chapter, floating roof storage vessels must be equipped with guidepole
controls as described in Appendix I: Acceptable Controls for Slotted
Guidepoles Under the Storage Tank Emissions Reduction Partnership
Program (available at http://www.epa.gov/ttn/atw/petrefine/petrefpg.html).
    (viii) If a flare is used as a control device for a storage vessel,
on and after [THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE
FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER], the owner or operator
must meet the requirements of Sec.  63.670 instead of the requirements
referenced from part 60, subpart Kb of this chapter for that flare.
    (9) * * *
    (i) If the owner or operator determines that it is unsafe to
perform the seal gap measurements required in Sec.  60.113a(a)(1) of
subpart Ka because the floating roof appears to be structurally unsound
and poses an imminent danger to inspecting personnel, the owner or
operator shall comply with the requirements in either Sec.
63.120(b)(7)(i) or Sec.  63.120(b)(7)(ii) of subpart G (only up to the
compliance date specified in paragraph (h) of this section for

compliance with Sec.  63.660, as applicable) or either Sec.
63.1063(c)(2)(iv)(A) or Sec.  63.1063(c)(2)(iv)(B) of subpart WW.
* * * * *
    (10) Storage vessels described by paragraph (n)(1) of this section
are to comply with 40 CFR part 61, subpart Y except as provided in
paragraphs (n)(10)(i) through (n)(8)(vi) of this section. Storage
vessels described by paragraph (n)(2) electing to comply with 40 CFR
part 61, subpart Y shall comply with subpart Y except as provided for
in paragraphs (n)(10)(i) through (n)(10)(viii) of this section.
    (i) Storage vessels that are to comply with Sec.  61.271(b) of this
chapter are exempt from the secondary seal requirements of Sec.
61.271(b)(2)(ii) of this chapter during the gap measurements for the
primary seal required by Sec.  61.272(b) of this chapter.
    (ii) If the owner or operator determines that it is unsafe to
perform the seal gap measurements required in Sec.  61.272(b) of this
chapter or to inspect the vessel to determine compliance with Sec.
61.272(a) of this chapter because the roof appears to be structurally
unsound and poses an imminent danger to inspecting personnel, the owner
or operator shall comply with the requirements in either Sec.
63.120(b)(7)(i) or Sec.  63.120(b)(7)(ii) of subpart G (only up to the
compliance date specified in paragraph (h) of this section for
compliance with Sec.  63.660, as applicable) or either Sec.
63.1063(c)(2)(iv)(A) or Sec.  63.1063(c)(2)(iv)(B) of subpart WW.
    (iii) If a failure is detected during the inspections required by
Sec.  61.272(a)(2) of this chapter or during the seal gap measurements
required by Sec.  61.272(b)(1) of this chapter, and the vessel cannot
be repaired within 45 days and the vessel cannot be emptied within 45
days, the owner or operator may utilize up to two extensions of up to
30 additional calendar days each. The owner or operator is not required
to provide a request for the extension to the Administrator.
    (iv) If an extension is utilized in accordance with paragraph
(n)(10)(iii) of this section, the owner or operator shall, in the next
periodic report, identify the vessel, provide the information listed in
Sec.  61.272(a)(2) or Sec.  61.272(b)(4)(iii) of this chapter, and
describe the nature and date of the repair made or provide the date the
storage vessel was emptied.
    (v) Owners and operators of storage vessels complying with 40 CFR
part 61, subpart Y may submit the inspection reports required by Sec.
61.275(a), (b)(1), and (d) of this chapter as part of the periodic
reports required by this subpart, rather than within the 60-day period
specified in Sec.  61.275(a), (b)(1), and (d) of this chapter.
    (vi) The reports of rim seal inspections specified in Sec.
61.275(d) of this chapter are not required if none of the measured gaps
or calculated gap areas exceed the limitations specified in Sec.
61.272(b)(4) of this chapter. Documentation of the inspections shall be
recorded as specified in Sec.  61.276(a) of this chapter.
    (vii) To be in compliance with Sec.  61.271(b)(3) of this chapter,
floating roof storage vessels must be equipped with guidepole controls
as described in Appendix I: Acceptable Controls for Slotted Guidepoles
Under the Storage Tank Emissions Reduction Partnership Program
(available at http://www.epa.gov/ttn/atw/petrefine/petrefpg.html).
    (viii) If a flare is used as a control device for a storage vessel,
on and after [THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE
FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER], the owner or operator
must meet the requirements of Sec.  63.670 instead of the requirements
referenced from part 61, subpart Y of this chapter for that flare.
    (o) * * *
    (2) * * *
    (i) Comply with paragraphs (o)(2)(i)(A) through (D) of this
section.
