
For a new source:


9. Is the capacity > 151 m3 and vapor pressure > 3.4 kPa (maximum) and
liquid HAP content > 2% by weight (annual average)?
Yes [ ]
i
No [
OR
J

10. Is the capacity between 76 and 151 m3 and vapor pressure > 77 kPa
(maximum) and liquid HAP > 2% by weight (annual average)?
Note: Ifthe answerto question 9 or 10 is "Yes", it is a Group 1 storage vessel. If
both answers are "No", it is a Group 2 storage vessel.
Yes [ ]
]
No [
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Petroleum Refinery MACT Standard Guidance
C. Wastewater Streams
1. Is it water or wastewater that, during production or processing:
Comes into direct contact with or results from the Droduction or use of anv raw
material, intermediate product, finished product, byproduct, or waste product?
Is discharged into any individual drain system?
Yes[ ] No[
]
Yes[ ] No[
]
2. Does refinery have a total annual benzene loading > 10 megagrams per year,
and a flow rate > 0.02 liters per minute, and benzene concentration > 10 ppm
by weight, and subject to control requirements under 40 CFR 61 Subpart FF?
Note: Wastewater streams applicability criteria are the same for existing and new
sources. If the answer to question 2 is "Yes", it is a Group 1 wastewater stream. If
the answer is "No", it is a Group 2 wastewater stream.
Yes[ ] No[
]
D. Gasoline Loading Racks
1. Is it any of the following equipment, which is necessary to fill gasoline cargo
tanks? Please check the equipment below that applies.
[ ] Loading arms [ ] Shutoffvalves
[ ] Pumps [ ] Reliefvalves
[ ] Meters [ ] Other piping and valves
Yes[ ] No[
]
2. Is it a gasoline loading rack classified underSIC2911?
Yes[ ] No[
]
3. Does it have a gasoline throughput > 75,700 liters (20,000 gallons) per day?
Note: Gasoline loading racks applicability criteria are the same for existing and new
sources. Ifthe answerto question 3 is "Yes", it is a Group 1 gasoline loading rack.
If the answer is "No", it is a Group 2 gasoline loading rack.
Yes[ ] No[
]
E. Marine Tank Vessel Loading
1. Is it a land- or sea-based terminal or structure that loads liquid commodities in
bulk onto marine tank vessel loading?
Yes[ ] No[
]
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Petroleum Refinery MACT Standard Guidance
2. Is vessel loading associated with an existing or new source?

[ ] Existing source
[ ] New source

Existing sources - sources that commenced construction on or before July 14,
1994;

New sources - sources that commenced construction after July 14, 1994. A
process unit constructed at an existing source is subject to new source
requirements if the new unit has the potential to emit 10 tons per year (tpy) or more
of any one HAP or 25 tpy or more of total HAPs. Otherwise it is subject to existing
source standards. A change to an existing source or an addition of an emission
point is subject to existing source standards, unless it is a reconstructed source,
which is subject to new source standards.

For an existing source:

3. Is vapor pressure of liquid loaded > 10.3 kPaand emissions > 9.1 megagrams
of any one HAP or > 22.7 megagrams of total HAPs per year?
Yes[ ] No[
1
Note: If the answer to question 3 is "Yes", it is a Group 1 marine tank vessel
loading. Ifthe answer is "No", it is a Group 2 marine tank vessel loading.
J
For a new source:

4. Is vapor pressure of liquid loaded > 10.3 kPa?
Yes [ ] No [
i
Note: Ifthe answer to question 4 is "Yes", it is a Group 1 marine tank vessel
loading. Ifthe answer is "No", it is a Group 2 marine tank vessel loading.
J
F. Equipment Leaks

