[Federal Register Volume 67, Number 70 (Thursday, April 11, 2002)]
[Rules and Regulations]
[Pages 17762-17822]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 02-7222]
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Part II
Environmental Protection Agency
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40 CFR Part 63
National Emission Standards for Hazardous Air Pollutants for Petroleum
Refineries: Catalytic Cracking Units, Catalytic Reforming Units, and
Sulfur Recovery Units; Final Rule
Federal Register / Vol. 67 , No. 70 / Thursday, April 11, 2002 /
Rules and Regulations
[[Page 17762]]
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ENVIRONMENTAL PROTECTION AGENCY
40 CFR Part 63
[FRL-7163-7]
RIN 2060-AF28
National Emission Standards for Hazardous Air Pollutants for
Petroleum Refineries: Catalytic Cracking Units, Catalytic Reforming
Units, and Sulfur Recovery Units
AGENCY: Environmental Protection Agency (EPA).
ACTION: Final rule.
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SUMMARY: This action establishes final national emission standards for
hazardous air pollutants (NESHAP) for certain types of affected sources
at petroleum refineries. The affected sources include catalytic
cracking units (CCU), catalytic reforming units, and sulfur recovery
units, as well as associated by-pass lines. The EPA has identified
petroleum refineries as major sources of hazardous air pollutants
(HAP). Hazardous air pollutants that would be reduced by this final
rule include organics (acetaldehyde, benzene, formaldehyde, hexane,
phenol, toluene, and xylene); reduced sulfur compounds (carbonyl
sulfide, carbon disulfide); inorganics (hydrogen chloride, chlorine);
and particulate metals (antimony, arsenic, beryllium, cadmium,
chromium, cobalt, lead, manganese, and nickel). The health effects of
exposure to these HAP can include cancer, respiratory irritation, and
damage to the nervous system. These final standards implement section
112(d) of the Clean Air Act (CAA) by requiring all petroleum refineries
that are major sources to meet standards reflecting the application of
the maximum achievable control technology (MACT). When fully
implemented, this rule will reduce HAP emissions from the affected
sources by nearly 11,000 tons per year tpy--an 87 percent reduction
from current levels. Emissions of other pollutants such as volatile
organic compounds (VOC), particulate matter (PM), carbon monoxide (CO),
and hydrogen sulfide will be reduced by about 60,000 tpy.
EFFECTIVE DATE: April 11, 2002.
ADDRESSES: Docket No. A-97-36 contains supporting information used in
developing this rule. The docket is located at the U.S. Environmental
Protection Agency, 401 M Street, SW., Washington, DC 20460 in room M-
1500, Waterside Mall (ground floor), and may be inspected from 8:30
a.m. to 5:30 p.m., Monday through Friday, excluding legal holidays.
FOR FURTHER INFORMATION CONTACT: For information on the basis for the
rule, contact Mr. Robert B. Lucas, Waste and Chemical Process Group,
Emission Standards Division (C439-03), Office of Air Quality Planning
and Standards, U.S. Environmental Protection Agency, Research Triangle
Park, North Carolina 27711, telephone number (919)
541-0884, electronic mail address, ``[email protected];'' for
information concerning legal matters, contact Mr. Richard Vetter,
Emission Standards Division (C439-03), Office of Air Quality Planning
and Standards, U.S. Environmental Protection Agency, Research Triangle
Park, North Carolina 27711, telephone number (919) 541-2127, electronic
mail address, ``[email protected]'' for questions concerning
compliance determinations, contact Mr. Thomas Ripp, Office of
Enforcement and Compliance Assurance (2223A), U.S. Environmental
Protection Agency, 1200 Pennsylvania Avenue, NW., Washington, DC 20460,
telephone number (202) 564-7003, electronic mail address,
``[email protected]'' or for information on the test methods, contact
Ms. Rima Howell, Emissions Monitoring and Analysis Division (D205-02),
Office of Air Quality Planning and Standards, U.S. Environmental
Protection Agency, Research Triangle Park, North Carolina 27711,
telephone number (919)
541-0443, electronic mail address, ``[email protected]''. For
applicability determination questions, refer to the table in the
SUPPLEMENTARY INFORMATION section.
SUPPLEMENTARY INFORMATION: Docket. The docket is an organized and
complete file of all the information considered by the EPA in the
development of this rule. The docket is a dynamic file because material
is added throughout the rulemaking process. The docketing system is
intended to allow members of the public and industries involved to
readily identify and locate documents so that they can effectively
participate in the rulemaking process. Along with the proposed and
promulgated rules and their preambles, the contents of the docket will
serve as the record in the case of judicial review. (See section
307(d)(7)(A) of the CAA.) Other material related to this rulemaking is
available for review in the docket or copies may be mailed on request
from the Air Docket by calling (202) 260-7548. A reasonable fee may be
charged for copying docket materials.
World Wide Web (WWW). In addition to being available in the docket,
an electronic copy of today's final rule will also be available on the
WWW through the Technology Transfer Network (TTN). Following signature,
a copy of the rule will be posted on the TTN's policy and guidance page
for newly proposed or promulgated rules at
http://www.epa.gov/ttn/oarpg. The TTN provides information and
technology exchange in various areas of air pollution control. If more
information regarding the TTN is needed, call the TTN HELP line at
(919) 541-5384.
Judicial Review. Today's action constitutes final administrative
action on the proposed NESHAP for CCU, catalytic reforming units, and
sulfur recovery units (63 FR 48890, September 11, 1998). Under section
307(b)(1) of the CAA, judicial review of the final rule is available
only by filing a petition for review in the U.S. Court of Appeals for
the District of Columbia Circuit by June 10, 2002. Under section
307(b)(2) of the CAA, the requirements that are the subject of this
document may not be challenged later in civil or criminal proceedings
brought by the EPA to enforce these requirements.
Regional Contacts for Applicability Determination
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Region I, Director, Air Compliance Region II, U.S. EPA, 290
Programs, EPA New England, 1 Congress Broadway, New York, NY 10007-
Street, Suite 1100 (SEA), Boston, MA 1866, Phone (212) 637-3000,
02114-2023, Phone contact: (617) 918- FAX (212) 637-3526.
1656 FAX: (617) 918-1112.
Region III, Dianne Walker (3AP11) U.S. Region IV, Leonardo Ceron, U.S.
EPA, 1650 Arch Street, Philadelphia, EPA, 61 Forsyth Street, SW.,
PA 19103-2029, Phone: (215) 814-3297, Atlanta, GA 30303-3104, Phone:
FAX: (215) 814-5103. (404) 562-9900, FAX: (404-562-
8174.
Region V, Kathy Keith U.S. EPA, 77 West Region VI, U.S. EPA, Martin E.
Jackson Boulevard, Chicago, IL 60604- Brittain (214) 665-7206,
3507, Phone: (312) 353-6956, FAX: Jonathan York (214) 665-7289,
(312) 353-4135. Barry Feldman (214) 665-7439,
Fountain Place, 12th Floor,
Suite 1200, 1445 Ross Avenue,
Dallas, TX 75292-2733, FAX:
(214) 665-2146.
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Region VII, Bill Peterson, U.S. EPA, Region VIII, Art Palomares (303-
726 Minnesota Avenue, Kansas City, KS 312-6332), e-mail:
66101, Phone: (913) 551-7881, FAX: [email protected], Tami
(913) 551-7467. Thomas-Burton (303-312-6581).
e-mail: [email protected], U.S. EPA,
MACT Enforcement, 999 18th
Street, Suite 500, ENF-T,
Denver, Colorado 80202, FAX:
303-312-6409.
Region IX, John Kim, U.S. EPA, 75 Region X, Kai-Hon Shum, U.S.
Hawthorne Street (AIR-5), San EPA, Office of Air Quality,
Francisco, CA 94105, Phone: (415) 744- 1200 Sixth Avenue (OAQ-107),
1263, FAX: (415) 744-2499. Seattle, Washington 98101,
Phone: (206) 553-2117, FAX:
206-553-0149.
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Regulated Entities. Categories and entities potentially regulated
by this action include:
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Category SIC code NAIC Examples of regulated entities
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Industry....................................... 2911 32411 Petroleum refineries that operate CCU,
catalytic reforming units, or sulfur
recovery units.
Federal Government............................. .......... .......... Not affected.
State/local/tribal............................. .......... .......... Not affected.
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This table is not intended to be exhaustive, but rather provides a
guide for readers regarding entities likely to be regulated by this
action. To determine whether your facility is regulated by this action,
you should examine the applicability criteria in Sec. 63.1561 of the
final rule. If you have any questions regarding the applicability of
this action to a particular entity, consult the appropriate person
listed in the preceding FOR FURTHER INFORMATION CONTACT section.
Outline. The information in this preamble is organized as follows:
I. Background
II. Summary of Final Rule and Changes Since Proposal
A. Who must comply with this rule?
B. What equipment is covered?
C. When must I comply?
D. What are the emission limitations and other standards?
E. How do I demonstrate initial compliance?
F. How do I demonstrate continuous compliance?
G. What are the notification, recordkeeping, and reporting
requirements?
III. Summary of Environmental, Energy, and Economic Impacts
A. What are the air quality impacts?
B. What are the cost impacts?
C. What are the economic impacts?
D. What are the non-air health and environmental impacts?
E. What are the energy impacts?
IV. Summary of Major Comments and Responses
A. Why did we extend the compliance date?
B. What is the new alternative nickel emission limitation?
C. Why did we not change the proposed nickel emission
limitation?
D. How did we change the proposed monitoring requirements?
V. Administrative Requirements
A. Executive Order 12866, Regulatory Planning and Review
B. Executive Order 13132, Federalism
C. Executive Order 13175, Consultation and Coordination with
Indian Tribal Governments
D. Executive Order 13045, Protection of Children from
Environmental Health Risks and Safety Risks
E. Executive Order 13211, Actions Concerning Regulations that
Significantly Affect Energy Supply, Distribution or Use
F. Unfunded Mandates Reform Act of 1995
G. Regulatory Flexibility Act (RFA), as Amended by Small
Business Regulatory Enforcement Act of 1996 (SBREFA), 5 U.S.C. 601
et seq.
H. Paperwork Reduction Act
I. National Technology Transfer and Advancement Act of 1995
J. Congressional Review Act
I. Background
The CAA was created in part to protect and enhance the quality of
the Nation's air resources to promote public health and welfare and the
productive capability of its population. Section 112(d) of the CAA
requires us (the EPA) to establish standards for all categories and
subcategories of major sources of HAP and for area sources listed for
regulation under section 112(c). Major sources are those that emit or
have the potential to emit at least 10 tpy of any single HAP or 25 tpy
of any combination of HAP. Area sources are stationary sources of HAP
that are not major sources.
We received 40 public comments on the proposed NESHAP. Commenters
included industry representatives and trade associations, State and
local agencies, environmental groups, vendors, and technical experts.
To provide interested individuals the opportunity for oral
presentations of data, views, or arguments concerning the proposed
rule, we held a public hearing on October 14, 1998, and extended the
end of the public comment period from November 10, 1998, to December 1,
1998 (Docket A-97-36). Today's final rule reflects our full
consideration of all the comments we received. Major public comments on
the proposed rule along with our responses to these comments are
summarized in this document. See the Response to Comment Document
(Docket A-97-36) for detailed responses to all the comments.
II. Summary of Final Rule and Changes Since Proposal
We revised the overall format of the rule to make it easier to
understand, implement, and enforce. Separate sections of this ``plain
language'' final rule cover the requirements for each type of HAP
(i.e., metal HAP, organic HAP, inorganic HAP, or overall HAP) from an
affected source. Each section of the rule refers you (the refinery
owner or operator) to tables at the end of the rule that list the
specific rule requirements and give step-by-step instructions on how to
demonstrate initial and continuous compliance.
For purposes of the final rule, the title has been changed to
``National Emission Standards for Hazardous Air Pollutants for
Petroleum Refineries: Catalytic Cracking Units, Catalytic Reforming
Units, and Sulfur Recovery Units'' to better describe the affected
population. The source category list will be amended to reflect this
name change in a separate action.
In the past year, six petroleum refining companies have signed
voluntary settlements with EPA which will add controls for CCU and SRU
that will comply with this final rule. We have not revised the impact
estimates to reflect the controls resulting from these settlements.
A. Who Must Comply With This Rule?
The final rule (subpart UUU) applies to you if your petroleum
refinery is a major source of HAP emissions and includes an affected
source covered by the rule. Based on our data, we believe all 164
existing petroleum refineries in the U.S. and its territories are major
[[Page 17764]]
sources; 132 of these facilities have one or more of the affected
sources subject to the rule requirements.
B. What Equipment Is Covered?
Section 63.1562 of the final rule identifies each type of affected
source as well as equipment or processes not covered by the rule. As
proposed, three types of existing, new, or reconstructed units are
subject to the rule. These are:
Each CCU that regenerates catalyst;
Each catalytic reforming unit that regenerates catalyst;
and
Each sulfur recovery unit and the tail gas treatment unit
serving it.
The rule also applies to each by-pass line serving a new, existing,
or reconstructed affected source. We have clarified the applicability
of the rule to emphasize that the unit is the affected source while the
emission limits and standards apply to the specified type of vent
associated with the unit.
The final rule applies only to the predominant type of CCU--those
using a fluidized bed (i.e., fluid CCU). We also revised the
applicability of the rule to exclude redundant sulfur recovery units
not located at a petroleum refinery and used by the refinery only for
emergency or maintenance backup. Consistent with the proposed rule, the
final rule doesn't apply to a sulfur recovery unit that doesn't recover
elemental sulfur, certain equipment associated with by-pass lines
(i.e., low leg drains, high point bleeds, analyzer vents, open-ended
valves or lines, or pressure relief valves needed for safety reasons),
or gaseous streams routed to a fuel gas system.
C. When Must I Comply?
Section 63.1563 of the final rule gives the compliance dates. As
discussed further in section IV.A of this document, we have included
provisions allowing an extended compliance date for existing fluid CCU
located at a petroleum refinery that commits to hydrotreating the CCU
feed to comply with the gasoline sulfur control requirements in the
Tier 2 Motor Vehicle Emission Standards (40 CFR part 80) and the
applicable emission limitations in subpart UUU. The compliance date for
these existing affected sources will depend on when the refinery must
meet the 30 parts per million (ppm) limit for gasoline sulfur content,
but can't be any later than December 31, 2009. Otherwise, affected
sources must comply within 3 years from today's date.
We also clarified the compliance dates for new or reconstructed
affected sources. If you started your new or reconstructed affected
source before today's date, you must comply with the applicable rule
requirements by today. If you start your new or reconstructed affected
source after today's date, you must comply with the rule requirements
upon startup.
D. What Are the Emission Limitations and Other Standards?
The final rule includes emission limitations for HAP emissions of
particulate metals and organic compounds from CCU, organic and
inorganic compounds from catalytic reforming units, and reduced sulfur
compounds from sulfur recovery units. An emission limitation means any
emission limit, operating limit, opacity limit, or visible emissions
limit. Surrogates are used in this rule to represent the HAP emissions.
They allow easier, less expensive measurement and monitoring
requirements. For CCU, PM and nickel (Ni) are used as surrogates for
metal HAP. Carbon monoxide is used as a surrogate for organic HAP
emissions. Total organic carbon (TOC) is a surrogate for organic HAP
emissions from catalytic reforming units while hydrogen chloride (HCl)
represents inorganic HAP emissions. Sulfur dioxide (SO2) or
total reduced sulfur (TRS) represent the reduced sulfur HAP emissions
from sulfur recovery units.
We made no changes in the MACT floor determinations of control
technologies serving as the basis of the proposed rule. The emission
control technologies and limits are discussed in the preamble to the
proposed NESHAP (63 FR 48890). However, we did revise in other respects
the emission limitations and standards that reflect the performance of
the MACT floor technologies.
In response to public comments, we clarified the requirements for
affected sources also subject to the new source performance standard
(NSPS) for petroleum refineries (40 CFR part 60, subpart J) and added
new compliance options. If your affected source is also subject to the
NSPS, complying with the NSPS emission limitations also allows you to
comply with this rule. If your affected source isn't subject to the
NSPS, you can elect to comply with the NSPS emission limitations in
order to be in compliance with this rule.
As further discussed in section IV.B of this document, we also
added a second Ni limit as another metal HAP compliance option for CCU.
This alternative provides an emission limit formatted to account for
the variable characteristics of these units. We added it to the rule
both to credit and encourage hydrotreating of the CCU feed as a means
of reducing metal HAP emissions to the atmosphere.
We also made a change to the TOC emission limit for catalytic
reforming units in Sec. 63.1562(b)(1)(iii) of the proposed rule. This
provision exempted emissions during depressuring and purging operations
if the reactor vent pressure or differential pressure between the
reactor vent and the gas transfer system to the control device were
under 1 pound per square inch gauge (psig). Since 5 psig is the limit
in States with facilities representing the MACT floor, we revised this
provision to state that the emission limitations do not apply to
depressuring and purging when the reactor vent pressure is 5 psig or
less.
The final rule also includes specific operating limits for
monitored process or control device operating parameters. Operating
limits also may apply if you choose to comply with certain options,
such as the alternative Ni emission limitations for CCU.
Tables 1, 2, 8, and 9 to the final rule (subpart UUU) show the
final emission limitations for CCU. Tables 15, 16, 22, and 23 to
subpart UUU give the emission limitations for catalytic reforming
units. The final emission limitations for sulfur recovery units are in
Tables 29 and 30 to subpart UUU.
The final rule also includes work practice standards for HAP
emissions from by-pass lines. A work practice standard may include a
design, equipment, work practice, or operational requirement. Table 36
to subpart UUU lists the four options provided under the final rule.
The final rule also includes work practice standards for all affected
sources. These standards require you to prepare an operation,
maintenance, and monitoring plan according to the rule requirements and
comply with the procedures in the plan. This plan must be consistent
with good air pollution control practices for minimizing emissions.
E. How Do I Demonstrate Initial Compliance?
You must install and operate the required continuous monitoring
systems and show that you meet each emission limitation or work
practice standard that applies to you. The requirements for
demonstrating initial compliance differ by unit type and according to
whether or not your affected source is also subject to the NSPS
requirements.
If your CCU or sulfur recovery unit is also subject to the NSPS,
you must meet the applicable emission limitations and monitoring
requirements in this rule. These requirements in this case are the same
as the NSPS. If you have already
[[Page 17765]]
done a performance test to demonstrate initial compliance with the
NSPS, you aren't required to do another test to demonstrate initial
compliance with the limits in this rule. If you have already done a
performance test, you aren't required to do another one to show that
your continuous opacity and emission monitoring systems meet the
applicable performance specifications. You can demonstrate initial
compliance for these affected sources by submitting a written statement
in your Notification of Compliance Status certifying that you comply
with the applicable NSPS requirements.
We have revised the requirements for affected sources not subject
to the NSPS to account for the new compliance options, as well as
revisions to monitoring requirements. Your requirements for
demonstrating initial compliance will vary according to the compliance
option you elect and the type of continuous monitoring system you must
use.
1. HAP Metal Emissions From CCU
If you elect to comply with the NSPS, you must install and operate
a continuous opacity monitoring system to measure and record the
opacity of emissions from each catalyst regenerator vent. The final
rule also requires a continuous opacity monitoring system if your CCU
has a fresh feed capacity of 20,000 barrels per day (or more) and uses
an add-on control device other than a wet scrubber (e.g., an
electrostatic precipitator) to control the catalyst regenerator vent
emissions. You also must install and operate a continuous opacity
monitoring system if your CCU isn't equipped with an add-on control
device. If you use a continuous opacity monitoring system and elect to
comply with either of the Ni limits, you also must install and operate
a continuous parameter monitoring system to measure and record the gas
flow rate. Or, you can use the approved alternative procedure in the
final rule to determine the gas flow rate.
For a smaller CCU (fresh feed capacity 20,000 barrels per day or
less) that uses an electrostatic precipitator to control emissions from
the catalyst regenerator vent, you can use a continuous opacity
monitoring system (with a continuous monitoring parameter system for
gas flow rate if you elect either of the Ni options) or continuous
parameter monitoring systems. The continuous parameter monitoring
systems must measure and record the gas flow rate as well as the
voltage and secondary current (or total power input).
If you use a wet scrubber to control emissions from your catalyst
regenerator vent, you must use continuous parameter monitoring systems
to measure and record the pressure drop across the scrubber, the gas
flow rate, and the total liquid (or scrubbing liquor) flow rate,
regardless of unit capacity. In response to comments, we exempted non-
Venturi wet scrubbers of the jet-ejector design from monitoring
requirements and operating limits for pressure drop.
Section 63.1573 of the final rule provides approved alternative
monitoring procedures. If applicable, you can use these alternative
procedures to determine the gas flow rate rather than a continuous
parameter monitoring system.
You must prepare a site-specific test plan and do a performance
test to demonstrate initial compliance with the applicable emission
limitation(s). If you use a continuous opacity monitoring system and
elect to meet the NSPS, you also must do a site-specific performance
evaluation test plan and performance evaluation to show that your
monitoring system meets the applicable performance specification.
If you use a continuous opacity monitoring system and elect the PM
limit, you must use the performance test results to establish a site-
specific opacity operating limit. If you elect either Ni limit, you
must use the performance test results to establish a site-specific Ni
operating limit based on opacity, gas flow rate, equilibrium catalyst
Ni concentration, and coke burn-rate (depending on the format of the
option you elect). You can use EPA Method 6010b, 6020, 7520, or 7521 in
``Test Methods for Evaluating Solid Waste, Physical/Chemical Methods,''
EPA Publication SW-846, Revision 5 (April 1998) or an alternative
method satisfactory to the Administrator to analyze the equilibrium
catalyst Ni concentration. The final rule includes procedures for
establishing each type of operating limit.
If you use continuous parameter monitoring systems for an
electrostatic precipitator and elect the PM emission limitation, you
must use the performance test results to establish operating limits for
gas flow rate and voltage and secondary current (or total power input).
If you elect either of the Ni limits, you must establish operating
limits for the equilibrium catalyst Ni concentration. If you use a wet
scrubber, you must use the performance test results to establish
operating limits for pressure drop and liquid-to-gas ratio (if you
elect the PM limit) as well as equilibrium catalyst Ni concentration
(if you elect either of the Ni limits).
Table 3 to subpart UUU shows the requirements for continuous
monitoring systems for HAP metal emissions from CCU. Table 4 to subpart
UUU shows the performance test requirements under each of the four
compliance options. You have demonstrated initial compliance with the
metal HAP emission limitations if you meet the conditions in Table 5 to
subpart UUU.
2. Organic HAP Emissions From CCU
Table 10 to subpart UUU shows the requirements for continuous
monitoring systems for organic HAP emissions from CCU. If you elect to
comply with the NSPS requirements, you must install and operate a
continuous emission monitoring system to measure and record the
concentration by volume (dry basis) of CO emissions from each catalyst
regenerator vent.
If you don't elect to comply with the NSPS requirements, you must
use continuous parameter monitoring systems. In response to comments,
we have revised the proposed requirements for thermal incinerators to
include a continuous parameter monitoring system to measure and record
the oxygen content (percent dry basis) in the incinerator vent stream
as well as the combustion zone temperature. If your unit is not
equipped with a combustion control device, the final rule requires that
you use a continuous emission monitoring system. Like the NSPS, if you
can demonstrate that emissions from your vent average 50 ppm or less,
the final rule does not require a continuous emission monitoring system
or a continuous parameter monitoring system.
To demonstrate initial compliance, you must prepare a site-specific
test plan and do a performance test to show that your vent meets the
emission limit. If you use a continuous emission monitoring system and
elect to comply with the NSPS, you also must prepare a site-specific
performance evaluation test plan and do a performance evaluation to
show that your system meets the applicable performance specification.
If you use continuous parameter monitoring systems, you must use
the test results to establish operating limits for combustion zone
temperature and oxygen concentration in the vent stream. We also
clarified the performance test provisions for flares, which require a
visible emissions test by Method 22 with a 2-hour observation period.
Table 11 to subpart UUU shows the performance test requirements for
organic HAP emissions. You have demonstrated initial compliance with
[[Page 17766]]
the organic HAP emission limits if you meet the conditions in Table 12
to subpart UUU.
3. Organic HAP Emissions From Catalytic Reforming Units
Table 17 to subpart UUU shows the continuous monitoring system
requirements for organic HAP emissions from catalytic reforming units.
We didn't revise the proposed requirements for continuous monitoring
systems for these units.
To demonstrate initial compliance, you must prepare a site-specific
test plan and do a performance test to show that your vent meets the
applicable emission limitation. We revised the proposed performance
test procedures to remove Method 18 (40 CFR part 60, appendix A) for
measurement of TOC concentration. You can use Method 25 or 25A for TOC
concentration. We also clarified the requirements for flares (see
section II.E of this document). Using the performance test results, you
must establish operating limits for the combustion zone temperature of
your combustion control device. Table 18 to subpart UUU shows the
performance test requirements. You have demonstrated initial compliance
with the emission limitations if you meet the conditions in Table 19 to
subpart UUU.
4. Inorganic HAP Emissions From Catalytic Reforming Units
Table 24 to subpart UUU shows the continuous monitoring system
requirements for inorganic HAP emissions from catalytic reforming
units. We revised the proposed requirements for wet scrubbers to
include a continuous parameter monitoring system to measure and record
the pH of the water (or scrubbing liquid) exiting the scrubber instead
of a continuous parameter monitoring system for pressure drop. You can
also use the approved monitoring alternative for pH strips in lieu of a
continuous parameter monitoring system. We also revised the proposed
rule to include requirements for units with an internal scrubbing
system (i.e., no add-on control device) based on use of colormetric
tube sampling systems.
Table 25 to subpart UUU shows the performance test requirements for
inorganic HAP emissions from catalytic reforming units. You must
prepare a site-specific test plan and do a performance test to show
that you meet the applicable emission limitation. We revised the
proposed performance test requirements to specify that you can't make
any test runs during the first hour or the last 6 hours of the cycle
for a semi-regenerative or cyclic regeneration unit. Using the results
of the performance test, you must establish operating limits for the
liquid-to-gas ratio and pH of the scrubber water (or scrubbing liquid).
If you don't use a control device, you must establish an operating
limit for the HCl concentration using colormetric tubes. You can use
Method 26 in 40 CFR part 60, appendix B, to measure emissions from
these units. You have achieved initial compliance with the inorganic
HAP emission standards if you meet the conditions in Table 26 to
subpart UUU.
5. Organic HAP Emissions From Sulfur Recovery Units
Table 31 to subpart UUU shows the continuous monitoring system
requirements for organic HAP emissions from sulfur recovery units. If
you elect to comply with the NSPS requirements, you must install and
operate a continuous emission monitoring system to measure and record
the concentration (dry basis, zero percent excess air) of SO2 emissions
exiting each exhaust stack for the unit if you use an oxidation or
reduction control system followed by incineration. If you use a
reduction control system without incineration, you must use continuous
emission monitoring systems to measure and record the concentration of
reduced sulfur and oxygen emissions. If you elect to comply with the
TRS limit and use an incinerator to control emissions from your vent,
you must install and operate a continuous emission monitoring system or
a continuous parameter monitoring system to measure and record the
combustion zone temperature and the oxygen content (percent, dry basis)
in the vent stream of the incinerator. If you do not use an add-on
control device to control emissions from your vent, you must install
and operate a continuous emission monitoring system to measure and
record the concentration of TRS.
You must prepare a site-specific test plan and do a performance
test to show that emissions from your vent meet the applicable
standard. If you use a continuous emission monitoring system and elect
to meet the NSPS, you also must do a site-specific performance
evaluation test plan and a performance evaluation to show that your
system meets the applicable performance specification. If you use
continuous parameter monitoring systems, you must establish operating
limits for oxygen concentration as well as for combustion zone
temperature. Table 32 to subpart UUU shows the performance test
requirements for each option. You have demonstrated initial compliance
if you meet the conditions specified in Table 33 to subpart UUU.
6. HAP Emissions From Bypass Lines
We revised the proposed standards for by-pass lines to include two
new equipment options suggested by commenters. Table 37 to subpart UUU
shows the performance test requirement applicable to a flow indicator,
level recorder, or electronic valve position monitor. You have achieved
initial compliance if you meet the applicable conditions for the work
practice option you select shown in Table 38 to subpart UUU.
7. Continuous Monitoring System Requirements
We added new sections (Secs. 63.1572 and 63.1573) to the final rule
to clearly identify the requirements for monitor installation and
operation and monitoring alternatives. Table 40 to subpart UUU shows
the requirements for continuous opacity monitoring systems and
continuous emission monitoring systems, which are the same as the NSPS.
Table 41 to subpart UUU shows the requirements for installation and
operation of continuous parameter monitoring systems. We have revised
these requirements to include more detailed requirements for
inspections and calibration checks as well as performance
specifications for some types of systems. We also revised the rule to
clarify that each continuous parameter monitoring system must measure
and record on an hourly or hourly average basis and determine and
record the daily average value.
The final rule also specifies that you operate your monitors (or
collect data at all required intervals) at all times the affected
source is operating. This does not apply to monitoring malfunctions,
associated repairs, required quality assurance or control activities,
and preapproved planned maintenance activities. You may not use data
recorded during monitoring malfunctions, associated repairs, and
required quality assurance or control activities in data averages and
calculations or to meet a minimum data availability requirement.
8. Performance Tests, Performance Evaluations, and Engineering
Assessments
Section 63.1571 of the final rule contains general information and
criteria you must meet for these activities. We have clarified the rule
to specify that you can do your performance test at any time from
today's date to your compliance date. In response to comments, we
revised
[[Page 17767]]
Sec. 63.1564(e) of the proposed rule to require that the tests be done
under normal operating conditions rather than at ``maximum
representative operating capacity for the process.'' You must base your
process or control device operating limits on the performance test
measurements. However, unless you elect one of the two Ni options for
metal HAP emissions from CCU, you can adjust the measured values, if
necessary, using control device design specifications, manufacturer
recommendations, or other applicable data. You must document any
adjustment to the satisfaction of your permitting authority. We added
special provisions to the rule for adjusting the Ni-related values.
This section of the rule also covers how to change your operating
limit. While you can change your site-specific opacity operating limit
or Ni operating limit only by doing a new performance test, you can
change other operating limits for continuous parameter monitoring
systems by doing another performance test, a performance test in
conjunction with an engineering assessment, or by an engineering
assessment. You must establish a revised limit if you make any change
in the process or operating conditions that could affect control system
performance or if you change the designated conditions after the last
performance or compliance tests were done.
F. How Do I Demonstrate Continuous Compliance?
A new section, Sec. 63.1570, of the final rule states your general
requirements for complying with this rule. You must be in compliance
with all of the non-opacity emission limits during the times specified
in Sec. 63.6(g)(1). You must be in compliance with the opacity emission
limits during the times specified in Sec. 63.6(h)(1). You must always
operate and maintain your affected source, including air pollution and
control and monitoring equipment, according to the provisions in
Sec. 63.6(e)(1)(i).
Subpart UUU requires that you develop and implement a startup,
shutdown, and malfunction plan according to the requirements in
Sec. 63.6(e)(3). During periods of startup, shutdown, or malfunction,
you must operate your affected source and control equipment according
to your plan.
You must report each instance in which you did not meet each
emission limitation or work practice standard that applies to you. This
includes periods of startup, shutdown, and malfunction. These instances
are deviations from the emission limitations and work practice
standards that must be reported according the requirements in
Sec. 63.1575 of the final rule.
Consistent with Secs. 63.6(e) and 63.7(e)(1), a deviation that
occurs during a period of startup, shutdown, or malfunction is not a
violation if you demonstrate to the Administrator's satisfaction that
you were operating in accordance with your startup, shutdown, and
malfunction plan. The Administrator will determine whether a deviation
that occurs during a period of startup, shutdown, or malfunction is a
violation according to the provisions in Sec. 63.6(e). As proposed,
multiple deviations from the same control device at the same time when
you monitor process or control device operating parameters are a single
deviation. You still must report each deviation.
You must demonstrate continuous compliance with each emission
limitation and work practice standard that applies to you. To
demonstrate continuous compliance with the emission limitations for
CCU, you must meet each of the conditions specified in Tables 6 and 7
to subpart UUU (for metal HAP emissions) and Tables 13 and 14 to
subpart UUU (for organic HAP emissions). For catalytic reforming units,
you must meet each of the conditions in Tables 20 and 21 to subpart UUU
(for organic HAP emissions) and Tables 27 and 28 to subpart UUU (for
inorganic HAP emissions). For HAP emissions from sulfur recovery units,
you must meet each of the conditions in Tables 34 and 35 to subpart
UUU. Continuous compliance requirements for by-pass lines are in Table
39 to subpart UUU. We have revised the continuous compliance
requirements to reflect the inclusion of new compliance options and
monitoring requirements.
G. What Are the Notification, Recordkeeping, and Reporting
Requirements?
Sections 63.1574 through 63.1576 of the final rule describe the
requirements for notices, reports, and records. As proposed, you may be
required to provide up to seven types of one-time notifications of
applicability, intention to construct or reconstruct (including
construction and startup dates), performance test dates, and compliance
status.