* * * * *
    (D) If a flare is used as a control device, on and after [THE DATE
3 YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN
THE FEDERAL REGISTER], the flare shall meet the requirements of Sec.
63.670. Prior to [THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE
FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER], the flare shall meet
the applicable requirements of 40 CFR part 61, subpart FF and subpart G
of this part, or the requirements of Sec.  63.670.
    (ii) Comply with paragraphs (o)(2)(ii)(A) through (C) of this
section.
* * * * *
    (C) If a flare is used as a control device, on and after [THE DATE
3 YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN
THE FEDERAL REGISTER], the flare shall meet the requirements of Sec.
63.670. Prior to [THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE
FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER], the flare shall meet
the applicable requirements of 40 CFR part 61, subpart FF and subpart G
of this part, or the requirements of Sec.  63.670.
    (p) * * *
    (2) Equipment leaks that are also subject to the provisions of 40
CFR part 60, subpart GGGa, are required to comply only with the
provisions specified in 40 CFR part 60, subpart GGGa. Owners and
operators of equipment leaks that are subject to the provisions of 40
CFR part 60, subpart GGGa and subject to this subpart may elect to
monitor equipment leaks following the provisions in Sec.  63.661,
provided that the equipment is in compliance with all other provisions
of 40 CFR part 60, subpart GGGa.
* * * * *
0
14. Section 63.641 is amended by:
0
a. Adding, in alphabetical order, new definitions of ``Assist air,''
``Assist steam,'' ``Center steam,'' ``Closed blowdown system,''
``Combustion zone,'' ``Combustion zone gas,'' ``Decoking operations,''
``Delayed coking unit,'' ``Flare,'' ``Flare purge gas,'' ``Flare
supplemental gas,'' ``Flare sweep gas,'' ``Flare vent gas,''
``Halogenated vent stream or halogenated stream,'' ``Halogens and
hydrogen halides,'' ``Lower steam,'' ``Net heating value,'' ``Perimeter
assist air,'' ``Pilot gas,'' ``Premix assist air,'' ``Total steam,''
and ``Upper steam''; and
0
b. Revising the definitions of ``Delayed coker vent,'' ``Emission
point,'' ``Group 1 storage vessel,'' ``Miscellaneous process vent,''
``Periodically discharged,'' and ``Reference control technology for
storage vessels''.
    The revisions and additions read as follows:

Sec.  63.641  Definitions.

* * * * *
    Assist air means all air that intentionally is introduced prior to
or at a flare tip through nozzles or other hardware conveyance for the
purposes including, but not limited to, protecting the design of the
flare tip, promoting turbulence for mixing or inducing air into the
flame. Assist air includes premix assist air and perimeter assist air.
Assist air does not include the surrounding ambient air.
    Assist steam means all steam that intentionally is introduced prior
to or at a flare tip through nozzles or other hardware conveyance for
the purposes including, but not limited to, protecting the design of
the flare tip, promoting turbulence for mixing or inducing air into the
flame. Assist steam includes, but is not necessarily limited to, center
steam, lower steam and upper steam.
* * * * *
    Center steam means the portion of assist steam introduced into the
stack of a flare to reduce burnback.

    Closed blowdown system means a system used for depressuring process
vessels that is not open to the atmosphere and is configured of piping,
ductwork, connections, accumulators/knockout drums, and, if necessary,
flow inducing devices that transport gas or vapor from process vessel
to a control device or back into the process.
* * * * *
    Combustion zone means the area of the flare flame where the
combustion zone gas combines for combustion.
    Combustion zone gas means all gases and vapors found just after a
flare tip. This gas includes all flare vent gas, total steam, and
premix air.
* * * * *
    Decoking operations means the sequence of steps conducted at the
end of the delayed coking unit's cooling cycle to open the coke drum to
the atmosphere in order to remove coke from the coke drum. Decoking
operations begin at the end of the cooling cycle when steam released
from the coke drum is no longer discharged via the delayed coker vent
to the unit's blowdown system but instead is vented directly to the
atmosphere. Decoking operations include atmospheric depressuring
(venting), deheading, draining, and decoking (coke cutting).
    Delayed coker vent means a vent that is typically intermittent in
nature, and usually occurs only during the cooling cycle of a delayed
coking unit coke drum when vapor from the coke drums cannot be sent to
the fractionator column for product recovery, but instead is routed to
the atmosphere through the delayed coking unit's blowdown system. The
emissions from the decoking operations, which include direct
atmospheric venting, deheading, draining, or decoking (coke cutting),
are not considered to be delayed coker vents.