1. Is it a vent from a wastewater system drain, tank mixer, or sample valve on a
storage tank?
Yes [ ] No [
i
Note: Ifthe answer to question 1 is "Yes", the equipment leaks provision does not
apply.
J
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Petroleum Refinery MACT Standard Guidance
2. Is it an emission of organic HAPs from any of the following which is/are "in
oraanic hazardous air Dollutant service" (eauiDment containina or contactina
fluid > 5% by weight total organic HAP):
pump?
compressor?
pressure relief device?
sampling connection system?
open-ended valve or line?
valve?
instrumentation system?
Note: Equipment leaks applicability criteria are the same for existing and new
sources.
Note to inspector. The applicability sections of this checklist (i.e., General
Applicability and Applicability for Specific Emission Points) determines whetherthe
Petroleum Refinery MACT Standard applies to a particular refinery, and whether it
applies to a particular emission point. Unless otherwise noted, refineries are
required to control emissions from all Group 1 emission points to which the MACT
standard applies. Group 2 emission points are subject only to recordkeeping
requirements unless otherwise noted in the inspection guide.
Yes[ ] No[
]
Yes[ ] No[
]
Yes[ ] No[
]
Yes[ ] No[
]
Yes[ ] No[
]
Yes[ ] No[
]
Yes[ ] No[
]
III. COMPLIANCE DEADLINES
A. All new sources
Were all emission points in compliance at startupor by August 18, 1995,
whichever was later?
Yes [ ] No[ ]
B. Existing Miscellaneous Process Vents and Gasoline Loading Racks
Were all emission points in compliance by August 18, 1998?
Yes [ ] No[ ]
C. Existing Wastewater Streams
1. Were all emission points in compliance by August 18, 1998?
Yes [ ] No[ ]
2. Are all wastewater streams in compliance with the benzene waste
operations NESHAP (40 CFR 61, Subpart FF)?
Yes [ ] No [ ]
D. Existing Storage Vessels
1. Were all fixed roofvessels in compliance by August 18, 1998?
Yes [ ] No [ ]
2. Were fixed roofvessels for which the tanks that must be replaced in
compliance by August 18, 1999?
Yes [ ] No [ ]
3. Were floating roofvessels in compliance by August 18, 2005, or the next
scheduled maintenance and degassing after August 18, 1998, whichever is
first?
Yes [ ] No [ ]
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Petroleum Refinery MACT Standard Guidance
E. Marine Tank Vessel Loading Operations
1. Were operations in compliance by August 18, 1999?
Yes[ ] No[ ]
2. Are operations used to generate credit in an emissions average?
Yes [ ] No[ ]
Ifyes, were operations in compliance by August 18, 1998?
Yes[ ] No[ ]
If operations were not in compliance by August 18, 1998, was a case-by-
case 1-year extension granted?
Yes[ ] No[ ]
F. Equipment Leaks
1. Were equipment leaks in compliance by August 18, 1998?
Yes[ ] No[ ]
2. For sources that are complying with 40 CFR 60 Subpart VV or 40 CFR 63
Subpart H, are they meeting the deadlines in the 3 phases of emissions
reductions?
Yes[ ] No[ ]
IV. GENERAL STANDARDS TO ALL APPLICABLE EMISSIONS POINTS
A. Performance Testing
1. Did the facility conduct and initial performance test of all pollution control
equipment for which it is required?
(See Section I of this checklist for applicability. If the pollution control
equipment is required by the MACT standard, an initial performance test is
required. Note that no performance tests are required for floating roofs or
process heaters > 44 MW with vent introduced into the flame zone.)
Yes [ ] No[ ]
2. Was the initial performance test aDDroved bv EPA?
Yes[ ] No[ ]
3. Did the facility notifv the reaulatorv authority 30 davs Driorto conductina
each performance test?
Yes[ ] No[ ]
4. Were the tests conducted at the maximum reDresentative ODeratina
caDacitv?
Yes[ ] No[ ]
Were controls operating at either maximum or minimum representative
operating conditions for monitored parameters, whichever result in lower
emission reduction? [40 CFR 63.642 (d)(3)])
Yes[ ] No[ ]
B. Operating Permits
Did the owner or operator of the source subject to the standard apply for a one-
time Part 70 or Part 71 operating permit from the appropriate authority?
Yes [ ] No[ ]
C. Application for Approval of Construction or Reconstruction
If the source is a new or reconstructed source, did it submit an application for
approval of construction or reconstruction?
Yes[ ] No[ ]
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Petroleum Refinery MACT Standard Guidance
D. Notification of Compliance Status (NCS) Reports
1. Did the facilitv submit a Notification of ComDliance Status (NCS^ within
150 davs after each aDDlicable comDiiance deadline, or with the next
periodic report for new Group 1 emission points or floating roof storage
vessels brought into compliance after August 18, 1998?1
(See part III of this checklist for applicable compliance deadlines.)
Note: The NCS report may be included as a separate report, as an operating permit
application, or in an amendment to an operating permit application).
Yes[ ] No[ ]
2. Did the reDort identify each emission Doint and method of comDiiance?
Yes [ ] No[ ]
3. Did the report include the following:
a) Information on individual emission Doints to demonstrate comDiiance.
such as range of monitored parameters? [40 CFR 63.654(f)(1) and
(f)(3)]
Yes[ ] No[ ]
b^ Results of continuous monitorina svstem Derformance evaluations? MO
CFR 63.654(f)(4)]
Yes[ ] No[ ]
c) Determination of rule aDDlicabilitv to flexible ODeration units and storaae
vessels and distillation units for which use varies from year to year?
[40 CFR 63.654(h)(6)]1
Yes[ ] No[ ]
4. If the facility was required to conduct initial performance tests, did it submit
one examDle comDlete test reDort for each test method used?
Note: For additional tests using the same method, only the results of the each
additional test must be submitted. [40 CFR 63.654 (f)(2)]
Yes[ ] No[ ]
E. Periodic Reports
1. Have any compliance exceptions occurred within any 6-month reporting
period?
Yes [ ] No[ ]
a) If yes, has the facility submitted periodic reports within 60 days
after the end of each 6- month period?
Yes[ ] No[ ]
b) If the facility uses emissions averaging, has the facility submitted
reports quarterly? [40 CFR 63.654(g)]
Yes[ ] No[ ]
2. Were any new Group 1 emission points added or did any Group 2 emission
points become Group 1 emission points during the last 6-month period?
Yes[ ] No[ ]
a) If yes, was an NCS report included with the periodic report?
Yes[ ] No[ ]
3. Were any floating storage vessels brought into compliance during the last
6-month period?
Yes [ ] No[ ]
a) If yes, was an NCS report included with the periodic report?
Yes[ ] No[ ]
1This requirement reflects an amendment to 40 CFR Part 63 Subpart CC made on August 18, 1998.
For more information, see Appendix G.
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Petroleum Refinery MACT Standard Guidance
F. Startup, Shutdown and Malfunction Plans and Reports
1. Has the facility developed and implemented a startup, shutdown, and
malfunction plan for the entire facility?
Note: The plan is not required to include wastewater.
Yes[ ] No[ ]
a) If ves. does the malfunction Dlan describe procedures for ODeratina and
maintainina the source durina periods of startuD. shutdown, and
malfunction?
Yes [ ] No[ ]
Does the Dlan also include a Droaram of corrective action for
malfunction of process and air pollution control equipment used to
comply with the relevant standard?
Note: EPA typically defines malfunctions as rare, unforeseeable occurrences and
does not allow for facilities to operate in malfunction for extended periods of time.
Yes[ ] No[ ]
2. Has the facility prepared a Startup, Shutdown, and Malfunction Report to
document each:
a) Start of operation of a process unit for production?
Yes[ ] No[ ]
b) Cessation of a process unit for maintenance, repair, or eauiDment
replacement?
Yes[ ] No[ ]
c) Malfunction of a Drocess unit?
Yes[ ] No[ ]
3. Are corrective actions to address each malfunction consistent with the
startup, shutdown, and malfunction plan?
Yes [ ] No[ ]
a) If yes, has the facility submitted a statement to this effect in the semi-
annual report? [40 CFR 63.10(d)(5)(I)]
Yes[ ] No[ ]
b) If a malfunction occurs and corrective actions are not consistent with
the startup, shutdown, and malfunction plan, has the facility reported
this in the periodic report for the time period in which the malfunction
occurred?1
Note: If a malfunction does not occur during a reporting period, a startup, shutdown,
and malfunction report is not required.
Yes[ ] No[ ]
G. Reports Required for Special Situations
1. Does the facility use/intend to use alternative procedures (e.a.. procedures
other than those described in the MACT Standard) or devices to comply
with the MACT standard?
Yes[ ] No[ ]
a) If yes, has the facility submitted the following information 18 months
before the compliance date for existing sources, or with the approval of
construction for new sources:
Yes[ ] No[ ]
Reauest for aDDroval to monitor an alternative control device
operating parameter, with supporting justification? [40 CFR
63.654(h)(4)]
Yes [ ] No[ ]
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Petroleum Refinery MACT Standard Guidance
1This requirement reflects an amendment to 40 CFR Part 63 Subpart CC made on August 18, 1998.
For more information, see Appendix G.
Reauest for aDDroval to use data compression svstems instead of
keeping hourly records, with supporting information? [40 CFR
63.654(h)(5)]
Yes[ ] No[ ]
Request to use other alternative monitoring methods, with
supporting justification? [40 CFR 63.654(h)(5)(iv) and 63.8(f)(4)(H)]
Yes [ ] No[ ]
Request to establish an alternative emission standard, with a test
plan or results of testing and monitoring? [40 CFR 63.6(g)(2)]
Note: If EPA finds the alternative standard equivalent to the MACT standard, EPA
will request public comment and publish a Federal Register notice allowing its use.
Prior to conducting the inspection, the inspector should determine whether EPA has
recently adopted any alternative standards equivalent to the MACT standard, with
which the facility intends to comply.
Yes[ ] No[ ]
H. Requests for Extension of Compliance
1. Has the facility requested an extension of compliance either:
a) at least 12 months before the compliance date? or
Yes[ ] No[ ]
b) 18 months prior if emissions averaging is used?
Note: Facilities may request an extension of compliance if emissions reductions
been achieved early, or is the source is unable to comply with the relevant standard.
Requests for an extension of compliance can only be made for existing sources.
Yes [ ] No[ ]
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Petroleum Refinery MACT Standard Guidance
2. If the facility submitted a request for an extension, did the request include
the following:
a) Description of controls to be installed?
Yes[ ] No[ ]
b) Compliance schedule?
Yes [ ] No[ ]
c) Interim emission control steps?
Yes[ ] No[ ]
I. Applications for a Performance Test Waiver
1. Is the facility unable to conduct a performance test for reasons such as
technical or economic infeasibility, or other reasons, has an extension of
compliance been requested?
Yes[ ] No[ ]
2. If yes, has the facility submitted an application for waiver of a performance
test to the Administrator?
Yes[ ] No[ ]
3. Did the application include information justifying the request and detailing
the infeasibility? [40 CFR 63.7(h)(3)(iii)]
Yes[ ] No[ ]
J. Recordkeeping
1. Does the facility keep records of reports submitted, monitoring results, and
other records for at least 5 years? [40 CFR 63.642(e) and 63.654(l)(4)]
Yes [ ] No[ ]
2. Are records keDt so that thev are accessible within 24 hours of reauest in
either hard copy or computer-readable form? [40 CFR 63.642(e)]
Yes[ ] No[ ]
3. Are the following records maintained on site:
Records of the occurrence and duration of each startuD. shutdown, or
malfunction of operation and air pollution control equipment? [40 CFR
63.10(b)(2)(l-ii)]
Yes[ ] No[ ]
Records of actions that are consistent and inconsistent with the
startup, shutdown, and malfunction plan? [40 CFR 63.10(b)(2)(iv-v)]
Yes[ ] No[ ]
Records of continuous monitorina svstem calibration checks (if
continuous monitoring is required)? [40 CFR 63.10(b)(x)]
Yes[ ] No[ ]
• Records for storaae vessels?. [40 CFR 63.654(hCn]
Yes [ ] No[ ]
• Complete test reports and reported results for anv reauired
performance tests? [64.654(l)(2)]
Yes[ ] No[ ]
• Values of continuously monitored parameters? [40 CFR
63.654(l)(3)]
Yes[ ] No[ ]
Any additional records required by permit?
Yes[ ] No[ ]
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Petroleum Refinery MACT Standard Guidance
V. REQUIREMENTS FOR MISCELLANEOUS PROCESS VENTS
A. Miscellaneous Process Vents Control Requirements
1. Is the source an existing source, and the vent contains 20 ppmv or more of
organic HAPs, and emits 33 kg/day or more of total VOCs?
Yes[ ] No[ ]
2. Is the source a new source, and the vent contains 20 ppmv or more of
organic HAPs, and emits 6.8 kg/day or more of VOCs?
Yes [ ] No[ ]
a) If yes to 1 or 2, does the facility control its Miscellaneous Process
Vents by:
• Using a flare? or
Yes[ ] No[ ]
• Reducing organic HAPs by 98% orto 20 ppmv using
incinerators, boilers, process heaters, or other devices? or
Yes[ ] No[ ]
• If a boiler or process heater is used, the vent stream must be
introduced into the flame zone of the control device, or in a
location such that the required percent reduction or
concentration is achieved?
Yes[ ] No[ ]
B. Miscellaneous Process Vents Testing Requirements
1. Initial Performance Tests
a) Vents routed to a flare
Does the facility control Miscellaneous Process Vents emissions by
routing vents to a flare or by using other control devices?
Yes[ ] No[ ]
1) If the facility uses a flare, has the facility conducted an initial
performance test for each control device?
Yes [ ] No[ ]
2) Did the initial performance test show that the flare is operating
properly, and that the emission rate does not exceed the capacity
of the flame to control the emissions?
Yes[ ] No[ ]
3) For vents routed to a flare, did the initial performance test measure
the following:
• Emissions visibility?
Yes[ ] No[ ]
• Net heat value of combusted gas?
Yes[ ] No[ ]
• Flow rate of gases being combusted?
Yes[ ] No[ ]
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Petroleum Refinery MACT Standard Guidance

b) Vents routed to an incinerator or a boiler or process heater < 44
MW



For vents routed to an incinerator or a boiler or process heater < 44 MW
(150 MMBtu/hr) where the vent streams are not introduced into the
flame zone of the boiler or process heater, did the initial performance
test show compliance with the requirement to reduce organic HAPs by
98% or to 20 ppmv? [40 CFR 63.645 and 63.116 except (d) and (e)]
Yes [ ]
No [ ]

c) Vents routed to other control devices



Does the facility control Miscellaneous Process Vents emissions with:



1) Vents routed to a boiler or process heater > 44 MW(150
MMBtu/hr)? or
Yes [ ]
No [ ]
2) Vent streams that are introduced into the flame zone of the boiler or
process heater? or
Yes [ ]
No [ ]

3) A control device for which a performance test was conducted for
determination of compliance with an NSPS if no process changes
have been made?
Yes [ ]
No [ ]
Note: If the facility answered yes to any of these questions (B.1 .c) performance
tests are not required for these vents.