We added a one-time notice for owner and operators to obtain an
extension of compliance on the emission limitations for an existing
CCU. To obtain the extension, the owner or operator must commit to
adding hydrotreatment of the CCU feedstock to meet the final Tier 2
gasoline sulfur control standards (40 CFR part 80, subpart J).
We have streamlined the data requirements for the Notification of
Compliance Status by removing certain information on operation,
maintenance, and monitoring of affected sources and control systems.
This information is to be included in a separate operation,
maintenance, and monitoring plan submitted to your permitting authority
for review and approval. The plan must cover each affected source,
monitoring system or procedure, and control device or method. This plan
also contains information such as the procedures you will use to
monitor certain process or control device operating parameters, your
quality assurance/quality control plan for continuous monitoring
systems, and monitoring and maintenance schedules.
You must submit a semiannual compliance report containing the
information specified in the rule. We revised the rule to require that
you submit the report whether or not a deviation occurred during the
reporting period. However, only summary information is required if no
deviation occurred. As proposed, the rule does not require that you
make emergency reports if actions taken are consistent with your
startup, shutdown, and malfunction plan. If actions taken are not
consistent with your plan, you must report the events and the response
in your semiannual compliance report.
We also revised the proposed rule in response to comments to
include provisions allowing the permitting authority to approve a
period of planned routine maintenance for a refinery with multiple CCU
served by a single wet scrubber emission control device. During this
pre-approved time period, the refinery may take the control device and/
or one of the process units out of service for maintenance while the
remaining process unit(s) continues to operate. To obtain approval, you
must submit a written request at least 6 months before the planned
maintenance is scheduled to begin that contains the specified
information and data. This includes:
A description of the planned routine maintenance and why
it is necessary;
The date the maintenance will begin and end;
A quantified estimate of the emissions (including HAP and
criteria pollutants) that would be released with an analysis of the
environmental benefits (i.e., emission reduction) that would result as
opposed to delaying the maintenance until the next unit turnaround; and
Actions to be taken to minimize emissions during the
period.
[[Page 17768]]
You must include a copy of the request in the compliance report due
for the period before the planned maintenance is scheduled to begin. In
the compliance report due after the routine planned maintenance is
complete, you must provide followup information on the maintenance
including the number of hours the control device did not operate.
As proposed, you must keep records of the information and data
required by Sec. 63.10. This includes information and data you must
record to show continuous compliance with the emission limitations and
work practice standards. You also must keep records of any changes that
affect the performance of your emission control system.
III. Summary of Environmental, Energy, and Economic Impacts
In response to comments, we revised the environmental impacts
analysis in two major respects. First, we incorporated the most current
(1998) facility-specific data available. We removed thermal (non-fluid)
CCU from the analysis because these units are not subject to the final
rule. Finally, we changed the HAP metal emission estimate methodology
to allow more site-specific and unit-specific estimates based on
equilibrium catalyst Ni concentrations. The revised environmental
impacts analysis is available in the docket (Docket A-97-37).
A. What Are the Air Quality Impacts?
We estimate nationwide HAP emissions from process vents on CCU,
catalytic reforming units, and sulfur recovery units at 12,700 tpy at
the current level of control. Most of the 162 existing refineries will
meet the requirements of the rule within 3 years for all affected
sources. A small number of fluid CCU may be granted an extension of
compliance to install hydrotreating unit(s). When this rule is fully
implemented for all affected sources, nationwide HAP emissions will be
reduced by about 11,000 tpy, an 87 percent reduction. Emissions of non-
HAP such as VOC, CO, PM, and hydrogen sulfide will be reduced by about
55 percent from the current level of about 109,000 tpy. Little or no
adverse secondary air impacts, water, or solid waste impacts are
anticipated from the implementation of these standards.
B. What Are the Cost Impacts?
For most facilities, the costs of the rule will be incurred over
the next 3 years. For a few facilities, the costs for fluid CCU will be
incurred over the next 8 years as hydrotreatment units are installed to
meet the requirements of Tier 2 and this rule. The nationwide capital
and annualized costs of control equipment (1998 dollars) are estimated
at $163 million and $37.2 million/yr, respectively. When fully
implemented, this rule is expected to result in an overall annual
national cost of $47.3 million. This includes a cost of $37.2 million
for operation and maintenance of control devices and a monitoring,
recordkeeping, and reporting cost of $10.1 million ($9.2 million for
operation and maintenance of monitoring systems and $0.9 million for
recordkeeping and reporting).
About 75 percent of the facilities are currently meeting at least
one of the emission limits required under the final rule. The costs for
this rule are for the small fraction of refineries not already meeting
the standard. Based on our cost analysis, only 29 of the 124 CCU (23
percent) and 53 of the 185 sulfur recovery units (29 percent) will
require new or upgraded controls. We estimate that 102 of the 177
catalytic reforming units will require new or upgraded control systems
for HCl.
C. What Are the Economic Impacts?
The economic analysis for the proposed rule showed that the
estimated price increase of refined petroleum products is 0.24 percent
for refineries expected to incur compliance costs as a result of the
rule. The estimated decrease in output is 0.17 percent of domestic
refinery products. The decline in domestic production is due to higher
imports and reduced quantity demanded due to higher prices. However,
the value of domestic shipments is expected to increase by 0.07 percent
because the estimated price increase more than offsets the lower
production volume. Annual net exports (exports minus imports) are
predicted to decrease by 0.76 percent. Employment in the industry is
likely to decrease by 0.19 percent (136 jobs). No plant closures or
significant regional impacts are expected. The impacts for the final
rule are expected to be similar to those predicted for the proposed
rule since the overall costs and number of affected facilities changed
only slightly; both overall capital and annual costs and number of
affected sources are estimated to be lower for the final rule.
Therefore, a new economic analysis was not considered necessary and was
not conducted for the final rule. For more information on the economic
impact analysis methodology and results, consult the ``Economic Impact
Analysis for the Petroleum Refinery NESHAP'' (Docket A-97-37).
D. What Are the Non-Air Health and Environmental Impacts?
The control requirements in this rule are based on air pollution
control systems currently in widespread use throughout the petroleum
refining industry. The reduction in emissions of HAP and criteria
pollutants will result in reduced deposition to waterbodies. The
reduction in VOC will reduce ozone formation resulting in less damage
to agricultural crops and forests. A small increase in annual water
usage, about 6.2 million gallons nationwide, will result from the
increased use of wet scrubbers.
E. What Are the Energy Impacts?
The energy impacts also are about the same as the proposed rule.
Once fully implemented, annual electric usage is expected to increase
by about 67,000 megawatt-hours (MW-hrs), primarily for CCU and sulfur
recovery unit control systems. National natural gas usage, primarily
for sulfur recovery unit control systems, is expected to increase by
about 1.5 billion cubic feet per year.
IV. Summary of Major Comments and Responses
A. Why Did We Extend the Compliance Date?
Comment: Several industry commenters urge us to defer or delay
promulgation of the rule to allow time to coordinate with the Tier 2
gasoline sulfur control requirements and other rules such as the
reformulated gasoline (RFG) Phase II standard and the revised national
ambient air quality standard for PM. Their major concern is that plants
will be required to install expensive controls that may be extraneous
as soon as they are installed depending on the outcome of the Tier 2
and other rules.
Response: To comply with the Tier 2 gasoline sulfur control
requirements, individual refineries ultimately will need to produce
gasoline with an average sulfur content of 30 ppm. The majority of
refineries will need to undertake major construction projects to meet
this limit. Since these projects could require modification of CCU and
other affected sources, we revised the schedule to delay promulgation
of this rule until completion of the Tier 2, which was promulgated on
February 10, 2000 (65 FR 6698).
For some refineries, the Tier 2 rule significantly impacts its CCU.
These refineries will have construction projects adding hydrotreating
of the feed to the CCU. For these refineries, we also extended the
compliance date to allow more time for construction projects. We
believe that this will encourage refinery
[[Page 17769]]
owners and operators to employ hydrotreating of the feedstock to comply
with the Tier 2 rule. As discussed in more detail below, we believe
that hydrotreating the feedstock has increased environmental benefits
relative to other methods of reducing gasoline sulfur.
The extended compliance date for existing CCU is based on when and
how a refinery produces low sulfur gasoline to meet the Tier 2 limit.
Hydrotreating the feed to the CCU is one of the means of producing low
sulfur gasoline. As discussed further below, hydrotreating the
feedstock provides environmental benefits not realized with other
methods of producing low sulfur gasoline. It is also, unfortunately,
significantly more expensive than other methods of reducing the sulfur
content of gasoline.
A refinery owner or operator must determine which technology to use
in reducing gasoline sulfur to meet the fuel standards. A number of
alternatives are available. Refineries may elect to hydrotreat after
the CCU, to hydrotreat the CCU feedstock or to implement some other
form of desulfurization technology. Hydrotreating the feedstock removes
metals as well as sulfur. While hydrotreating the feedstock to the unit
would allow greater flexibility within the overall refinery operations
and would better position the refinery for any additional sulfur fuel
standards that might be promulgated in the future, such as standards to
reduce sulfur in diesel fuel (64 FR 26142, May 13, 1999), the cost of
hydrotreating the CCU feed is considerably more than post-unit
hydrotreating for desulfurization. Thus, despite the greater
flexibility realized through hydrotreating the feedstock, there is an
economic bias against its use to reduce gasoline sulfur to meet the
fuel standards. We believe that this bias could increase substantially
if we do not coordinate the compliance dates for these NESHAP and the
Tier 2 rule. A substantial increase in the economic bias against
hydrotreating the feedstock would likely result in less refineries
implementing this method of reducing gasoline sulfur, thereby foregoing
a potentially significant environmental benefit.
Some facilities will take longer than 3 years to comply with the
Tier 2 standards. Should these facilities elect to install
hydrotreatment units for the feed to the CCU, these new units will not
be operating at the compliance date for the MACT standard, 3 years
promulgation. To avoid non-compliance, an owner or operator would be
required to install expensive PM controls to comply with the MACT
standard. These new controls might then become redundant with the later
startup of the hydrotreatment unit for the feed to the CCU. Therefore,
if the owner or operator elects to install a hydrotreatment unit for
the feed to the CCU, the MACT compliance date for the CCU becomes the
same as the Tier 2 compliance date.
Linking the compliance dates for the two rules, in this particular
instance for those refineries that elect to hydrotreat the CCU
feedstock, will allow the refinery to coordinate both decision making
and the actual construction projects and, thus, minimize disruption to
the refinery operations. We believe that not linking the compliance
dates for the two rules could result in an environmental benefit being
foregone and that linking them will result in a net environmental
benefit because the number of process unit shutdowns and startups would
be minimized. Shutdowns and startups can result in considerably more
emissions to the atmosphere than operations under normal conditions. An
estimate of the emissions reductions that would result from linking the
compliance dates for the CCU MACT standards and Tier 2 fuel standards
is not possible at this time. This is because we lack information
regarding how the refineries will choose to comply with the fuel
standards and the uncertainties associated with startup and shutdown of
these refinery operations.
Linking the MACT standards' compliance date to the Tier 2 fuel
standards' compliance date (i.e., the date the refinery produces low
sulfur gasoline at 30 ppm) will not result in an overall or complete
delay of the MACT standards for all CCU. While we believe that linking
the compliance dates will serve as an incentive to hydrotreat the CCU
feedstock, we nevertheless expect that the majority of facilities will
comply with the fuel standards without implementing CCU feedstock
hydrotreating. In some cases, even those that elect to hydrotreat the
feedstock will comply in 3 years or less to take advantage of the
various pooling, averaging, banking, and trading options provided in
the final Tier 2 standards. The remainder of refineries will begin
production of low sulfur gasoline over the next 8-year period, although
most are expected to be in full compliance (i.e., producing gasoline at
the 30 ppm annual average) by the year 2006. In no case will refineries
be allowed any later than December 31, 2009, to comply with the MACT
standard for CCU, which corresponds to the final Tier 2 compliance
date.
B. What Is the New Alternative Nickel Emission Limitation?
Comment: Several industry commenters urge us to include a rate-
based Ni alternative of 0.007 lb Ni/1,000 lbs of coke burn-off in the
final rule. According to the commenters, this approach avoids
penalizing large units with low HAP emissions and equates to the NSPS
for PM by using the highest or worst case Ni equilibrium concentration
to convert PM to Ni. Most of the units that can comply with the PM
limit cannot comply with the mass-based Ni limit due to their greater
size. The commenters argue that larger units should not be subject to a
more restrictive Ni limit than smaller units due to their greater
processing capacity.
Environmental groups and one independent technical expert strongly
disagree that we should provide the second Ni alternative at the level
suggested by industry (i.e., 0.007 lb/1,000 lbs of coke burn-off).
Commenters claim that this alternative is not technically equivalent to
the MACT floor, is not protective of the environment as it is set at a
level that allows all refiners to process heavy feeds with no control
device, will actually increase emissions, and poses difficulties in
ensuring continuous compliance.
Response: After careful review of all the information and data
collected following proposal and received as part of the public
comments, we decided to include an additional metal HAP alternative for
CCU formatted in terms of Ni emissions per 1,000 lbs of coke burn-off.
We concluded that this particular format (i.e., lb Ni/1,000 lbs of coke
burn-off) does account for the wide variation of processing capacity
within the industry and, with the new provisions added to the final
rule, there are adequate means of ensuring continuous compliance.
We also concluded that the technical approach recommended by the
industry commenters (using equilibrium catalyst Ni concentration to
make a direct conversion of the PM emission standard to a Ni limit) is
not appropriate. As discussed further in the Response to Comment
Document, we must reject any method to derive a Ni emission limit in
terms of lb Ni/1,000 lb coke burn-off based on the PM emission limit
and some arbitrarily selected equilibrium catalyst concentration,
whether it is a median, average or highest measured value. The emission
limits calculated using these approaches do not correlate with actual
emissions (in lb Ni/1,000 lbs coke burn-off) of any CCU, and the
resulting Ni emission limits are not
[[Page 17770]]
``equivalent'' to the technology-based standard used as a basis of the
PM emission limit that characterizes performance of the MACT floor
technologies. This is because the equilibrium catalyst Ni concentration
in no way reflects the performance of the MACT floor technology, as PM
emissions. The equilibrium catalyst Ni concentration of a CCU is
dependent on a complex mixture of operating and economic
considerations; it is not totally dictated by the variability of Ni in
the crude oil or the unit feed. In addition, we have no data or
information to relate the equilibrium catalyst metals concentration to
the best performing facilities (i.e., the equilibrium catalyst metal
concentration does not reflect or relate to control device
performance).
Although we do not accept the recommended approach in determining
the emission limit based on an equilibrium catalyst conversion factor,
we feel that the alternative format in terms of lb Ni/1,000 lb of coke
burn-off has considerable merit. This particular format allows for
flexible compliance on the part of the plant owner/operator. An
emission limit expressed in this format can be met by using front-end
hydrotreating, in-process operational changes, or end of pipe add-on
controls alone or in combination.
In addition, to comply with the Tier 2 fuel standards, an owner or
operator must choose one of a number of available methods of reducing
sulfur in gasoline. One of those methods is to hydrotreat CCU
feedstocks. This method of compliance has environmental benefits not
realized with other methods. This is because feedstock hydrotreating
has the potential to reduce Ni emissions from CCU, depending on what
operating changes are made in the catalyst regeneration processes in
conjunction with the feedstock hydrotreating. We believe that a Ni
emission limit, in terms of lb Ni/1,000 lbs coke burn-off, has a
potential to encourage feedstock hydrotreating as a means to comply
with this limit and the Tier 2 fuel standards.
To determine an appropriate emission limit, we examined the
available emissions data for the top performing CCU in terms of lb Ni
emissions/1,000 lb coke burn-off rate. Although the currently available
source test data are somewhat limited and are generally assumed to be
representative of the lowest Ni emitters across the industry, they do
allow an analysis following the basic criteria established for a MACT
floor determination.
Through review of the emission data, we found that the average
emission rates, as well as each individual test run result for the top-
ranked CCU, are all below 0.001 lb Ni/1,000 lbs coke burn-off. Based on
our data analysis, we determined that the emission limit of 0.001 lb
Ni/1,000 lbs coke burn-off adequately characterizes performance of the
MACT floor technology while taking into account process and measurement
variability. This analysis provides an emission limit in the
alternative format (Ni emissions per unit coke burn) that is reflective
of the MACT floor technology. This emission limit is included in the
final rule as an alternative format to the PM or Ni lb/hr limits that
were also selected to characterize the performance of the MACT floor
technologies. The determination of the emission limit formatted in
terms of coke burn-off that is used to characterize the MACT floor
technology is discussed in more detail in the Response to Comments
Document (Docket A-97-36).
C. Why Did We Not Change the Proposed Nickel Emission Limitation?
Comment: Three commenters believe we should relax the proposed Ni
emission limitation (lbs/hr) for metal HAP emissions from CCU. They
question the method we used to determine the numerical emission limit
that characterizes the MACT floor technology in this particular format.
According to the commenters, our variability analysis is flawed for
several reasons.
We used the z-statistic rather than the student's t-
statistic, which is appropriate for small samples from populations.
We used the average relative standard deviation instead of
the more representative maximum relative standard deviation.
The analysis includes data known to be false or
problematic.
We used the 95 percent confidence level rather than the 98
percent interval, which the commenter claims is an EPA precedent.
The commenters also believe the level of emissions that would be
excluded by the higher limit is trivial and of little environmental
significance. Raising the limit would allow some refineries to avoid
installing controls that are not cost effective and provide real de
minimus relief. The commenters support a standard of 760 lbs/yr based
on their approach.
Response: We acknowledge the quality assurance concerns regarding
the results of certain Ni emission measurements and the use of larger
confidence intervals about the average emission value in setting an
emission limit that reflects use of the MACT floor technology. However,
we also believe that the analysis must use the average of the top 12
percent or the 6th percentile facility, rather than the emissions of
the 12th percentile facility. There are 124 fluid CCU in the U.S. and
its territories; the 6th percentile of the industry would be
represented by the emissions reductions achieved by the 7th and 8th
ranked units. Reanalysis of the data, considering the reviewer's
comments on the statistical approach while using the 6th percentile
unit, yields an emission limit nearly identical to the proposed limit.
In response to this comment, we examined the emission rates of the
top performing unit for which we have documented source test results.
We found that the average emission rates, as well as each individual
test run result for the top eight ranked units, are all below 200 lbs/
yr. The 9th and 10th ranked units have similar average emission rates,
but a wider fluctuation in the individual test run results. From the
test data available, we determined that the proposed emission limit of
250 lbs/yr adequately characterizes the performance of the MACT floor
technologies while taking into account process variability. For these
reasons, we made no change in the proposed Ni lb/hr emission limit.
D. How Did We Change the Proposed Monitoring Requirements?
Comment: Environmental groups urge us to require continuous
emission monitoring systems for HCl, TRS, and either CO, TOC, or total
hydrocarbons (THC) for existing and new affected sources. They say
these systems are commercially available, feasible (as stated in the
background information document), ensure standards are met at all
times, and provide better HAP monitoring. They say the cost of these
systems is decreasing, and they may no longer be too costly. Also, the
continuous monitoring of a process allows the operator greater
flexibility in operation which could result in increased output,
improved efficiency, and overall cost savings. Two commenters
specifically request continuous emission monitoring systems for TRS
limits. Due to the TRS emissions from refineries and numerous
exceedances, more accurate information than operating parameter values
is needed to assess compliance.
Response: We agree with the commenters' recommendations that the
NSPS experience with continuous emission monitoring systems
demonstrates their technical and economic feasibility for this
industry,
[[Page 17771]]
provides better data, and needs to be encouraged.
In determining monitoring requirements, we looked at the various
options. One of the options examined was requiring continuous emission
or opacity monitors for all affected sources under this rule. We did
not select this option because of the high capital and operating costs.
However, in response to these comments, we reexamined these options
to look for ways to encourage their use or require their use if needed.
As a result, we included options in the rule allowing plants to choose
to comply with the NSPS monitoring requirements.
We also included requirements in the rule for continuous opacity
monitoring systems for catalyst regenerator vents on any CCU with a
fresh feed capacity greater than 20,000 barrels per day (and not using
wet scrubbers). We also added continuous opacity monitors as a
monitoring option for smaller units. Continuous opacity monitoring
systems are already required for the larger units under Federal/State
implementation plan requirements in 40 CFR part 51, appendix P;
therefore, these costs are not attributable to the standard. We did not
require a continuous opacity monitoring system for a unit with a wet
scrubber because of interference from water vapor in wet scrubber
exhaust gases. For these units, parameter monitoring is still the only
monitoring method.
A continuous emission monitoring system for TRS or reduced sulfur
emissions is also required in the final rule for any sulfur recovery
unit with no add-on control device. The cost of continuous emission
monitoring systems for these units is reasonable and does not pose any
economic hardship for plants that do not use a control device. For
units with add-on control devices, we are confident that the process or
control device parameter monitoring allowed in place of continuous
emission or opacity monitoring systems provides adequate assurance of
continuous compliance.
V. Administrative Requirements
A. Executive Order 12866, Regulatory Planning and Review
Under Executive Order 12866 (58 FR 5173, October 4, 1993), the EPA
must determine whether the regulatory action is ``significant'' and
therefore subject to review by the Office of Management and Budget
(OMB) and the requirements of the Executive Order. The Executive Order
defines a ``significant regulatory action'' as one that is likely to
result in a rule that may:
(1) Have an annual effect on the economy of $100 million or more or
adversely affect in a material way the economy, a sector of the
economy, productivity, competition, jobs, the environment, public
health or safety, or State, local, or tribal governments or
communities;
(2) Create a serious inconsistency or otherwise interfere with an
action taken or planned by another agency;
(3) Materially alter the budgetary impact of entitlement, grants,
user fees, or loan programs or the rights and obligations of recipients
thereof; or
(4) Raise novel legal or policy issues arising out of legal
mandates, the President's priorities, or the principles set forth in
the Executive Order.
Pursuant to the terms of Executive Order 12866, OMB has notified
EPA that it considers this a ``significant regulatory action'' within
the meaning of the Executive Order. EPA has submitted this action to
OMB for review. Changes made in response to OMB suggestions or
recommendations are documented in the public record.
B. Executive Order 13132, Federalism
Executive Order 13132, entitled ``Federalism'' (64 FR 43255, August
10, 1999), requires EPA to develop an accountable process to ensure
``meaningful and timely input by State and local officials in the
development of regulatory policies that have federalism implications.''
``Policies that have federalism implications'' is defined in the
Executive Order to include regulations that have ``substantial direct
effects on the States, on the relationship between the national
government and the States, or on the distribution of power and
responsibilities among the various levels of government.''
Under section 6 of Executive Order 13132, EPA may not issue a
regulation that has federalism implications, that imposes substantial
direct compliance costs, and that is not required by statute, unless
the Federal government provides the funds necessary to pay the direct
compliance costs incurred by State and local governments, or EPA
consults with State and local officials early in the process of
developing the proposed regulation. The EPA also may not issue a
regulation that has federalism implications and that preempts State
law, unless the EPA consults with State and local officials early in
the process of developing the proposed regulation.
This final rule does not have federalism implications. It will not
have substantial direct effects on the States, on the relationship
between the national government and the States, or on the distribution
of power and responsibilities among the various levels of government,
as specified in Executive Order 13132. None of the affected facilities
are owned or operated by State governments. Thus, the requirements of
section 6 of the Executive Order do not apply to this rule.
C. Executive Order 13175, Consultation and Coordination With Indian
Tribal Governments
Executive Order 13175, entitled ``Consultation and Coordination
with Indian Tribal Governments'' (65 FR 67249, November 6, 2000),
requires EPA to develop an accountable process to ensure ``meaningful
and timely input by tribal officials in the development of regulatory
policies that have tribal implications.'' ``Policies that have tribal
implications'' is defined in the Executive Order to include regulations
that have ``substantial direct effects on one or more Indian tribes, on
the relationship between the Federal government and the Indian tribes,
or on the distribution of power and responsibilities between the
Federal government and Indian tribes.''
This final rule does not have tribal implications. It will not have
substantial direct effects on tribal governments, on the relationship
between the Federal government and Indian tribes, or on the
distribution of power and responsibilities between the Federal
government and Indian tribes, as specified in Executive Order 13175.
Thus, Executive Order 13175 does not apply to this rule.
D. Executive Order 13045, Protection of Children From Environmental
Health Risks and Safety Risks
Executive Order 13045 (62 FR 19885, April 23, 1997) applies to any
rule that: (1) Is determined to be ``economically significant,'' as
defined under Executive Order 12866, and (2) concerns an environmental
health or safety risk that EPA has reason to believe may have a
disproportionate effect on children. If the regulatory action meets
both criteria, the EPA must evaluate the environmental health or safety
effects of the planned rule on children and explain why the planned
regulation is preferable to other potentially effective and reasonably
feasible alternatives considered by the EPA.
This final rule is not subject to Executive Order 13045 because it
is not an economically significant regulatory action as defined by
Executive Order 12866. The EPA interprets Executive Order 13045 as
applying only to
[[Page 17772]]
regulatory actions that are based on health or safety risks, such that
the analysis required under section 5-501 of the Executive Order has
the potential to influence the regulation. These final NESHAP are not
subject to Executive Order 13045 because they are based on technology
performance and not on health or safety risks.
E. Executive Order 13211, Actions Concerning Regulations That
Significantly Affect Energy Supply, Distribution or Use
This rule is not a ``significant energy action'' as defined in
Executive Order 13211, ``Actions Concerning Regulations That
Significantly Affect Energy Supply, Distribution, or Use'' (66 FR 28355
(May 22, 2001)) because it is not likely to have a significant adverse
effect on the supply, distribution, or use of energy.
F. Unfunded Mandates Reform Act of 1995
Title II of the Unfunded Mandates Reform Act of 1995 (UMRA), Public
Law 104-4, establishes requirements for Federal agencies to assess the
effects of their regulatory actions on State, local, and tribal
governments and the private sector. Under section 202 of the UMRA, the
EPA generally must prepare a written statement, including a cost-
benefit analysis, for proposed and final rules with ``Federal
mandates'' that may result in expenditures by State, local, and tribal
governments, in the aggregate, or by the private sector, of $100
million or more in any 1 year. Before promulgating an EPA rule for
which a written statement is needed, section 205 of the UMRA generally
requires the EPA to identify and consider a reasonable number of
regulatory alternatives and adopt the least costly, most cost-
effective, or least-burdensome alternative that achieves the objectives
of the rule. The provisions of section 205 do not apply when they are
inconsistent with applicable law. Moreover, section 205 allows the EPA
to adopt an alternative other than the least-costly, most cost-
effective, or least-burdensome alternative if the Administrator
publishes with the final rule an explanation why that alternative was
not adopted. Before the EPA establishes any regulatory requirements
that may significantly or uniquely affect small governments, including
tribal governments, it must have developed under section 203 of the
UMRA a small government agency plan. The plan must provide for
notifying potentially affected small governments, enabling officials of
affected small governments to have meaningful and timely input in the
development of EPA regulatory proposals with significant Federal
intergovernmental mandates, and informing, educating, and advising
small governments on compliance with the regulatory requirements.
The EPA has determined that this rule does not contain a Federal
mandate that may result in estimated costs of $100 million or more to
either State, local, or tribal governments, in the aggregate, or to the
private sector in any 1 year. The rule does not significantly or
uniquely impact small governments because it contains no requirements
that apply to such governments or impose obligations upon them. Thus,
the requirements of the UMRA do not apply to this rule.
G. Regulatory Flexibility Act (RFA), As Amended by the Small Business
Regulatory Enforcement Fairness Act of 1996 (SBREFA), 5 U.S.C. 601 et
seq.
The EPA has determined that it is not necessary to prepare a
regulatory flexibility analysis in connection with this final rule. For
the purposes of assessing the impacts of today's rule on small
entities, small entities are defined as: (1) A firm having no more than
1,500 employees and no more than 75,000 barrels per day capacity of
petroleum-based inputs, including crude oil or bona fide feedstocks;\1\
according to Small Business Administration (SBA) size standards
established under the North American Industry Classification System
(NAICS); (2) a small government jurisdiction that is a government of a
city, county, town, school district or special district with a
population of less than 50,000; and (3) a small organization that is
any not-for-profit enterprise which is independently owned and operated
and is not dominant in its field. Small entities in NAICS 32411 only
will be affected.
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\1\ Capacity includes owned or leased facilities as well as
facilities under a processing agreement or an agreement such as an
exchange agreement or a throughput. The total product to be
delivered under the contract must be at least 90 percent refined by
the successful bidder from either crude oil or bona fide feedstocks.
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After considering the economic impacts of today's final rule on
small entities, EPA has concluded that this action will not have a
significant economic impact on a substantial number of small entities.
We have determined that nine of the 23 small refiners own one or more
of the affected sources. None of the 9 small refiners will need
additional air pollution control equipment for CCU or sulfur recovery
units. Only those costs for monitoring, reporting, and recordkeeping
would be incurred by these firms. Six small refiners will need to add
control equipment for catalytic reforming units. Annual total
compliance costs for the nine affected small refiners would be less
than 0.01 percent of estimated revenues. For more information, please
consult the public docket for this final rule.
Although this final rule will not have a significant economic
impact on a substantial number of small entities, EPA nonetheless has
tried to reduce the impact of this rule on small entities. As discussed
in the preamble to the proposed rule, EPA met with representatives of
five small refineries and listened to their concerns. In response, we
exercised the maximum degree of flexibility in minimizing impacts on
small business through the alternative Nickel standard and
subcategorization for catalytic reforming units. The rule reflects the
minimum level of control allowed under the CAA. Since proposal, we have
further reduced the economic impact on all refineries, including small
businesses, by subcategorizing CCU and, in appropriate circumstances,
extending the compliance date to coincide with the Tier 2 gasoline
sulfur control rule.
H. Paperwork Reduction Act
The information collection requirements in this final rule are
being submitted for approval to OMB under the requirements of the
Paperwork Reduction Act, 44 U.S.C. 3501 et seq. An information
collection request (ICR) document has been prepared by EPA (ICR No.
1844.01), and a copy may be obtained from Sandy Farmer, Office of
Environmental Information, Collection Strategies Division, U.S.
Environmental Protection Agency (2137), 1200 Pennsylvania Avenue, NW.,
Washington, DC 20460, or by calling (202) 260-2740.
The information collection requirements in the final rule include
mandatory notifications, records, and reports required by the NESHAP
General Provisions (40 CFR part 63, subpart A). These information
requirements are needed to confirm the compliance status of major
sources, to identify any non-major sources not subject to the standard
and any new or reconstructed sources subject to the standards, to
confirm that emission control devices are being properly operated and
maintained, and to ensure that the standards are being achieved. Based
on the recorded and reported information, EPA can decide which
facilities, records, or processes should be inspected. These
recordkeeping and reporting requirements are specifically authorized
under section 114 of the CAA (42 U.S.C. 7414). All information
submitted to EPA for which a claim of
[[Page 17773]]
confidentiality is made will be safeguarded according to EPA policies
in 40 CFR part 2, subpart B.
The annual public reporting and recordkeeping burden for this
collection of information (averaged over the first 3 years after the
effective date of this rule) is estimated to total 19,428 labor hours
per year at a total annual cost of $1.3 million. This estimate includes
initial notifications, a performance test, one-time preparation of a
startup, shutdown, and malfunction plan and operation, maintenance, and
monitoring plan, semiannual deviation summary reports, and
recordkeeping for 132 plants expected to be subject to the rule during
this ICR clearance period. Total capital costs associated with the
monitoring equipment over the 3-year period of the ICR is estimated at
$15.8 million; the annualized cost of capital is estimated at $1.1
million. This estimate includes the capital and startup costs
associated with installation of monitoring equipment.
Burden means the total time, effort, or financial resources
expended by persons to generate, maintain, retain, or disclose or
provide information to or for a Federal agency. This includes the time
needed to review instructions; develop, acquire, install, and utilize
technology and systems for the purposes of collecting, validating, and
verifying information, processing and maintaining information, and
disclosing and providing information; adjust the existing ways to
comply with any previously applicable instructions and requirements;
train personnel to be able to respond to a collection of information;
search data sources; complete and review the collection of information;
and transmit or otherwise disclose the information.
An Agency may not conduct or sponsor, and a person is not required
to respond to, a collection of information unless it displays a
currently valid OMB control number. The OMB control number for EPA's
regulations are listed in 40 CFR part 9 and 48 CFR chapter 15.
I. National Technology Transfer and Advancement Act of 1995
Section 12(d) of the National Technology Transfer and Advancement
Act of 1995 (NTTAA), Public Law 104-113, Sec. 12(d) (15 U.S.C. 272
note) directs EPA to use voluntary consensus in their regulatory and
procurement activities unless to do so would be inconsistent with
applicable law or otherwise impracticable. Voluntary consensus
standards are technical standards (e.g., material specifications, test
methods, sampling procedures, business practices) developed or adopted
by one or more voluntary consensus bodies. The NTTTA requires Federal
agencies to provide Congress, through annual reports to OMB, with
explanations when an agency does not use available and applicable
voluntary consensus standards.