    Delayed coking unit means a refinery process unit in which high
molecular weight petroleum derivatives are thermally cracked and
petroleum coke is produced in a series of closed, batch system
reactors. A delayed coking unit includes, but is not limited to, all of
the coke drums associated with a single fractionator; the fractionator,
including the bottoms receiver and the overhead condenser; the coke
drum cutting water and quench system, including the jet pump and coker
quench water tank; and the coke drum blowdown recovery compressor
system.
* * * * *
    Emission point means an individual miscellaneous process vent,
storage vessel, wastewater stream, equipment leak, decoking operation
or heat exchange system associated with a petroleum refining process
unit; an individual storage vessel or equipment leak associated with a
bulk gasoline terminal or pipeline breakout station classified under
Standard Industrial Classification code 2911; a gasoline loading rack
classified under Standard Industrial Classification code 2911; or a
marine tank vessel loading operation located at a petroleum refinery.
* * * * *
    Flare means a combustion device lacking an enclosed combustion
chamber that uses an uncontrolled volume of ambient air to burn gases.
For the purposes of this rule, the definition of flare includes, but is
not necessarily limited to, air-assisted flares, steam-assisted flares
and non-assisted flares.
    Flare purge gas means gas introduced between a flare header's water
seal and the flare tip to prevent oxygen infiltration (backflow) into
the flare tip. For a flare with no water seal, the function of flare
purge gas is performed by flare sweep gas and, therefore, by
definition, such a flare has no flare purge gas.
    Flare supplemental gas means all gas introduced to the flare in
order to improve the combustible characteristics of combustion zone
gas.
    Flare sweep gas means, for a flare with a flare gas recovery
system, the minimum amount of gas necessary to maintain a constant flow
of gas through the flare header in order to prevent oxygen buildup in
the flare header; flare sweep gas in these flares is introduced prior
to and recovered by the flare gas recovery system. For a flare without
a flare gas recovery system, flare sweep gas means the minimum amount
of gas necessary to maintain a constant flow of gas through the flare
header and out the flare tip in order to prevent oxygen buildup in the
flare header and to prevent oxygen infiltration (backflow) into the
flare tip.
    Flare vent gas means all gas found just prior to the flare tip.
This gas includes all flare waste gas (i.e., gas from facility
operations that is directed to a flare for the purpose of disposing of
the gas), flare sweep gas, flare purge gas and flare supplemental gas,
but does not include pilot gas, total steam or assist air.
* * * * *
    Group 1 storage vessel means:
    (1) Prior to [THE DATE OF PUBLICATION OF THE FINAL RULE AMENDMENTS
IN THE FEDERAL REGISTER]:
    (i) A storage vessel at an existing source that has a design
capacity greater than or equal to 177 cubic meters and stored-liquid
maximum true vapor pressure greater than or equal to 10.4 kilopascals
and stored-liquid annual average true vapor pressure greater than or
equal to 8.3 kilopascals and annual average HAP liquid concentration
greater than 4 percent by weight total organic HAP;
    (ii) A storage vessel at a new source that has a design storage
capacity greater than or equal to 151 cubic meters and stored-liquid
maximum true vapor pressure greater than or equal to 3.4 kilopascals
and annual average HAP liquid concentration greater than 2 percent by
weight total organic HAP; or
    (iii) A storage vessel at a new source that has a design storage
capacity greater than or equal to 76 cubic meters and less than 151
cubic meters and stored-liquid maximum true vapor pressure greater than
or equal to 77 kilopascals and annual average HAP liquid concentration
greater than 2 percent by weight total organic HAP.
    (2) On and after [THE DATE OF PUBLICATION OF THE FINAL RULE
AMENDMENTS IN THE FEDERAL REGISTER]:
    (i) A storage vessel at an existing source that has a design
capacity greater than or equal to 151 cubic meters (40,000 gallons) and
stored-liquid maximum true vapor pressure greater than or equal to 5.2
kilopascals (0.75 pounds per square inch) and annual average HAP liquid
concentration greater than 4 percent by weight total organic HAP;
    (ii) A storage vessel at an existing source that has a design
storage capacity greater than or equal to 76 cubic meters (20,000
gallons) and less than 151 cubic meters (40,000 gallons) and stored-
liquid maximum true vapor pressure greater than or equal to 13.1
kilopascals (1.9 pounds per square inch) and annual average HAP liquid
concentration greater than 4 percent by weight total organic HAP;
    (iii) A storage vessel at a new source that has a design storage
capacity greater than or equal to 151 cubic meters (40,000 gallons) and
stored-liquid maximum true vapor pressure greater than or equal to 3.4
kilopascals (0.5 pounds per square inch) and annual average HAP liquid
concentration greater than 2 percent by weight total organic HAP; or
    (iv) A storage vessel at a new source that has a design storage
capacity greater than or equal to 76 cubic meters (20,000 gallons) and
less than 151 cubic meters (40,000 gallons) and stored-liquid maximum
true vapor pressure greater than or equal to 13.1 kilopascals (1.9
pounds per square inch) and annual average HAP liquid concentration

greater than 2 percent by weight total organic HAP.