2.
Sampling for initial performance tests



a) Does the facility conduct performance test sampling and analysis
according to the prescribed EPA-approved methods?
Yes [ ]
No [ ]
3.
Follow-up tests to process changes



a) Have any process changes occurred at the facility?
Yes [ ]
No [ ]
1) If yes, for each process change affecting a Group 2 process vent,
did the facility recalculate the TOC emission rate to determine
whether the vent remains a Group 2 process vent or becomes a
Group 1 process vent?
Yes [ ]
No [ ]

2) Was recalculation based on vent stream flow rate and TOC
measurements as specified for initial performance tests or best
engineering assessment practices?
Yes [ ]
No [ ]
Note: That process changes include, but are not limited to, changes in production
capacity, production rate, or catalyst type; whenever there is replacement, removal,
or addition of recovery equipment; and debottlenecking activities.


(Process changes do riot include process upsets, unintentional, temporary process
changes, or changes that are within the range on which the original calculation was
based.)


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Petroleum Refinery MACT Standard Guidance
C. Miscellaneous Process Vents Monitoring Requirements
1. Miscellaneous process vents routed to a flare
For miscellaneous process vents routed to a flare, is a monitoring device
caDable of continuouslv detectina the Dresence of a Dilot flame (includina. but
not limited to a thermocouple, an ultraviolet beam sensor, or an infrared
sensor) used?
Yes[ ] No[ ]
2. Miscellaneous process vents routed to incinerators other than catalytic
incinerators
For miscellaneous process vents routed to incinerators other than catalytic
incinerators, is a temperature monitorina device with a continuous recorder
used?
Yes [ ] No[ ]
Is the device located in the firebox or in the duct work immediately
downstream of the firebox in a position before anv substantial heat exchanae
occurs?
Yes[ ] No[ ]
3. Miscellaneous Process Vents routed to catalytic incinerators
For Miscellaneous Process Vents routed to catalytic incinerators, is a
temperature monitorina device with a continuous recorder used?
Yes[ ] No[ ]
Is the device located in the gas stream immediately before and after the
catalyst bed?
Yes[ ] No[ ]
4. Miscellaneous process vents routed to boiler or process heaters with a
design heat capacity <44 megawatts where the vent streams are not
introduced into the flame zone
For miscellaneous process vents routed to boiler or process heaters with a
design heat capacity <44 megawatts where the vent streams are not
introduced into the flame zone, is a temperature monitorina device with a
continuous recorder used?
Yes[ ] No[ ]
Is the device located in the firebox?
Note: No monitoring is required for boilers or process heaters.
Yes [ ] No[ ]
5. Refineries that use a vent system with bypass line valves that have not
been sealed or secured.
For refineries that use a vent system with bypass line valves that have not
been sealed or secured, is a flow indicator that determines at least everv hour
whether a vent stream flow is present used?
Yes[ ] No[ ]
Is the indicator located at the entrance to any bypass line that could divert
the vent stream away from the control device to the atmosphere?
Yes[ ] No[ ]
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Petroleum Refinery MACT Standard Guidance
6. Refineries that use a vent system with bypass lines, where the valves
have been secured in the closed position with a car-seal or a lock-and
key-type configuration.
For refineries that use a vent system with bypass lines, where the valves have
been secured in the closed position with a car-seal or a lock-and key-type
confiauration. are the valves visuallv insDected at least everv other month to
ensure that they are maintained in the closed position and the vent stream is
not diverted through the bypass line?
Yes[ ] No[ ]
7. Refineries using other approved control devices
For refineries using other approved control devices or requesting to monitor
other parameters, is the facility complying with any site-specific monitoring
requirements?
Yes [ ] No[ ]
D. Miscellaneous Process Vents Reporting Requirements
1. Notice of Compliance Status (NCS) reports
a) All miscellaneous process vents affected by the MACT standard
For miscellaneous process vents affected by the MACT standard, has the
refinery submitted an NCS report that identifies the following:
1) Each vent?
Yes [ ] No[ ]
2) Whether the process vent is Group 1 or Group 2?
Yes [ ] No[ ]
3) For each Group 1 vent that is not included in an emissions average,
the method of compliance (e.g., use of a flare or other control device
meeting the requirements of the MACT standard)? [40 CFR
63.643(a)]
Note: If the required information has been submitted at an earlier date, or at different
times, and/or in different submittals, later submittals may refer to earlier submittals
instead of duplicating and resubmitting previously submitted information.
Yes [ ] No[ ]
4) For miscellaneous process vents with control devices required to be
tested underthe MACT standard, did the NCS include information on
each testina method, and results of the performance test since there
are different requirements for each test and test method used?
Yes [ ] No [ ]
5) For each test method used, did the NCS include the following test
results:
a) The percentage reduction of organic HAPs or TOC or the outlet
concentration of organic HAPs or TOC (ppm by volume on a dry
basis corrected to 3 percent oxygen), determined as specified in 40
CFR 63.116(c)?
Yes [ ] No [ ]
b) The value of the monitored parameter specified in 40 CFR 63
Subpart CC, Table 10 or a site specific parameter approved by the
permitting authority, averaged overthe full period ofthe performance
test?
Yes [ ] No[ ]
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Petroleum Refinery MACT Standard Guidance
6) For each test method used, does the NCS include the following
supporting information:
a) Sampling site description?
Yes[ ] No[ ]
b) Description of sampling and analysis procedures, and any
modifications to standard procedures?
Yes [ ] No[ ]
c) Quality assurance procedures?
Yes[ ] No[ ]
d) Record of operating conditions during the test?
Yes[ ] No[ ]
e) Record of preparation of standards?
Yes[ ] No[ ]
f) Record of calibrations?
Yes[ ] No[ ]
g) Raw data sheets for field sampling?
Yes [ ] No[ ]
h) Raw data sheets for field and laboratory analyses?
Yes[ ] No[ ]
1) Documentation of calculations?
Yes[ ] No[ ]
j) Any other information required by the test method?
Yes[ ] No[ ]
7) If the same test is conducted for multiple emission points, did the
facility submit the following:
a) one complete test report for each test method used for each
emission point?
Yes[ ] No[ ]
b) for additional tests using the same method, the additional test
results?
Yes [ ] No[ ]
8) Miscellaneous Process Vents Controlled by Flares
a) For vents controlled by flares, did the NCS include the following test
results:
all visible emission readings?
Yes[ ] No[ ]
heat content determinations?
Yes[ ] No[ ]
flow rate measurements?
Yes[ ] No[ ]
exit velocity determinations made during the compliance
determination? [40 CFR 63.654(f)(1 )(iv)(A)]
Yes [ ] No[ ]
b^ For vents controlled bv flares, a statement of whether a flame was
Dresentatthe Dilot liaht over the full Deriod of the comDliance
determination? [40 CFR 63.654(f)(1)(iv)(B)]
Yes[ ] No[ ]
c) If a parameter other than the presence of a pilot flame is monitored,
the acceptable range forthe parameter and the rationale (including
any supporting data or calculations) forthe range?
Note: Results of a prior performance test can be used if that test was conducted
using the methods specified in 40 CFR 63.645 and test conditions were
representative of current operating conditions.
Yes[ ] No[ ]
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Petroleum Refinery MACT Standard Guidance
9) Vents routed to an incinerator or boiler or process heater < 44
MW where the vent streams are not introduced into the flame
zone
In addition to the information required for all miscellaneous process
vents, do NCS reports for vents routed to an incinerator or boiler or
process heater < 44 MW where the vent streams are not introduced
into the flame zone include the following information:
a) Average firebox temperature (or gas stream temperature for
catalytic incinerators) over the duration of the performance test?
Yes[ ] No[ ]
b) Acceptable range for the daily average firebox temperature and
rationale for the range?
Yes [ ] No[ ]
c) Times at which an operating day begins and ends?
Yes[ ] No[ ]
2. Periodic reports
a) Has the refinerv experienced anv compliance exceptions or periods of
excess emissions?
(Compliance exceptions and periods of excess emissions do not include
periods of startup, shutdown, malfunction, performance testing and
monitoring system calibration.)
Yes[ ] No[ ]
b) Has the refinerv submitted the appropriate periodic reports reaardina the
compliance exceptions or periods of excess emissions?
Yes[ ] No[ ]
1) Were the reports submitted no later than 60 days after the end of
each 6-month period when any compliance exceptions occur?
Note: The first 6-month period begins on the date the NCS report is required to be
submitted.
Yes[ ] No[ ]
2) If the refinery uses emissions averaging, were the reports submitted
quarterly?
Yes [ ] No[ ]
3) For control devices for which an initial performance test is required
(flare, incinerator, and boiler or process heater < 44 MW where the
vent streams are not introduced into the flame zone), did the facility
submit the following information in the periodic report:
• Complete test report for initial performance test results?
Yes[ ] No[ ]
• Times and duration of periods when monitoring devices are
not operating?
Yes[ ] No[ ]
4) Periodic Reports for vents routed to a flare
For vents routed to a flare, did the facility submit a record of each
pilot flame determination (or alternate parameter upon request and
approval) in the periodic report?
Yes[ ] No[ ]
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Petroleum Refinery MACT Standard Guidance
5) Periodic Reports for vents routed to an incinerator or boiler
or process heater < 44 MW where the vent streams are not
introduced into the flame zone
For vents routed to an incinerator or boiler or process heater < 44
MW where the vent streams are not introduced into the flame zone,
did the facility submit the following information in the periodic
report:
• Record of each firebox temperature value or a block
average of values for periods of 1 hour or less?
Yes[ ] No[ ]
• Record of the dailv averaae firebox temperature?
Note'. If all hourly temperature values are within the range reported in the NCS, the
facility may record that all values are within the range instead of daily average
values.
Yes [ ] No[ ]
VI. REQUIREMENTS FOR STORAGE VESSELS
A. Control Requirements for Storage Vessels
1. For storage vessels with floating roofs does the facility use one of the
following control devices?
Yes[ ] No[ ]
a) Internal floating roof with specified seals?
Yes[ ] No[ ]
b) External floating roof?
Yes[ ] No[ ]
c) External floating roof converted to an internal floating roof (i.e., fixed roof
installed above the external floating roof)?
Yes[ ] No[ ]
2. For storage vessels with closed vent systems, does the facility use a closed
vent system routed to a flare or other control device that reduces HAP
emissions by 95% or to 20 ppmv?
Yes [ ] No[ ]
3. Are all storage vessels that store a liquid with a maximum true vapor
pressure of total organic HAPs > 76.6 kPa controlled by a closed vent
system and control device? [40 CFR 63.119(a)(2)]
Yes[ ] No[ ]
- If yes, are, work practices, as specified in 40 CFR 63.119(b) through (e),
followed for each of the control methods?
Yes[ ] No[ ]
4. Storage vessels at new sources
a) In addition to the above control requirements, did storage vessels at new
sources also install deck fitting controls, as specified in 40 CFR
63.119(c)(2)(l) through (xii), on all floating roof tanks?
Yes[ ] No[ ]
b) Do storage vessels at new sources also apply the control requirements of
40 CFR 63.119(b)(5) and (b)(6)?
Yes[ ] No[ ]
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Petroleum Refinery MACT Standard Guidance
B. Testing Requirements for Storage Vessels