Consistent with the NTTAA, we conducted searches to identify
voluntary consensus standards for use in emissions testing. The search
for emissions testing procedures identified 34 voluntary consensus
standards that appeared to have possible use in lieu of EPA standard
reference methods. After reviewing the available standards, we
determined that 26 of the candidate consensus standards identified for
measuring emissions of the HAP or surrogates subject to the emission
limitations in the rule would not be practical due to lack of
equivalency, documentation, validation data, and other important
technical and policy considerations. Eight of the remaining candidate
consensus are under development or currently under EPA review. We plan
to follow, review, and consider adopting these standards after their
development and we complete further review.
One consensus standard, ASTM D6216-98, is practical for EPA use in
Performance Specification 1 (PS-1) in 40 CFR part 60, appendix B,
``Specifications and Test Procedures for Opacity Continuous Emission
Monitoring Systems in Stationary Sources.'' This ASTM method can best
be used in place of the design specification verification procedures
currently in sections 5 and 6 of PS-1. We proposed ASTM D6216-98 for
incorporation by reference in another rulemaking (63 FR 50824,
September 23, 1998). Comments from the proposal have been addressed and
we expect to complete this action in the near future. For these
reasons, we do not propose to adopt ASTM D6216-98 in lieu of PS-1
requirements as it would be impractical to us to act independently from
the other rulemaking already undergoing promulgation, and because ASTM
D6216 does not address all the requirements specified in PS-1.
Tables 4 and 40 in subpart UUU list the EPA test methods and
performance specifications included in this rule. Most of these methods
and performance specifications have been used by States and industry
for more than 10 years. Nevertheless, as provided by Sec. 63.7(f) of
the NESHAP General Provisions (40 CFR part 63, subpart A), any State or
facility may apply to EPA for permission to use an alternative method
in place of any of the EPA test methods or performance specifications
listed in the rule.
J. Congressional Review Act
The Congressional Review Act, 5 U.S.C. 801 et seq., as added by the
Small Business Regulatory Enforcement Fairness Act of 1996, generally
provides that before a rule may take effect, the agency promulgating
the rule must submit a rule report, which includes a copy of the rule,
to each House of the Congress and to the Comptroller General of the
United States. The EPA will submit a report containing this rule and
other required information to the U.S. Senate, the U.S. House of
Representatives, and the Comptroller General of the United States prior
to publication of the rule in the Federal Register. This rule is not a
``major rule'' as defined by 5 U.S.C. 804(2).
List of Subjects in 40 CFR Part 63
Environmental protection, Air pollution control, Petroleum
refineries.
Dated: March 19, 2002.
Christine Todd Whitman,
Administrator.
For the reasons stated in the preamble, title 40, chapter I, part
63 of the Code of Federal Regulations is amended as follows:
PART 63--[AMENDED]
1. The authority citation for part 63 continues to read as follows:
Authority: 42 U.S.C. 7401, et seq.
2. Part 63 is amended by adding subpart UUU to read as follows:
Subpart UUU--National Emission Standards for Hazardous Air
Pollutants for Petroleum Refineries: Catalytic Cracking Units,
Catalytic Reforming Units, and Sulfur Recovery Units
Sec.
What This Subpart Covers
63.1560 What is the purpose of this subpart?
63.1561 Am I subject to this subpart?
63.1562 What parts of my plant are covered by this subpart?
63.1563 When do I have to comply with this subpart?
Catalytic Cracking Units, Catalytic Reforming Units, Sulfur Recovery
Units, and Bypass Lines
63.1564 What are my requirements for metal HAP emissions from
catalytic cracking units?
63.1565 What are my requirements for organic HAP emissions from
catalytic cracking units?
63.1566 What are my requirements for organic HAP emissions from
catalytic reforming units?
63.1567 What are my requirements for inorganic HAP emissions from
catalytic reforming units?
[[Page 17774]]
63.1568 What are my requirements for HAP emissions from sulfur
recovery units?
63.1569 What are my requirements for HAP emissions from bypass
lines?
General Compliance Requirements
63.1570 What are my general requirements for complying with this
subpart?
63.1571 How and when must I conduct a performance test or other
initial compliance demonstration?
63.1572 What are my monitoring installation, operation, and
maintenance requirements?
63.1573 What are my monitoring alternatives?
Notifications, Reports, and Records
63.1574 What notifications must I submit and when?
63.1575 What reports must I submit and when?
63.1576 What records must I keep, in what form, and for how long?
Other Requirements and Information
63.1577 What parts of the General Provisions apply to me?
63.1578 Who implements and enforces this subpart?
63.1579 What definitions apply to this subpart?
Tables
Table 1 to Subpart UUU of Part 63--Metal HAP Emission Limits for
Catalytic Cracking Units
Table 2 to Subpart UUU of Part 63--Operating Limits for Metal HAP
Emissions from Catalytic Cracking Units
Table 3 to Subpart UUU of Part 63--Continuous Monitoring Systems for
Metal HAP Emissions from Catalytic Cracking Units
Table 4 to Subpart UUU of Part 63--Requirements for Performance
Tests for Metal HAP Emissions from Catalytic Cracking Units Not
Subject to the New Source Performance Standard (NSPS) for
Particulate Matter (PM)
Table 5 to Subpart UUU of Part 63--Initial Compliance with Metal HAP
Emission Limits for Catalytic Cracking Units
Table 6 to Subpart UUU of Part 63--Continuous Compliance with Metal
HAP Emission Limits for Catalytic Cracking Units
Table 7 to Subpart UUU of Part 63--Continuous Compliance with
Operating Limits for Metal HAP Emissions from Catalytic Cracking
Units
Table 8 to Subpart UUU of Part 63--Organic HAP Emission Limits for
Catalytic Cracking Units
Table 9 to Subpart UUU of Part 63--Operating Limits for Organic HAP
Emissions from Catalytic Cracking Units
Table 10 to Subpart UUU of Part 63--Continuous Monitoring Systems
for Organic HAP Emissions from Catalytic Cracking Units
Table 11 to Subpart UUU of Part 63--Requirements for Performance
Tests for Organic HAP Emissions from Catalytic Cracking Units Not
Subject to the New Source Performance Standard (NSPS) for Carbon
Monoxide (CO)
Table 12 to Subpart UUU of Part 63--Initial Compliance with Organic
HAP Emission Limits for Catalytic Cracking Units
Table 13 to Subpart UUU of Part 63--Continuous Compliance with
Organic HAP Emission Limits for Catalytic Cracking Units
Table 14 to Subpart UUU of Part 63--Continuous Compliance with
Operating Limits for Organic HAP Emissions from Catalytic Cracking
Units
Table 15 to Subpart UUU of Part 63--Organic HAP Emission Limits for
Catalytic Reforming Units
Table 16 to Subpart UUU of Part 63--Operating Limits for Organic HAP
Emissions from Catalytic Reforming Units
Table 17 to Subpart UUU of Part 63--Continuous Monitoring Systems
for Organic HAP Emissions from Catalytic Reforming Units
Table 18 to Subpart UUU of Part 63--Requirements for Performance
Tests for Organic HAP Emissions from Catalytic Reforming Units
Table 19 to Subpart UUU of Part 63--Initial Compliance with Organic
HAP Emission Limits for Catalytic Reforming Units
Table 20 to Subpart UUU of Part 63--Continuous Compliance with
Organic HAP Emission Limits for Catalytic Reforming Units
Table 21 to Subpart UUU of Part 63--Continuous Compliance with
Operating Limits for Organic HAP Emissions from Catalytic Reforming
Units
Table 22 to Subpart UUU of Part 63--Inorganic HAP Emission Limits
for Catalytic Reforming Units
Table 23 to Subpart UUU of Part 63--Operating Limits for Inorganic
HAP Emission Limitations for Catalytic Reforming Units
Table 24 to Subpart UUU of Part 63--Continuous Monitoring Systems
for Inorganic HAP Emissions from Catalytic Reforming Units
Table 25 to Subpart UUU of Part 63--Requirements for Performance
Tests for Inorganic HAP Emissions from Catalytic Reforming Units
Table 26 to Subpart UUU of Part 63--Initial Compliance with
Inorganic HAP Emission Limits for Catalytic Reforming Units
Table 27 to Subpart UUU of Part 63--Continuous Compliance with
Inorganic HAP Emission Limits for Catalytic Reforming Units
Table 28 to Subpart UUU of Part 63--Continuous Compliance with
Operating Limits for Inorganic HAP Emissions from Catalytic
Reforming Units
Table 29 to Subpart UUU of Part 63--HAP Emission Limits for Sulfur
Recovery Units
Table 30 to Subpart UUU of Part 63--Operating Limits for HAP
Emissions from Sulfur Recovery Units
Table 31 to Subpart UUU of Part 63--Continuous Monitoring Systems
for HAP Emissions from Sulfur Recovery Units
Table 32 to Subpart UUU of Part 63--Requirements for Performance
Tests for HAP Emissions from Sulfur Recovery Units Not Subject to
the New Source Performance Standards (NSPS) for Sulfur Oxides
Table 33 to Subpart UUU of Part 63--Initial Compliance with HAP
Emission Limits for Sulfur Recovery Units
Table 34 to Subpart UUU of Part 63--Continuous Compliance with HAP
Emission Limits for Sulfur Recovery Units
Table 35 to Subpart UUU of Part 63--Continuous Compliance with
Operating Limits for HAP Emissions from Sulfur Recovery Units
Table 36 to Subpart UUU of Part 63--Work Practice Standards for HAP
Emissions from Bypass Lines
Table 37 to Subpart UUU of Part 63--Requirements for Performance
Tests for Bypass Lines
Table 38 to Subpart UUU of Part 63--Initial Compliance with Work
Practice Standards for HAP Emissions from Bypass Lines
Table 39 to Subpart UUU of Part 63--Continuous Compliance with Work
Practice Standards for HAP Emissions from Bypass Lines
Table 40 to Subpart UUU of Part 63--Requirements for Installation,
Operation, and Maintenance of Continuous Opacity Monitoring Systems
and Continuous Emission Monitoring Systems
Table 41 to Subpart UUU of Part 63--Requirements for Installation,
Operation, and Maintenance of Continuous Parameter Monitoring
Systems
Table 42 to Subpart UUU of Part 63--Additional Information for
Initial Notification of Compliance Status
Table 43 to Subpart UUU of Part 63--Requirements for Reports
Table 44 to Subpart UUU of Part 63--Applicability of NESHAP General
Provisions to Subpart UUU
What This Subpart Covers
Sec. 63.1560 What is the purpose of this subpart?
This subpart establishes national emission standards for hazardous
air pollutants (HAP) emitted from petroleum refineries. This subpart
also establishes requirements to demonstrate initial and continuous
compliance with the emission limitations and work practice standards.
Sec. 63.1561 Am I subject to this subpart?
(a) You are subject to this subpart if you own or operate a
petroleum refinery that is located at a major source of HAP emissions.
(1) A petroleum refinery is an establishment engaged primarily in
petroleum refining as defined in the Standard Industrial Classification
(SIC) code 2911 and the North American Industry Classification (NAIC)
code 32411, and used mainly for:
(i) Producing transportation fuels (such as gasoline, diesel fuels,
and jet fuels), heating fuels (such as kerosene, fuel gas distillate,
and fuel oils), or lubricants;
(ii) Separating petroleum; or
(iii) Separating, cracking, reacting, or reforming an intermediate
petroleum
[[Page 17775]]
stream, or recovering a by-product(s) from the intermediate petroleum
stream (e.g., sulfur recovery).
(2) A major source of HAP is a plant site that emits or has the
potential to emit any single HAP at a rate of 9.07 megagrams (10 tons)
or more per year or any combination of HAP at a rate of 22.68 megagrams
(25 tons) or more per year.
(b) [Reserved]
Sec. 63.1562 What parts of my plant are covered by this subpart?
(a) This subpart applies to each new, reconstructed, or existing
affected source at a petroleum refinery.
(b) The affected sources are:
(1) Each catalytic cracking unit that regenerates catalyst.
(2) Each catalytic reforming unit that regenerates catalyst.
(3) Each sulfur recovery unit and the tail gas treatment unit
serving it.
(4) Each bypass line serving a new, existing, or reconstructed
catalytic cracking unit, catalytic reforming unit, or sulfur recovery
unit. This means each vent system that contains a bypass line (e.g.,
ductwork) that could divert an affected vent stream away from a control
device used to comply with the requirements of this subpart.
(c) An affected source is a new affected source if you commence
construction of the affected source after September 11, 1998, and you
meet the applicability criteria in Sec. 63.1561 at the time you
commenced construction.
(d) Any affected source is reconstructed if you meet the criteria
in Sec. 63.2.
(e) An affected source is existing if it is not new or
reconstructed.
(f) This subpart does not apply to:
(1) A thermal catalytic cracking unit.
(2) A sulfur recovery unit that does not recover elemental sulfur
or where the modified reaction is carried out in a water solution which
contains a metal ion capable of oxidizing the sulfide ion to sulfur
(e.g., the LO-CAT II process).
(3) A redundant sulfur recovery unit not located at a petroleum
refinery and used by the refinery only for emergency or maintenance
backup.
(4) Equipment associated with bypass lines such as low leg drains,
high point bleed, analyzer vents, open-ended valves or lines, or
pressure relief valves needed for safety reasons.
(5) Gaseous streams routed to a fuel gas system.
Sec. 63.1563 When do I have to comply with this subpart?
(a) If you have a new or reconstructed affected source, you must
comply with this subpart according to the requirements in paragraphs
(a)(1) and (2) of this section.
(1) If you startup your affected source before April 11, 2002, then
you must comply with the emission limitations and work practice
standards for new and reconstructed sources in this subpart no later
than April 11, 2002.
(2) If you startup your affected source after April 11, 2002, you
must comply with the emission limitations and work practice standards
for new and reconstructed sources in this subpart upon startup of your
affected source.
(b) If you have an existing affected source, you must comply with
the emission limitations and work practice standards for existing
affected sources in this subpart by no later than April 11, 2005 except
as specified in paragraph (c) of this section.
(c) We will grant an extension of compliance for an existing
catalytic cracking unit allowing additional time to meet the emission
limitations and work practice standards for catalytic cracking units in
Secs. 63.1564 and 63.1565 if you commit to hydrotreating the catalytic
cracking unit feedstock and to meeting the emission limitations of this
subpart on the same date that your facility meets the final Tier 2
gasoline sulfur control standard (40 CFR part 80, subpart J). To obtain
an extension, you must submit a written notification to your permitting
authority according to the requirements in Sec. 63.1574(e). Your
notification must include the information in paragraphs (c)(1) and (2)
of this section.
(1) Identification of the affected source with a brief description
of the controls to be installed (if needed) to comply with the emission
limitations for catalytic cracking units in this subpart.
(2) A compliance schedule, including the information in paragraphs
(c)(2)(i) through (iv) of this section.
(i) The date by which onsite construction or the process change is
to be initiated.
(ii) The date by which onsite construction or the process change is
to be completed.
(iii) The date by which your facility will achieve final compliance
with both the final Tier 2 gasoline sulfur control standard as
specified in Sec. 80.195, and the emission limitations and work
practice standards for catalytic cracking units in this subpart. In no
case will your permitting authority grant an extension beyond the date
you are required to meet the Tier 2 gasoline sulfur control standard or
December 31, 2009, whichever comes first. If you don't comply with the
emission limitations and work practice standards for existing catalytic
cracking units by the specified date, you will be out-of-compliance
with the requirements for catalytic cracking units beginning April 11,
2005.
(iv) A brief description of interim emission control measures that
will be taken to ensure proper operation and maintenance of the process
equipment during the period of the compliance extension.
(d) If you have an area source that increases its emissions or its
potential to emit such that it becomes a major source of HAP, the
requirements in paragraphs (d)(1) and (2) of this section apply.
(1) Any portion of the existing facility that is a new affected
source or a new reconstructed source must be in compliance with the
requirements of this subpart upon startup.
(2) All other parts of the source must be in compliance with the
requirements of this subpart by no later than 3 years after it becomes
a major source or, if applicable, the extended compliance date granted
according to the requirements in paragraph (c) of this section.
(e) You must meet the notification requirements in Sec. 63.1574
according to the schedule in Sec. 63.1574 and in 40 CFR part 63,
subpart A. Some of the notifications must be submitted before the date
you are required to comply with the emission limitations and work
practice standards in this subpart.
Catalytic Cracking Units, Catalytic Reforming Units, Sulfur
Recovery Units, and Bypass Lines
Sec. 63.1564 What are my requirements for metal HAP emissions from
catalytic cracking units?
(a) What emission limitations and work practice standards must I
meet? You must:
(1) Meet each emission limitation in Table 1 of this subpart that
applies to you. If your catalytic cracking unit is subject to the NSPS
for PM in Sec. 60.102 of this chapter, you must meet the emission
limitations for NSPS units. If your catalytic cracking unit isn't
subject to the NSPS for PM, you can choose from the four options in
paragraphs (a)(1)(i) through (iv) of this section:
(i) You can elect to comply with the NSPS requirements (Option 1);
(ii) You can elect to comply with the PM emission limit (Option 2);
(iii) You can elect to comply with the Nickel (Ni) lb/hr emission
limit (Option 3); or
(iv) You can elect to comply with the Ni lb/1,000 lbs of coke burn-
off emission limit (Option 4).
[[Page 17776]]
(2) Comply with each operating limit in Table 2 of this subpart
that applies to you.
(3) Prepare an operation, maintenance, and monitoring plan
according to the requirements in Sec. 63.1574(f) and operate at all
times according to the procedures in the plan.
(4) The emission limitations and operating limits for metal HAP
emissions from catalytic cracking units required in paragraphs (a)(1)
and (2) of this section do not apply during periods of planned
maintenance preapproved by the applicable permitting authority
according to the requirements in Sec. 63.1575(j).
(b) How do I demonstrate initial compliance with the emission
limitations and work practice standard? You must:
(1) Install, operate, and maintain a continuous monitoring
system(s) according to the requirements in Sec. 63.1572 and Table 3 of
this subpart.
(2) Conduct a performance test for each catalytic cracking unit not
subject to the NSPS for PM according to the requirements in
Sec. 63.1571 and under the conditions specified in Table 4 of this
subpart.
(3) Establish each site-specific operating limit in Table 2 of this
subpart that applies to you according to the procedures in Table 4 of
this subpart.
(4) Use the procedures in paragraphs (b)(4)(i) through (iv) of this
section to determine initial compliance with the emission limitations.
(i) If you elect Option 1 in paragraph (a)(1)(i) of ths section,
the NSPS requirements, compute the PM emission rate (lb/1,000 lbs of
coke burn-off) for each run using Equations 1, 2, and 3 (if applicable)
of this section as follows:
[GRAPHIC] [TIFF OMITTED] TR11AP02.000
Where:
Rc = Coke burn-off rate, kg/hr (lb/hr);
Qr = Volumetric flow rate of exhaust gas from catalyst
regenerator before adding air or gas streams. Example: You may measure
after an electrostatic precipitator, but you must measure before a
carbon monoxide boiler, dscm/min (dscf/min);
Qa = Volumetric flow rate of air to catalytic cracking unit
catalyst regenerator, as determined from instruments in the catalytic
cracking unit control room, dscm/min (dscf/min);
%CO2 = Carbon dioxide concentration in regenerator exhaust,
percent by volume (dry basis);
%CO = Carbon monoxide concentration in regenerator exhaust, percent by
volume (dry basis);
%O2 = Oxygen concentration in regenerator exhaust, percent
by volume (dry basis);
K1 = Material balance and conversion factor, 0.2982 (kg-
min)/(hr-dscm-%) (0.0186 (lb-min)/(hr-dscf-%));
K2 = Material balance and conversion factor, 2.088 (kg-min)/
(hr-dscm) (0.1303 (lb-min)/(hr-dscf));
K3 = Material balance and conversion factor, 0.0994 (kg-
min)/(hr-dscm-%) (0.0062 (lb-min)/(hr-dscf-%));
Qoxy = Volumetric flow rate of oxygen-enriched air stream to
regenerator, as determined from instruments in the catalytic cracking
unit control room, dscm/min (dscf/min); and
%Oxy = Oxygen concentration in oxygen-enriched air stream,
percent by volume (dry basis).
[GRAPHIC] [TIFF OMITTED] TR11AP02.001
Where:
E = Emission rate of PM, kg/1,000 kg (lb/1,000 lb) of coke burn-off;
Cs = Concentration of PM, g/dscm (lb/dscf);
Qsd = Volumetric flow rate of the catalytic cracking unit
catalyst regenerator flue gas as measured by Method 2 in appendix A to
part 60 of this chapter, dscm/hr (dscf/hr);
Rc = Coke burn-off rate, kg coke/hr (1,000 lb coke/hr); and
K = Conversion factor, 1.0 (kg\2\/g)/(1,000 kg) (1,000 lb/(1,000 lb)).
[GRAPHIC] [TIFF OMITTED] TR11AP02.002
Where:
Es = Emission rate of PM allowed, kg/1,000 kg (1b/1,000 lb)
of coke burn-off in catalyst regenerator;
1.0 = Emission limitation, kg coke/1,000 kg (lb coke/1,000 lb);
A = Allowable incremental rate of PM emissions, 0.18 g/million cal
(0.10 lb/million Btu); and
H = Heat input rate from solid or liquid fossil fuel, million cal/hr
(million Btu/hr). Make sure your permitting authority approves
procedures for determining the heat input rate.
Rc = Coke burn-off rate, kg coke/hr (1,000 lb coke/hr)
determined using Equation 1 of this section; and
K' = Conversion factor to units to standard, 1.0 (kg\2\/g)/(1,000 kg)
(10\3\ lb/(1,000 lb)).
(ii) If you elect Option 2 in paragraph (a)(1)(ii) of this section,
the PM emission limit, compute your PM emission rate (lb/1,000 lbs of
coke burn-off) using Equations 1 and 2 of this section and your site-
specific opacity operating limit (if you use a continuous opacity
monitoring system) using Equation 4 of this section as follows:
[GRAPHIC] [TIFF OMITTED] TR11AP02.003
Where:
Opacity limit = Maximum permissible hourly average opacity, percent, or
10 percent, whichever is greater;
Opacityst = Hourly average opacity measured during the
source test runs, percent; and
PMEmRst = PM emission rate measured during the source test,
lb/1,000 lbs coke burn.
[GRAPHIC] [TIFF OMITTED] TR11AP02.004
(iii) If you elect Option 3 in paragraph (a)(1)(iii) of this
section, the Ni lb/hr emission limit, compute your Ni emission rate
using Equation 5 of this section and your site-specific Ni operating
limit (if you use a continuous opacity monitoring system) using
Equations 6 and 7 of this section as follows:
Where:
ENi1 = Mass emission rate of Ni, mg/hr (lb/hr); and
[[Page 17777]]
CNi = Ni concentration in the catalytic cracking unit
catalyst regenerator flue gas as measured by Method 29 in appendix A to
part 60 of this chapter, mg/dscm (lbs/dscf).
[GRAPHIC] [TIFF OMITTED] TR11AP02.005
Where:
Opacityl = Opacity value for use in Equation 7 of this
section, percent, or 10 percent, whichever is greater; and
NiEmR1st = Average Ni emission rate calculated as the
arithmetic average Ni emission rate using Equation 5 of this section
for each of the performance test runs, g Ni/hr.
[GRAPHIC] [TIFF OMITTED] TR11AP02.006
Where:
Ni operating limit1 = Maximum permissible hourly average Ni
operating limit, percent-acfm-ppmw, i.e., your site-specific Ni
operating limit;
Qmon,st = Hourly average actual gas flow rate as measured by
the continuous parameter monitoring system during the performance test
or using the alternative procedure in Sec. 63.1573, acfm; and
E-Catst = Ni concentration on equilibrium catalyst measured
during source test, ppmw.
(iv) If you elect Option 4 in paragraph (a)(1)(iv) of this section,
the Ni lbs/1,000 lbs of coke burn-off emission limit, compute your Ni
emission rate using Equations 1 and 8 of this section and your site-
specific Ni operating limit (if you use a continuous opacity monitoring
system) using Equations 9 and 10 of this section as follows:
[GRAPHIC] [TIFF OMITTED] TR11AP02.007
Where:
ENi2 = Normalized mass emission rate of Ni, mg/kg coke (lb/
1,000 lbs coke).
[GRAPHIC] [TIFF OMITTED] TR11AP02.008
Where:
Opacity2 = Opacity value for use in Equation 10 of this
section, percent, or 10 percent, whichever is greater; and
NiEmR2st = Average Ni emission rate calculated as the
arithmetic average Ni emission rate using Equation 8 of this section
for each of the performance test runs, mg/kg coke.
[GRAPHIC] [TIFF OMITTED] TR11AP02.009
Where:
Ni operating limit2 = Maximum permissible hourly average Ni
operating limit, percent-ppmw-acfm-hr/kg coke, i.e., your site-specific
Ni operating limit; and
Rc,st = Coke burn rate from Equation 1 of this section, as
measured during the initial performance test, kg coke/hr.
(5) Demonstrate initial compliance with each emission limitation
that applies to you according to Table 5 of this subpart.
(6) Demonstrate initial compliance with the work practice standard
in paragraph (a)(3) of this section by submitting your operation,
maintenance, and monitoring plan to your permitting authority as part
of your Notification of Compliance Status.
(7) Submit the Notification of Compliance Status containing the
results of the initial compliance demonstration according to the
requirements in Sec. 63.1574.
(c) How do I demonstrate continuous compliance with the emission
limitations and work practice standards? You must:
(1) Demonstrate continuous compliance with each emission limitation
in Tables 1 and 2 of this subpart that applies to you according to the
methods specified in Tables 6 and 7 of this subpart.
(2) Demonstrate continuous compliance with the work practice
standard in paragraph (a)(3) of this section by maintaining records to
document conformance with the procedures in your operation,
maintenance, and monitoring plan.
(3) If you use a continuous opacity monitoring system and elect to
comply with Option 3 in paragraph (a)(1)(iii) of this section,
determine continuous compliance with your site-specific Ni operating
limit by using Equation 11 of this section as follows:
[GRAPHIC] [TIFF OMITTED] TR11AP02.010
[[Page 17778]]
Where:
Ni operating value1 = Maximum permissible hourly average Ni
standard operating value, %-acfm-ppmw;
Opacity = Hourly average opacity, percent;
Qmon = Hourly average actual gas flow rate as measured by
continuous parameter monitoring system or calculated by alternative
procedure in Sec. 63.1573, acfm; and
E-Cat = Ni concentration on equilibrium catalyst from weekly or more
recent measurement, ppmw.
(4) If you use a continuous opacity monitoring system and elect to
comply with Option 4 in paragraph (a)(1)(iv) of this section, determine
continuous compliance with your site-specific Ni operating limit by
using Equation 12 of this section as follows:
[GRAPHIC] [TIFF OMITTED] TR11AP02.011
Where:
Ni operating value2 = Maximum permissible hourly average Ni
standard operating value, percent-acfm-ppmw-hr/kg coke.
Sec. 63.1565 What are my requirements for organic HAP emissions from
catalytic cracking units?
(a) What emission limitations and work practice standards must I
meet? You must:
(1) Meet each emission limitation in Table 8 of this subpart that
applies to you. If your catalytic cracking unit is subject to the NSPS
for carbon monoxide (CO) in Sec. 60.103 of this chapter, you must meet
the emission limitations for NSPS units. If your catalytic cracking
unit isn't subject to the NSPS for CO, you can choose from the two
options in paragraphs (a)(1)(i) through (ii) of this section:
(i) You can elect to comply with the NSPS requirements (Option 1);
or
(ii) You can elect to comply with the CO emission limit (Option 2).
(2) Comply with each site-specific operating limit in Table 9 of
this subpart that applies to you.
(3) Prepare an operation, maintenance, and monitoring plan
according to the requirements in Sec. 63.1574(f) and operate at all
times according to the procedures in the plan.
(4) The emission limitations and operating limits for organic HAP
emissions from catalytic cracking units required in paragraphs (a)(1)
and (2) of this section do not apply during periods of planned
maintenance preapproved by the applicable permitting authority
according to the requirements in Sec. 63.1575(j).
(b) How do I demonstrate initial compliance with the emission
limitations and work practice standards? You must:
(1) Install, operate, and maintain a continuous monitoring system
according to the requirements in Sec. 63.1572 and Table 10 of this
subpart. Except:
(i) Whether or not your catalytic cracking unit is subject to the
NSPS for CO in Sec. 60.103 of this chapter, you don't have to install
and operate a continuous emission monitoring system if you show that CO
emissions from your vent average less than 50 parts per million (ppm),
dry basis. You must get an exemption from your permitting authority,
based on your written request. To show that the emissions average is
less than 50 ppm (dry basis), you must continuously monitor CO
emissions for 30 days using a CO continuous emission monitoring system
that meets the requirements in Sec. 63.1572.
(ii) If your catalytic cracking unit isn't subject to the NSPS for
CO, you don't have to install and operate a continuous emission
monitoring system or a continuous parameter monitoring system if you
vent emissions to a boiler (including a ``CO boiler'') or process
heater that has a design heat input capacity of at least 44 megawatts
(MW).
(iii) If your catalytic cracking unit isn't subject to the NSPS for
CO, you don't have to install and operate a continuous emission
monitoring system or a continuous parameter monitoring system if you
vent emissions to a boiler or process heater in which all vent streams
are introduced into the flame zone.
(2) Conduct each performance test for a catalytic cracking unit not
subject to the NSPS for CO according to the requirements in
Sec. 63.1571 and under the conditions specified in Table 11 of this
subpart.
(3) Establish each site-specific operating limit in Table 9 of this
subpart that applies to you according to the procedures in Table 11 of
this subpart.
(4) Demonstrate initial compliance with each emission limitation
that applies to you according to Table 12 of this subpart.
(5) Demonstrate initial compliance with the work practice standard
in paragraph (a)(3) of this section by submitting the operation,
maintenance, and monitoring plan to your permitting authority as part
of your Notification of Compliance Status according to Sec. 63.1574.
(6) Submit the Notification of Compliance Status containing the
results of the initial compliance demonstration according to the
requirements in Sec. 63.1574.
(c) How do I demonstrate continuous compliance with the emission
limitations and work practice standards? You must:
(1) Demonstrate continuous compliance with each emission limitation
in Tables 8 and 9 of this subpart that applies to you according to the
methods specified in Tables 13 and 14 of this subpart.
(2) Demonstrate continuous compliance with the work practice
standard in paragraph (a)(3) of this section by complying with the
procedures in your operation, maintenance, and monitoring plan.
Sec. 63.1566 What are my requirements for organic HAP emissions from
catalytic reforming units?
(a) What emission limitations and work practice standards must I
meet? You must:
(1) Meet each emission limitation in Table 15 of this subpart that
applies to you. You can choose from the two options in paragraphs
(a)(1)(i) through (ii) of this section:
(i) You can elect to vent emissions of total organic compounds
(TOC) to a flare that meets the control device requirements in
Sec. 63.11(b) (Option 1); or
(ii) You can elect to use a control device to meet a TOC percent
reduction standard or concentration limit, whichever is less stringent
(Option 2).
(2) Comply with each site-specific operating limit in Table 16 of
this subpart that applies to you.
(3) The emission limitations in Tables 15 and 16 of this subpart
apply to emissions from catalytic reforming unit process vents that
occur during depressuring and purging operations. These process vents
include those used during unit depressurization, purging, coke burn,
catalyst rejuvenation, and reduction or activation purge.
[[Page 17779]]
(4) The emission limitations in Tables 15 and 16 of this subpart do
not apply to emissions from process vents during depressuring and
purging operations when the reactor vent pressure is 5 pounds per
square inch gauge (psig) or less.
(5) Prepare an operation, maintenance, and monitoring plan
according to the requirements in Sec. 63.1574(f) and operate at all
times according to the procedures in the plan.
(b) How do I demonstrate initial compliance with the emission
limitations and work practice standard? You must:
(1) Install, operate, and maintain a continuous monitoring
system(s) according to the requirements in Sec. 63.1572 and Table 17 of
this subpart.
(2) Conduct each performance test for a catalytic reforming unit
according to the requirements in Sec. 63.1571 and under the conditions
specified in Table 18 of this subpart.
(3) Establish each site-specific operating limit in Table 16 of
this subpart that applies to you according to the procedures in Table
18 of this subpart.
(4) Use the procedures in paragraph (b)(4)(i) or (ii) of this
section to determine initial compliance with the emission limitations.
(i) If you elect the percent reduction standard under Option 2,
calculate the emission rate of TOC using Equation 1 of this section (if
you use Method 25) or Equation 2 of this section (if you use Method
25A); then calculate the mass emission reduction using Equation 3 of
this section as follows:
[GRAPHIC] [TIFF OMITTED] TR11AP02.012
Where:
E = Emission rate of TOC in the vent stream, kilograms-C per hour;
K 4 = Constant, 6.0 x 10-5 (kilograms per
milligram)(minutes per hour);
M c = Mass concentration of total gaseous nonmethane organic
as measured and calculated using Method 25 in appendix A to part 60 of
this chapter, mg/dscm; and
Q s = Vent stream flow rate, dscm/min, at a temperature of
20 degrees Celsius (C).
[GRAPHIC] [TIFF OMITTED] TR11AP02.013
Where:
E = Emission rate of TOC in the vent stream, kilograms-C per hour;
K 5 = Constant, 9.0 x 10 -5(parts per million)
-1 (gram-mole per standard cubic meter) (gram-C per gram-
mole-propane) (kilogram per gram) (minutes per hour), where the
standard temperature (standard cubic meter) is at 20 degrees C (uses
36g-C/g.mole propane);
C TOC = Concentration of TOC on a dry basis in ppmv as
propane as measured by Method 25A in appendix A to part 60 of this
chapter; and
Q s = Vent stream flow rate, dry standard cubic meters per
minute, at a temperature of 20 degrees C.
[GRAPHIC] [TIFF OMITTED] TR11AP02.014
Where:
E i = Mass emission rate of TOC at control device inlet, kg/
hr; and
E o = Mass emission rate of TOC at control device outlet,
kg/hr.
(5) If you elect the 20 parts per million by volume (ppmv)
concentration limit, correct the measured TOC concentration for oxygen
(O2) content in the gas stream using Equation 4 of this
section as follows:
[GRAPHIC] [TIFF OMITTED] TR11AP02.015
(6) You are not required to do a TOC performance test if:
(i) You elect to vent emissions to a flare as provided in paragraph
(a)(1)(i) of this section (Option 1); or
(ii) You elect the TOC percent reduction or concentration limit in
paragraph (a)(1)(ii) of this section (Option 2), and you use a boiler
or process heater with a design heat input capacity of 44 MW or greater
or a boiler or process heater in which all vent streams are introduced
into the flame zone.
(7) Demonstrate initial compliance with each emission limitation
that applies to you according to Table 19 of this subpart.
(8) Demonstrate initial compliance with the work practice standard
in paragraph (a)(5) of this section by submitting the operation,
maintenance, and monitoring plan to your permitting authority as part
of your Notification of Compliance Status.
(9) Submit the Notification of Compliance Status containing the
results of the initial compliance demonstration according to the
requirements in Sec. 63.1574.
(c) How do I demonstrate continuous compliance with the emission
limitations and work practice standards? You must:
(1) Demonstrate continuous compliance with each emission limitation
in Tables 15 and 16 of this subpart that applies to you according to
the methods specified in Tables 20 and 21 of this subpart.
(2) Demonstrate continuous compliance with the work practice
standards in paragraph (a)(3) of this section by complying with the
procedures in your operation, maintenance, and monitoring plan.
Sec. 63.1567 What are my requirements for inorganic HAP emissions from
catalytic reforming units?
(a) What emission limitations and work practice standards must I
meet? You must:
(1) Meet each emission limitation in Table 22 of this subpart that
applies to you. These emission limitations apply during coke burn-off
and catalyst rejuvenation. You can choose from the two options in
paragraphs (a)(1)(i) through (ii) of this section:
(i) You can elect to use a control device to meet either a percent
reduction standard for hydrogen chloride (HCl) emissions (Option 1); or
(ii) You can elect to meet an HCl concentration limit (Option 2).
(2) Meet each site-specific operating limit in Table 23 of this
subpart that applies to you. These operating limits apply during coke
burn-off and catalyst rejuvenation.
[[Page 17780]]
(3) Prepare an operation, maintenance, and monitoring plan
according to the requirements in Sec. 63.1574(f) and operate at all
times according to the procedures in the plan.
(b) How do I demonstrate initial compliance with the emission
limitations and work practice standard? You must:
(1) Install, operate, and maintain a continuous monitoring
system(s) according to the requirements in Sec. 63.1572 and Table 24 of
this subpart.
(2) Conduct each performance test for a catalytic reforming unit
according to the requirements in Sec. 63.1571 and the conditions
specified in Table 25 of this subpart.
(3) Establish each site-specific operating limit in Table 23 of
this subpart that applies to you according to the procedures in Table
25 of this subpart.
(4) Demonstrate initial compliance with each emission limitation
that applies to you according to Table 26 of this subpart.
(5) Demonstrate initial compliance with the work practice standard
in paragraph (a)(3) of this section by submitting the operation,
maintenance, and monitoring plan to your permitting authority as part
of your Notification of Compliance Status.
(6) Submit the Notification of Compliance Status containing the
results of the initial compliance demonstration according to the
requirements in Sec. 63.1574.
(c) How do I demonstrate continuous compliance with the emission
limitations and work practice standard? You must:
(1) Demonstrate continuous compliance with each emission limitation
in Tables 22 and 23 of this subpart that applies to you according to
the methods specified in Tables 27 and 28 of this subpart.
(2) Demonstrate continuous compliance with the work practice
standard in paragraph (a)(3) of this section by maintaining records to
document conformance with the procedures in your operation, maintenance
and monitoring plan.
Sec. 63.1568 What are my requirements for HAP emissions from sulfur
recovery units?
(a) What emission limitations and work practice standard must I
meet? You must:
(1) Meet each emission limitation in Table 29 of this subpart that
applies to you. If your sulfur recovery unit is subject to the NSPS for
sulfur oxides in Sec. 60.104 of this chapter, you must meet the
emission limitations for NSPS units. If your sulfur recovery unit isn't
subject to the NSPS for sulfur oxides, you can choose from the options
in paragraphs (a)(1)(i) through (ii) of this section:
(i) You can elect to meet the NSPS requirements (Option 1); or
(ii) You can elect to meet the total reduced sulfur (TRS) emission
limitation (Option 2).
(2) Meet each operating limit in Table 30 of this subpart that
applies to you.
(3) Prepare an operation, maintenance, and monitoring plan
according to the requirements in Sec. 63.1574(f) and operate at all
times according to the procedures in the plan.
(b) How do I demonstrate initial compliance with the emission
limitations and work practice standards? You must:
(1) Install, operate, and maintain a continuous monitoring system
according to the requirements in Sec. 63.1572 and Table 31 of this
subpart.
(2) Conduct each performance test for a sulfur recovery unit not
subject to the NSPS for sulfur oxides according to the requirements in
Sec. 63.1571 and under the conditions specified in Table 32 of this
subpart.
(3) Establish each site-specific operating limit in Table 30 of
this subpart that applies to you according to the procedures in Table
32 of this subpart.
(4) Correct the reduced sulfur samples to zero percent excess air
using Equation 1 of this section as follows:
[GRAPHIC] [TIFF OMITTED] TR11AP02.016
Where:
Cadj = pollutant concentration adjusted to zero percent
oxygen, ppm or g/dscm;
Cmeas = pollutant concentration measured on a dry basis, ppm
or g/dscm;
20.9c = 20.9 percent oxygen--0.0 percent oxygen (defined
oxygen correction basis), percent;
20.9 = oxygen concentration in air, percent;
%O2 = oxygen concentration measured on a dry basis, percent.
(5) Demonstrate initial compliance with each emission limitation
that applies to you according to Table 33 of this subpart.
(6) Demonstrate initial compliance with the work practice standard
in paragraph (a)(3) of this section by submitting the operation,
maintenance, and monitoring plan to your permitting authority as part
of your notification of compliance status.
(7) Submit the notification of compliance status containing the
results of the initial compliance demonstration according to the
requirements in Sec. 63.1574.
(c) How do I demonstrate continuous compliance with the emission
limitations and work practice standards? You must:
(1) Demonstrate continuous compliance with each emission limitation
in Tables 29 and 30 of this subpart that applies to you according to
the methods specified in Tables 34 and 35 of this subpart.
(2) Demonstrate continuous compliance with the work practice
standard in paragraph (a)(3) of this section by complying with the
procedures in your operation, maintenance, and monitoring plan.
Sec. 63.1569 What are my requirements for HAP emissions from bypass
lines?
(a) What work practice standards must I meet? (1) You must meet
each work practice standard in Table 36 of this subpart that applies to
you. You can choose from the four options in paragraphs (a)(1)(i)
through (iv) of this section:
(i) You can elect to install an automated system (Option 1);
(ii) You can elect to use a manual lock system (Option 2);
(iii) You can elect to seal the line (Option 3); or
(iv) You can elect to vent to a control device (Option 4).
(2) As provided in Sec. 63.6(g), we, the EPA, may choose to grant
you permission to use an alternative to the work practice standard in
paragraph (a)(1) of this section.
(3) You must prepare an operation, maintenance, and monitoring plan
according to the requirements in Sec. 63.1574(f) and operate at all
times according to the procedures in the plan.
(b) How do I demonstrate initial compliance with the work practice
standards? You must:
(1) If you elect the option in paragraph (a)(1)(i) of this section,
conduct each performance test for a bypass line according to the
requirements in Sec. 63.1571 and under the conditions specified in
Table 37 of this subpart.
[[Page 17781]]
(2) Demonstrate initial compliance with each work practice standard
in Table 36 of this subpart that applies to you according to Table 38
of this subpart.
(3) Demonstrate initial compliance with the work practice standard
in paragraph (a)(3) of this section by submitting the operation,
maintenance, and monitoring plan to your permitting authority as part
of your notification of compliance status.
(4) Submit the notification of compliance status containing the
results of the initial compliance demonstration according to the
requirements in Sec. 63.1574.
(c) How do I demonstrate continuous compliance with the work
practice standards? You must:
(1) Demonstrate continuous compliance with each work practice
standard in Table 36 of this subpart that applies to you according to
the requirements in Table 39 of this subpart.
(2) Demonstrate continuous compliance with the work practice
standard in paragraph (a)(2) of this section by complying with the
procedures in your operation, maintenance, and monitoring plan.
General Compliance Requirements
Sec. 63.1570 What are my general requirements for complying with this
subpart?
(a) You must be in compliance with all of the non-opacity standards
in this subpart during the times specified in Sec. 63.6(f)(1).
(b) You must be in compliance with the opacity and visible emission
limits in this subpart during the times specified in Sec. 63.6(h)(1).
(c) You must always operate and maintain your affected source,
including air pollution control and monitoring equipment, according to
the provisions in Sec. 63.6(e)(1)(i). During the period between the
compliance date specified for your affected source and the date upon
which continuous monitoring systems have been installed and validated
and any applicable operating limits have been set, you must maintain a
log detailing the operation and maintenance of the process and
emissions control equipment.
(d) You must develop and implement a written startup, shutdown, and
malfunction plan (SSMP) according to the provisions in Sec. 63.6(e)(3).
(e) During periods of startup, shutdown, and malfunction, you must
operate in accordance with your SSMP.
(f) You must report each instance in which you did not meet each
emission limitation and each operating limit in this subpart that
applies to you. This includes periods of startup, shutdown, and
malfunction. You also must report each instance in which you did not
meet the work practice standards in this subpart that apply to you.
These instances are deviations from the emission limitations and work
practice standards in this subpart. These deviations must be reported
according to the requirements in Sec. 63.1575.
(g) Consistent with Secs. 63.6(e) and 63.7(e)(1), deviations that
occur during a period of startup, shutdown, or malfunction are not
violations if you demonstrate to the Administrator's satisfaction that
you were operating in accordance with the SSMP. The SSMP must require
that good air pollution control practices are used during those
periods. The plan must also include elements designed to minimize the
frequency of such periods (i.e., root cause analysis). The
Administrator will determine whether deviations that occur during a
period of startup, shutdown, or malfunction are violations, according
to the provisions in Sec. 63.6(e) and the contents of the SSMP.
Sec. 63.1571 How and when do I conduct a performance test or other
initial compliance demonstration?
(a) When must I conduct a performance test? You must conduct
performance tests and report the results by no later than 150 days
after the compliance date specified for your source in Sec. 63.1563 and
according to the provisions in Sec. 63.7(a)(2). If you are required to
do a performance evaluation or test for a semi-regenerative catalytic
reforming unit catalyst regenerator vent, you may do them at the first
regeneration cycle after your compliance date and report the results in
a followup Notification of Compliance Status report due no later than
150 days after the test.
(1) For each emission limitation or work practice standard where
initial compliance is not demonstrated using a performance test,
opacity observation, or visible emission observation, you must conduct
the initial compliance demonstration within 30 calendar days after the
compliance date that is specified for your source in Sec. 63.1563.
(2) For each emission limitation where the averaging period is 30
days, the 30-day period for demonstrating initial compliance begins at
12:00 a.m. on the compliance date that is specified for your source in
Sec. 63.1563 and ends at 11:59 p.m., 30 calendar days after the
compliance date that is specified for your source in Sec. 63.1563.
(3) If you commenced construction or reconstruction between
September 11, 1998 and April 11, 2002, you must demonstrate initial
compliance with either the proposed emission limitation or the
promulgated emission limitation no later than October 8, 2002 or within
180 calendar days after startup of the source, whichever is later,
according to Sec. 63.7(a)(2)(ix).
(4) If you commenced construction or reconstruction between
September 11, 1998 and April 11, 2002, and you chose to comply with the
proposed emission limitation when demonstrating initial compliance, you
must conduct a second compliance demonstration for the promulgated
emission limitation by October 10, 2005, or after startup of the
source, whichever is later, according to Sec. 63.7(a)(2)(ix).
(b) What are the general requirements for performance test and
performance evaluations? You must:
(1) Conduct each performance test according to the requirements in
Sec. 63.7(e)(1).
(2) Except for opacity and visible emission observations, conduct
three separate test runs for each performance test as specified in
Sec. 63.7(e)(3). Each test run must last at least 1 hour.
(3) Conduct each performance evaluation according to the
requirements in Sec. 63.8(e).
(4) Not conduct performance tests during periods of startup,
shutdown, or malfunction, as specified in Sec. 63.7(e)(1).
(5) Calculate the average emission rate for the performance test by
calculating the emission rate for each individual test run in the units
of the applicable emission limitation using Equation 2, 5, or 8 of
Sec. 63.1564, and determining the arithmetic average of the calculated
emission rates.
(c) What procedures must I use for an engineering assessment? You
may choose to use an engineering assessment to calculate the process
vent flow rate, net heating value, TOC emission rate, and total organic
HAP emission rate expected to yield the highest daily emission rate
when determining the emission reduction or outlet concentration for the
organic HAP standard for catalytic reforming units. If you use an
engineering assessment, you must document all data, assumptions, and
procedures to the satisfaction of the applicable permitting authority.
An engineering assessment may include the approaches listed in
paragraphs (c)(1) through (c)(4) of this section. Other engineering
assessments may be used but are subject to review and approval by the
applicable permitting authority.
(1) You may use previous test results provided the tests are
representative of current operating practices at the process unit, and
provided EPA
[[Page 17782]]
methods or approved alternatives were used;
(2) You may use bench-scale or pilot-scale test data representative
of the process under representative operating conditions;
(3) You may use maximum flow rate, TOC emission rate, organic HAP
emission rate, or organic HAP or TOC concentration specified or implied
within a permit limit applicable to the process vent; or
(4) You may use design analysis based on engineering principles,
measurable process parameters, or physical or chemical laws or
properties. Examples of analytical methods include, but are not limited
to:
(i) Use of material balances based on process stoichiometry to
estimate maximum TOC concentrations;
(ii) Calculation of hourly average maximum flow rate based on
physical equipment design such as pump or blower capacities; and
(iii) Calculation of TOC concentrations based on saturation
conditions.
(d) Can I adjust the process or control device measured values when
establishing an operating limit? If you do a performance test to
demonstrate compliance, you must base the process or control device
operating limits for continuous parameter monitoring systems on the
results measured during the performance test. You may adjust the values
measured during the performance test according to the criteria in
paragraphs (d)(1) through (3) of this section.
(1) If you must meet the HAP metal emission limitations in
Sec. 63.1564, you elect the option in paragraph (a)(1)(iii) in
Sec. 63.1564 (Ni lb/hr), and you use continuous parameter monitoring
systems, you must establish an operating limit for the equilibrium
catalyst Ni concentration based on the laboratory analysis of the
equilibrium catalyst Ni concentration from the initial performance
test. Section 63.1564(b)(2) allows you to adjust the laboratory
measurements of the equilibrium catalyst Ni concentration to the
maximum level. You must make this adjustment using Equation 1 of this
section as follows:
[GRAPHIC] [TIFF OMITTED] TR11AP02.017
Where:
Ecat-Limit = Operating limit for equilibrium catalyst Ni concentration,
mg/kg;
NiEmR1st = Average Ni emission rate calculated as the
arithmetic average Ni emission rate using Equation 5 of this section
for each performance test run, g Ni/hr; and
Ecatst = Average equilibrium Ni concentration from
laboratory test results, mg/kg.
(2) If you must meet the HAP metal emission limitations in
Sec. 63.1564, you elect the option in paragraph (a)(1)(iv) in
Sec. 63.1564 (Ni lb/1,000 lb of coke burn-off), and you use continuous
parameter monitoring systems, you must establish an operating limit for
the equilibrium catalyst Ni concentration based on the laboratory
analysis of the equilibrium catalyst Ni concentration from the initial
performance test. Section 63.1564(b)(2) allows you to adjust the
laboratory measurements of the equilibrium catalyst Ni concentration to
the maximum level. You must make this adjustment using Equation 2 of
this section as follows:
[GRAPHIC] [TIFF OMITTED] TR11AP02.018
Where:
NiEmR2st = Average Ni emission rate calculated as the
arithmetic average Ni emission rate using Equation 8 of Sec. 63.1564
for each performance test run, mg/kg coke burn-off.
(3) If you choose to adjust the equilibrium catalyst Ni
concentration to the maximum level, you can't adjust any other
monitored operating parameter (i.e., gas flow rate, voltage, pressure
drop, liquid-to-gas ratio).
(4) Except as specified in paragraph (d)(3) of this section, if you
use continuous parameter monitoring systems, you may adjust one of your
monitored operating parameters (flow rate, voltage and secondary
current, pressure drop, liquid-to-gas ratio) from the average of
measured values during the performance test to the maximum value (or
minimum value, if applicable) representative of worst-case operating
conditions, if necessary. This adjustment of measured values may be
done using control device design specifications, manufacturer
recommendations, or other applicable information. You must provide
supporting documentation and rationale in your Notification of
Compliance Status, demonstrating to the satisfaction of your permitting
authority, that your affected source complies with the applicable
emission limit at the operating limit based on adjusted values.
(e) Can I change my operating limit? You may change the established
operating limit by meeting the requirements in paragraphs (e)(1)
through (3) of this section.
(1) You may change your established operating limit for a
continuous parameter monitoring system by doing an additional
performance test, a performance test in conjunction with an engineering
assessment, or an engineering assessment to verify that, at the new
operating limit, you are in compliance with the applicable emission
limitation.
(2) You must establish a revised operating limit for your
continuous parameter monitoring system if you make any change in
process or operating conditions that could affect control system
performance or you change designated conditions after the last
performance or compliance tests were done. You can establish the
revised operating limit as described in paragraph (e)(1) of this
section.
(3) You may change your site-specific opacity operating limit or Ni
operating limit only by doing a new performance test.
Sec. 63.1572 What are my monitoring installation, operation, and
maintenance requirements?
(a) You must install, operate, and maintain each continuous
emission monitoring system according to the requirements in paragraphs
(a)(1) through (4) of this section.
[[Page 17783]]
(1) You must install, operate, and maintain each continuous
emission monitoring system according to the requirements in Table 40 of
this subpart.
(2) If you use a continuous emission monitoring system to meet the
NSPS CO or SO2 limit, you must conduct a performance
evaluation of each continuous emission monitoring system according to
the requirements in Sec. 63.8 and Table 40 of this subpart. This
requirement does not apply to an affected source subject to the NSPS
that has already demonstrated initial compliance with the applicable
performance specification.
(3) As specified in Sec. 63.8(c)(4)(ii), each continuous emission
monitoring system must complete a minimum of one cycle of operation
(sampling, analyzing, and data recording) for each successive 15-minute
period.
(4) Data must be reduced as specified in Sec. 63.8(g)(2).
(b) You must install, operate, and maintain each continuous opacity
monitoring system according to the requirements in paragraphs (b)(1)
through (3) of this section.
(1) Each continuous opacity monitoring system must be installed,
operated, and maintained according to the requirements in Table 40 of
this subpart.
(2) If you use a continuous opacity monitoring system to meet the
NSPS opacity limit, you must conduct a performance evaluation of each
continuous opacity monitoring system according to the requirements in
Sec. 63.8 and Table 40 of this subpart. This requirement does not apply
to an affected source subject to the NSPS that has already demonstrated
initial compliance with the applicable performance specification.
(3) As specified in Sec. 63.8(c)(4)(i), each continuous opacity
monitoring system must complete a minimum of one cycle of sampling and
analyzing for each successive 10-second period and one cycle of data
recording for each successive 6-minute period.
(c) You must install, operate, and maintain each continuous
parameter monitoring system according to the requirements in paragraphs
(c)(1) through (7) of this section.
(1) Each continuous parameter monitoring system must be installed,
operated, and maintained according to the requirements in Table 41 of
this subpart and in a manner consistent with the manufacturer's
specifications or other written procedures that provide adequate
assurance that the equipment will monitor accurately.
(2) The continuous parameter monitoring system must complete a
minimum of one cycle of operation for each successive 15-minute period.
You must have a minimum of four successive cycles of operation to have
a valid hour of data (or at least two if a calibration check is
performed during that hour or if the continuous parameter monitoring
system is out-of-control).
(3) Each continuous parameter monitoring system must have valid
hourly average data from at least 75 percent of the hours during which
the process operated.
(4) Each continuous parameter monitoring system must determine and
record the hourly average of all recorded readings and if applicable,
the daily average of all recorded readings for each operating day. The
daily average must cover a 24-hour period if operation is continuous or
the number of hours of operation per day if operation is not
continuous.
(5) Each continuous parameter monitoring system must record the
results of each inspection, calibration, and validation check.
(d) You must monitor and collect data according to the requirements
in paragraphs (d)(1) and (2) of this section.
(1) Except for monitoring malfunctions, associated repairs, and
required quality assurance or control activities (including as
applicable, calibration checks and required zero and span adjustments),
you must conduct all monitoring in continuous operation (or collect
data at all required intervals) at all times the affected source is
operating.
(2) You may not use data recorded during monitoring malfunctions,
associated repairs, and required quality assurance or control
activities for purposes of this regulation, including data averages and
calculations, for fulfilling a minimum data availability requirement,
if applicable. You must use all the data collected during all other
periods in assessing the operation of the control device and associated
control system.
Sec. 63.1573 What are my monitoring alternatives?
(a) What is the approved alternative for monitoring gas flow rate?
You can elect to use this alternative to a continuous parameter
monitoring system for the catalytic regenerator exhaust gas flow rate
for your catalytic cracking unit if the unit does not introduce any
other gas streams into the catalyst regeneration vent (i.e., complete
combustion units with no additional combustion devices). If you select
this alternative, you must use the same procedure for the performance
test and for monitoring after the performance test.
(1) Install and operate a continuous parameter monitoring system to
measure and record the hourly average volumetric air flow rate to the
catalytic cracking unit regenerator. Or, you can determine and record
the hourly average volumetric air flow rate to the catalytic cracking
unit regenerator using the catalytic cracking unit control room
instrumentation.
(2) Install and operate a continuous parameter monitoring system to
measure and record the temperature of the gases entering the control
device (or exiting the catalyst regenerator if you do not use an add-on
control device).
(3) Calculate and record the hourly average actual exhaust gas flow
rate using Equation 1 of this section as follows:
[GRAPHIC] [TIFF OMITTED] TR11AP02.019
Where:
Qgas = Hourly average actual gas flow rate, acfm;
1.12 = Default correction factor to convert gas flow from dry standard
cubic feet per minute (dscfm) to standard cubic feet per minute (scfm);
Qair = Volumetric flow rate of air to regenerator, as
determined from the catalytic cracking unit control room
instrumentations, dscfm;
Qoxy = Volumetric flow rate of oxygen-enriched air stream to
regenerator, as determined from the catalytic cracking unit control
room instrumentations, dscfm;
Tempgas = Temperature of gas stream in vent measured as near
as practical to the control device or opacity monitor, deg.K. For wet
scrubbers, temperature of gas prior to the wet scrubber; and
[[Page 17784]]
Pvent = Absolute pressure in the vent measured as near as
practical to the control device or opacity monitor, atm. When used in
conjunction with opacity in the final vent stack, you can assume
Pvent = 1 atm.
(b) What is the approved alternative for monitoring pH levels? If
you use a wet scrubber to control inorganic HAP emissions from your
vent on a catalytic reforming unit, you can measure and record the pH
of the water (or scrubbing liquid) exiting the scrubber at least once
an hour during coke burn-off and catalyst rejuvenation using pH strips
as an alternative to a continuous parameter monitoring system. The pH
strips must meet the requirements in Table 41 of this subpart.
(c) Can I use another type of monitoring system? You may request
approval from your permitting authority to use an automated data
compression system. An automated data compression system does not
record monitored operating parameter values at a set frequency (e.g.,
once every hour) but records all values that meet set criteria for
variation from previously recorded values. Your request must contain a
description of the monitoring system and data recording system,
including the criteria used to determine which monitored values are
recorded and retained, the method for calculating daily averages, and a
demonstration that the system meets all of the criteria in paragraphs
(c)(1) through (5) of this section:
(1) The system measures the operating parameter value at least once
every hour;
(2) The system records at least 24 values each day during periods
of operation;
(3) The system records the date and time when monitors are turned
off or on;
(4) The system recognizes unchanging data that may indicate the
monitor is not functioning properly, alerts the operator, and records
the incident; and
(5) The system computes daily average values of the monitored
operating parameter based on recorded data.
(d) Can I monitor other process or control device operating
parameters? You may request approval to monitor parameters other than
those required in this subpart. You must request approval if:
(1) You use a control device other than a thermal incinerator,
boiler, process heater, flare, electrostatic precipitator, or wet
scrubber;
(2) You use a combustion control device (e.g., incinerator, flare,
boiler or process heater with a design heat capacity of at least 44 MW,
boiler or process heater where the vent stream is introduced into the
flame zone), electrostatic precipitator, or scrubber but want to
monitor a parameter other than those specified; or
(3) You wish to use another type of continuous emission monitoring
system that provides direct measurement of a pollutant (i.e., a PM or
multi-metals HAP continuous emission monitoring system, a carbonyl
sulfide/carbon disulfide continuous emission monitoring system, a TOC
continuous emission monitoring system, or HCl continuous emission
monitoring system).
(e) How do I request to monitor alternative parameters? You must
submit a request for review and approval or disapproval to the
Administrator. The request must include the information in paragraphs
(e)(1) through (5) of this section.
(1) A description of each affected source and the parameter(s) to
be monitored to determine whether the affected source will continuously
comply with the emission limitations and an explanation of the criteria
used to select the parameter(s).
(2) A description of the methods and procedures that will be used
to demonstrate that the parameter can be used to determine whether the
affected source will continuously comply with the emission limitations
and the schedule for this demonstration. You must certify that you will
establish an operating limit for the monitored parameter(s) that
represents the conditions in existence when the control device is being
properly operated and maintained to meet the emission limitation.
(3) The frequency and content of monitoring, recording, and
reporting, if monitoring and recording are not continuous. You also
must include the rationale for the proposed monitoring, recording, and
reporting requirements.
(4) Supporting calculations.
(5) Averaging time for the alternative operating parameter.
Notifications, Reports, and Records
Sec. 63.1574 What notifications must I submit and when?
(a) Except as allowed in paragraphs (a)(1) through (3) of this
section, you must submit all of the notifications in Secs. 63.6(h),
63.7(b) and (c), 63.8(e), 63.8(f)(4), 63.8(f)(6), and 63.9(b) through
(h) that apply to you by the dates specified.
(1) You must submit the notification of your intention to construct
or reconstruct according to Sec. 63.9(b)(5) unless construction or
reconstruction had commenced and initial startup had not occurred
before April 11, 2002. In this case, you must submit the notification
as soon as practicable before startup but no later than July 10, 2002.
This deadline also applies to the application for approval of
construction or reconstruction and approval of construction or
reconstruction based on State preconstruction review required in
Secs. 63.5(d)(1)(i) and 63.5(f)(2).
(2) You must submit the notification of intent to conduct a
performance test required in Sec. 63.7(b) at least 30 calendar days
before the performance test is scheduled to begin (instead of 60 days).
(3) If you are required to conduct a performance test, performance
evaluation, design evaluation, opacity observation, visible emission
observation, or other initial compliance demonstration, you must submit
a notification of compliance status according to Sec. 63.9(h)(2)(ii).
You can submit this information in an operating permit application, in
an amendment to an operating permit application, in a separate
submission, or in any combination. In a State with an approved
operating permit program where delegation of authority under section
112(l) of the CAA has not been requested or approved, you must provide
a duplicate notification to the applicable Regional Administrator. If
the required information has been submitted previously, you do not have
to provide a separate notification of compliance status. Just refer to
the earlier submissions instead of duplicating and resubmitting the
previously submitted information.
(i) For each initial compliance demonstration that does not include
a performance test, you must submit the Notification of Compliance
Status no later than 30 calendar days following completion of the
initial compliance demonstration.
(ii) For each initial compliance demonstration that includes a
performance test, you must submit the notification of compliance
status, including the performance test results, no later than 150
calendar days after the compliance date specified for your affected
source in Sec. 63.1573.
(b) As specified in Sec. 63.9(b)(2), if you startup your new
affected source before April 11, 2002, you must submit the initial
notification no later than August 9, 2002.
(c) As specified in Sec. 63.9(b)(3), if you start your new or
reconstructed affected source on or after April 11, 2002, you must
submit the initial notification no
[[Page 17785]]
later than 120 days after you become subject to this subpart.
(d) You also must include the information in Table 42 of this
subpart in your notification of compliance status.
(e) If you request an extension of compliance for an existing
catalytic cracking unit as allowed in Sec. 63.1563(c), you must submit
a notification to your permitting authority containing the required
information by October 13, 2003.
(f) As required by this subpart, you must prepare and implement an
operation, maintenance, and monitoring plan for each affected source,
control system, and continuous monitoring system. The purpose of this
plan is to detail the operation, maintenance, and monitoring procedures
you will follow.
(1) You must submit the plan to your permitting authority for
review and approval along with your notification of compliance status.
While you do not have to include the entire plan in your part 70 or 71
permit, you must include the duty to prepare and implement the plan as
an applicable requirement in your part 70 or 71 operating permit. You
must submit any changes to your permitting authority for review and
approval and comply with the plan until the change is approved.
(2) Each plan must include, at a minimum, the information specified
in paragraphs (f)(2)(i) through (x) of this section.
(i) Process and control device parameters to be monitored for each
affected source, along with established operating limits.
(ii) Procedures for monitoring emissions and process and control
device operating parameters for each affected source.
(iii) Procedures that you will use to determine the coke burn-rate,
the volumetric flow rate (if you use process data rather than direct
measurement), and the rate of combustion of liquid or solid fossil
fuels if you use an incinerator-waste heat boiler to burn the exhaust
gases from a catalyst regenerator.
(iv) Procedures and analytical methods you will use to determine
the equilibrium catalyst Ni concentration, the equilibrium catalyst Ni
concentration monthly rolling average, and the hourly or hourly average
Ni operating value.
(v) Procedures you will use to determine the pH of the water (or
scrubbing liquid) exiting a wet scrubber if you use pH strips.
(vi) Procedures you will use to determine the HCl concentration of
gases from a semi-regenerative catalytic reforming unit with an
internal scrubbing system (i.e., no add-on control device) when you use
a colormetric tube sampling system, including procedures for correcting
for pressure (if applicable to the sampling equipment).
(vii) Procedures you will use to determine the gas flow rate for a
catalytic cracking unit if you use the alternative procedure based on
air flow rate and temperature.
(viii) Monitoring schedule, including when you will monitor and
when you will not monitor an affected source (e.g., during the coke
burn-off, regeneration process).
(ix) Quality control plan for each continuous opacity monitoring
system and continuous emission monitoring system you use to meet an
emission limit in this subpart. This plan must include procedures you
will use for calibrations, accuracy audits, and adjustments to the
system needed to meet applicable requirements for the system.
(x) Maintenance schedule for each affected source, monitoring
system, and control device that is generally consistent with the
manufacturer's instructions for routine and long-term maintenance.
Sec. 63.1575 What reports must I submit and when?
(a) You must submit each report in Table 43 of this subpart that
applies to you.
(b) Unless the Administrator has approved a different schedule, you
must submit each report by the date in Table 43 of this subpart and
according to the requirements in paragraphs (b)(1) through (5) of this
section.
(1) The first compliance report must cover the period beginning on
the compliance date that is specified for your affected source in
Sec. 63.1563 and ending on June 30 or December 31, whichever date is
the first date following the end of the first calendar half after the
compliance date that is specified for your affected source in
Sec. 63.1563.
(2) The first compliance report must be postmarked or delivered no
later than July 31 or January 31, whichever date follows the end of the
first calendar half after the compliance date that is specified for
your affected source in Sec. 63.1563.
(3) Each subsequent compliance report must cover the semiannual
reporting period from January 1 through June 30 or the semiannual
reporting period from July 1 through December 31.