1. Initial Performance Tests for Closed Vent Systems Routed to a Flare


a) For storage vessels equipped with a closed vent system routed to a flare,
has the facility conducted an initial performance test or compliance
determination, as specified in 40 CFR 63.11(b), to ensure compliance with
the control requirement to reduce total organic HAP emissions by 95% or
to 20 ppmv?
Yes [ ]
No [ ]
1) Ifyes, did the test include the measurement/determination ofthe
following:


• Emissions visibility?
Yes [ ]
No [ ]
• Net heat value of combusted gas?
Yes [ ]
No [ ]
• Flow rate of gases being combusted?
Yes [ ]
No [ ]
• Exit velocity?
Yes [ ]
No [ ]
2. Initial Performance Tests for Closed Vent Systems Routed to a Control
Device Other Than a Flare


a) For storage vessels equipped with a closed vent system routed to a
control device other than a flare, did the facility conduct either an initial
design evaluation, as specified in 40 CFR 63.120(d)(1 )(l), or an initial
performance test, as specified in 40 CFR 63.120(d)(1)(H)?
Yes [ ]
No [ ]
C. Monitoring and Inspection Requirements for Storage Vessels for Storage
Vessels Required to Apply Controls


1. Storage vessels equipped with a closed vent system


For storage vessels equipped with a closed vent system, does the facility
monitor the parameters proposed in the Notice of Compliance Status (NCS)
report to ensure that the control device is being properly operated and
maintained?
Yes [ ]
No [ ]
Note: There are no monitoring requirements for storage vessels equipped with
floating roofs.


2. Closed vent systems routed to a control device


Does the facility inspect closed vent systems routed to a control device every
12 months as specified in 40 CFR 63.148?
Yes [ ]
No [ ]
3. Storage Vessels with floating roofs


a) Do the storage vessels have a single-seal system or a double-seal
system?
Yes [ ]
No [ ]
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Petroleum Refinery MACT Standard Guidance
b) Storage vessels with a single seal system
For storage vessels with a single seal system and equipped with a fixed
roof and an internal floating roof or an external floating roof converted to an
internal floating roof, does the refinery conduct the following inspections:
1) Visuallv insDect the internal floatina roof and Drimarv seal throuah
manholes and roof hatches at least once every 12 months after initial
fill, or at least every 12 months after the compliance date?
Yes[ ] No[ ]
2) Visuallv inspect the internal floatina roof and Drimarv seal each time
the storaae vessel is emDtied and deaassed and at least once everv
10 vears after the compliance date?
Yes [ ] No[ ]
3) Visuallv inspect aaskets. slotted membranes, and sleeve seal (if anv)
each time the storaae vessel is emptied and deaassed and at least
once everv 10 vears after the comDliance date (new source only)?
Yes[ ] No[ ]
c) Storage vessels with a double single seal system
For storage vessels with a double single seal system and equipped with a
fixed roof and an internal floating roof or an external floating roof converted
to an internal floating roof, does the refinery conduct the following:
1) Visuallv inspect the internal floatina roof. Drimarv seal, and secondary
seal each time the vessel is emptied and degassed and at least once
everv 5 vears after the comDliance date? or
Yes[ ] No[ ]
2) Visuallv insDect the internal floatina roof and the secondary seal
throuah manholes and roof hatches at least once everv 12 months
after initial fill, or at least every 12 months after the compliance date;
and
Yes[ ] No[ ]
3) Visuallv insDect the internal floatina roof. Drimarv seal, and secondary
seal each time the vessel is emptied and degassed and at least once
every 10 years after the compliance date?
Yes[ ] No[ ]
d) Storage vessels equipped with an external floating roof
1) For storage vessels equipped with an external floating roof, does the
facility visuallv insDect the followina. each time the vessel is emDtied
and deaassed:
external floating roof?
Yes [ ] No[ ]
- the primary and secondary seals?
Yes[ ] No[ ]
fittings?
Yes[ ] No[ ]
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Petroleum Refinery MACT Standard Guidance
2) For storage vessels equipped with an external floating roof, does the
facility conduct the following additional inspections:
• For single-seal systems, does the facility:
- Measure the gaps between the vessel wall and the primary seal
by the compliance date and at least once a year, until a
secondary seal is installed?
Yes[ ] No[ ]
- When a secondary seal is installed, measure gaps between the
vessel wall and both the primary and secondary seal within 90
calendar days of installation, and then comply with the double-
seal inspection requirements? [40 CFR 63.120(b)(1 )(ii)]
Yes [ ] No[ ]
• For double-seal systems, does the facility:
- Measure the gaps between the vessel wall and the primary seal
during hydrostatic testing or by the compliance date and at
least once every 5 years thereafter?
Yes[ ] No[ ]
- Measure the gaps between the vessel wall and the secondary
seal by the compliance date and at least once a year?
Yes[ ] No[ ]
D. Reporting Requirements for Storage Vessels Equipped with Closed Vent
Systems
1. Notice of Compliance Status Reports
a) Storage vessels equipped with a closed vent system routed to a
flare
For storage vessels equipped with a closed vent system routed to a flare,
does the NCS contain the results of the initial performance test, including:
• Flare design, such as steam-assisted, air-assisted, or non-
assisted?
Yes[ ] No[ ]
• Visible emissions readings?
Yes[ ] No[ ]
• Heat content determinations?
Yes [ ] No[ ]
• Flow rate measurements?
Yes[ ] No[ ]
• Exit velocity determinations?
Yes[ ] No[ ]
• Periods during the compliance determination when the pilot flame is
absent?
Yes[ ] No[ ]
b) NCS Reports for storage vessels equipped with a closed vent
system routed to a control device other than a flare
For storage vessels equipped with a closed vent system routed to a
control device other than a flare, does the NCS also include:
• Description of the parameter(s) to be monitored to ensure proper
operation and maintenance of the control device?
Yes[ ] No[ ]
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Petroleum Refinery MACT Standard Guidance
• Explanation of the parameter selection?
Yes [ ]
No [ ]
• Frequency of monitoring?
Yes [ ]
No [ ]
• Design evaluation documentation, as specified in 40 CFR
63.120(d)( 1)(I), or results of the initial performance test including
identification of emission points sharing the control device?
Yes [ ]
No [ ]
2. Periodic Reports


a) Have any compliance exceptions regarding storage vessels occurred?
Yes [ ]
No [ ]
If yes, has the facility submitted the appropriate periodic reports for
storage vessels?
Yes [ ]
No [ ]
b) Periodic Reports for storage vessels equipped with a closed vent
system routed to a control device