(4) Each subsequent compliance report must be postmarked or
delivered no later than July 31 or January 31, whichever date is the
first date following the end of the semiannual reporting period.
(5) For each affected source that is subject to permitting
regulations pursuant to part 70 or 71 of this chapter, and if the
permitting authority has established dates for submitting semiannual
reports pursuant to Sec. 70.6(a)(3)(iii)(A) or Sec. 71.6(a)(3)(iii)(A)
of this chapter, you may submit the first and subsequent compliance
reports according to the dates the permitting authority has established
instead of according to the dates in paragraphs (b)(1) through (4) of
this section.
(c) The compliance report must contain the information required in
paragraphs (c)(1) through (4) of this section.
(1) Company name and address.
(2) Statement by a responsible official, with that official's name,
title, and signature, certifying the accuracy of the content of the
report.
(3) Date of report and beginning and ending dates of the reporting
period.
(4) If there are no deviations from any emission limitation that
applies to you and there are no deviations from the requirements for
work practice standards, a statement that there were no deviations from
the emission limitations or work practice standards during the
reporting period and that no continuous emission monitoring system or
continuous opacity monitoring system was inoperative, inactive,
malfunctioning, out-of-control, repaired, or adjusted.
(d) For each deviation from an emission limitation and for each
deviation from the requirements for work practice standards that occurs
at an affected source where you are not using a continuous opacity
monitoring system or a continuous emission monitoring system to comply
with the emission limitation or work practice standard in this subpart,
the compliance report must contain the information in paragraphs (c)(1)
through (3) of this section and the information in paragraphs (d)(1)
through (3) of this section.
(1) The total operating time of each affected source during the
reporting period.
(2) Information on the number, duration, and cause of deviations
(including unknown cause, if applicable), as applicable, and the
corrective action taken.
(3) Information on the number, duration, and cause for monitor
downtime incidents (including
[[Page 17786]]
unknown cause, if applicable, other than downtime associated with zero
and span and other daily calibration checks).
(e) For each deviation from an emission limitation occurring at an
affected source where you are using a continuous opacity monitoring
system or a continuous emission monitoring system to comply with the
emission limitation, you must include the information in paragraphs
(d)(1) through (3) of this section and the information in paragraphs
(e)(1) through (13) of this section.
(1) The date and time that each malfunction started and stopped.
(2) The date and time that each continuous opacity monitoring
system or continuous emission monitoring system was inoperative, except
for zero (low-level) and high-level checks.
(3) The date and time that each continuous opacity monitoring
system or continuous emission monitoring system was out-of-control,
including the information in Sec. 63.8(c)(8).
(4) The date and time that each deviation started and stopped, and
whether each deviation occurred during a period of startup, shutdown,
or malfunction or during another period.
(5) A summary of the total duration of the deviation during the
reporting period (recorded in minutes for opacity and hours for gases
and in the averaging period specified in the regulation for other types
of emission limitations), and the total duration as a percent of the
total source operating time during that reporting period.
(6) A breakdown of the total duration of the deviations during the
reporting period and into those that are due to startup, shutdown,
control equipment problems, process problems, other known causes, and
other unknown causes.
(7) A summary of the total duration of downtime for the continuous
opacity monitoring system or continuous emission monitoring system
during the reporting period (recorded in minutes for opacity and hours
for gases and in the averaging time specified in the regulation for
other types of standards), and the total duration of downtime for the
continuous opacity monitoring system or continuous emission monitoring
system as a percent of the total source operating time during that
reporting period.
(8) A breakdown of the total duration of downtime for the
continuous opacity monitoring system or continuous emission monitoring
system during the reporting period into periods that are due to
monitoring equipment malfunctions, non-monitoring equipment
malfunctions, quality assurance/quality control calibrations, other
known causes, and other unknown causes.
(9) An identification of each HAP that was monitored at the
affected source.
(10) A brief description of the process units.
(11) The monitoring equipment manufacturer(s) and model number(s).
(12) The date of the latest certification or audit for the
continuous opacity monitoring system or continuous emission monitoring
system.
(13) A description of any change in the continuous emission
monitoring system or continuous opacity monitoring system, processes,
or controls since the last reporting period.
(f) You also must include the information required in paragraphs
(f)(1) through (2) of this section in each compliance report, if
applicable.
(1) A copy of any performance test done during the reporting period
on any affected unit. The report may be included in the next semiannual
report. The copy must include a complete report for each test method
used for a particular kind of emission point tested. For additional
tests performed for a similar emission point using the same method, you
must submit the results and any other information required, but a
complete test report is not required. A complete test report contains a
brief process description; a simplified flow diagram showing affected
processes, control equipment, and sampling point locations; sampling
site data; description of sampling and analysis procedures and any
modifications to standard procedures; quality assurance procedures;
record of operating conditions during the test; record of preparation
of standards; record of calibrations; raw data sheets for field
sampling; raw data sheets for field and laboratory analyses;
documentation of calculations; and any other information required by
the test method.
(2) Any requested change in the applicability of an emission
standard (e.g., you want to change from the PM standard to the Ni
standard for catalytic cracking units or from the HCl concentration
standard to percent reduction for catalytic reforming units) in your
periodic report. You must include all information and data necessary to
demonstrate compliance with the new emission standard selected and any
other associated requirements.
(g) You may submit reports required by other regulations in place
of or as part of the compliance report if they contain the required
information.
(h) The reporting requirements in paragraphs (h)(1) and (2) of this
section apply to startups, shutdowns, and malfunctions:
(1) When actions taken to respond are consistent with the plan, you
are not required to report these events in the semiannual compliance
report and the reporting requirements in Secs. 63.6(e)(3)(iii) and
63.10(d)(5) do not apply.
(2) When actions taken to respond are not consistent with the plan,
you must report these events and the response taken in the semiannual
compliance report. In this case, the reporting requirements in
Secs. 63.6(e)(3)(iv) and 63.10(d)(5) do not apply.
(i) If the applicable permitting authority has approved a period of
planned maintenance for your catalytic cracking unit according to the
requirements in paragraph (j) of this section, you must include the
following information in your compliance report.
(1) In the compliance report due for the 6-month period before the
routine planned maintenance is to begin, you must include a full copy
of your written request to the applicable permitting authority and
written approval received from the applicable permitting authority.
(2) In the compliance report due after the routine planned
maintenance is complete, you must include a description of the planned
routine maintenance that was performed for the control device during
the previous 6-month period, and the total number of hours during those
6 months that the control device did not meet the emission limitations
and monitoring requirements as a result of the approved routine planned
maintenance.
(j) If you own or operate multiple catalytic cracking units that
are served by a single wet scrubber emission control device (e.g., a
Venturi scrubber), you may request the applicable permitting authority
to approve a period of planned routine maintenance for the control
device needed to meet requirements in your operation, maintenance, and
monitoring plan. You must present data to the applicable permitting
authority demonstrating that the period of planned maintenance results
in overall emissions reductions. During this pre-approved time period,
the emission control device may be taken out of service while
maintenance is performed on the control device and/or one of the
process units while the remaining process unit(s) continue to operate.
During the period the emission control device is unable to operate, the
emission limits, operating limits, and monitoring requirements
applicable to the unit that is operating and the wet scrubber emission
control device do not
[[Page 17787]]
apply. The applicable permitting authority may require that you take
specified actions to minimize emissions during the period of planned
maintenance.
(1) You must submit a written request to the applicable permitting
authority at least 6 months before the planned maintenance is scheduled
to begin with a copy to the EPA Regional Administrator.
(2) Your written request must contain the information in paragraphs
(j)(2)(i) through (v) of this section.
(i) A description of the planned routine maintenance to be
performed during the next 6 months and why it is necessary.
(ii) The date the planned maintenance will begin and end.
(iii) A quantified estimate of the HAP and criteria pollutant
emissions that will be emitted during the period of planned
maintenance.
(iv) An analysis showing the emissions reductions resulting from
the planned maintenance as opposed to delaying the maintenance until
the next unit turnaround.
(v) Actions you will take to minimize emissions during the period
of planned maintenance.
Sec. 63.1576 What records must I keep, in what form, and for how long?
(a) You must keep the records specified in paragraphs (a)(1)
through (3) of this section.
(1) A copy of each notification and report that you submitted to
comply with this subpart, including all documentation supporting any
initial notification or Notification of Compliance Status that you
submitted, according to the requirements in Sec. 63.10(b)(2)(xiv).
(2) The records in Sec. 63.6(e)(1)(iii) through (v) related to
startup, shutdown, and malfunction.
(3) Records of performance tests, performance evaluations, and
opacity and visible emission observations as required in
Sec. 63.10(b)(2)(viii).
(b) For each continuous emission monitoring system and continuous
opacity monitoring system, you must keep the records required in
paragraphs (b)(1) through (5) of this section.
(1) Records described in Sec. 63.10(b)(2)(vi) through (xi).
(2) Monitoring data for continuous opacity monitoring systems
during a performance evaluation as required in Sec. 63.6(h)(7)(i) and
(ii).
(3) Previous (i.e., superceded) versions of the performance
evaluation plan as required in Sec. 63.8(d)(3).
(4) Requests for alternatives to the relative accuracy test for
continuous emission monitoring systems as required in
Sec. 63.8(f)(6)(i).
(5) Records of the date and time that each deviation started and
stopped, and whether the deviation occurred during a period of startup,
shutdown, or malfunction or during another period.
(c) You must keep the records in Sec. 63.6(h) for visible emission
observations.
(d) You must keep records required by Tables 6, 7, 13, and 14 of
this subpart (for catalytic cracking units); Tables 20, 21, 27 and 28
of this subpart (for catalytic reforming units); Tables 34 and 35 of
this subpart (for sulfur recovery units); and Table 39 of this subpart
(for bypass lines) to show continuous compliance with each emission
limitation that applies to you.
(e) You must keep a current copy of your operation, maintenance,
and monitoring plan onsite and available for inspection. You also must
keep records to show continuous compliance with the procedures in your
operation, maintenance, and monitoring plan.
(f) You also must keep the records of any changes that affect
emission control system performance including, but not limited to, the
location at which the vent stream is introduced into the flame zone for
a boiler or process heater.
(g) Your records must be in a form suitable and readily available
for expeditious review according to Sec. 63.10(b)(1).
(h) As specified in Sec. 63.10(b)(1), you must keep each record for
5 years following the date of each occurrence, measurement,
maintenance, corrective action, report, or record.
(i) You must keep each record on site for at least 2 years after
the date of each occurrence, measurement, maintenance, corrective
action, report, or record, according to Sec. 63.10(b)(1). You can keep
the records offsite for the remaining 3 years.
Other Requirements and Information
Sec. 63.1577 What parts of the General Provisions apply to me?
Table 44 of this subpart shows which parts of the General
Provisions in Secs. 63.1 through 63.15 apply to you.
Sec. 63.1578 Who implements and enforces this subpart?
(a) This subpart can be implemented and enforced by us, the U.S.
EPA, or a delegated authority such as your State, local, or tribal
agency. If the U.S. EPA Administrator has delegated authority to your
State, local, or tribal agency, then that Agency has the authority to
implement and enforce this subpart. You should contact your U.S. EPA
Regional Office to find out if this subpart is delegated to your State,
local, or tribal agency.
(b) In delegating implementation and enforcement authority of this
subpart to a State, local, or tribal agency under 40 CFR part 63,
subpart E, the authorities contained in paragraph (c) of this section
are retained by the Administrator of the U.S. EPA and are not
transferred to the State, local, or tribal agency.
(c) The authorities that will not be delegated to State, local, or
tribal agencies are listed in paragraphs (c)(1) through (5) of this
section.
(1) Approval of alternatives to the non-opacity emission
limitations and work practice standards in Secs. 63.1564 through
63.1569 under Sec. 63.6(g).
(2) Approval of alternative opacity emission limitations in
Secs. 63.1564 through 63.1569 under Sec. 63.6(h)(9).
(3) Approval of major alternatives to test methods under
Sec. 63.7(e)(2)(ii) and (f) and as defined in Sec. 63.90.
(4) Approval of major alternatives to monitoring under Sec. 63.8(f)
and as defined in Sec. 63.90.
(5) Approval of major alternatives to recordkeeping and reporting
under Sec. 63.10(f) and as defined in Sec. 63.90.
Sec. 63.1579 What definitions apply to this subpart?
Terms used in this subpart are defined in the Clean Air Act (CAA),
in 40 CFR 63.2, the General Provisions of this part (Secs. 63.1 through
63.15), and in this section as listed.
Boiler means any enclosed combustion device that extracts useful
energy in the form of steam and is not an incinerator.
Catalytic cracking unit means a refinery process unit in which
petroleum derivatives are continuously charged; hydrocarbon molecules
in the presence of a catalyst suspended in a fluidized bed are
fractured into smaller molecules, or react with a contact material
suspended in a fluidized bed to improve feedstock quality for
additional processing; and the catalyst or contact material is
continuously regenerated by burning off coke and other deposits. The
unit includes, but is not limited to, the riser, reactor, regenerator,
air blowers, spent catalyst or contact material stripper, catalyst or
contact material recovery equipment, and regenerator equipment for
controlling air pollutant emissions and equipment used for heat
recovery.
Catalytic cracking unit catalyst regenerator means one or more
regenerators (multiple regenerators) which comprise that portion of the
catalytic cracking unit in which coke burn-off and catalyst or contact
material
[[Page 17788]]
regeneration occurs and includes the regenerator combustion air
blower(s).
Catalytic reforming unit means a refinery process unit that reforms
or changes the chemical structure of naphtha into higher octane
aromatics through the use of a metal catalyst and chemical reactions
that include dehydrogenation, isomerization, and hydrogenolysis. The
catalytic reforming unit includes the reactor, regenerator (if
separate), separators, catalyst isolation and transport vessels (e.g.,
lock and lift hoppers), recirculation equipment, scrubbers, and other
ancillary equipment.
Catalytic reforming unit regenerator means one or more regenerators
which comprise that portion of the catalytic reforming unit and
ancillary equipment in which the following regeneration steps typically
are performed: depressurization, purge, coke burn-off, catalyst
rejuvenation with a chloride (or other halogenated) compound(s), and a
final purge. The catalytic reforming unit catalyst regeneration process
can be done either as a semi-regenerative, cyclic, or continuous
regeneration process.
Coke burn-off means the coke removed from the surface of the
catalytic cracking unit catalyst or the catalytic reforming unit
catalyst by combustion in the catalyst regenerator. The rate of coke
burn-off is calculated using Equation 2 in Sec. 63.1564.
Combustion device means an individual unit of equipment such as a
flare, incinerator, process heater, or boiler used for the destruction
of organic HAP or VOC.
Combustion zone means the space in an enclosed combustion device
(e.g., vapor incinerator, boiler, furnace, or process heater) occupied
by the organic HAP and any supplemental fuel while burning. The
combustion zone includes any flame that is visible or luminous as well
as that space outside the flame envelope in which the organic HAP
continues to be oxidized to form the combustion products.
Contact material means any substance formulated to remove metals,
sulfur, nitrogen, or any other contaminants from petroleum derivatives.
Continuous regeneration reforming means a catalytic reforming
process characterized by continuous flow of catalyst material through a
reactor where it mixes with feedstock, and a portion of the catalyst is
continuously removed and sent to a special regenerator where it is
regenerated and continuously recycled back to the reactor.
Control device means any equipment used for recovering, removing,
or oxidizing HAP in either gaseous or solid form. Such equipment
includes, but is not limited to, condensers, scrubbers, electrostatic
precipitators, incinerators, flares, boilers, and process heaters.
Cyclic regeneration reforming means a catalytic reforming process
characterized by continual batch regeneration of catalyst in situ in
any one of several reactors (e.g., 4 or 5 separate reactors) that can
be isolated from and returned to the reforming operation while
maintaining continuous reforming process operations (i.e., feedstock
continues flowing through the remaining reactors without change in feed
rate or product octane).
Deviation means any instance in which an affected source subject to
this subpart, or an owner or operator of such a source:
(1) Fails to meet any requirement or obligation established by this
subpart, including but not limited to any emission limit, operating
limit, or work practice standard;
(2) Fails to meet any term or condition that is adopted to
implement an applicable requirement in this subpart and that is
included in the operating permit for any affected source required to
obtain such a permit; or
(3) Fails to meet any emission limit, operating limit, or work
practice standard in this subpart during startup, shutdown, or
malfunction, regardless of whether or not such failure is permitted by
this subpart.
Emission limitation means any emission limit, opacity limit,
operating limit, or visible emission limit.
Flame zone means the portion of a combustion chamber of a boiler or
process heater occupied by the flame envelope created by the primary
fuel.
Flow indicator means a device that indicates whether gas is
flowing, or whether the valve position would allow gas to flow, in or
through a line.
Fuel gas system means the offsite and onsite piping and control
system that gathers gaseous streams generated by the source, may blend
them with sources of gas, if available, and transports the blended
gaseous fuel at suitable pressures for use as fuel in heaters,
furnaces, boilers, incinerators, gas turbines, and other combustion
devices located within or outside of the refinery. The fuel is piped
directly to each individual combustion device, and the system typically
operates at pressures over atmospheric. The gaseous streams can contain
a mixture of methane, light hydrocarbons, hydrogen, and other
miscellaneous species.
HCl means for the purposes of this subpart, gaseous emissions of
hydrogen chloride that serve as a surrogate measure for total emissions
of hydrogen chloride and chlorine as measured by Method 26 or 26A in
appendix A to part 60 of this chapter or an approved alternative
method.
Incinerator means an enclosed combustion device that is used for
destroying organic compounds, with or without heat recovery. Auxiliary
fuel may be used to heat waste gas to combustion temperatures. An
incinerator may use a catalytic combustion process where a substance is
introduced into an exhaust stream to burn or oxidize contaminants while
the substances itself remains intact, or a thermal process which uses
elevated temperatures as a primary means to burn or oxidize
contaminants.
Ni means, for the purposes of this subpart, particulate emissions
of nickel that serve as a surrogate measure for total emissions of
metal HAP, including but not limited to: antimony, arsenic, beryllium,
cadmium, chromium, cobalt, lead, manganese, nickel, and selenium as
measured by Method 29 in appendix A to part 60 of this chapter or by an
approved alternative method.
Oxidation control system means an emission control system which
reduces emissions from sulfur recovery units by converting these
emissions to sulfur dioxide.
PM means, for the purposes of this subpart, emissions of
particulate matter that serve as a surrogate measure of the total
emissions of particulate matter and metal HAP contained in the
particulate matter, including but not limited to: antimony, arsenic,
beryllium, cadmium, chromium, cobalt, lead, manganese, nickel, and
selenium as measured by Methods 5B or 5F in appendix A to part 60 of
this chapter or by an approved alternative method.
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 vent means, for the purposes of this subpart, a gas stream
that is continuously or periodically discharged during normal operation
of a catalytic cracking unit, catalytic reforming unit, or sulfur
recovery unit, including gas streams that are discharged directly to
the atmosphere, gas streams that are routed to a control device prior
to discharge to the atmosphere, or gas streams that are diverted
through a product recovery device line prior to control or discharge to
the atmosphere.
Reduced sulfur compounds means hydrogen sulfide, carbonyl sulfide,
and carbon disulfide.
[[Page 17789]]
Reduction control system means an emission control system which
reduces emissions from sulfur recovery units by converting these
emissions to hydrogen sulfide.
Responsible official means responsible official as defined in 40
CFR 70.2.
Semi-regenerative reforming means a catalytic reforming process
characterized by shutdown of the entire reforming unit (e.g., which may
employ three to four separate reactors) at specified intervals or at
the owner's or operator's convenience for in situ catalyst
regeneration.
Sulfur recovery unit means a process unit that recovers elemental
sulfur from gases that contain reduced sulfur compounds and other
pollutants, usually by a vapor-phase catalytic reaction of sulfur
dioxide and hydrogen sulfide. This definition does not include a unit
where the modified reaction is carried out in a water solution which
contains a metal ion capable of oxidizing the sulfide ion to sulfur,
e.g., the LO-CAT II process.
TOC means, for the purposes of this subpart, emissions of total
organic compounds, excluding methane and ethane, that serve as a
surrogate measure of the total emissions of organic HAP compounds,
including but not limited to, acetaldehyde, benzene, hexane, phenol,
toluene, and xylenes and non-HAP VOC as measured by Method 25 or 25A in
appendix A to part 60 of this chapter or an approved alternative
method.
TRS means, for the purposes of this subpart, emissions of total
reduced sulfur compounds, expressed as an equivalent sulfur dioxide
concentration, that serve as a surrogate measure of the total emissions
of sulfide HAP carbonyl sulfide and carbon disulfide as measured by
Method 15 in appendix A to part 60 of this chapter or by an approved
alternative method.
Work practice standard means any design, equipment, work practice,
or operational standard, or combination thereof, that is promulgated
pursuant to section 112(h) of the CAA.
Table 1 to Subpart UUU of Part 63.--Metal HAP Emission Limits for
Catalytic Cracking Units
[As stated in Sec. 63.1564(a)(1), you must meet each emission
limitation in the following table that applies to you]
------------------------------------------------------------------------
You must meet the following emission
For each new or existing catalytic limits for each catalyst regenerator
cracking unit * * * vent * * *
------------------------------------------------------------------------
1. Subject to the new source PM emissions must not exceed 1.0
performance standard (NSPS) for kilogram (kg) per 1,000 kg (1.0 lb/
PM in 40 CFR 60.102. 1,000 lb) of coke burn-off in the
catalyst regenerator; if the
discharged gases pass through an
incinerator or waste heat boiler in
which you burn auxiliary or
supplemental liquid or solid fossil
fuel, you must limit the
incremental rate of PM to no more
than 43.0 grams per Megajoule (g/
MJ) or 0.10 pounds per million
British thermal units (lb/million
Btu) of heat input attributable to
the liquid or solid fossil fuel;
and the opacity of emissions must
not exceed 30 percent, except for
one 6-minute average opacity
reading in any 1-hour period.
2. Option 1: NSPS requirements not PM emissions must not exceed 1.0 kg/
subject to the NSPS for PM in 40 1,000 kg (1.0 lb/1,000 lb) of coke
CFR 60.102. burn-off in the catalyst
regenerator; if the discharged
gases pass through an incinerator
or waste heat boiler in which you
burn auxiliary or in supplemental
liquid or solid fossil fuel, you
must limit the incremental rate of
PM to no more than 43.0 g/MJ or lb/
million Btu of heat input
attributable to the liquid or solid
fossil fuel; and the opacity of
emissions must not exceed 30
percent, except for one 6-minute
average opacity reading in any 1-
hour period.
3. Option 2: PM limit not subject PM emissions must not exceed 1.0 kg/
to the NSPS for PM in 40 CFR 1,000 kg (1.0 lb/1,000 lbs) of coke
60.102. burn-off in the catalyst
regenerator.
4. Option 3: Ni lb/hr not subject Nickel (Ni) emissions must not
to the NSPS for PM in 40 CFR exceed 13,000 milligrams per hour
60.102. (mg/hr) (0.029 lb/hr).
5. Option 4: Ni Lb/1,000 lbs of Ni emissions must not exceed 1.0 mg/
coke burn-off not subject to the kg (0.001 lb/1,000 lbs) of coke
NSPS for PM in 40 CFR 60.102. burn-off in the catalyst
regenerator.
------------------------------------------------------------------------
Table 2 to Subpart UUU of Part 63.--Operating Limits for Metal HAP Emissions From Catalytic Cracking Units
[As stated in Sec. 63.1564(a)(2), you must meet each operating limit in the following table that applies to
you]
----------------------------------------------------------------------------------------------------------------
For this type of
For each new or existing continuous monitoring For this type of control You must meet this
catalytic cracking unit * * * system * * * device * * * operating limit * * *
----------------------------------------------------------------------------------------------------------------
1. Subject to the NSPS for PM in Continuous opacity Not applicable.......... Not applicable.
40 CFR 60.102. monitoring system.
2. Option 1: NSPS requirements Continuous opacity Not applicable.......... Not applicable.
not subject to the NSPS for PM monitoring system.
in 40 CFR 60.102.
3. Option 2: PM limit not subject a. Continuous opacity Electrostatic Maintain the hourly
to the NSPS for PM in 40 CFR monitoring system. precipitator. average opacity of
60.102. emissions from your
catalyst regenerator
vent no higher than the
site-specific opacity
limit established
during the performance
test.
[[Page 17790]]
b. Continuous parameter Electrostatic Maintain the daily
monitoring systems. precipitator. average gas flow rate
no higher than the
limit established in
the performance test;
and maintain the daily
average voltage and
secondary current (or
total power input)
above the limit
established in the
performance test.
c. Continuous parameter Wet scrubber............ Maintain the daily
monitoring systems. average pressure drop
above the limit
established in the
performance test (not
applicable to a wet
scrubber of the non-
venturi jet-ejector
design); and maintain
the daily average
liquid-to-gas ratio
above the limit
established in the
performance test.
4. Option 3: Ni lb/hr not subject a. Continuous opacity Electrostatic Maintain the daily
to the NSPS for PM in 40 CFR monitoring system. precipitator. average Ni operating
60.102. value no higher than
the limit established
during the performance
test.
b. Continuous parameter i. Electrostatic Maintain the daily
monitoring systems. precipitator. average gas flow rate
no higher than the
limit established
during the performance
test; maintain the
monthly rolling average
of the equilibrium
catalyst Ni
concentration no higher
than the limit
established during the
performance test; and
maintain the daily
average voltage and
secondary current (or
total power input)
above the established
during the performance
test.
ii. Wet scrubber........ Maintain the monthly
rolling average of the
equilibrium catalyst Ni
concentration no higher
than the limit
established during the
performance test;
maintain the daily
average pressure drop
above the limit
established during the
performance test (not
applicable to a non-
venturi wet scrubber of
the jet-ejector
design); and maintain
the daily average
liquid-to-gas ratio
above the limit
established during the
performance test.
5. Option 4: Ni lb/1,000 lbs of a. Continuous opacity Electrostatic Maintain the daily
coke burn-off not subject to the monitoring system precipitator. average Ni operating
NSPS for PM in 40 CFR 60.102. value no higher than
the Ni operating limit
established during the
performance test.
b. Continuous parameter i. Electrostatic Maintain the monthly
monitoring systems. precipitator. rolling average of the
equilibrium catalyst Ni
concentration no higher
than the limit
established during the
performance test; and
maintain the daily
average voltage and
secondary current for
total power input)
above the limit
established during the
performance test.
[[Page 17791]]
ii. Wet scrubber........ Maintain the monthly
rolling average of the
equilibrium catalyst Ni
concentration no higher
than the limit
established during the
performance test;
maintain the daily
average pressure drop
above the limit
established during the
performance test (not
applicable to a non-
venturi wet scrubber of
the jet-ejector
design); and maintain
the daily average
liquid-to-gas ratio
above the limit
established during the
performance test.
----------------------------------------------------------------------------------------------------------------
Table 3 to Subpart UUU of Part 63.--Continous Monitoring Systems for Metal HAP Emissions From Catalytic Cracking
Units
[As stated in Sec. 63.1564(b)(1), you must meet each requirement in the following table that applies to you]
----------------------------------------------------------------------------------------------------------------
And you use this type of You must install,
For each new or existing If your catalytic control device for your operate, and maintain a
catalytic cracking unit * * * cracking unit is * * * vent * * * * * *
----------------------------------------------------------------------------------------------------------------
1. Subject to the NSPS for PM in Any size................. Electrostatic Continous opacity
40 CFR 60.102. precipitator or wet monitoring system to
scrubber or no control measure and record the
device. opacity of emissions
from each catalyst
regenerator vent.
2. Option 1: NSPS limits not Any size................. Electrostatic Continuous opacity
subject to the NSPS for PM in 40 precipitator or wet monitoring system to
CFR 60.102. scrubber or no control measure and record the
device. opacity of emissions
from each catalyst
regenerator vent.
3. Option 2: PM limit not subject a. Over 20,000 barrels Electrostatic Continous opacity
to the NSPS for PM in 40 CFR per day fresh feed precipitator. monitoring system to
60.102. capacity. measure and record the
opacity of emissions
from each catalyst
regenerator vent.
b. Up to 20,000 barrels Electrostatic Continuous opacity
per day fresh feed precipitator. monitoring system to
capacity. measure and record the
opacity of emissions
from each catalyst
regenerator vent; or
continuous parameter
monitoring systems to
measure and record the
gas flow rate to the
control device and the
voltage and secondary
current (or total power
input) to the control
device.
c. Any size.............. i. Wet scrubber......... (1) Continuous parameter
monitoring system to
measure and record the
pressure drop across
the scrubber, gas flow
rate to the scrubber,
and total liquid (or
scrubbing liquor) flow
rate to the scrubber.
(2) If you use a wet
scrubber of the non-
venturi jet-ejector
design, you're not
required to install and
operate a continuous
parameter monitoring
system for pressure
drop.
d. Any size.............. No electrostatic Continous opacity
precipitator or wet monitoring system to
scrubber. measure and record the
opacity of emissions
from each catalyst
regenerator vent.
[[Page 17792]]
4. Option 3: Ni lb/hr not subject a. Over 20,000 barrels Electrostatic Continous opacity
to the NSPS for PM in 40 CFR per day fresh feed precipitator. monitoring system to
60.102. capacity. measure and record the
opacity of emissions
from each catalyst
regenerator vent and
continuous parameter
monitoring system to
measure and record the
gas flow rate.
b. Up to 20,000 barrels Electrostatic Continuous opacity
per day fresh feed precipitator. monitoring system to
capacity. measure and record the
opacity of emissions
from each catalyst
regenerator vent and
continuous parameter
monitoring system to
measure and record the
gas flow rate; or
continuous parameter
monitoring systems to
measure and record the
gas flow rate and the
voltage and secondary
current (or total power
input) to the control
device.
c. Any size.............. Wet scrubber............ (1) Continuous parameter
monitoring system to
measure and record the
pressure drop across
the scrubber, gas flow
rate to the scrubber,
and total liquid (or
scrubbing liquor) flow
rate to the scrubber.
(2) If you use a wet
scrubber of the non-
venturi jet-ejector,
design, you're not
required to install and
operate a continuous
parameter monitoring
system for pressure
drop.
d. Any size.............. No electrostatic Continuous opacity
precipitator or wet monitoring system to
scrubber. measure and record the
opacity of emissions
from each catalyst
regenerator vent and
continuous parameter
monitoring system to
measure and record the
gas flow rate.
5. Option 4: Ni lb/1,000 lbs of a. Over 20,000 barrels Electrostatic Continuous opacity
coke burn-off not subject to the per day fresh feed precipitator. monitoring system to
NSPS for PM in 40 CFR 60.102. capacity. measure and record the
opacity of emissions
from each catalyst
regenerator vent and
continuous parameter
monitoring system to
measure and record the
gas flow rate.
b. Up to 20,000 barrels Electrostatic Continuous opacity
per day fresh feed precipitator. monitoring system to
capacity. measure and record the
opacity of emissions
from each catalyst
regenerator vent and
continuous parameter
monitoring system to
measure and record the
gas flow rate; or
continuous parameter
monitoring systems to
measure and record the
gas flow rate and the
voltage and secondary
current (or total power
input) to the control
device.
c. Any size.............. Wet scrubber............ Continuous parameter
monitoring system to
measure and record the
pressure drop across
the scrubber, gas flow
rate to the scrubber,
and total liquid (or
scrubbing liquor) flow
rate to the scrubber.
[[Page 17793]]
d. Any size.............. No electrostatic Continuous opacity
precipitator or wet monitoring system to
scrubber measure and record the
opacity of emissions
from each catalyst
regenerator vent and
continuous parameter
monitoring system to
measure and record the
gas flow rate.
----------------------------------------------------------------------------------------------------------------
Table 4 to Subpart UUU of Part 63.--Requirements for Performance Tests for Metal HAP Emissions From Catalytic
Cracking Units Not Subject to the New Source Performance Standard (NSPS) for Particulate Matter (PM)
[As stated in Sec. 63.1564(b)(2), you must meet each requirement in the following table that applies to you]
----------------------------------------------------------------------------------------------------------------
For each new or existing
catalytic cracking unit catalyst You must * * * Using * * * According to these
regenerator vent * * * requirements * * *
----------------------------------------------------------------------------------------------------------------
1. If you elect Option 1 in item a. Select sampling port's Method 1 or 1A in Sampling sites must be
2 of Table 1, Option 2 in item 3 location and the number appendix A to part 60 located at the outlet
of Table 1, Option 3 in item 4 of traverse ports. of this chapter. of the control device
of Table 1, or Option 4 in item or the outlet of the
5 of Table 1 of this subpart. regenerator, as
applicable, and prior
to any releases to the
atmosphere.
b. Determine velocity and Method 2, 2A, 2C, 2D,
volumetric flow rate. 2F, or 2G in appendix A
to part 60 of this
chapter, as applicable.
c. Conduct gas molecular Method 3, 3A, or 3B in
weight analysis. appendix A to part 60
of this chapter, as
applicable.
d. Measure moisture Method 4 in appendix A
content of the stack to part 60 of this
gas. chapter.
e. If you use an electro-
static precipitator,
record the total number
of fields in the control
system and how many
operated during the
applicable performance
test.
f. If you use a wet
scrubber, record the
total amount (rate) of
water (or scrubbing
liquid) and the amount
(rate) of make-up liquid
to the scrubber during
each test run.