For storage vessels equipped with a closed vent system routed to a
control device, do periodic reports include a description of the following:


• Routine maintenance for the control device that was performed
during the previous 6 months?
Yes [ ]
No [ ]
• Routine maintenance anticipated for the control device for the next
6 months?
Yes [ ]
No [ ]
• For a control device that is a flare, each occurrence and cause
when the requirements specified in 40 CFR 63.11(b) are not met?
Yes [ ]
No [ ]
• For a control device other than a flare, each occurrence and cause
of monitored parameters being outside the ranges documented in
the NCS?
Yes [ ]
No [ ]
c) Periodic reports for storage vessels equipped with any type of
floating roof


For storage vessels equipped with any type of floating roof, do the
periodic reports contain the results of each inspection in which a failure
was detected, including:


1) Date of inspection?
Yes [ ]
No [ ]
2) Identification of the storage vessel?
Yes [ ]
No [ ]
3) Description of the failure?
Yes [ ]
No [ ]
4) Nature and date of repair or date the vessel was emptied?
Yes [ ]
No [ ]
d) Did the facility apply for an extension beyond the 45 day period for
correcting failures identified during inspections of storage vessels?
Yes [ ]
No [ ]
1) If the facility applied for an extension, did the corresponding
periodic reports also include the following information:


• Description of the failure?
Yes [ ]
No [ ]
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Petroleum Refinery MACT Standard Guidance
• Statement that alternate storage capacity is unavailable?
Yes[ ] No[ ]
• Schedule of actions that will ensure that the control
equipment will be repaired or the vessel will be emptied as
soon as possible?
Note: If the vessel cannot be repaired or emptied within 45 days, the facility may
utilize up to 2 extensions of up to 30 additional days each.
Yes [ ] No[ ]
e) Storage vessels equipped with an external floating roof
For storage vessels equipped with an external floating roof, did the
facility conduct anv aaD measurement?
Yes[ ] No[ ]
1) If yes, did the facility notify the Administrator 30 days in advance of
the gap measurement?
Yes[ ] No[ ]
2) Were the requirements of 40 CFR 63.120(b)(3), (4), (5), or (6) not
met for any of the gap measurements?
Yes[ ] No[ ]
If yes, were the results of the gap measurement in which the
requirements were not met included in the periodic reports?
Yes[ ] No[ ]
- Was the following information included in the reports:
• Date of seal gap measurement?
Yes [ ] No[ ]
• Raw data and calculations described in 63.120(b)(5) or (6)?
Yes[ ] No[ ]
• Description of seal conditions that are not met?
Yes[ ] No[ ]
• Nature and date of repair or date the vessel was emptied?
Yes[ ] No[ ]
f) Floating Roof Storage Vessel Brought into Compliance after
August 18,1998.
Do the Periodic Reports include a NCS for each floating roof storage
vessel brought into compliance during the reporting period?1
Yes[ ] No[ ]
a) If yes, does the NCS include the method of compliance?
Yes [ ] No[ ]
b) If yes, does the NCS include a list of all other floating roofs subject
to control requirements that are not yet in compliance and their
expected compliance date?
Yes[ ] No[ ]
c) If yes, forfloating roof vessels brought into compliance, including
those brought into compliance during the last reporting period, does
the NCS include the actual date of compliance?
Yes[ ] No[ ]
3. Internal Inspection Notifications
a) Did the facility notifv the Administrator of fillina or refillina of each storaae
vessel with organic HAPs?
Yes[ ] No[ ]
b) Did the facility notifv the Administrator at least 30 calendar davs Drior to
any scheduled internal inspections?
Yes [ ] No[ ]
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If not, was the internal inspection not planned? and
Yes[ ] No[ ]
- Could the owner/operator of the refinery not have known about the
inspection 30 calendar days in advance of refilling the vessel with
organic HAPs?
Yes [ ] No[ ]
c) If the inspection is not planned and the owner/operator could not have
known about it in advance, did the facility notify the Administrator at
least 7 calendar davs Driorto refillina the storaae vessel?
Yes[ ] No[ ]
If the notification was made by telephone, was it immediately
followed by written documentation demonstrating why the
inspection was unplanned?
Yes[ ] No[ ]
1This requirement reflects an amendment to 40 CFR Part 63 Subpart CC made on August 18, 1998.
For more information, see Appendix G.
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Petroleum Refinery MACT Standard Guidance
If the notification was made in writing, was it is received by the
Administrator at least 7 calendar days prior to the refilling?
Note: If the State or local permitting authority has received delegation of the Refinery
MACT (not all states have as of August 1997), they can waive the notification
requirements for all or some storage vessels at petroleum refineries. The State or
local permitting authority may also grant permission to refill storage vessels sooner
than 30 days after submitting the required notification under 40 CFR
64.654(h)(2)(l)(A) or sooner than 7 days after submitting the notification under 40
CFR 64.654(h)(2)(l)(B) on a case-by-case basis.
Yes[ ] No[ ]
E. Recordkeeping Requirements for Storage Vessels
1) All Storage Vessels
- For all storage vessels, does the facility maintain records of Group 1 or
Group 2 determinations, vessel dimensions, and analysis of capacity for 5
years?
Yes [ ] No[ ]
- In addition, does the facility maintain all information required to be reported
for 5 years?
Yes[ ] No[ ]
2) Storage vessels equipped with a closed vent system routed to a
control device
For storage vessels equipped with a closed vent system routed to a control
device, does the facility also maintain the following records for 5 years:

a) Complete test report for initial performance test results?
Yes [ ] No[ ]
b) Measured values of monitored parameters?
Yes [ ] No[ ]
c) Planned routine maintenance performed, including:
- The first time of day and date the control requirements are not met at the
beginning of the planned routine maintenance? and
Yes [ ] No[ ]
- The first time of day and date the control requirements are met at the
conclusion of the planned routine maintenance?
Yes [ ] No [ ]
4) For storage vessels equipped with any type of floating roof, does the facility
retain records of each inspection performed? MO CFR 63.123c and (e)l
Yes [ ] No [ ]
5) For storage vessels equipped with an external floating roof, does the facility
retain records of each seal aaD measurement, includina date, raw data
obtained in the measurement, and the calculations described in 40 CFR
63.120(b)(3) and (4)?
Yes [ ] No[ ]
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VII. REQUIREMENTS FOR WASTEWATER STREAMS
A. Control Requirements for Wastewater Streams
Note: If a refinery is in compliance with the benzene waste NESHAP [40 CFR 61
Subpart FF], it is considered to be in compliance with the refinery MACT standard.
Provisions of the benzene waste NESHAP apply to the following wastewater
streams at petroleum refineries:
(1)	Total benzene loading > 10 Mg per year, and
(2)	Flow rate > .02 liters per minute, and
(3)	Benzene concentration > 10 ppm by weight, and
(4)	Not exempt from controls under the benzene waste NESHAP.)
1. Has the refinery reduced benzene mass emissions from wastewater streams
by 99% by using suppression followed by steam stripping, biotreatment, or
other treatment process?
Yes[ ] No[ ]
2. For vents from steam strippers and other waste management or treatment
units, does the facility utilize a control device that achieves 95% emission
reduction or 20 ppmv at the outlet of the control device?
Yes [ ] No[ ]
B. Testing and Monitoring Requirements for Wastewater Streams
1. Do all wastewater streams at the facility comply with the testing
requirements of the benzene waste NESHAP found in 40 CFR 61.340 through
61.355?
Yes[ ] No[ ]
2. Is testing done at the required frequency?
Yes[ ] No[ ]
3. If required, are periodic measurements of the benzene concentration in the
wastewater performed?
Yes[ ] No[ ]
4. If required, does the facility conduct monitoring of the process or control
device operating parameter?
Yes[ ] No[ ]
C. Reporting and Recordkeeping Requirements for Wastewater Streams
1. Do all wastewater streams comply with the reporting requirements of the
benzene waste NESHAP found in 40 CFR 61.356 and 61.357? [40 CFR
63.654(a)]
Yes [ ] No[ ]
2. In addition, is all information required to be reported retained for 5 years? [40
CFR 63.654(l)(4)]
Note: Since affected sources should already be in compliance with 40 CFR 61
Subpart FF, they will not need to make any changes to their current reporting and
recordkeeping procedures in order to comply with the Petroleum MACT standard.
Yes[ ] No[ ]
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VIII. REQUIREMENTS FOR GASOLINE LOADING RACKS
A. Control Requirements for Gasoline Loading Racks
Is the facility in compliance with the gasoline distribution facilities NESHAP
found in 40 CFR 63 Subpart R, which requires the facility to:
1.	Reduce emissions of total organic compounds (TOC) to 10 milligrams per
liter of gasoline loaded; and
2.	Load gasoline only in vaportight cargo tanks that have been tested to assure
vaportightness?
Yes[ ] No[ ]
B. Testing and Monitoring Requirements for Gasoline Loading Racks
1. Is the facility in compliance with the testing and monitoring requirements of
the gasoline distribution facilities NESHAP found in 40 CFR 63.425(a)
through (c) (performance tests), 63.425(e) through (h) (annual certification),
63.425(f) (leak detection tests), 63.425(g) (nitrogen pressure decay field
tests), and 63.427 (continuous monitoring)?
Yes [ ] No[ ]
2. Initial Performance Tests
a) Did the facility conduct an initial performance test for gasoline racks
according to the test methods and procedures in 40 CFR 60.503 (except
using a reading of 500 ppm to determine the level of leaks to be repaired
under 40 CFR 60.503)?
Yes[ ] No[ ]
b) Did the facility conduct any follow-up tests following process changes?
Yes[ ] No[ ]
If yes, did the refinery document the reasons for any change in the
operating parameter value since the previous test?
Yes[ ] No[ ]
c) If the facility is using a closed vent system and control device as specified
in 40 CFR 60.112b(a)(3) to control emissions from gasoline loading racks,
did the facility conduct initial performance tests on the control devices?
[40 CFR 63.423]
Yes[ ] No[ ]
d) If the facility uses a flare to control emissions, and emissions from the
gasoline loading rack cannot be measured using the methods specified in
40 CFR 60.503, is the refinery in compliance with the provisions of 40
CFR 63.11(b)?
Yes [ ] No[ ]
3. Annual Certification Tests
Does the facility conduct annual tests on gasoline cargo tanks to certify that
emissions controls are functioning properly?
Yes[ ] No[ ]
If yes, is the annual performance test conducted according to the
vacuum and pressure tests described in Method 27 of 40 CFR 60
Appendix A?
Yes[ ] No[ ]
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4.
Leak Detection Tests



During loading operations, does the facility conduct a leak detection test for
gasoline cargo tanks according to Method 21 of 40 CFR 60 Appendix A?
Yes [ ]
No [ ]
a) Are the tests conducted on each compartment durina the loadina of
that compartment, or while the compartment is still under pressure?
Yes [ ]
No [ ]

b) In addition to Method 21, are the following requirements for the test
met [40 CFR 63.425]:



• To eliminate a positive instrument drift, does the dwell time for
each leak detection not exceed two times the instrument
response time?
Yes [ ]
No [ ]
• Is the instrument purged with ambient air between each leak
detection?
Yes [ ]
No [ ]
• Is the duration of the purge in excess of two instrument
response times?
Yes [ ]
No [ ]
• Does the facility attempt to block the wind from the area being
monitored, and record the highest detector reading and location
for each leak?
Yes [ ]
No [ ]
5.
Additional Testing Requirements



a) For cargo tanks with manifolded product lines, does the facility conduct a
nitrogen pressure decay field test on each compartment of each tank?
(This test is described in 40 CFR 63.425(g).)
Yes [ ]
No [ ]
b) Does the facility also conduct a continuous performance pressure decay
test, as described in 40 CFR 63.425 (h)?
Yes [ ]
No [ ]
6.
Continuous Monitoring



Are gasoline loading racks in compliance with the continuous monitoring
requirements of 40 CFR 63.427(a) and (b)?
Yes [ ]
No [ ]
a) Is the continuous monitoring system installed, calibrated, certified,
operated and maintained according to manufacturer specifications?
Yes [ ]
No [ ]
b) Is the location where the continuous monitoring system is installed
appropriate to the type of system used (e.g., carbon adsorption,
refrigeration condenser, thermal oxidation, or flare)?
Yes [ ]
No [ ]
C. Reporting and Recordkeeping Requirements for Gasoline Loading Racks