2. Option 1: Elect NSPS.......... a. Measure PM emissions.. Method 5B or 5F (40 CFR You must maintain a
part 60, appendix A) to sampling rate of at
determine PM emissions least 0.15 dry standard
and associated moisture cubic meters per minute
content for units (dscm/min) (0.53 dry
without wet scrubbers. standard cubic feet per
Method 5B (40 CFR part minute (dscf/min)).
60, appendix A) to
determine PM emissions
and associated moisture
content for unit with
wet scrubber.
b. Compute PM emission Equations 1, 2, and 3 of
rate (lbs/1,000 lbs) of Sec. 63.1564 (if
coke burn-off. applicable).
c. Measure opacity of Continuous opacity You must collect opacity
emissions.. monitoring system. monitoring data every
10 seconds during the
entire period of the
initial Method 5
performance test and
reduce the data to 6-
minute averages.
3. Option 2: PM limit............ a. Measure PM emissions.. See item 2. of this See item 2. of this
table. table.
b. Compute coke burn-off Equations 1 and 2 of ........................
rate and PM emission Sec. 63.1564
rate.
[[Page 17794]]
c. Establish your site- Data from the continuous You must collect opacity
specific opacity opacity monitoring monitoring data every
operating limit if you system. 10 seconds during the
use a continuous opacity entire period of the
monitoring system. initial Method 5
performance test and
reduce the data to 6-
minute averages;
determine and record
the hourly average
opacity from all the 6-
minute averages; and
compute the site-
specific limit using
Equation 4 of Sec.
63.1564.
4. Option 3: Ni lb/hr............ a. Measure concentration Method 29 (40 CFR part You must maintain a
of Ni and total metal 60, appendix A). sampling rate of at
HAP. least 0.028 dscm/min
(0.74 dscf/min).
b. Compute Ni emission Equation 5 of Sec. ........................
rate (lb/hr). 63.1564
c. Determine the EPA Method 6010B or 6020 You must obtain 1 sample
equilibrium catalyst Ni or EPA Method 7520 or for each of the 3 runs;
concentration. 7521 in SW-846 1; or, determine and record
you can use an the average equilibrium
alternative method catalyst Ni
satisfactory to the concentration for each
Administrator. of the 3 runs; and you
may adjust the results
for an individual run
to the maximum value
using Equation 1 of
Sec. 63.1571.
d. If you use a i. Equations 6 and 7 of (1) You must collect
continuous opacity Sec. 63.1564 using opacity monitoring data
monitoring system, data from continuous every 10 seconds during
establish your site- opacity monitoring the entire period of
specific Ni operating system, gas flow rate, the initial Ni
limit. results of equilibrium performance test;
catalyst Ni reduce the data to 6-
concentration analysis, minute averages; and
and Ni emission rate determine and record
from Method 29 test. the hourly average
opacity from all the 6-
minute averages.
(2) You must collect gas
flow rate monitoring
data every 15 minutes
during the entire
period of the initial
Ni performance test;
measure the gas flow as
near as practical to
the continuous opacity
monitoring system; and
determine and record
the hourly average
actual gas flow rate
from all the readings.
5. Option 4: Ni lbs/1,000 lbs of a. Measure concentration Method 29 (40 CFR part You must maintain a
coke burn-off. of Ni and total metal 60, appendix A). sampling rate of at
HAP. least 0.028 dscm/min
(0.74 dscf/min).
b. Compute Ni emission Equations 1 and 8 of ........................
rate (lb/1,000 lbs of Sec. 63.1564.
coke burn-off).
c. Determine the EPA Method 6010B or 6020 You must obtain 1 sample
equilibrium catalyst Ni or EPA Method 7520 or for each of the 3 runs;
concentration. 7521 (SW-846) 1; or, determine and record
you can use an the equilibrium
alternative method catalyst Ni
satisfactory to the concentration for each
Administrator. of the 3 samples; and
you may adjust the
laboratory results to
the maximum value using
Equation 2 of Sec.
63.1571.
[[Page 17795]]
d. If you use a i. Equations 9 and 10 of (1) You must collect
continuous opacity Sec. 63.1564 with data opacity monitoring data
monitoring system, from continuous opacity every 10 seconds during
establish your site- monitoring system, coke the entire period of
specific Ni operating burn-off rate, gas flow the initial Ni
limit. rate, results of performance test;
equilibrium catalyst Ni reduce the data to 6-
concentration analysis, minute averages; and
and Ni emission rate determine and record
from Method 29 test. the hourly average
opacity from all the 6-
minute averages.
(2) You must collect gas
flow rate monitoring
data every 15 minutes
during the entire
period of the initial
Ni performance test;
measure the gas flow
rate as near as
practical to the
continuous opacity
monitoring system; and
determine and record
the hourly average
actual gas flow rate
from all the readings.
e. Record the catalyst
addition rate for each
test and schedule for
the 10-day period prior
to the test.
6. If you elect Option 2 in Entry a. Establish each Data from the continuous
3 in Table 1, Option 3 in Entry operating limit in Table parameter monitoring
4 in Table 1, or Option 4 in 2 of this subpart that systems and applicable
Entry 5 in Table 1 of this applies to you. performance test
subpart and you use continuous methods.
parameter monitoring systems.
b. Electrostatic Data from the continuous You must collect gas
precipitator or wet parameter monitoring flow rate monitoring
scrubber: gas flow rate. systems and applicable data every 15 minutes
performance test during the entire
methods. period of the initial
performance test; and
determine and record
the maximum hourly
average gas flow rate
from all the readings.
c. Electrostatic Data from the continuous You must collect voltage
precipitator: voltage parameter monitoring and secondary current
and secondary current systems and applicable (or total power input)
(or total power input). performance test monitoring data every
methods. 15 minutes during the
entire period of the
initial performance
test; and determine and
record the minimum
hourly average voltage
and secondary current
(or total power input)
from all the readings.
d. Electrostatic Results of analysis for You must determine and
precipitator or wet equilibrium catalyst Ni record the average
scrubber: equilibrium concentration. equilibrium catalyst Ni
catalyst Ni concentration for the 3
concentration. runs based on the
laboratory results. You
may adjust the value
using Equation 1 or 2
of Sec. 63.1571 as
applicable.
e. Wet scrubber: pressure Data from the continuous You must collect
drop (not applicable to parameter monitoring pressure drop
non-venturi scrubber of systems and applicable monitoring data every
jet ejector design). performance test 15 minutes during the
methods. entire period of the
initial performance
test; and determine and
record the minimum
hourly average pressure
drop from all the
readings.
[[Page 17796]]
f. Wet scrubber: liquid- Data from the continuous You must collect gas
to-gas ratio. parameter monitoring flow rate and total
systems and applicable water (or scrubbing
performance test liquid) flow rate
methods. monitoring data every
15 minutes during the
entire period of the
initial performance
test; determine and
record the hourly
average gas flow rate
and total water (or
scrubbing liquid) flow
rate from all the
readings; and determine
and record the minimum
liquid-to-gas ratio.
g. Alternative procedure Data from the continuous You must collect air
for gas flow rate. parameter monitoring flow rate monitoring
systems and applicable data or determine the
performance test air flow rate using
methods. control room
instrumentation every
15 minutes during the
entire period of the
initial performance
test; determine and
record the hourly
average rate of all the
readings; and determine
and record the maximum
gas flow rate using
Equation 1 of Sec.
63.1573.
----------------------------------------------------------------------------------------------------------------
\1\ EPA Method 6010B, Inductively Coupled Plasma-Atomic Emission Spectrometry, EPA Method 6020, Inductively
Coupled Plasma-Mass Spectrometry, EPA Method 7520, Nickel Atomic Absorption, Direct Aspiration, and EPA Method
7521, Nickel Atomic Absorption, Direct Aspiration are included in ``Test Methods for Evaluating Solid Waste,
Physical/Chemical Methods,'' EPA Publication SW-846, Revision 5 (April 1998). The SW-846 and Updates (document
number 955-001-00000-1) are available for purchase from the Superintendent of Documents, U.S. Government
Printing Office, Washington, DC 20402, (202) 512-1800; and from the National Technical Information Services
(NTIS), 5285 Port Royal Road, Springfield, VA 22161, (703) 487-4650. Copies may be inspected at the Air and
Radiation Docket and Information Center, U.S. Environmental Protection Agency, 401 M Street, SW, Washington,
DC; or at the Office of the Federal Register, 800 North Capitol Street, NW, Suite 700, Washington, DC.
[[Page 17797]]
Table 5 to Subpart UUU of Part 63.--Initial Compliance With Metal HAP
Emission Limits for Catalytic Cracking Units
[As stated in Sec. 63.1564(b)(5), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
For each new and existing
catalytic cracking unit For the following You have
catalyst regenerator vent * emission limit * * * demonstrated initial
* * compliance if * * *
------------------------------------------------------------------------
1. Subject to the NSPS for PM emissions must You have already
PM in 40 CFR 60.102. not exceed 1.0 kg/ conducted a
1,000 kg (1.0 lb/ performance test to
1,000 lb) of coke demonstrate initial
burn-off in the compliance with the
catalyst NSPS and the
regenerator; if the measured PM
discharged gases emission rate is
pass through an less than or equal
incinerator or to 1.0 kg/1,000 kg
waste heat boiler (1.0 lb/1,000 lb)
in which you burn of coke burn-off in
auxiliary or the catalyst
supplemental liquid regenerator. As
or solid fossil part of the
fuel, you must Notification of
limit the Compliance Status,
incremental rate of you must certify
PM to no more than that your vent
43.0 grams per meets the PM limit.
Megajoule (g/MJ) or You are not
0.10 pounds per required to do
million British another performance
thermal units (lb/ test to demonstrate
million Btu) of initial compliance.
heat input If applicable, you
attributable to the have already
liquid or solid conducted a
fossil fuel; and performance test to
the opacity of demonstrate initial
emissions 30 compliance with the
percent, except for NSPS and the
one 6-minute measured PM rate is
average opacity less than or equal
reading in any 1- to 43.0 g/MJ or
hour period. 0.010 lb/million
Btu of heat input
attributable to the
liquid or solid
fossil fuel. As
part of the
Notification of
Compliance Status,
you must certify
that your vent
meets the PM
emission limit. You
are not required to
do another
performance test to
demonstrate initial
compliance. You
have already
conducted a
performance test to
demonstrate initial
compliance with the
NSPS and the
average hourly
opacity of
emissions is no
more than 30
percent. Except:
one 6-minute
average in any 1-
hour period can
exceed 30 percent.
As part of the
Notification of
Compliance Status,
you must certify
that your vent
meets the opacity
limit. You are not
required to do
another performance
test to demonstrate
initial compliance.
You have already
conducted a
performance
evaluation to
demonstrate initial
compliance with the
applicable
performance
specification. As
part of your
Notification of
Compliance Status,
you certify that
your continuous
opacity monitoring
system meets the
requirements in
Sec. 63.1572. You
are not required to
do a performance
evaluation to
demonstrate initial
compliance.
2. Option 1: Elect NSPS not PM emissions must The average PM
subject to the NSPS for PM. not exceed 1.0 kg/ emission rate,
1,000 kg (1.0 lb/ measured using EPA
1,000 lb) of coke method 5 over the
burn-off in the period of the
catalyst initial performance
regenerator; if the test, is no higher
discharged gases than 1.0 kg/1,000
pass through an kg (1.0 lb/1,000
incinerator or lbs) of coke burn-
waste heat boiler off in the catalyst
in which you burn regenerator. The PM
auxiliary or emission rate is
supplemental liquid calculated using
or solid fossil Equations 1 and 2
fuel, you must of the Sec.
limit the 63.1564. If
incremental rate of applicable, the
PM to no more than average PM emission
43.0 grams per rate, measured
Megajoule (g/MJ) or using EPA Method 5
0.10 pounds per over the period of
million British the initial
thermal units (lb/ performance test,
million Btu) of is no higher than
heat input 43.0 g/MJ or 0.010
attributable to the lb/million Btu of
liquid or solid heat input
fossil fuel; and attributable to the
the opacity of liquid or solid
emissions must not fossil fuel. The PM
exceed 30 percent, emission rate is
except for one 6- calculated using
minute average Equation 3 of Sec.
opacity reading in 63.1564; no more
any 1-hour period. than one 6-minute
average measured by
the continuous
opacity monitoring
system exceeds 30
percent opacity in
any 1-hour period
over the period of
the performance
test; and your
performance
evaluation shows
the continuous
opacity monitoring
system meets the
applicable
requirements in
Sec. 63.1572.
[[Page 17798]]
3. Option 2: not subject to PM emissions must The average PM
the NSPS for PM. not exceed 1.0 kg/ emission rate,
1,000 kg (1.0 lb/ measured using EPA
1,000 lb) of coke Method 5 over the
burn-off in the period of the
catalyst initial performance
regenerator. test, is less than
or equal to 1.0 kg/
1,000 kg (1.0 lb/
1,000 lbs) of coke
burn-off in the
catalyst
regenerator. The PM
emission rate is
calculated using
Equations 1 and 2
of Sec. 63.1564;
and if you use a
continuous opacity
monitoring system,
your performance
evaluation shows
the system meets
the applicable
requirements in
Sec. 63.1572.
4. Option 3: not subject to Nickel (Ni) The average Ni
the NSPS for PM. emissions from your emission rate,
catalyst measured using
regenerator vent Method 29 over the
must not exceed period of the
13,000 mg/hr (0.029 initial performance
lb/hr). test, is not more
than 13,000 mg/hr
(0.029 lb/hr). The
Ni emission rate is
calculated using
Equation 5 of Sec.
63.1564; and if you
use a continuous
opacity monitoring
system, your
performance
evaluation shows
the system meets
the applicable
requirements in
Sec. 63.1572.
5. Option 4: Ni lb/1,000 lbs Ni emissions from The average Ni
of coke burn-off not your catalyst emission rate,
subject to the NSPS for PM. regenerator vent measured using
must not exceed 1.0 Method 29 over the
mg/kg (0.001 lb/ period of the
1,000 lbs) of coke initial performance
burn-off in the test, is not more
catalyst than 1.0 mg/kg
regenerator. (0.001 lb/1,000
lbs) of coke burn-
off in the catalyst
regenerator. The Ni
emission rate is
calculated using
Equation 8 of Sec.
63.1564; and if you
use a continuous
opacity monitoring
system, your
performance
evaluation shows
the system meets
the applicable
requirements in
Sec. 63.1572.
------------------------------------------------------------------------
Table 6 to Subpart UUU of Part 63.--Continuous Compliance With Metal HAP
Emission Limits for Catalytic Cracking Units
[As stated in Sec. 63.1564(c)(1), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
Subject to this
For each new and existing emission limit for You must demonstrate
catalytic cracking unit * * your catalyst continuous
* regenerator vent * * compliance by * * *
----------------------------------------*-------------------------------
1. Subject to the NSPS for a. PM emissions must i. Determining and
PM in 40 CFR 60.102. not exceed 1.0 lb/ recording each day
1,000 lbs of coke the average coke
burn-off in the burn-off rate
catalyst (thousands of
regenerator; if the kilograms per hour)
discharged gases using Equation 2 in
pass through an Sec. 63.1564 and
incinerator or the hours of
waste heat boiler operation for each
in which you burn catalyst
auxiliary or regenerator;
supplemental liquid maintaining PM
or solid fossil emission rate below
fuel, incremental 1.0 kg/1,000 kg
rate of PM can't (1.0 lb/1,000 lbs)
exceed 43.0 g/MJ of coke burn-off;
(0.10 lb/million if applicable,
Btu) of heat input determining and
attributable to the recording each day
liquid or solid the rate of
fossil fuel; and combustion of
opacity of liquid or solid
emissions can't fossil fuels
exceed 30 percent, (liters/hour or
except for one 6- kilograms/hour)
minute average using Equation 3 of
opacity reading in Sec. 63.1564 and
any 1-hour period. the hours of
operation during
which liquid or
solid fossil-fuels
are combusted in
the incinerator-
waste heat boiler;
if applicable,
maintaining PM rate
below 43 g/MJ (0.10
lb/million Btu) of
heat input
attributable to the
solid or liquid
fossil fuel;
collecting the
continuous opacity
monitoring data for
each catalyst
regenerator vent
according to Sec.
63.1572; and
maintaining each 6-
minute average at
or below 30 percent
except that one 6-
minute average
during a 1-hour
period can exceed
30 percent.
2. Option 1: Elect NSPS not See item 1.a. of See item 1.a.i. of
subject to the NSPS for PM this table. this table.
in 40 CFR 60.102.
[[Page 17799]]
3. Option 2: PM limit not PM emissions must Determining and
subject to the NSPS for PM. not exceed 1.0 lb/ recording each day
1,000 lbs of coke the average coke
burn-off in the burn-off rate
catalyst (thousands of
regenerator. kilograms per hour)
and the hours of
operation for each
catalyst
regenerator by
Equation 2 of Sec.
63.1564. You can
use process data to
determine the
volumetric flow
rate; and
maintaining PM
emission rate below
1.0 kg/1,000 kg
(1.0 lb/1,000 lbs)
of coke burn-off.
4. Option 3: Ni lb/hr not Ni emissions must Maintaining Ni
subject to the NSPS for PM. not exceed 13,000 emission rate below
mg/hr (0.029 lb/ 13,000 mg/hr (0.029
hr). lb/hr).
5. Option 4: Ni lb/1,000 lbs Ni emissions must Determining and
of coke burn-off not not exceed 1.0 mg/ recording each day
subject to the NSPS for PM. kg (0.001 lb/1,000 the average coke
lbs) of coke burn- burn-off rate
off in the catalyst (thousands of
regenerator. kilograms per hour)
and the hours of
operation for each
catalyst
regenerator by
Equation 2 of Sec.
63.1564. You can
use process data to
determine the
volumetric flow
rate; and
maintaining Ni
emission rate below
1.0 mg/kg (0.001 lb/
1,000 lbs) of coke
burn-off in the
catalyst
regenerator.
------------------------------------------------------------------------
Table 7 to Subpart UUU of Part 63.--Continuous Compliance With Operating Limits for Metal HAP Emissions From
Catalytic Cracking Units
[As stated in Sec. 63.1564(c)(1), you must meet each requirement in the following table that applies to you]
----------------------------------------------------------------------------------------------------------------
You must demonstrate
For each new or existing If you use * * * For this operating limit continuous compliance by
catalytic cracking unit * * * * * * * * *
----------------------------------------------------------------------------------------------------------------
1. Subject to NSPS for PM in 40 Continuous opacity Not applicable.......... Complying with Table 6
CFR 60.102. monitoring system. of this subpart.
2. Option 1: Elect NSPS not Continuous opacity Not applicable.......... Complying with Table 6
subject to the NSPS for PM in 40 monitoring system. of this subpart.
CFR 60.102.
3. Option 2: PM limit not subject a. Continuous opacity The opacity of emissions Collecting the hourly
to the NSPS for PM in 40 CFR monitoring system. from your catalyst average continuous
60.102. regenerator vent must opacity monitoring
not exceed the site- system data according
specific opacity to Sec. 63.1572; and
operating limit maintaining each 6-
established during the minute average in each
performance test 1-hour period at or
below the site-specific
limit.
b. Continuous parameter i. The daily average gas Collecting the hourly
monitoring systems-- flow rate to the and daily average gas
electrostatic control device must not flow rate monitoring
precipitator. exceed the operating data according to Sec.
limit established 63.1572 \1\; and
during the performance maintaining the daily
test. average gas flow rate
at limit or below the
established during the
performance test.
ii. The daily average Collecting the hourly
voltage and secondary and daily average
current (or total power voltage and secondary
input) to the control current (or total power
device must not fall input) monitoring data
below the operating according to Sec.
limit established 63.1572; and
during the performance maintaining the daily
test. average voltage and
secondary current (or
total power input) at
or above the limit
established during the
performance test.
c. Continuous parameter i. The daily average Collecting the hourly
monitoring systems--wet pressure drop across and daily average
scrubber. the scrubber must not pressure drop
fall below the monitoring data
operating limit according to Sec.
established during the 63.1572; and
performance test. maintaining the daily
average press drop
above the limit
established during the
performance test.
[[Page 17800]]
ii. The daily average Collecting the hourly
liquid-to-gas ratio average gas flow rate
must not fall below the and water (or scrubbing
operating limit liquid) flow rate
established during the monitoring data
performance test. according to Sec.
63.1572 \1\;
determining and
recording the hourly
average liquid-to-gas
ratio; determining and
recording the daily
average liquid-to-gas
ratio; and maintaining
the daily average
liquid-to-gas ratio
above the limit
established during the
performance test.
4. Option 3: Ni lb/hr not subject a. Continuous opacity The daily average Ni Collecting the hourly
to the NSPS for PM in 40 CFR monitoring system. operating value must average continuous
60.102. not exceed the site- opacity monitoring
specific Ni operating system data according
limit established Sec. 63.1572;
during the performance determining and
test. recording equilibrium
catalyst Ni
concentration at least
once a week collecting
the hourly average gas
flow rate monitoring
data according to Sec.
63.1572 \1\;
determining and
recording the hourly
average Ni operating
value using Equation 11
of Sec. 63.1564;
determining and
recording the daily
average Ni operating
value; and maintaining
the daily average Ni
operating value below
the site-specific Ni
operating limit
established the
performance test.
b. Continuous parameter i. The daily average gas See item 3.b.i. of this
monitoring systems-- flow rate to the table.
electrostatic control device must
precipitator. notice exceed the level
established in the
performance test.
ii. The daily average See item 3.b.ii. of this
voltage and secondary table.
current (or total power
input) must not fall
below the level
established in the
performance test.
iii. The monthly rolling Determining the
average of equilibrium recording the
catalyst Ni equilibrium catalyst Ni
concentration must not concentration at least
exceed the level once a week;
established during the determining and
performance test. recording the monthly
rolling average of the
equilibrium catalyst Ni
concentration once each
week using the weekly
or most recent value;
and maintaining the
monthly rolling average
below the limit
established in the
performance test
c. Continuous parameter i. The daily average See item 3.c.i. of this
monitoring systems--wet pressure drop must not table.
scrubber. fall below the
operating limit
established in the
performance test.
ii. The daily average See item 3.c.ii. of this
liquid-to-gas ratio table.
must not fall below the
operating limit
established during the
performance test.
[[Page 17801]]
iii. The monthly rolling Determining and
average equilibrium recording the
catalyst Ni equilibrium catalyst Ni
concentration must not concentration at least
exceed the level once a week;
established during the determining and
performance test. recording the monthly
rolling average of
equilibrium catalyst Ni
concentration once each
week using the weekly
or most recent value;
and maintaining the
monthly rolling average
below the limit
established in the
performance test.
5. Option 4: Ni lb/ton of coke a. Continuous opacity The daily average Ni Collecting the hourly
burn-off not subject to the NSPS monitoring system. operating value must average continuous
for PM in 40 CFR 60.102 not exceed the site- opacity monitoring
specific Ni operating system data according
limit established to Sec. 63.1572;
during the performance collecting the hourly
test. average gas flow rate
monitoring data
according to Sec.
63.1572 \1\;
determining and
recording equilibrium
catalyst Ni
concentration at least
once a week;
determining and
recording the hourly
average Ni operating
value using Equation 12
of Sec. 63.1564;
determining and
recording the daily
average Ni operating
value; and maintaining
the daily average Ni
operating value below
the site-specific Ni
operating limit
established during the
performance test.
b. Continuous parameter i. The daily average gas See item 3.b.i. of this
monitoring systems-- flow rate to the table.
electrostatic control device must not
precipitator. exceed the level
established in the
performance test.
ii. The daily average See item 3.b.ii. of this
voltage and secondary table.
current (or total power
input) must not fall
below the level
established in the
performance test.
iii. The monthly rolling See item 4.b.iii. of
average equilibrium this table.
catalyst Ni
concentration must not
exceed the level
established during the
performance test.
c. Continuous parameter i. The daily average See item 3.c.i. of this
monitoring systems--wet pressure drop must not table.
scrubber. fall below the
operating limit
established in the
performance test.
ii. The daily average
liquid-to-gas ratio
must not fall below the
operating limit
established during the
performance test. See
item 3.c.ii. of this
table.
iii. The monthly rolling See item 4.c.iii. of
average equilibrium this table.
catalyst Ni
concentration must not
exceed the level
established during the
performance test.
----------------------------------------------------------------------------------------------------------------
\1\ If applicable, you can use the alternative in Sec. 63.1573 for gas flow rate instead of a continuous
parameter monitoring system if you used the alternative method in the initial performance test. If so, you
must continuously monitor and record the air flow rate to the regenerator and the temperature of the gases
entering the control device as described in Sec. 63.1573. You must determine and record the hourly average
gas flow rate using Equation 1 of Sec. 63.1573 and the daily average gas flow rate. You must maintain the
daily average gas flow rate below the operating limit established during the performance test.
[[Page 17802]]
Table 8 to Subpart UUU of Part 63.--Organic HAP Emission Limits for
Catalytic Cracking Units
[As stated in Sec. 63.1565(a)(1), you must meet each emission
limitation in the following table that applies to you]
------------------------------------------------------------------------
You must meet the
following emission
For each new and existing catalytic cracking unit limit for each
* * * catalyst regenerator
vent * * *
------------------------------------------------------------------------
1. Subject to the NSPS for carbon monoxide (CO) in CO emissions from
40 CFR 60.103. the catalyst
regenerator vent or
CO boiler serving
the catalytic
cracking unit must
not exceed 500
parts per million
volume (ppmv) (dry
basis).
2. Not subject to the NSPS for CO in 40 CFR 60.103 a. CO emissions from
the catalyst
regenerator vent or
CO boiler serving
the catalytic
cracking unit must
not exceed 500 ppmv
(dry basis).
b. If you use a
flare to meet the
CO limit, the flare
must meet the
requirements for
control devices in
Sec. 63.11(b):
visible emissions
must not exceed a
total of 5 minutes
during any 2
consecutive hours.
------------------------------------------------------------------------
Table 9 to Subpart UUU of Part 63.--Operating Limits for Organic HAP Emissions From Catalytic Cracking Units
[As stated in Sec. 63.1565(a)(2), you must meet each operating limit in the following table that applies to
you]
----------------------------------------------------------------------------------------------------------------
For this type of
For each new or existing continuous monitoring For this type of control You must meet this
catalytic cracking unit * * * system * * * device * * * operating limit * * *
----------------------------------------------------------------------------------------------------------------
1. Subject to the NSPS for carbon Continuous emission Not applicable.......... Not applicable.
monoxide (CO) in 40 CFR 60.103. monitoring system.
2. Not subject to the NSPS for CO a. Continuous emission Not applicable.......... Not applicable.
in 40 CFR 60.103. monitoring system.
b. Continuous parameter i. Thermal incinerator.. Maintain the daily
monitoring systems. average combustion zone
temperature above the
limit established
during the performance
test; and maintain the
daily average oxygen
concentration in the
vent stream (percent,
dry basis) above the
limit established
during the performance
test.
ii. Boiler or process Maintain the daily
heater with a design average combustion zone
heat input capacity temperature above the
under 44 MW or a boiler limit established in
or process heater in the performance test.
which all vent streams
are not introduced into
the flame zone.
iii. Flare.............. The flare pilot light
must be present at all
times and the flare
must be operating at
all times that
emissions may be vented
to it.
----------------------------------------------------------------------------------------------------------------
Table 10 to Subpart UUU of Part 63.--Continuous Monitoring Systems for
Organic HAP Emissions From Catalytic Cracking Units
[As stated in Sec. 63.1565(b)(1), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
You must install,
And you use this operate, and
For each new or existing type of control maintain this type
catalytic cracking unit * * device for your vent of continuous
* * * * monitoring system *
* *
------------------------------------------------------------------------
1. Subject to the NSPS for Not applicable...... Continuous emission
carbon monoxide (CO) in 40 monitoring system
CFR 60.103. to measure and
record the
concentration by
volume (dry basis)
of CO emissions
from each catalyst
regenerator vent.
2. Not subject to the NSPS a. Thermal Continuous emission
for CO in 40 CFR 60.103. incinerator. monitoring system
to measure and
record the
concentration by
volume (dry basis)
of CO emissions
from each catalyst
regenerator vent;
or continuous
parameter
monitoring systems
to measure and
record the
combustion zone
temperature and
oxygen content
(percent, dry
basis) in the
incinerator vent
stream.
b. Process heater or Continuous emission
boiler with a monitoring system
design heat input to measure and
capacity under 44 record the
MW or process concentration by
heater or boiler in volume (dry basis)
which all vent of CO emissions
streams are not from each catalyst
introduced into the regenerator vent;
flame zone. or continuous
parameter
monitoring systems
to measure and
record the
combustion zone
temperature.
[[Page 17803]]
c. Flare............ Monitoring device
such as a
thermocouple, an
ultraviolet beam
sensor, or infrared
sensor to
continuously detect
the presence of a
pilot flame.
d. No control device Continuous emission
monitoring system
to measure and
record the
concentration by
volume (dry basis)
of CO emissions
from each catalyst
regenerator vent.
------------------------------------------------------------------------
Table 11 to Subpart UUU of Part 63.--Requirements for Performance Tests for Organic HAP Emissions From Catalytic
Cracking Units Not Subject to New Source Performance Standard (NSPS) for Carbon Monoxide (CO)
[As stated in Sec. 63.1565(b)(2) and (3), you must meet each requirement in the following table that applies to
you]
----------------------------------------------------------------------------------------------------------------
According to these
For * * * You must * * * Using * * * requirements * * *
----------------------------------------------------------------------------------------------------------------
1. Each new or existing catalytic a. Select sampling port's Method 1 or 1A in Sampling sites must be
cracking unit catalyst location and the number appendix A to part 60 located at the outlet
regenerator vent. of traverse ports. of this chapter. of the control device
or the outlet of the
regenerator, as
applicable, and prior
to any releases to the
atmosphere.
b. Determine velocity and Method 2, 2A, 2D, 2F, or
volumetric flow rate. 2G in appendix A to
part 60 of this
chapter, as applicable.
c. Conduct gas molecular Method 3, 3A, or 3B in
weight analysis. appendix A to part 60
of this chapter, as
applicable.
d. Measure moisture Method 4 in appendix A
content of the stack to part 60 of this
gas. chapter.
2. For each new or existing Measure CO emissions..... Data from your Collect CO monitoring
catalytic cracking unit catalyst continuous emission data for each vent for
regenerator vent if you use a monitoring system. 24 consecutive
continuous emission monitoring operating hours; and
system. reduce the continuous
emission monitoring
data to 1-hour averages
computed from four or
more data points
equally spaced over
each 1-hour period.
3. Each catalytic cracking unit a. Measure the CO Method 10, 10A, or 10B
catalyst regenerator vent if you concentration (dry in appendix A to part
use continuous parameter basis) of emissions 60 of this chapter, as
monitoring systems. exiting the control applicable.
device.
b. Establish each Data from the continuous
operating limit in Table parameter monitoring
9 of this subpart that systems.
applies to you.
c. Thermal incinerator Data from the continuous Collect temperature
combustion zone parameter monitoring monitoring data every
temperature. systems. 15 minutes during the
entire period of the CO
initial performance
test; and determine and
record the minimum
hourly average
combustion zone
temperature from all
the readings.
d. Thermal incinerator: Data from the continuous Collect oxygen
oxygen, content parameter monitoring concentration (percent,
(percent, dry basis) in systems. dry basis) monitoring
the incinerator vent data every 15 minutes
stream. during the entire
period of the CO
initial performance
test; and determine and
record the minimum
hourly average percent
excess oxygen
concentration from all
the readings.
[[Page 17804]]
e. If you use a process Data from the continuous Collect the temperature
heater or boiler with a parameter monitoring monitoring data every
design heat input systems. 15 minutes during the
capacity under 44 MW or entire period of the CO
process heater or boiler initial performance
in which all vent test; and determine and
streams are not record the minimum
introduced into the hourly average
flame zone, establish combustion zone
operating limit for temperature from all
combustion zone the readings.
temperature.
f. If you use a flare, Method 22 (40 CFR part Maintain a 2-hour
conduct visible emission 60, appendix A). observation period; and
observations. record the presence of
a flame at the pilot
light over the full
period of the test.
g. If you use a flare, 40 CFR
determine that the flare 60.11(b)(6)through(8).
meets the requirements
for net heating value of
the gas being combusted
and exit velocity.
----------------------------------------------------------------------------------------------------------------
Table 12 to Subpart UUU of Part 63.--Initial Compliance With Organic HAP
Emission Limits for Catalytic Cracking Units
[As stated in Sec. 63.1565(b)(4), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
You have
For each new and existing For the following demonstrated initial
catalytic cracking unit * * emission limit * * * compliance if * * *
--------------*---------------------------------------------------------
1. Subject to the NSPS for CO emissions from You have already
carbon monoxide (CO) in 40 your catalyst conducted a
CFR 60.103. regenerator vent or performance test to
CO boiler serving demonstrate initial
the catalytic compliance with the
cracking unit must NSPS and the
not exceed 500 ppmv measured CO
(dry basis). emissions are less
than or equal to
500 ppm (dry
basis). As part of
the Notification of
Compliance Status,
you must certify
that your vent
meets the CO limit.
You are not
required to conduct
another performance
test to demonstrate
initial compliance.
You have already
conducted a
performance
evaluation to
demonstrate initial
compliance with the
applicable
performance
specification. As
part of your
Notification of
Compliance Status,
you must certify
that your
continuous emission
monitoring system
meets the
applicable
requirements in
Sec. 63.1572. You
are not required to
conduct another
performance
evaluation to
demonstrate initial
compliance.
2. Not subject to the NSPS a. CO emissions from i. If you use a
for CO in 40 CFR 60.103. your catalyst continuous
regenerator vent or parameter
CO boiler serving monitoring system,
the catalytic the average CO
cracking unit must emissions measured
not exceed 500 ppmv by Method 10 over
(dry basis). the period of the
initial performance
test are less than
or equal to 500
ppmv (dry basis).
ii. If you use a
continuous emission
monitoring system,
the hourly average
CO emissions over
the 24-hour period
for the initial
performance test
are not more than
500 ppmv (dry
basis); and your
performance
evaluation shows
your continuous
emission monitoring
system meets the
applicable
requirements in
Sec. 63.1572.
b. If you use a Visible emissions,
flare, visible measured by Method
emissions must not 22 during the 2-
exceed a total of 5 hour observation
minutes during any period during the
2 operating hours. initial performance
test, are no higher
than 5 minutes.
------------------------------------------------------------------------
[[Page 17805]]
Table 13 to Subpart UUU of Part 63--Continuous Compliance With Organic HAP Emission Limits for Catalytic
Cracking Units
[As stated in Sec. 63.1565(c)(1), you must meet each requirement in the following table that applies to you]
----------------------------------------------------------------------------------------------------------------
Subject to this emission You must demonstrate
For each new and existing limit for your catalyst If you must * * * continuous compliance by
catalytic cracking unit * * ;* regenerator vent * * * * * *
----------------------------------------------------------------------------------------------------------------
1. Subject to the NSPS for carbon CO emissions from your Continuous emission Collecting the hourly
monoxide (CO) in 40 CFR 60.103. catalyst regenerator monitoring system. average CO monitoring
vent or CO boiler data according to Sec.
serving the catalytic 63.1572; and
cracking unit must not maintaining the hourly
exceed 500 ppmv (dry average CO
basis). concentration at or
below 500 ppmv (dry
basis).
2. Not subject to the NSPS for CO i. CO emissions from your Continuous emission Same as above.
in 40 CFR 60.103. catalyst regenerator monitoring system.
vent or CO boiler
serving the catalytic
cracking unit must not
exceed 500 ppmv (dry
basis).
ii. CO emissisons from Continuous parameter Maintaining the hourly
your catalyst monitoring system. average CO
regenerator vent or CO concentration below 500
boiler serving the ppmv (dry basis).
catalytic cracking unit
must not exceed 500 ppmv
(dry basis).
iii. Visible emissions Control device-flare.... Maintaining visible
from a flare must not emissions below a total
exceed a total of 5 of 5 minutes during any
minutes during any 2- 2-hour operating
hour period. period.
----------------------------------------------------------------------------------------------------------------
Table 14 to Subpart UUU of Part 63--Continuous Compliance With Operating Limits for Organic HAP Emissions From
Catalytic Cracking Units
[As stated in Sec. 63.1565(c)(1), you must meet each requirement in the following table that applies to you]
----------------------------------------------------------------------------------------------------------------
You must demonstrate
For each new existing catalytic If you use * * * For this operating limit continuous compliance by
cracking unit * * * * * * * * *
----------------------------------------------------------------------------------------------------------------
1. Subject to NSPS for carbon Continuous emission Not applicable.......... Complying with Table 13
monoxide (CO) in 40 CFR 60.103. monitoring system. of this subpart.
2. Not subject to the NSPS for CO a. Continuous emission Not applicable.......... Complying with Table 13
in 40 CFR 60.103. monitoring system. of this subpart.
b. Continuous parameter i. The daily average Collecting the hourly
monitoring systems-- combustion zone and daily average
thermal incinerator. temperature must not temperature monitoring
fall below the level data according to Sec.
established during the 63.1572; and
performance test. maintaining the daily
average combustion zone
temperature above the
limit established
during the performance
test.
ii. The daily average Collecting the hourly
oxygen concentration in and daily average
the vent stream oxygen concentration
(percent, dry basis) monitoring data
must not fall below the according to Sec.
level established 63.1572; and
during the performance maintaining the daily
test. average oxygen
concentration above the
limit established
during the performance
test.
c. Continuous parameter The daily combustion Collecting the average
monitoring systems-- zone temperature must hourly and daily
boiler or process heater not fall below the temperature monitoring
with a design heat input level established in data according to Sec.
capacity under 44 MW or the performance test. 63.1572; and
boiler or process heater maintaining the daily
in which all vent average combustion zone
streams are not temperature above the
introduced into the limit established
flame zone. during the performance
test.
d. Continuous parameter The flare pilot light Collecting the flare
monitoring system-- must be present at all monitoring data
flare. times and the flare according to Sec.
must be operating at 63.1572; and recording
all times that for each 1-hour period
emissions may be vented whether the monitor was
to it. continuously operating
and the pilot light was
continuously present
during each 1-hour
period.
----------------------------------------------------------------------------------------------------------------
[[Page 17806]]
Table 15 to Subpart UUU of Part 63.--Organic HAP Emission Limits for
Catalytic Reforming Units
[As stated in Sec. 63.1566(a)(1), you must meet each emission
limitation in the following table that applies to you]
------------------------------------------------------------------------
You must meet this emission
For each new or existing catalytic limit for each process vent
reforming unit * * * during depressuring and
purging operation * * *
------------------------------------------------------------------------
1. Option 1............................... Vent emissions to a flare
that meets the requirements
for control devices in Sec.
63.11(b). Visible
emissions from a flare must
not exceed a total of 5
minutes during any 2-hour
operating period.
2. Option 2............................... Using a control device,
reduce uncontrolled
emissions of total organic
compounds (TOC) from your
process vent by 98 percent
by weight or to a
concentration of 20 ppmv
(dry basis), corrected to 3
percent oxygen, whichever
is less stringent. If you
vent emissions to a boiler
or process heater to comply
with the percent reduction
or concentration emission
limitation, the vent stream
must be introduced into the
flame zone, or any other
location that will achieve
the percent reduction or
concentration standard.
------------------------------------------------------------------------
Table 16 to Subpart UUU of Part 63.--Operating Limits for Organic HAP
Emissions From Catalytic Reforming Units
[As stated in Sec. 63.1566(a)(2), you must meet each operating limit in
the following table that applies to you]
------------------------------------------------------------------------
You must meet this
operating limit
For each new or existing For this type of during depressuring
catalytic reforming unit * * control device * * * and purging
* operations * * *
------------------------------------------------------------------------
1. Option 1: vent to flare.. Flare that meets the The flare pilot
requirements for light must be
control devices in present at all
Sec. 63.11(b). times and the flare
must be operating
at all times that
emissions may be
vented to it.
2. Option 2: percent Thermal incinerator, The daily average
reduction or concentration boiler or process combustion zone
limit. heater with a temperature must
design heat input not fall below the
capacity under 44 limit established
MW, or boiler or during the
process heater in performance test.
which all vent
streams are not
introduced into the
flame zone.
------------------------------------------------------------------------
Table 17 to Subpart UUU of Part 63.--Continuous Monitoring Systems for
Organic HAP Emissions From Catalytic Reforming Units
[As stated in Sec. 63.1566(b)(1), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
You must install and
If you use this type operate this type of
For each new or exiting of control device * continuous
catalytic reforming unit * * * * monitoring system *
* * *
------------------------------------------------------------------------
1. Option 1: vent to a flare Flare that meets the Monitoring device
requirements for such as a
control devices in thermocouple, an
Sec. 63.11(b). ultraviolet beam
sensor, or infrared
sensor to
continuously detect
the presence of a
pilot flame.
2. Option 2: percent Thermal incinerator, Continuous parameter
reduction or concentration process heater or monitoring systems
limit. boiler with a to measure and
design heat input record the
capacity under 44 combustion zone
MW, or process temperature.
heater or boiler in
which all vent
streams are not
introduced into the
flame zone.
------------------------------------------------------------------------
Table 18 to Subpart UUU of Part 63.--Requirements for Performance Tests for Organic HAP Emissions From
Catalytic Reforming Units
[As stated in Sec. 63.1566(b)(2) and (3), you must meet each requirement in the following table that applies to
you]
----------------------------------------------------------------------------------------------------------------
For each new or exiting catalytic According to these
reforming unit * * * You must * * * Using * * * requirements * * *
----------------------------------------------------------------------------------------------------------------
1. Option 1: vent to a flare..... a. Conduct visible Method 22 (40 CFR 60, 2-hour observation
emission observations. appendix A). period. Record the
presence of a flame at
the pilot light over
the full period of the
test.
b. Determine that the Not applicable.......... 40 CFR 60.11(b)(6)
flare meets the through (8).
requirements for net
heating value of the gas
being combusted and exit
velocity.
2. Option 2: percent reduction or a. Select sampling site.. Method 1 or 1A (40 CFR Sampling sites must be
concentration limit. part 60, appendix A). located at the inlet
No traverse site (if you elect the
selection method is emission reduction
needed for vents standard) and outlet of
smaller than 0.10 meter the control device and
in diameter. prior to any releases
to the atmosphere.
[[Page 17807]]
b. Measure gas volumetric Method 2, 2A, 2C, 2D, ........................
flow rate. 2F, or 2G (40 CFR part
60, appendix A), as
applicable.
c. Measure TOC Method 25 (40 CFR part Take either an
concentration (for 60, appendix A) to integrated sample or
percent reduction measure TOC four grab samples
standard). concentration at the during each run. If you
inlet and outlet of the use a grab sampling
control device. If the technique, take the
TOC outlet samples at
concentration is approximately equal
expected to be less intervals in time, such
than 50 ppm, you can as 15-minute intervals
use Method 25A to during the run.
measure TOC
concentration at the
inlet and the outlet of
the control device.
d. Calculate TOC emission Calculate emission rate ........................
rate and mass emission by Equation 1 of Sec.
reduction. 63.1566 (if you use
Method 25) or Equation
2 of Sec. 63.1566 (if
you use Method 25A).
Calculate mass emission
reduction by Equation 3
of Sec. 63.1566.
e. Measure TOC Method 25A (40 CFR part
concentration (for 60, appendix A) to
concentration standard). measure TOC
concentration at the
outlet of the control
device.
f. Determine oxygen Method 3A or 3B (40 CFR
content in the gas part 60, appendix A),
stream at the outlet of as applicable.
the control device.
g. Correct the measured Equation 4 of Sec.
TOC concentration for 63.1566
oxygen content.
h. Established each Data from the continuous Collect the temperature
operating limit in Table parameter monitoring monitoring data every
16 of this subpart that systems. 15 minutes during the
applies to you for a entire period of the
thermal incinerator, or initial TOC performance
process heater or boiler test. Determine and
with a design heat input record the minimum
capacity under 44 MW, or hourly average
process heater or boiler combustion zone
in which all vent temperature.
streams are not
introduced into the
flame zone.
----------------------------------------------------------------------------------------------------------------
Table 19 to Subpart UUU of Part 63--Initial Compliance With Organic HAP
Emission Limits for Catalytic Reforming Units
[As stated in Sec. 63.1566(b)(7), you must meet each requirement in the
following table that applies to you.]
------------------------------------------------------------------------
You have
For . . . For the following demonstrated initial
emission limit . . . compliance if . . .
------------------------------------------------------------------------
1. Each new and existing a. Visible emissions Visible emissions,
catalytic reforming unit. from a flare must measured using
not exceed a total Method 22 over the
of 5 minutes during 2-hour observation
any 2 consecutive period of the
hours. performance test do
not exceed a total
of 5 minutes.
b. Reduce The mass emission
uncontrolled reduction measured
emissions of TOC using Method 25
from your process over the period of
vent using a the performance
control device, by test, is at least
98 percent by 98 percent by
weight or to a weight. The mass
concentration of 20 emission reduction
ppmv, on a dry is calculated using
basis, corrected to Equations 1 (or 2)
3 percent oxygen, and 3 of Sec.
whichever is less 63.1566 or the TOC
stringent. concentration,
measured by Method
25A over the period
of the performance
test, does not
exceed 20 ppmv (dry
basis), corrected
to 3 percent oxygen
using Equation 4 of
Sec. 63.1566.
------------------------------------------------------------------------
[[Page 17808]]
Table 20 to Subpart UUU of Part 63.--Continuous Compliance With Organic
HAP Emission Limits for Catalytic Reforming Units
[As stated in Sec. 63.1566(c)(1), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
You must demonstrate
continuous
For * * * For this emission compliance during
limit * * * depressuring and
purging by * * *
------------------------------------------------------------------------
1. Option 1: Each new or Vent emissions from Maintaining visible
existing catalytic your process vent emissions from a
reforming unit. to a flare that flare below a total
meets the of 5 minutes during
requirements in any 2 consecutive
Sec. 63.11(b). hours.
2. Option 2: Each new or Using a control Maintaining a 98
existing catalytic device, reduce percent by weight
reforming unit. uncontrolled TOC emission
emissions of TOC reduction; or
from your process maintaining a TOC
vent by 98 percent concentration of
by weight or to a not more than 20
concentration of 20 ppmv (dry basis),
ppmv, (dry basis), corrected to 3
corrected to 3 percent oxygen,
percent oxygen, whichever is less
whichever is less stringent.
stringent.
------------------------------------------------------------------------
Table 21 to Subpart UUU of Part 63.--Continuous Compliance With Operating Limits for Organic HAP Emissions From
Catalytic Reforming Units
[As stated in Sec. 63.1566(c)(1), you must meet each requirement in the following table that applies to you]
----------------------------------------------------------------------------------------------------------------
You must demonstrate
For this operating limit continuous compliance
For * * * If you use * * * * * * during depressuring and
purging by * * *
----------------------------------------------------------------------------------------------------------------
1. Each new or existing catalytic a. Flare that meets the The flare pilot light Collecting flare
reforming unit. requirements in Sec. must be present at all monitoring data
63.11(b). times and the flare according to Sec.
must be operating at 63.1572; and recording
all times that for each 1-hour period
emissions may be vented whether the monitor was
to it. continuously operating
and the pilot light was
continuously present
during each 1-hour
period.
b. Thermal incinerator, Maintain the daily Collecting the hourly
boiler or process heater average combustion zone and daily temperature
with a design input temperature above the monitoring data
capacity under 44 MW or limit established according to Sec.
boiler or process heater during the performance 63.1572; and
in which all vent test. maintaining the daily
streams are not average combustion zone
introduced into the temperature above the
flame zone. limit established
during the performance
test.
----------------------------------------------------------------------------------------------------------------
Table 22 to Subpart UUU of Part 63--Inorganic HAP Emission Limits for
Catalytic Reforming Units
[As stated in Sec. 63.1567(a)(1), you must meet each emission
limitation in the following table that applies to you]
------------------------------------------------------------------------
You must meet this
emission limit for
your process vent
For * * * during coke burn-off
and catalyst
rejuvenation * * *
------------------------------------------------------------------------
1. Each existing semi-regenerative catalytic Reduce uncontrolled
reforming unit. emissions of
hydrogen chloride
(HC1) by 92 percent
by weight using a
control device or
to a concentration
of 30 ppmv (dry
basis), corrected
to 3 percent
oxygen.
2. Each existing cyclic or continuous catalytic Reduce uncontrolled
reforming unit. emissions of HC1 by
97 percent by
weight using a
control device or
to a concentration
of 10 ppmv (dry
basis), corrected
to 3 percent
oxygen.
3. Each new semi-regenerative, cyclic, or Reduce uncontrolled
continuous catalytic reforming unit. emissions of HC1 by
97 percent by
weight using a
control device or
to a concentration
of 10 ppmv (dry
basis), corrected
to 3 percent
oxygen.
------------------------------------------------------------------------
Table 23 to Subpart UUU of Part 63.--Operating Limits for Inorganic HAP
Emission Limitations for Catalytic Reforming Units
[As stated in Sec. 63.1567(a)(2), you must meet each operating limit in
the following table that applies to you]
------------------------------------------------------------------------
You must meet this
If you use this type operating limit
For * * * of control device * during coke burn-off
* * and catalytst
rejuvenation . . .
------------------------------------------------------------------------
1. Each new or existing a. Wet scrubber..... The daily average pH
catalytic reforming unit. of the water (or
scrubbing liquid)
exiting the
scrubber must not
fall below the
limit established
during the
performance test;
and the daily
average liquid-to-
gas ratio must not
fall below the
limit established
during the
performance test.
b. Internal The HCl
scrubbing system concentration in
(i.e., no add-on the catalyst
control device). regenerator exhaust
gas must not exceed
the limit
established during
the performance
test.
------------------------------------------------------------------------
[[Page 17809]]
Table 24 to Subpart UUU of Part 63.--Continuous Monitoring Systems for
Inorganic HAP Emissions From Catalytic Reforming Units
[As stated in Sec. 63.1567(b)(1), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
You must install and
operate this type of
If you use this type of control device for your continuous
vent * * * monitoring system *
* *
------------------------------------------------------------------------
1. Wet scrubber................................... Continuous parameter
monitoring system
to measure and
record the pH of
the water (or
scrubbing liquid)
exiting the
scrubber during
coke burn-off and
catalyst
rejuvenation. If
applicable, you can
use the alternative
in Sec. 63.1573
instead of a
continuous
parameter
monitoring system
for pH of the water
(or scrubbing
liquid); and
continuous
parameter
monitoring systems
to measure and
record the gas flow
rate to the
scrubber and the
total water (or
scrubbing liquid)
flow rate to the
scrubber during
coke burn-off and
catalyst
rejuvenation.
2. Internal scrubbing system (i.e., no add-on Colormetric tube
control device). sampling system to
measure the HCl
concentration in
the catalyst
regenerator exhaust
gas during coke
burn-off and
catalyst
rejuvenation.
------------------------------------------------------------------------
Table 25 to Subpart UUU of Part 63.--Requirements for Performance Tests for Inorganic HAP Emissions From
Catalytic Reforming Units
[As stated in Sec. 63.1567(b)(2) and (3), you must meet each requirement in the following table that applies to
you]
----------------------------------------------------------------------------------------------------------------
If you use this type of control According to these
device or system * * * You must * * * Using * * * requirements * * *
----------------------------------------------------------------------------------------------------------------
1. Wet scrubber.................. a. Measure the HCl i. Method 26A (40 CFR (1) Sampling rate must
concentration at the part 60, appendix A). be at least 0.014 dscm/
outlet of the control min (0.5 dscf/min). You
device (for the must do the test during
concentration standard) the coke burn-off and
or at the inlet and catalyst rejuvenation
outlet of the control cycle, but don't make
d4evice (for the percent any test runs during
reduction standard). the first hour or the
last 6 hours of the
cycle.
(2) Record the total
amount (rate) of
scrubbing liquid or
solution and the amount
(rate) of make-up
liquid to the scrubber
during each test run.
b. Establish operating ........................ (1) Measure and record
limit for pH level. the pH of the water (or
scrubbing liquid)
exiting the scrubber
every 15 minutes during
the entire period of
the performance test.
Determine and record
the hourly average pH
level from the recorded
values.
(2) If you use the
alternative method in
Sec. 63.1573, measure
and record the pH of
the water (or scrubbing
liquid) exiting the
scrubber during coke
burn-off and catalyst
rejuvenation using pH
strips at least three
times during each run.
Determine and record
the average pH level.
c. Establish operating Data from the continuous Measure and record the
limit for liquid-to-gas parameter monitoring gas flow rate to the
ratio. systems. scrubber and the total
water (or scrubbing
liquid) flow rate to
the scrubber every 15
minutes during the
entire period of the
performance test.
Determine and record
the hourly average gas
flow rate and total
water (or scrubbing
liquid) flow rate.
Determine and record
the minimum liquid-to-
gas ratio.
2. Internal scrubbing system a. Measure the Method 26 (40 CFR part Sampling rate must be at
(i.e., no add-on control concentration of HCl in 60, appendix A). least 0.014 dscm/min
device). the catalyst regenerator (0.5 dscf/min). You
exhaust gas. must do the test during
the coke burn-off and
catalyst rejuvenation
cycle, but don't make
any test runs during
the first hour or the
last 6 hours of the
cycle.
[[Page 17810]]
b. Establish operating Measure and record the
limit for HCl HCl concentration in
concentration. the catalyst
regenerator exhaust gas
using the colorimetric
tube sampling system at
least three times
during each test run.
Determine and record
the average HCl
concentration.
----------------------------------------------------------------------------------------------------------------
Table 26 to Subpart UUU of Part 63.--Initial Compliance With Inorganic
HAP Emission Limits for Catalytic Reforming Units
[As stated in Sec. 63.1567(b)(4), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
You have
For* * * For the following demonstrated initial
emission limit * * * compliance if * * *
------------------------------------------------------------------------
1. Each existing semi- Reduce uncontrolled Average emissions of
regenerative catalytic emissions of HCl by HCl measured using
reforming unit. 92 percent by Method 26 or 26A,
weight using a as applicable over
control device or the period of the
to a concentration performance test,
of 30 ppmv, (dry are reduced by 92
basis), corrected percent or to a
to 3 percent concentration less
oxygen. than or equal to 30
ppmv (dry basis)
corrected to 3
percent oxygen.
2. Each existing cyclic or Reduce uncontrolled Average emissions of
continuous catalytic emissions of HCl by HCl measured using
reforming unit and each new 97 percent by Method 26 or 26A,
semi-regenerative, cyclic, weight using a as applicable over
or continuous catalytic control device, or the period of the
reforming unit. to a concentration performance test,
of 10 ppmv (dry are reduced by 97
basis), corrected percent or to a
to 3 percent concentration less
oxygen. than or equal to 10
ppmv (dry basis)
corrected to 3
percent oxygen.
------------------------------------------------------------------------
Table 27 to Subpart UUU of Part 63.--Continuous Compliance With
Inorganic HAP Emission Limits for Catalytic Reforming Units
[As stated in Sec. 63.1567(c)(1), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
You must demonstrate
continuous
For this emission compliance during
For * * * limit * * * coke burn-off and
catalyst
rejuvenation by * *
--------------------------------------------------------------*---------
1. Each existing semi- Reduce uncontrolled Maintaining a 92
regenerative catalytic emissions of HCl by percent HCl
reforming unit. 92 percent by emission reduction
weight using a or an HCl
control device or concentration no
to a concentration more than 30 ppmv
of 30 ppmv (dry (dry basis),
basis), corrected corrected to 3
to 3 percent oxygen. percent oxygen.
2. Each existing cyclic or Reduce uncontrolled Maintaining a 97
continuous catalytic emissions of HCl by percent HCl control
reforming unit. 97 percent by efficiency or an
weight using a HCl concentration
control device, or no more than 10
to a concentration ppmv (dry basis),
of 10 ppmv (dry corrected to 3
basis), corrected percent oxygen.
to 3 percent
oxygen.
3. Each new semi- Reduce uncontrolled Maintaining a 97
regenerative, cyclic, or emissions of HCl by percent HCl control
continuous catalytic 97 percent by efficiency or an
reforming unit. weight using a HCl concentration
control device, or no more than 10
to a concentration ppmv (dry basis),
of 10 ppmv (dry corrected to 3
basis), corrected percent oxygen.
to 3 percent
oxygen.
------------------------------------------------------------------------
[[Page 17811]]
Table 28 to Subpart UUU of Part 63.--Continuous Compliance With Operating Limits for Inorganic HAP Emissions
From Catalytic Reforming Units
[As stated in Sec. 63.1567(c)(1), you must meet each requirement in the following table that applies to you]
----------------------------------------------------------------------------------------------------------------
You must demonstrate
continuous compliance
For * * * For this operating limit If you use this type of during coke burn-off and
* * * control device * * * catalyst rejuvenation by
* * *
----------------------------------------------------------------------------------------------------------------
1. Each new or existing catalytic a. The daily average pH i. Wet scrubber......... (1) Collecting the
reforming unit. of the water (or hourly and daily
scrubbing and liquid) average pH monitoring
exiting the scrubber data according to Sec.
must not fall below the 63.1572; and
level established during maintaining the daily
the performance test. average the pH above
the operating limit
established during the
performance test.
(2) If you use the
alternative in Sec.
63.1573, measuring and
recording the pH of the
water (or scrubbing
liquid) exiting the
scrubber every hour
according to Sec.
63.1572; determining
and recording the daily
average pH; and
maintaining the daily
average pH above the
operating limit
established during the
performance test.
b. The daily average Wet scrubber............ Collecting the hourly
liquid-to-gas ratio must average gas flow rate
not fall below the level and total water (or
established during the scrubbing liquid) flow
performance test. rate monitoring data;
determining and
recording the hourly
average liquid-to-gas
ratio; determining and
recording the daily
average liquid-to-gas
ratio; and maintaining
the daily average
liquid-to-gas ratio
above the limit
established during the
performance test.
c. The HCl concentration Internal scrubbing Measuring and recording
in the catalyst system (e.g., no add-on the concentration of
regenerator exhaust gas control device). HCl every 4 hours using
must not exceed the a colormetric tube
applicable operating sampling system; and
limit established during maintaining the HCl
the performance test. concentration below the
applicable operating
limit.
----------------------------------------------------------------------------------------------------------------
Table 29 to Subpart UUU of Part 63.--HAP Emission Limits for Sulfur
Recovery Units
[As stated in Sec. 63.1568(a)(1), you must meet each emission
limitation in the following table that applies to you]
------------------------------------------------------------------------
You must meet this emission
For * * * limit for each process vent * *
--------------------------------------------------------*---------------
1. Each new or existing Claus sulfur a. 250 ppmv (dry basis) of
recovery unit part of a sulfur sulfur dioxide (SO2) at zero
recovery plant of 20 long tons per day percent excess air if you use
or more and subject to the NSPS for an oxidation or reduction
sulfur oxides in 40 CFR 60.104(a)(2). control system followed by
incineration.
b. 300 ppmv of reduced sulfur
compounds calculated as ppmv
SO2 (dry basis) at zero
percent excess air if you use
a reduction control system
without incineration.
2. Each new or existing sulfur recovery a. 250 ppmv (dry basis) of SO2
unit (Claus or other type, regardless at zero percent excess air if
of size) not subject to the NSPS for you use an oxidation or
sulfur oxides in 40 CFR 60.104(a)(2): reduction control system
Option 1 (Elect NSPS). followed by incineration.
b. 300 ppmv of reduced sulfur
compounds calculated as ppmv
SO2 (dry basis) at zero
percent excess air if you use
a reduction control system
without incineration.
3. Each new or existing sulfur recovery 300 ppmv of total reduced
unit (Claus or other type, regardless sulfur (TRS) compounds,
of size) not subject to the NSPS for expressed as an equivalent SO2
sulfur oxides in paragraph (a)(2) of concentration (dry basis) at
40 CFR 60.104: Option 2 (TRS limit). zero percent oxygen.
------------------------------------------------------------------------
[[Page 17812]]
Table 30 to Subpart UUU of Part 63.--Operating Limits for HAP Emissions
From Sulfur Recovery Units
[As stated in Sec. 63.1568(a)(2), you must meet each operating limit in
the following table that applies to you]
------------------------------------------------------------------------
If use this type of You must meet this
For * * * control device operating limit* * *
------------------------------------------------------------------------
1. Each new or existing Not applicable...... Not applicable.
Claus sulfur recovery unit
part of a sulfur recovery
plant of 20 long tons per
day or more and subject to
the NSPS for sulfur oxides
in 40 CFR 60.104(a)(2).
2. Each new or existing Not applicable...... Not applicable.
sulfur recovery unit (Claus
or other type, regardless
of size) not subject to the
NSPS for sulfur oxides in
40 CFR 60.104(a)(2): Option
1 (Elect NSPS).
3. Each new or existing Thermal incinerator. Maintain the daily
sulfur recovery unit (Claus average combustion
or other type, regardless zone temperature
of size) not subject to the above the limit
NSPS for sulfur oxides in established during
40 CFR 60.104(a)(2): Option the performance
2 (TRS limit). test; and maintain
the daily average
oxygen
concentration in
the vent stream
(percent, dry
basis) above the
limit established
during the
performance test.
------------------------------------------------------------------------
Table 31 to Subpart UUU of Part 63.--Continuous Monitoring Systems for
HAP Emissions From Sulfur Recovery Units
[As stated in Sec. 63.1568(b)(1), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
You must install and
operate this
For * * * For this limit * * * continuous
monitoring system *
* *
------------------------------------------------------------------------
1. Each new or existing a. 250 ppmv (dry Continuous emission
Claus sulfur recovery unit basis) of SO2 at monitoring system
part to a sulfur recovery zero percent excess to measure and
plant of 20 long tons per air if you use an record the hourly
day and subject to the NSPS oxidation or average
for sulfur oxides in 40 CFR reduction control concentration of
60.104 (1) (2). system followed by SO2 (dry basis) at
incineration. zero percent excess
air for each
exhaust stack. This
system must include
an oxygen monitor
for correcting the
data for excess
air.
b. 300 ppmv of Continuous emission
reduced sulfur monitoring system
compounds to measure and
calculated as ppmv record the hourly
SO2 (dry basis) at average
zero percent excess concentration of
air if you use a reduced sulfur and
reduction control oxygen (O2)
system without emissions.
incineration. Calculate the
reduced sulfur
emissions as SO2
(dry basis) at zero
percent excess air.
Exception: You can
use an instrument
having an air or
SO2 dilution and
oxidation system to
convert the reduced
sulfur to SO2 for
continuously
monitoring and
recording the
concentration (dry
basis) at zero
percent excess air
of the resultant
SO2 instead of the
reduced sulfur
monitor. The
monitor must
include an oxygen
monitor for
correcting the data
for excess oxygen.
2. Option 1: Elect NSPS. a. 250 ppmv (dry Continuous emission
Each new or existing sulfur basis) of SO2 at monitoring system
recovery unit (Claus or zero percent excess to measure and
other type, regardless of air if you use an record the hourly
size) not subject to the oxidation or average
NSPS for sulfur oxides in reduction control concentration of
paragraph (a) (2) of 40 CFR system followed by SO2 (dry basis), at
60.104. incineration. zero percent excess
air for each
exhaust stack. This
system must include
an oxygen monitor
for correcting the
data for excess
air.
b. 300 ppmv of Continuous emission
reduced sulfur monitoring system
compounds to measure and
calculated as ppmv record the hourly
SO2 (dry basis) at average
zero percent excess concentration of
air if you use a reduced sulfur and
reduction control O2 emissions for
system without each exhaust stack.
incineration. Calculate the
reduced sulfur
emissions as SO2
(dry basis), at
zero percent excess
air. Exception: You
can use an
instrument having
an air or O2
dilution and
oxidation system to
convert the reduced
sulfur to SO2 for
continuously
monitoring and
recording the
concentration (dry
basis) at zero
percent excess air
of the resultant
SO2 instead of the
reduced sulfur
monitor. The
monitor must
include an oxygen
monitor for
correcting the data
for excess oxygen.
[[Page 17813]]
3. Option 2: TRS limit Each 300 ppmv of total Continuous emission
new or existing sulfur reduced sulfur monitoring system
recovery unit (Claus or (TRS) compounds, to measure and
Other type, regardless or expressed as an record the hourly
size) not subject to the equivalent SO2 average
NSPS for sulfur oxides in concentration (dry concentration of
40 CFR 60.104 (a) (2). basis) at zero TRS for each
percent oxygen. exhaust stack. This
monitor must
include an oxygen
monitor for
correcting the data
for excess oxygen;
or continuous
parameter
monitoring systems
to measure and
record the
combustion zone
temperature of each
thermal incinerator
and the oxygen
content (percent,
dry basis) in the
vent stream of the
incinerator.
------------------------------------------------------------------------
Table 32 to Subpart UUU of Part 63.--Requirements for Performance Tests for HAP Emissions From Sulfur Recovery
Units Not Subject to the New Source Performance Standards for Sulfur Oxides
[As stated in Sec. 63.1568(b)(2) and (3), you must meet each requirement in the following table that applies to
you]
----------------------------------------------------------------------------------------------------------------
According to these
For * * * You must * * * Using * * * requirements * * *
----------------------------------------------------------------------------------------------------------------
1. Each new and existing sulfur Measure SO2 concentration Data from continuous Collect SO2 monitoring
recovery unit: Option 1 (Elect (for an oxidation or emission monitoring data every 15 minutes
NSPS). reduction system system. for 24 consecutive
followed by operating hours. Reduce
incineration) or the the data to 1-hour
concentration of reduced averages computed from
sulfur (or SO2 if you four or more data
use an instrument to points equally spaced
convert the reduced over each 1-hour
sulfur to SO2) for a period.
reduction control system
without incineration.