1.
Did the facility include the NCS for the gasoline loading racks in the initial
NCS for the refinery?
Yes [ ]
No [ ]
2.
For gasoline loading racks, does the facility comply with the reporting and
recordkeeping requirements of the gasoline distribution facilities NESHAP
found in 40 CFR 63.428(b), (c), (g)(1), and (h)(1) through (h)(3)?
Yes [ ]
No [ ]
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3. Does the facility retain all required records for 5 years?
Yes [ ]
No [ ]
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Petroleum Refinery MACT Standard Guidance
IX. REQUIREMENTS FOR MARINE TANK VESSEL LOADING
A. Control Requirements for Marine Tank Vessel Loading
Are all marine tank vessel loading operations that are subject to the MACT
standard in compliance with the marine tank loading NESHAP found in 40 CFR
63 Subpart Y, which requires the following:
1. For existing sources does the facility utilize controls that:
• Collect vapors discharged during loading?
Yes[ ] No[ ]
• Load only in vapor tight vessels?
Yes [ ] No[ ]
• Reduce collected HAP emissions by 97% or use vapor balancing?
Yes[ ] No[ ]
2. For new sources does the facility utilize controls that:
• Collect vapors discharged during loading?
Yes[ ] No[ ]
• Load only in vapor tight vessels?
Yes[ ] No[ ]
• Reduce collected HAP by 98% or use vapor balancing?
Yes[ ] No[ ]
B. Testing and Monitoring Requirements for Marine Tank Vessel Loading
For all marine tank vessel loading subject to the MACT Standard, does the
refinery comply with the testing and monitoring requirements of the marine tank
loading NESHAP found in 40 CFR 63.560 through 63.567?
Note: The Initial Notification Report under 40 CFR 63.567(b) is not required.
Yes [ ] No[ ]
C. Reporting and Recordkeeping Requirements for Marine Tank Vessel
Loading
1. For all marine tank vessel loading subject to the MACT standard, does the
refinery comply with the reporting and recordkeeping requirements of the
marine tank loading NESHAP found in 40 CFR 63.566, 63.567(a) and (c)
through (I)?
Yes[ ] No[ ]
2. Does the facility retain all records required to be kept for 5 years?
Yes[ ] No[ ]
X. REQUIREMENTS FOR EQUIPMENT LEAKS
A Control Requirements for Equipment Leaks
1. For equipment leaks at existing sources, does the facility comply with either
of the following equipment leaks provisions:
(a) 40 CFR 60 Subpart VV (synthetic organic chemical manufacturing
industry (SOCMI) equipment leaks NSPS)?or
Yes[ ] No[ ]
(b) Modified 40 CFR 63 Subpart H (hazardous organic NESHAP (HON)
negotiated regulation)?
Yes[ ] No[ ]
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2. For equipment leaks at new sources, does the facility must comply with
modified 40 CFR 63 Subpart H?
Yes[ ] No[ ]
B. Testing, Inspection, and Monitoring Requirements for Equipment Leaks?
For all equipment leaks subject to the MACT standard, does the refinery
comply with the testing, inspection, and monitoring requirements for
equipment leaks in 40 CFR 60.1046 and 60.1047 (40 CFR 60 Subpart VV), or
40 CFR 63.162 through 63.180 (40 CFR 63 Subpart H)?
Yes [ ] No[ ]
C. Reporting and Recordkeeping Requirements for Equipment Leaks
For all equipment leaks subject to the MACT Standard, does the refinery
comply with the reporting and recordkeeping requirements for equipment
leaks found in 40 CFR 60.1048 and 60.1049 (40 CFR 60 Subpart VV),
(except the name rather than the signature of the person deciding to delay
repair must be recorded)1, or 40 CFR 63.181 and 63.182 (40 CFR 63 Subpart
H) (except for 63.182(b), (c)(2), and (c)(4))?
Yes[ ] No[ ]
XI. EMISSIONS AVERAGING
A Emissions Averaging Applicability
Did the facility conduct emissions averaging?
Yes[ ] No[ ]
If yes, did the facility conduct emissions averaging only for emission points at
a single refinery?
Note: Emissions averaging is not allowed across sources, such as across different
plant sites or between refinery and HON sources (i.e., units having a hazardous
organic air pollutant as its primary product) at the same plant site. In addition, an
emissions estimation is only required for points included in emissions averages, not
for all points in the source.
A limitation on the emissions averaging provision is that States have the authority to
disallow emissions averaging and require the application of standard control
requirements to all emission points.
Yes[ ] No[ ]
B. Emissions Averaging Credit/Debit System
1. Were emission credits and debits calculated on a mass basis usina
equations in 40 CFR 63.652(g) and (h) based on actual operations?
Yes [ ] No[ ]
2. Were credits calculated areaterthan or eaual to debits calculated on an
annual basis? [40 CFR 63.652(e)(3)!
Yes [ ] No[ ]
3. Did debits exceed credits by more than 30% in any one quarter? [40 CFR
652(e)(4)]
Yes [ ] No[ ]
1This requirement reflects an amendment to 40 CFR Part 63 Subpart CC made on August 18, 1998.
For more information, see Appendix G.
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4. Were any emission points otherthan the following used to generate
emissions averaging credits [40 CFR 63.652(c)(1) through (3)]:
•	Group 2 emission points.
•	Group 1 emission points controlled by technology with a higher nominal
efficiency than the reference control technology.
•	Emission points from which emissions are reduced by pollution reduction
measures, alone or in conjunction with other controls, that get more
emission reduction than required?
Yes[ ] No[ ]
5. Did the facility use any of the following emission points to generate
emissions averaging credits [40 CFR 63.652(d)]:
• Emission points already controlled on or before November 15, 1990,
unless the level of control was increased after November 15, 1990? (If so,
credit is allowed for the increase only.)
Yes [ ] No[ ]
• Group 1 emission points that are controlled by a reference control
technology, unless the technology has been approved for use in a different
manner and a higher nominal efficiency has been assigned?
(For example, it is not allowable to claim that an internal floating roof meeting only
the specifications stated in the reference control technology definition in 40 CFR
63.641 applied to a storage vessel is achieving greater than 95 percent control.)
Yes[ ] No[ ]
• Emission points on shutdown process units?
Yes[ ] No[ ]
• Emission points controlled to comply with a State or other Federal rule,
unless the level of control has been increased after November 15, 1990
above what is required by the State or other Federal rule?
Note: If the facility used any ofthese emission points, credit is allowed forthe
increase only.
Yes[ ] No[ ]
Note: Debits are generated if the required level of control of a Group 1 emission point, such as 98% for
miscellaneous process vents and 95% for storage vessels, is not achieved. [40 CFR 63.652(g)] (See
Table 2.3 for required level of control.) Debits and credits are calculated using formulas found in 40 CFR
63.652(g) and (h).
6. Did the facility conduct calculations from any of the following:
• Wastewater that is not process wastewater or wastewater streams
treated in biological treatment units? (Group 1 wastewater streams
cannot be left undercontrolled or uncontrolled to generate debits) [40 CFR
63.652(d)(4)]
Yes[ ] No[ ]
• More than 20 individual emission points in addition to those controlled by
pollution prevention measures?
Yes [ ] No[ ]
- Where pollution prevention measures are used, no more than 25
emission points total? [40 CFR 63.652(f)(1)]
Yes[ ] No[ ]
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• Emission points during periods of startup, shutdown, and malfunction?
[40 CFR 63.652(f)(2)]
Yes[ ] No[ ]
• Emission points for which continuous monitors are used and excess
emissions occur? [40 CFR 63.652(f)(3)] (For these periods, the monthly
credits and debits will be adjusted as specified in 40 CFR 63.652(f)(3)(l)
through (iii).)
Yes [ ] No[ ]
C. Approval of Emissions Averaging Plan
1. Did the facility submit for approval an emissions averaging plan in the
Implementation Plan or Operating Permit Application?
Yes[ ] No[ ]
2. Did the plan demonstrate that the credits will be sufficient to offset the debits
under representative operating conditions? [40 CFR 63.652(e)(3)(l)]
Note: The plan may include use of innovative technologies, different from the
reference control technology, provided that the innovative technologies achieve
greaterthan the level of control required for a Group 1 emission point.)
Yes[ ] No[ ]
3. Did the facilitv include a risk assessment in the Dlan of anv hazards or risks
of the plan, such as the risk from one large emission point versus the risk
from combined emission points?
Yes[ ] No[ ]
- Did the facility review such hazards and risks and compare them to point-
by-point compliance?
Yes[ ] No[ ]
D. Testing, Monitoring, Reporting, and Recordkeeping for Emissions
Averaging
1. For each emission Doint included in an emissions averaae. did the refinerv
perform testing, monitoring, reporting, and recordkeeping equivalent to the
requirements for Group 1 emission points that are not included in emissions
averaging? [40 CFR 63.653(a)]
Yes [ ] No[ ]
2. In addition, did the facilitv maintain the monthlv calculations of debits and
credits?
Yes[ ] No[ ]
3. Does the facility maintain the following records for emissions averaging:
• Initial performance test results (if applicable)?
Yes[ ] No[ ]
• Monthly debits, credits, and calculations using EPA-specified calculation
procedures?
Yes[ ] No[ ]
• Operating parameter monitoring results?
Yes[ ] No[ ]
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APPENDIX G. RECENT CHANGES
On August 18, 1998, EPA amended the MACT standard. A summary of the changes
made through the amendments is provided in the preamble to the amendments
(63 FR 44135) and below.
Startup, Shutdown and Malfunction Plans for Wastewater (Section 3.3.5)
The MACT standard was revised to clarify that a Startup, Shutdown Malfunction Plan
(SSMP) is not required for wastewater stream management units (unless the owner or
operator elects to comply with 40 CFR Part 63, Subpart G.) The MACT standard
references the Benzene Waste Operations NESHAP for wastewater requirements. The
EPA did not intend to add additional requirements for wastewater beyond the Benzene
Waste Operations NESHAP.
Wastewater stream control requirements (Section 2, Table 2-3 and Section 5 Table
5-1)
Previously, wastewater stream management units that received streams subject to the
MACT standard and 40 CFR Part 63, Subpart G (the HON) were required to comply with a
combination of requirements from 40 CFR Part 61, Subpart FF (the Benzene Waste
Operations NESHAP) and Subpart G. The standard was revised to allow
owners/operators the option to comply with only the requirements of Subpart G for
wastewater stream management units that receive both streams subject to Subpart G and
the MACT standard.
Startup, Shutdown and Malfunction Reports (Section 3.3.5)
Previously, refineries were required to report an action taken that is inconsistent with the
SSMP within two days of commencing the action and within seven days of completing the
action. These requirements have been replaced with the requirement to report actions
taken that are inconsistent with the SSMP in the next periodic report.
Clarification of Requirements for Installation and Calibration of Continuous
Monitoring Systems (CMS)
Previously, the MACT standard required a continuous monitoring system (CMS) to be
installed and calibrated according to manufacturer's specifications. This requirement has
been revised to allow procedures other than those specified by the manufacturer to be
followed.
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Requirement to Record Signature Owner or Operator When Equipment Leak
Repairs are Delayed (Section 4.6.3)
Previously, when an equipment leak was detected and could not be repaired within
15 days, the signature of the owner or operator (or designate) whose decision it was that
repair could not be affected was to be recorded. This requirement has been revised to
allow the name of the owner or operator (or designate) to be recorded instead.
Exemption of Secondary Seal From Requirements During Primary Seal Gap
Measurements (Section 4.2.3)
The MACT standard was revised to extend the provision exempting secondary seals from
seal gap requirements during primary seal gap measurements to storage vessels subject
to the Petroleum Refineries NESHAP that are to comply with Subpart Kb of 40 CFR Part
60. The EPA has determined the provision provides a necessary clarification that was not
considered in development of Subpart Kb.
Documentation of Compliance (Section 3.3.3 and 4.4.3)
Refineries with co-located gasoline loading racks that are subject to the MACT standard
are generally required to comply with the requirements of the Gasoline Distribution MACT
(40 CFR Part 63 Subpart R). The Gasoline Distribution MACT references notification
requirements of the General Provisions. It was not clear when the Notification of
Compliance status was required for gasoline loading racks at petroleum refineries. The
requirement has been clarified to state that any notifications of compliance status required
by the Gasoline Distribution MACT for gasoline loading racks co-located at refineries are
to be submitted within 150 days of the Petroleum Refinery NESHAP compliance date.
Revision of Notification of Compliance Status (NCS) Report Requirement for New
Group 1 Emission Point (Section 3.3.3)
Previously, facilities were required to provide a NCS report for a new Group 1 emission
point within 150 days of the change or addition of that point. The reporting requirements
are amended to allow the NCS report to be provided in the periodic report for the reporting
period in which the Group 1 emission point is added.
Semiannual Reporting of Inspection Results (Section 4.2.4)
For storage vessels complying with the reporting requirements of the MACT standard, if a
failure is detected during an inspection, it is required to be reported in the next periodic
report. Previously, for storage vessels complying with Subpart Kb or Subpart Ka, if a
failure is detected during an inspection, a report is to be provided to the Administrator
within 30 days or 60 days, respectively. Now, when a failure is detected during an
inspection of a storage vessel subject to the Petroleum Refineries NESHAP that is to
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comply with Subpart Kb or Subpart Ka, the failure is to be reported in the next periodic
report.
Extensions for EFR Seal Gap Measurements
As discussed previously, storage vessels subject to the MACT standard and a new source
performance standard (40 CFR Part 60 Subpart K, Ka or Kb) are only required to comply
with one of the standards. Procedures are specified for external floating roof storage
vessels that must comply with the MACT standard to allow seal gap measurements to be
delayed if it is determined that it is unsafe to perform the measurement. Provisions allow
the gap measurements to be delayed for 30 days while the unsafe conditions are
corrected. If the unsafe conditions cannot be corrected within that time period, the vessel
is to be emptied within 45 days of the determination that the roof is unsafe. The owner or
operator may use up to two extensions of 30 days each to empty the tank. These
provisions have been extended to storage vessels complying with Subparts Ka and Kb.
Extensions for Storage Vessel Repairs
In the MACT standard, when an internal floating roof is discovered to not meet the
requirements of the standard, it must be repaired or the associated storage vessel taken
out of service and emptied within 45 days. If a storage vessel cannot be emptied or
repaired within 45 days, the owner or operator may use up to two extensions of 30 days
each. If an extension is utilized, the owner or operator must, in the next periodic report,
identify the vessel, provide a description of the failure, document that alternate storage
capacity is unavailable, and specify a schedule of actions that will ensure that the control
equipment will be repaired or the vessel will be emptied as soon as possible. This
requirement has been extended to vessels complying with Subpart Kb, which does not
include provisions to be followed in the event that a failure is detected during an inspection
of a storage vessel control device and the storage vessel cannot be repaired or emptied
within 45 days.
Definition of Gasoline (Appendix E)
A definition for gasoline was added to the definitions in the MACT standard. The definition
was taken from 40 CFR Part 60 Subpart XX Standards of Performance for Bulk Gasoline
Terminals.
Report of Determination of Applicability for Flexible Operation Units and for
Distillation Columns and Storage Vessels for Which Use Varies (Section 3.3.3)
The MACT standard was revised to allow applicability determinations for flexible operation
units and distillation columns and storage vessels for which use varies to be reported in the
initial Notification of Compliance Status report (rather than 18 months prior to the
compliance date).
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Compliance of Agitators with Equipment Leaks Provisions (Figure 2-7)
Currently, owners and operators of refineries can comply with the equipment leaks
provisions of the MACT standard by complying with the equipment leaks provisions of
Subpart H. Some of the referenced provisions of Subpart H refer to agitators in heavy
liquid service. It is possible that, due to the references to agitators in Subpart H, the MACT
standard could be interpreted as applying to agitators. The MACT standard was revised
to specifically state that owners and operators are not required to comply with Subpart H
for agitators in heavy liquid service.
Overlap of Subparts XX and R for Gasoline Loading Racks (Section 5)
The current MACT standard requires gasoline loading racks located at refineries to be in
compliance with the control requirements of 40 CFR Part 63 Subpart R National Emission
Standards for Gasoline Distribution Facilities. New gasoline loading racks are also
subject to 40 CFR Part 60 Subpart XX New Source Performance Standard (NSPS) for
Bulk Gasoline Terminals. It is currently possible for a gasoline loading rack at a petroleum
refinery to be subject to both Subparts R and XX. The MACT Standard was revised to
require petroleum refineries with gasoline loading racks subject to both Subparts R and
XX to comply with the control requirements of Subpart R.
Corrections to Miscellaneous Process Vent Equations
Following promulgation of the Petroleum Refineries NESHAP, two errors were discovered
in two equations to be used to calculate kilograms per day of volatile organic compounds
(VOC) in miscellaneous process vent streams. These errors have been corrected.
Revision of Notification of Compliance Status Report Requirement for Existing
Group 1 Storage Vessels Brought Into Compliance After August 18,1998
(Sections 3.3.3 and 4.2.4)
The MACT standard allows floating roof storage vessels to be brought into compliance up
to 10 years after August 18, 1998, the compliance date for other emission points. A
Notification of Compliance Status (NCS) report is required to be submitted when these
vessels are brought into compliance. Previously, it was not clear when the NCS report is
to be submitted. The MACT standard has been revised to require a NCS report to be
submitted for storage vessels brought into compliance after August 18, 1998 with the
periodic report for the reporting period in which the vessel was brought into compliance.
The report will include a list of all Group 1 storage vessels and either the actual or
anticipated date of compliance for each vessel.
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Petroleum Refinery MACT Standard Guidance
APPENDIX H. EPA REGIONS AND REGIONAL CO
NTACTS FOR THE PETROLEUM REFINERY MACT
Standard Implementation
No Petroleum Refineries in
John York
EPA Reaion I
EPA Reaion VI (6EN-AT)

1445 Ross Avenue, Suite 700
Umesh Dholakia
Dallas, TX 75202-2733
EPA Reaion II
PH: (214) 665-7289
290 Broadway
FAX: (214) 665-7446
New York, NY 10007-1866

PH: (212) 637-4023/4065
Bill Peterson
FAX: (212) 637-3901/3998
EPA Reaion VII. ARTD/APCO

726 Minnesota Avenue
Patrick Foley
Kansas City, KS 66101
Reaion III (3AT12}
PH: (913) 551-7881
841 Chestnut Building
FAX: (913) 551-7065
Philadelphia, PA 19107

PH: (215) 814-2098
Tami Thomas-Burton
FAX: (215) 566-2114
EPA Reaion VIII (8 ENF-T)

999 18th Street, Suite 500
Leonardo Ceron
Denver, CO 80202-2405
EPA Reaion IV (AR-4^
PH: (303) 312-6581
Atlanta Federal Ctr.
FAX: (303) 312-6409
61 Forsyth St.

Atlanta, GA 30303-3104
Cyntia Steiner
PH: (404) 562-9129
EPA Reaion IXfAIR-5^
FAX: (404) 562-9095
75 Hawthorne Street

San Francisco, CA 94105
Kathy Keith
PH: (415) 744-1139
EPA Reaion V (AE-17J}
FAX: (415) 744-1076
77 W. Jackson Blvd.

Chicago, IL 60604
Kai-Hon Shum
PH: (312) 353-6956
EPA Reaion X (OAQV107}
FAX: (312) 353-8289
1200 Sixth Avenue

Seattle, WA 98101

PH: (206) 553-2117

FAX: (206) 553-0110
Jim Durham
(Technical Lead)
OAQPS. MD-13
RTP, NC 27711
PH: 919-541-5672
FAX: 919-541
Larry Brockman
(Guidance Documents)
OAQPS. MD-12
RTP, NC 27711
PH: 919-541-5394
FAX: 919-541-2664
Rafael Sanchez
(Compliance Assistance)
USEPA, OECA (2223-A)
1200 Pennsylvania Avenue, NW
Washington, DC 20044
PH: 202-564-7028 -FX -0050
H.1

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Petroleum Refinery MACT Standard Guidance
TECHNICAL REPORT DATA
(Please read Instructions on reverse before com
pletinq)
1. REPORT NO.
EPA-456/B-00-
001
2.
3. RECIPIENT'S ACCESSION
NO.
4. TITLE AND SUBTITLE
Petroleum Refinery MACT Standard Guidance
5. REPORT DATE
November, 2000
6. PERFORMING
ORGANIZATION CODE
7. AUTHOR(S)
8. PERFORMING
ORGANIZATION REPORT NO.
9. PERFORMING ORGANIZATION NAME AND ADDRESS
U.S. Environmental Protection Agency
Office of Air Quality Planning and Standards
Research Triangle Park, NC 27711
10. PROGRAM ELEMENT NO.
11. CONTRACT/GRANT NO.
12. SPONSORING AGENCY NAME AND ADDRESS
Director
Office of Air Quality Planning and Standards
Office of Air and Radiation
U.S. Environmental Protection Agency
Research Triangle Park, NC 27711
13. TYPE OF REPORT AND
PERIOD COVERED
Revision/Final
14. SPONSORING AGENCY
CODE
EPA/200/04
15. SUPPLEMENTARY NOTES

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Petroleum Refinery MACT Standard Guidance
16. ABSTRACT


This document can help you (both the regulated community and regulators) understand
the requirements for the Petroleum Refinery MACT Standard by helping you determine
the following things:


• if the rule applies to your plant and process

• what emission points are subject to the rule

• the control, testing, monitoring, and reporting requirements
• dates by which you much meet requirements, contacts, how to get more
information, etc


17.
KEY WORDS AND DOCUMENT ANALYSIS

a. DESCRIPTORS
b. IDENTIFIERS/OPEN ENDED TERMS
c. COSATI Field/Group

Air Pollution control

18. DISTRIBUTION STATEMENT
19. SECURITY CLASS (Report)
21. NO. OF PAGES

Unclassified
125
Release Unlimited



20. SECURITY CLASS (Page)
22. PRICE

Unclassified

EPA Form 2220-1 (Rev. 4-77) PREVIOUS EDITION IS OBSOLETE

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