2. Each new and existing sulfur a. Select sampling port's Method 1 or 1A appendix Sampling sites must be
recovery unit: Option 2 (TRS location and the number A to part 60 of this located at the outlet
limit). of traverse ports. chapter. of the control device
and prior to any
releases to the
atmosphere.
b. Determine velocity and Method 2, 2A, 2C, 2D,
volumetric flow rate. 2F, or 2G in appendix A
to part 60 of this
chapter, as applicable.
c. Conduct gas molecular Method 3, 3A, or 3B in Take the samples
weight analysis; obtain appendix A to part 60 simultaneously with
the oxygen concentration of this chapter, as reduced sulfur or
needed to correct the applicable. moisture samples.
emission rate for excess
air.
d. Measure moisture Method 4 in appendix A Make your sampling time
content of the stack to part 60 of this for each Method 4
gas. chapter. sample equal to that
for 4 Method 15
samples.
e. Measure the Method 15 or 15A in If the cross-sectional
concentration of TRS. appendix A to part 60 area of the duct is
of this chapter, as less than 5 square
applicable. meters (m2) or 54
square feet, you must
use the centroid of the
cross section as the
sampling point. If the
cross-sectional area is
5 m2 or more and the
centroid is more than 1
meter (m) from the
wall, your sampling
point may be at a point
no closer to the walls
than 1 m or 39 inches.
Your sampling rate must
be at least 3 liters
per minute or 0.10
cubic feet per minute
to ensure minimum
residence time for the
sample inside the
sample lines.
f. Calculate the SO2 The arithmetic average
equivalent for each run of the SO2 equivalent
after correcting for for each sample during
moisture and oxygen. the run.
g. Correct the reduced Equation 1 of Sec.
sulfur samples to zero 63.1568.
percent excess air.sa
[[Page 17814]]
h. Establish each Data from the continuous
operating limit in Table parameter monitoring
30 of this subpart that system.
applies to you.
i. Measure thermal Data from the continuous Collect temperature
incinerator: combustion parameter monitoring monitoring data every
zone temperature. system. 15 minutes during the
entire period of the
performance test; and
determine and record
the minimum hourly
average temperature
from all the readings.
j. Measure thermal Data from the continuous Collect oxygen
incinerator: oxygen parameter monitoring concentration (percent,
concentration (percent, system. dry basis) data every
dry basis) in the vent 15 minutes during the
stream. entire period of the
performance test; and
determine and record
the minimum hourly
average percent excess
oxygen concentration.
k. If you use a Data from continuous Collect TRS data every
continuous emission emission monitoring 15 minutes for 24
monitoring system, system. consecutive operating
measure TRS hours. Reduce the data
concentration. to 1-hour averages
computed from four or
more data points
equally spaced over
each 1-hour period.
----------------------------------------------------------------------------------------------------------------
Table 33 to Subpart UUU of Part 63.--Initial Compliance With HAP
Emission Limits for Sulfur Recovery Units
[As stated in Sec. 63.1568(b)(5), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
You have
For * * * For the following demonstrated initial
emission limit * * * compliance if * * *
------------------------------------------------------------------------
1. Each new or existing a. 250 ppmv (dry You have already
Clause sulfur recovery unit basis) SO2 at zero conducted a
part of a sulfur recovery percent excess air performance test to
plant of 20 long tons per if you use an demonstrate initial
day and subject to the NSPS oxidation or compliance with the
for sulfur oxides in 40 CFR reduction control NSPS and the hourly
60.104(a)(2). system followed by average SO2
incineration. emissions measured
by the continuous
emission monitoring
system are less
than or equal to
250 ppmv (dry
basis) at zero
percent excess air.
As part of the
Notification of
Compliance Status,
you must certify
that your vent
meets the SO2
limit. You are not
required to do
another performance
test to demonstrate
initial compliance.
You have already
conducted a
performance
evaluation to
demonstrate initial
compliance with the
applicable
performance
specification. As
part of your
Notification of
Compliance Status,
you must certify
that your
continuous emission
monitoring system
meets the
applicable
requirements in
Sec. 63.1572. You
are not required to
do another
performance
evaluation to
demonstrate initial
compliance.
b. 300 ppmv of You have already
reduced sulfur conducted a
compounds performance test to
calculated as ppmv demonstrate initial
SO2 (dry basis) at compliance with the
zero percent excess NSPS and the hourly
air if you use a average SO2
reduction control emissions measured
system without by your continuous
incineration. emission monitoring
system are less
than or equal to
250 ppmv (dry
basis) at zero
percent excess air.
As part of the
Notification of
Compliance Status,
you must certify
that your vent
meets the SO2
limit. You are not
required to do
another performance
test do demonstrate
initial compliance.
[[Page 17815]]
You have already
conducted a
performance
evaluation to
demonstrate initial
compliance with the
applicable
performance
specification. As
part of your
Notification of
Compliance Status,
you must certify
that your
continuous emission
monitoring system
meets the
applicable
requirements in
Sec. 63.1572. You
are not required to
do another
performance
evaluation to
demonstrate initial
compliance.
2. Option 1: Elect NSPS. a. 250 ppmv (dry The hourly average
Each new or existing sulfur basis) of SO2 at SO2 emissions
recovery unit (Claus or zero percent excess measured by the
other type, regardless of air if you use an continuous emission
size) not subject to the oxidation control monitoring system
NSPS for sulfur oxides in system followed by over the 24-hour
40 CFR 60.104(a)(2). incineration. period of the
initial performance
test are not more
than 250 ppvm (dry
basis) at zero
percent excess air;
and your
performance
evaluation shows
the monitoring
system meets the
applicable
requirements in
Sec. 63.1572.
b. 300 ppmv of The hourly average
reduced sulfur reduced sulfur
compounds emissions measured
calculated as ppmv by the continuous
SO2 (dry basis) at emission monitoring
zero percent excess system over the 24-
air if you use a hour period of the
reduction control performance test no
system without more than 300 ppmv,
incineration. calculated as ppmv
SO2 (dry basis) at
zero percent excess
air; and your
performance
evaluation shows
the continuous
emission monitoring
system meets the
applicable
requirements in
Sec. 63.1572.
3. Option 2: TRS limit. Each 300 ppmv of TRS If you do not use a
new or existing sulfur compounds expressed continuous emission
recovery unit (Claus or as an equivalent monitoring system,
other type, regardless of SO2 concentration the average TRS
size) not subject to the (dry basis) at zero emissions measured
NSPS for sulfur oxides in percent oxygen. using Method 15
40 CFR 60.104(a)(2). over the period of
the initial
performance test
are less than or
equal to 300 ppmv
expressed as
equivalent SO2
concentration (dry
basis) at zero
percent oxygen. If
you use a
continuous emission
monitoring system
the hourly average
TRS emissions
measured by the
continuous emission
monitoring system
over the 24-hour
period of the
performance test
are no more than
300 ppmv expressed
as an equivalent
SO2 concentration
(dry basis) at zero
percent oxygen; and
your performance
evaluation shows
the continuous
emission monitoring
system meets the
applicable
requirements in
Sec. 63.1572.
------------------------------------------------------------------------
Table 34 to Subpart UUU of Part 63.--Continuous Compliance With HAP
Emission Limits for Sulfur Recovery Units
[As stated in Sec. 63.1568(c)(1), you must meet each requirement in the
following table that applies to you.]
------------------------------------------------------------------------
You must demonstrate
For * * * For this emission continuous
limit * * * compliance by * * *
------------------------------------------------------------------------
1. Each new or existing a. 250 ppmv (dry Collecting the
Claus sulfur recovery unit basis) SO2 at zero hourly average SO2
part of a sulfur recovery percent excess air monitoring data
plant of 20 long tons per if you use an (dry basis, percent
or more and subject to the oxidation or excess air)
NSPS for sulfur oxides in reduction control according to Sec.
40 CFR 60.104(a)(2). system followed by 63.1572;
incineration. maintaining the
hourly average SO2
concentration at or
below the
applicable limit;
determining and
recording each 12-
hour average SO2
day concentration;
and reporting any
12-hour average SO2
concentration
greater than the
applicable emission
limitation in the
compliance report
required in Sec.
63.1575.
[[Page 17816]]
b. 300 ppmv of Collecting the
reduced sulfur hourly average
compounds reduced sulfur and
calculated as ppmv O2 data according
(dry basis) SO2 at to Sec. 63.1572;
zero percent excess and maintaining the
air if you use a hourly average
reduction control concentration of
system without reduced sulfur at
incineration. or below the
applicable limit;
and determining and
recording each 12-
hour average
concentration of
reduced sulfur; and
reporting any 12-
hour average
concentration of
reduced sulfur
greater than the
applicable emission
limitation in the
compliance report
required in Sec.
63.1575.
2. Option 1: Elect NSPS Each a. 250 ppmv (dry Collecting the
new or existing sulfur basis) of SO2 at hourly average SO2
recovery unit (Claus or zero percent excess monitoring data
other type, regardless of air (for oxidation (dry basis, percent
size) not subject to the or reduction system excess air)
NSPS for sulfur oxides in followed by according to Sec.
40 CFR 60.104(a)(2). incineration). 63.1572;
maintaining the
hourly average SO2
concentration at or
below the
applicable limit;
determining and
recording each 12-
hour average SO2
concentration; and
reporting any 12-
hour average SO2
concentration
greater than the
applicable emission
limitation in the
compliance report
required in Sec.
63.1575.
b. 300 ppmv of Collecting the
reduced sulfur hourly average
compounds reduced sulfur (and
calculated as ppmv air or O2 dilution
SO2 (dry basis) at and oxidation data)
zero percent excess according to Sec.
air (for reduction 63.1572;
control system maintaining the
without hourly average SO2
incineration). concentration at or
below the
applicable limit;
reducing the
monitoring data to
12-hour averages;
and reporting any
12-hour average SO2
concentration
greater than the
applicable limit in
the compliance
report required by
Sec. 63.1575.
3. Option 2: TRS limit Each 300 ppmv of TRS Collecting the
new or existing sulfur compounds, hourly average TRS
recovery unit (Claus or expressed as an SO2 monitoring data
other type, regardless of concentration (dry according to Sec.
size) not subject to the basis) at zero 63.1572, if you use
NSPS for sulfur oxides in percent oxygen or a continuous
40 CFR 60.104(a)(2). reduced sulfur emission monitoring
compounds system; maintaining
calculated as ppmv the hourly average
SO2 (dry basis) at concentration of
zero percent excess TRS at or below the
air. applicable limit;
reducing the TRS
monitoring data to
12-hour averages;
reporting any 12-
hour average TRS
greater than the
applicable limit in
the compliance
report required by
Sec. 63.1575; and
maintaining the
hourly average
concentration of
TRS below the
applicable limit if
you use continuous
parameter
monitoring systems.
------------------------------------------------------------------------
Table 35 to Subpart UUU of Part 63.--Continuous Compliance With
Operating Limits for HAP Emissions From Sulfur Recovery Units
[As stated in Sec. 63.1568(c)(1), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
You must demonstrate
For * * * For this operating continuous
limit * * * compliance by * * *
------------------------------------------------------------------------
1. Each new or existing Not applicable...... Meeting the
Claus sulfur recovery unit requirements of
part of a sulfur recovery Table 34 of this
plant of 20 long tons per subpart.
day or more and subject to
the NSPS for sulfur oxides
in paragraph 40 CFR
60.104(a)(2).
2. Option 1: Elect NSPS Each Not applicable...... Meeting the
new or existing sulfur requirements of
recovery unit (Claus or Table 34 of this
other type, regardless of subpart.
size) not subject to the
NSPS for sulfur oxides in
40 CFR 60.104(a)(2).
3. Option 2: TRS limit Each a. Maintain the Collecting the
new or existing sulfur daily average hourly and daily
recovery unit (Claus or combustion zone average temperature
other type, regardless of temperature above monitoring data
size) not subject to the the level according to Sec.
NSPS for sulfur oxides in established during 63.1572; and
40 CFR 60.104(a)(2) the performance maintaining the
test. daily average
combustion zone
temperature at or
above the limit
established during
the performance
test.
[[Page 17817]]
b. The daily average Collecting the
oxygen hourly and daily
concentration in average O2
the vent stream monitoring data
(percent, dry according to Sec.
basis) must not 63.1572; and
fall below the maintaining the
level established average O2
during the concentration above
performance test. the level
established during
the performance
test.
------------------------------------------------------------------------
Table 36 to Subpart UUU of Part 63.--Work Practice Standards for HAP
Emissions From Bypass Lines
[As stated in Sec. 63.1569(a)(1), you must meet each work practice
standard in the following table that applies to you]
------------------------------------------------------------------------
You must meet one of these
Option equipment standards * * *
------------------------------------------------------------------------
1. Option 1............................... Install and operate a device
(including a flow
indicator, level recorder,
or electronic valve
position monitor) to
continuously detect, at
least every hour, whether
flow is present in the
bypass line. Install the
device at or as near as
practical to the entrance
to any bypass line that
could divert the vent
stream away from the
control device to the
atmosphere.
2. Option 2............................... Install a car-seal or lock-
and-key device placed on
the mechanism by which the
bypass device flow position
is controlled (e.g., valve
handle, damper level) when
the bypass device is in the
closed position such that
the bypass line valve
cannot be opened without
breaking the seal or
removing the device.
3. Option 3............................... Seal the bypass line by
installing a solid blind
between piping flanges.
4. Option 4............................... Vent the bypass line to a
control device that meets
the appropriate
requirements in this
subpart.
------------------------------------------------------------------------
Table 37 to Subpart UUU of Part 63.--Requirements for Performance Tests
for Bypass Lines
[As stated in Sec. 63.1569(b)(1), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
For this standard . . . You must . . .
------------------------------------------------------------------------
1. Option 1: Install and operate a flow Record during the performance
indicator, level recorder, or test for each type of control
electronic valve position monitor. device whether the flow
indicator, level recorder, or
electronic valve position
monitor was operating and
whether flow was detected at
any time during each hour of
level the three runs
comprising the performance
test.
------------------------------------------------------------------------
Table 38 to Subpart UUU of Part 63.--Initial Compliance With Work
Practice Standards for HAP Emissions from Bypass Lines
[As stated in Sec. 63.1569(b)(2), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
For this work You have
For * * * practice standard * demonstrated initial
* * compliance if * * *
------------------------------------------------------------------------
1. Each new or existing a. Option 1: Install The installed
bypass line associated with and operate a equipment operates
a catalytic cracking unit, device (including a properly during
catalylic reforming unit, flow indicator, each run of the
or sulfur recovery unit. level recorder, or performance test
electronic valve and no flow is
position monitor) present in the line
to continuously during the test.
detect, at least
every hour, whether
flow is present in
the bypass line.
Install the device
at or as near as
practical to the
entrance to any
bypass line that
could divert the
vent stream away
from the control
device to the
atmosphere.
b. Option 2: Install As part of the
a car-seal or lock- notification of
and-key device compliance status,
placed on the you certify that
mechanism by which you installed the
the bypass device equipment, the
flow position is equipment was
controlled (e.g., operational by your
valve handle, compliance date,
damper level) when and you identify
the bypass device what equipment was
is in the closed installed.
position such that
the bypass line
valve cannot be
opened without
breaking the seal
or removing the
device.
c. Option 3: Seal See item 1.b. of
the bypass line by this table.
installing a solid
blind between
piping flanges.
d. Option 4: Vent See item 1.b. of
the bypass line to this table.
a control device
that meets the
appropriate
requirements in
this subpart.
------------------------------------------------------------------------
[[Page 17818]]
Table 39 to Subpart UUU of Part 63.--Continuous Compliance With Work
Practice Standards for HAP Emissions From Bypass Lines
[As stated in Sec. 63.1569(c)(1), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
You must demonstrate continuous
If you elect this standard * * * compliance by * * *
------------------------------------------------------------------------
1. Option 1: Flow indicator, level Continuously monitoring and
recorder, or electronic valve position recording whether flow is
monitor. present in the bypass line;
visually inspecting the device
at least once every hour if
the device is not equipped
with a recording system that
provides a continuous record;
and recording whether the
device is operating properly
and whether flow is present in
the bypass line.
2. Option 2: Car-seal or lock-and-key Visually inspecting the seal or
device. closure mechanism at least
once every month; and
recording whether the bypass
line valve is maintained in
the closed position and
whether flow is present in the
line.
3. Option 3: Solid blind flange........ Visually inspecting the blind
at least once a month; and
recording whether the blind is
maintained in the correct
position such that the vent
stream cannot be diverted
through the bypass line.
4. Option 4: Vent to control device.... Monitoring the control device
according to appropriate
subpart requirements.
5. Option 1, 2, 3, or 4................ Recording and reporting the
time and duration of any
bypass.
------------------------------------------------------------------------
Table 40 to Subpart UUU of Part 63.--Requirements for Installation,
Operation, and Maintenance of Continuous Opacity Monitoring Systems and
Continuous Emission Monitoring Systems
[As stated in Sec. 63.1572(a)(1) and (b)(1), you must meet each
requirement in the following table that applies to you]
------------------------------------------------------------------------
This type of continuous opacity or Must meet these requirements *
emission monitoring system * * * * *
------------------------------------------------------------------------
1. Continuous opacity monitoring system Performance specification 1 (40
CFR part 60, appendix B).
2. CO continuous emission monitoring Performance specification 4 (40
system. CFR part 60, appendix B); span
value of 1,000 ppm; and
procedure 1 (40 CFR part 60,
appendix F) except relative
accuracy test audits are
required annually instead of
quarterly.
3. CO continuous emission monitoring Performance specification 4 (40
system used to demonstrate emissions CFR part 60, appendix B); and
average under 50 ppm (dry basis). span value of 100 ppm.
4. SO2 continuous emission monitoring Performance specification 2 (40
for sulfur recovery unit with CFR part 60, appendix B); span
oxidation control system or reduction values of 500 ppm SO2 and 10
control system; this monitor must percent O2; use Methods 6 or
include an O2 monitor for correcting 6C and 3A or 3B (40 CFR part
the data for excess air. 60, appendix A) for certifying
O2 monitor; and procedure 1
(40 CFR part 60, appendix F)
except relative accuracy test
audits are required annually
instead of quarterly.
5. Reduced sulfur and O2 continuous Performance specification 5 (40
emission monitoring system for sulfur CFR part 60, appendix B),
recovery unit with reduction control except calibration drift
system not followed by incineration; specification is 2.5 percent
this monitor must include an O2 of the span value instead of 5
monitor for correcting the data for percent; 450 ppm reduced
excess air unless exempted. sulfur and 10 percent O2; use
Methods 15 or 15A and 3A or 3B
(40 CFR part 60, appendix A)
for certifying O2 monitor; if
Method 3A or 3B yields O2
concentrations below 0.25
percent during the performance
evaluation, the O2
concentration can be assumed
to be zero and the O2 monitor
is not required; and procedure
1 (40 CFR part 60, appendix
F), except relative accuracy
test audits, are required
annually instead of quarterly.
6. Instrument with an air or O2 Performance specification 5 (40
dilution and oxidation system to CFR part 60, appendix B); span
convert reduced sulfur to SO2 for value of 375 ppm SO2 and 10
continuously monitoring the percent O2; use Methods 15 or
concentration of SO2 instead of 15A and 3A or 3B for
reduced sulfur monitor and O2 monitor. certifying O2 monitor; and
procedure 1 (40 CFR part 60,
appendix F), except relative
accuracy test audits, are
required annually instead of
quarterly.
7. TRS continuous emission monitoring Performance specification 5 (40
system for sulfur recovery unit; this CFR part 60, appendix B).
monitor must include an O2 monitor for
correcting the data for excess air.
8. O2 monitor for oxygen concentration. If necessary due to
interferences, locate the
oxygen sensor prior to the
introduction of any outside
gas stream; performance
specification 3 (40 CFR part
60, appendix B; span value for
O2 sensor is 10 percent; and
procedure 1 (40 CFR part 60,
appendix F), except relative
accuracy test audits, are
required annually instead of
quarterly.
------------------------------------------------------------------------
Table 41 to Subpart UUU of Part 63.--Requirements for Installation,
Operation, and Maintenance of Continuous Parameter Monitoring Systems
[As stated in Sec. 63.1572(c)(1), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
If you use a continuous
parameter monitoring system You must * * *
to measure and record * * *
------------------------------------------------------------------------
1. Voltage and secondary At least monthly, inspect all components
current or total power of the continuous parameter monitoring
input. system for integrity and all electrical
connections for continuity; and record
the results of each inspection.
[[Page 17819]]
2. Pressure drop 1........... Locate the pressure sensor(s) in a
position that provides a representative
measurement of the pressure; minimize or
eliminate pulsating pressure, vibration,
and internal and external corrosion; use
a gauge with an accuracy 2
percent over the operating range; check
pressure tap for plugs at least once a
week; using a manometer, check gauge
calibration quarterly and transducer
calibration monthly; for a semi-
regenerative catalytic reforming unit,
you can check the calibration quarterly
and monthly or prior to regeneration,
whichever is longer; record the results
of each calibration; conduct calibration
checks any time the sensor exceeds the
manufacturer's specified maximum
operating pressure range, or install a
new pressure sensor; at least monthly,
inspect all components for integrity,
all electrical connections for
continuity, and all mechanical
connections for leakage; and record the
results of each inspection.
3. Air flow rate, gas flow Locate the flow sensor(s) and other
rate, or total water (or necessary equipment such as
scrubbing liquid) flow rate. straightening vanes in a position that
provides representative flow; use a flow
rate sensor with an accuracy within
5 percent; reduce swirling
flow or abnormal velocity distributions
due to upstream and downstream
disturbances; conduct a flow sensor
calibration check at least semiannually;
for a semi-regenerative catalytic
reforming unit, you can check the
calibration at least semiannually or
prior to regeneration, whichever is
longer; record the results of each
calibration; if you elect to comply with
Option 3 (Ni lb/hr) or Option 4 (Ni lb/
1,000 lbs of coke burn-off) for the HAP
metal emission limitations in Sec.
63.1564, install the continuous
parameter monitoring system for gas flow
rate as close as practical to the
continuous opacity monitoring system;
and if you don't use a continuous
opacity monitoring system, install the
continuous parameter monitoring system
for gas flow rate as close as practical
to the control device.
4. Combustion zone Install the temperature sensor in the
temperature. combustion zone or in the ductwork
immediately downstream of the combustion
zone before any substantial heat
exchange occurs; locate the temperature
sensor in a position that provides a
representative temperature;
use a temperature sensor with an accuracy
of 1 percent of the
temperature being measured, expressed in
degrees Celsius (C) or 0.5
degrees C, whichever is greater; shield
the temperature sensor system from
electromagnetic interference and
chemical contaminants; if you use a
chart recorder, it must have a
sensitivity in the minor division of at
least 20 degrees Fahrenheit; perform an
electronic calibration at least
semiannually according to the procedures
in the manufacturer's owners manual;
following the electronic calibration,
conduct a temperature sensor validation
check, in which a second or redundant
temperature sensor placed nearby the
process temperature sensor must yield a
reading within 16.7 degrees C of the
process temperature sensor's reading;
record the results of each calibration
and validation check; conduct
calibration and validation checks any
time the sensor exceeds the
manufacturer's specified maximum
operating temperature range, or install
a new temperature sensor; and at least
monthly, inspect all components for
integrity and all electrical connections
for continuity, oxidation, and galvanic
corrosion.
5. pH........................ Locate the pH sensor in a position that
provides a representative measurement of
pH; ensure the sample is properly mixed
and representative of the fluid to be
measured; check the pH meter's
calibration on at least two points every
8 hours of process operation;
at least monthly, inspect all components
for integrity and all electrical
components for continuity; record the
results of each inspection; and if you
use pH strips to measure the pH of the
water exiting a wet scrubber as an
alternative to a continuous parameter
monitoring system, you must use pH
strips with an accuracy of 10 percent.
6. HCl concentration......... Use a colormetric tube sampling system
with a printed numerical scale in ppmv,
a standard measurement range of 1 to 10
ppmv (or 1 to 30 ppmv if applicable),
and a standard deviation for measured
values of no more than 15
percent. System must include a gas
detection pump and hot air probe if
needed for the measurement range.
------------------------------------------------------------------------
1 Not applicable to non-venturi wet scrubbers of the jet-ejector design.
Table 42 to Subpart UUU of Part 63.--Additional Information for Initial
Notification of Compliance Status
[As stated in Sec. 63.1574(d), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
You must provide this additional
For * * * information * * *
------------------------------------------------------------------------
1. Identification of affected Nature, size, design, method of
sources and emission points. operation, operating design capacity of
each affected source; identify each
emission point for each HAP; identify
any affected source or vent associated
with an affected source not subject to
the requirements of subpart UUU.
[[Page 17820]]
2. Initial compliance........ Identification of each emission
limitation you will meet for each
affected source, including any option
you select (i.e., NSPS, PM or Ni, flare,
percent reduction, concentration,
options for bypass lines); if
applicable, certification that you have
already conducted a performance test to
demonstrate initial compliance with the
NSPS for an affected source;
certification that the vents meet the
applicable emission limit and the
continuous opacity or that the emission
monitoring system meets the applicable
performance specification; if
applicable, certification that you have
installed and verified the operational
status of equipment by your compliance
date for each bypass line that meets the
requirements of Option 2, 3, or 4 in
Sec. 63.1569 and what equipment you
installed; identification of the
operating limit for each affected
source, including supporting
documentation; if your affected source
is subject to the NSPS, certification of
compliance with NSPS emission
limitations and performance
specifications; a brief description of
performance test conditions (capacity,
feed quality, catalyst, etc.); an
engineering assessment (if applicable);
and if applicable, the flare design
(e.g., steam-assisted, air-assisted, or
non-assisted), all visible emission
readings, heat content determinations,
flow rate measurements, and exit
velocity determinations made during the
Method 22 test.
3. Continuous compliance..... Each monitoring option you elect; and
identification of any unit or vent for
which monitoring is not required; and
the definition of ``operating day.''
(This definition, subject to approval by
the applicable permitting authority,
must specify the times at which a 24-hr
operating day begins and ends.)
------------------------------------------------------------------------
Table 43 to Subpart UUU of Part 63.--Requirements for Reports
[As stated in Sec. 63.1575(a), you must meet each requirement in the
following table that applies to you]
------------------------------------------------------------------------
The report must You must submit
You must submit a(n) * * * contain * * * the report * * *
------------------------------------------------------------------------
1. Compliance report.......... If there are not Semiannually
deviations from any according to
emission limitation the
or work practice requirements in
standard that applies Sec. 63.1575(b
to you, a statement ).
that there were no
deviations from the
standards during the
reporting period and
that no continuous
opacity monitoring
system or continuous
emission monitoring
system was
inoperative,
inactive, out-of-
control, repaired, or
adjusted;
and if you have a
deviation from any
emission limitation
or work practice
standard during the
reporting period, the
report must contain
the information in
Sec. 63.1575(d) or
(e)
------------------------------------------------------------------------
Table 44 to Subpart UUU of Part 63.--Applicability of NESHAP General Provisions to Subpart UUU
[As stated in Sec. 63.1577, you must meet each requirement in the following table that applies to you]
----------------------------------------------------------------------------------------------------------------
Citation Subject Applies to subpart UUU Explanation
----------------------------------------------------------------------------------------------------------------
Sec. 63.1........................ Applicability........ Yes. Except that subpart
UUU specifies
calendar or
operating day.
Sec. 63.2........................ Definitions.......... Yes.
Sec. 63.3........................ Units and Yes.
Abbreviations.
Sec. 63.4........................ Prohibited Activities Yes.
Sec. 63.5(a)-(c)................. Construction and Yes............................ In Sec. 63.5(b)(4),
Reconstruction. replace the
reference to Sec.
63.9 with Sec.
63.9(b)(4) and (5).
Sec. 63.5(d)(1)(i)............... Application for Yes............................ Except, subpart UUU
Approval of specifies the
Construction or application is
Reconstruction--Gene submitted as soon
ral Application as practicable
Requirements. before startup but
no later than 90
days (rather than
60) after the
promulgation date
where construction
or reconstruction
had commenced and
initial startup had
not occurred before
promulgation.
Sec. 63.5(d)(1)(ii).............. ..................... Yes............................ Except that emission
estimates specified
in Sec.
63.5(d)(1)(ii)(H)
are not required.
Sec. 63.5(d)(1)(iii)............. ..................... No............................. Subpart UUU
specifies
submission of
notification of
compliance status.
Sec. 63.5(d)(2).................. ..................... No.
Sec. 63.5(d)(3).................. ..................... Yes............................ Except that Sec.
63.5(d)(3)(ii) does
not apply.
Sec. 63.5(d)(4).................. ..................... Yes.
Sec. 63.5(e)..................... Approval of
Construction or
Reconstruction.
[[Page 17821]]
Sec. 63.5(f)(1).................. Approval of Yes............................
Construction or
Reconstruction Based
on State Review.
Sec. 63.5(f)(2).................. ..................... Yes............................ Except that 60 days
is changed to 90
days and cross-
reference to Sec.
63.9(b)(2) does not
apply.
Sec. 63.6(a)..................... Compliance with Yes............................
Standards and
Maintenance--Applica
bility.
Sec. 63.6(b)(1)-(4).............. Compliance Dates for Yes............................
New and
Reconstructed
Sources.
Sec. 63.6(b)(5).................. ..................... Yes............................ Except that subpart
UUU specifies
different
compliance dates
for sources.
Sec. 63.6(b)(6).................. [Reserved]........... Not applicable.................
Sec. 63.6(b)(7).................. Compliance Dates for Yes............................
New and
Reconstructed Area
Sources That Become
Major.
Sec. 63.6(c)(1)-(2).............. Compliance Dates for Yes............................ Except that for
Existing Sources. subpart UUU
specifies different
compliance dates
for sources subject
to Tier II gasoline
sulfur control
requirements.
Sec. 63.6(c)(3)-(4).............. [Reserved]........... Not applicable.................
Sec. 63.6(c)(5).................. Compliance Dates for Yes............................
Existing Area
Sources That Become
Major.
Sec. 63.6(d)..................... [Reserved]........... Not applicable.................
Sec. 63.6(e)(1)-(2).............. Operation and Yes............................
Maintenance
Requirements.
Sec. 63.6(e)(3)(i)-(iii)......... Startup, Shutdown, Yes............................
and Malfunction Plan.
Sec. 63.6(e)(3)(iv).............. ..................... Yes............................ Except that reports
of actions not
consistent with
plan are not
required within 2
and 7 days of
action but rather
must be included in
next periodic
report.
Sec. 63.6(e)(3)(v)-(viii)........ ..................... Yes............................ The owner or
operator is only
required to keep
the latest version
of the plan.
Sec. 63.6(f)(1)-(2)(iii)(C)...... Compliance with Yes............................
Emission Standards.
Sec. 63.6(f)(2)-(iii)(D)......... ..................... No.............................
Sec. 63.6(f)(2)(iv)-(v).......... ..................... Yes............................
Sec. 63.6(f)(3).................. ..................... Yes............................
Sec. 63.6(g)..................... Alternative Standard. Yes............................
Sec. 63.6(h)..................... Opacity/VE Standards. Yes............................
Sec. 63.6(h)(2)(i)............... Determining No............................. Subpart UUU
Compliance with specifies methods.
Opacity/VE Standards.
Sec. 63.6(h)(2)(ii).............. [Reserved]........... Not applicable.................
Sec. 63.6(h)(2)(iii)............. ..................... Yes............................
Sec. 63.6(h)(3).................. [Reserved]........... Not applicable.................
Sec. 63.6(h)(4).................. Notification of Yes............................ Applies to Method 22
Opacity/VE tests.
Observation Date.
Sec. 63.6(h)(5).................. Conducting Opacity/VE No.............................
Observations.
Sec. 63.6(h)(6).................. Records of Conditions Yes............................ Applies to Method 22
During Opacity/VE observations.
Observations.
Sec. 63.6(h)(7)(i)............... Report COM Monitoring Yes............................
Data from
Performance Test.
Sec. 63.6(h)(7)(ii).............. Using COM Instead of No.............................
Method 9.
Sec. 63.6(h)(7)(iii)............. Averaging Time for Yes............................
COM during
Performance Test.
Sec. 63.6(h)(7)(iv).............. COM Requirements..... Yes............................
Sec. 63.6(h)(8).................. Determining Yes............................
Compliance with
Opacity/VE Standards.
[[Page 17822]]
Sec. 63.6(h)(9).................. Adjusted Opacity Yes............................
Standard.
Sec. 63.6(i)(1)-(14)............. Extension of Yes............................ Not applicable to an
Compliance. affected source
with Tier II
compliance date.
May be applicable
to an affected
source exempt from
Tier II rule.
Sec. 63.6(i)(15)................. [Reserved]........... Not applicable.................
Sec. 63.6(i)(16)................. ..................... Yes............................
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[FR Doc. 02-7222 Filed 4-10-02; 8:45 am]
BILLING CODE 6560-50-P