* * * * *
    Halogenated vent stream or halogenated stream means a stream
determined to have a mass rate of halogen atoms of 0.45 kilograms per
hour or greater, determined by the procedures presented in Sec.
63.115(d)(2)(v). The following procedures may be used as alternatives
to the procedures in Sec.  63.115(d)(2)(v)(A):
    (1) Process knowledge that halogen or hydrogen halides are present
in a vent stream and that the vent stream is halogenated, or
    (2) Concentration of compounds containing halogen and hydrogen
halides measured by Method 26 or 26A of part 60, Appendix A-8 of this
chapter, or
    (3) Concentration of compounds containing hydrogen halides measured
by Method 320 of Appendix A of this part.
    Halogens and hydrogen halides means hydrogen chloride (HCl),
chlorine (Cl2), hydrogen bromide (HBr), bromine
(Br2), and hydrogen fluoride (HF).
* * * * *
    Lower steam means the portion of assist steam piped to an exterior
annular ring near the lower part of a flare tip, which then flows
through tubes to the flare tip, and ultimately exits the tubes at the
flare tip.
* * * * *
    Miscellaneous process vent means a gas stream containing greater
than 20 parts per million by volume organic HAP that is continuously or
periodically discharged from a petroleum refining process unit meeting
the criteria specified in Sec.  63.640(a). Miscellaneous process vents
include 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 prior to control or discharge to the atmosphere. Miscellaneous
process vents include vent streams from: caustic wash accumulators,
distillation tower condensers/accumulators, flash/knockout drums,
reactor vessels, scrubber overheads, stripper overheads, vacuum pumps,
steam ejectors, hot wells, high point bleeds, wash tower overheads,
water wash accumulators, blowdown condensers/accumulators, and delayed
coker vents. Miscellaneous process vents do not include:
    (1) Gaseous streams routed to a fuel gas system, provided that on
and after [THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL
RULE AMENDMENTS IN THE FEDERAL REGISTER], any flares receiving gas from
the fuel gas system are in compliance with Sec.  63.670;
    (2) Relief valve discharges regulated under Sec.  63.648;
    (3) Leaks from equipment regulated under Sec.  63.648;
    (4) [Reserved];
    (5) In situ sampling systems (onstream analyzers) until [THE DATE 3
YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN THE
FEDERAL REGISTER]. After this date, these sampling systems will be
included in the definition of miscellaneous process vents;
    (6) Catalytic cracking unit catalyst regeneration vents;
    (7) Catalytic reformer regeneration vents;
    (8) Sulfur plant vents;
    (9) Vents from control devices such as scrubbers, boilers,
incinerators, and electrostatic precipitators applied to catalytic
cracking unit catalyst regeneration vents, catalytic reformer
regeneration vents, and sulfur plant vents;
    (10) Vents from any stripping operations applied to comply with the
wastewater provisions of this subpart, subpart G of this part, or 40
CFR part 61, subpart FF;
    (11) Emissions associated with delayed coking unit decoking
operations;
    (12) Vents from storage vessels;
    (13) Emissions from wastewater collection and conveyance systems
including, but not limited to, wastewater drains, sewer vents, and sump
drains; and
    (14) Hydrogen production plant vents through which carbon dioxide
is removed from process streams or through which steam condensate
produced or treated within the hydrogen plant is degassed or deaerated.
    Net heating value means the energy released as heat when a compound
undergoes complete combustion with oxygen to form gaseous carbon
dioxide and gaseous water (also referred to as lower heating value).
* * * * *
    Perimeter assist air means the portion of assist air introduced at
the perimeter of the flare tip or above the flare tip. Perimeter assist
air includes air intentionally entrained in lower and upper steam.
Perimeter assist air includes all assist air except premix assist air.
    Periodically discharged means discharges that are intermittent and
associated with routine operations, maintenance activities, startups,
shutdowns, malfunctions, or process upsets.
* * * * *
    Pilot gas means gas introduced into a flare tip that provides a
flame to ignite the flare vent gas.
* * * * *
    Premix assist air means the portion of assist air that is
introduced to the flare vent gas prior to the flare tip. Premix assist
air also includes any air intentionally entrained in center steam.
* * * * *
    Reference control technology for storage vessels means either:
    (1) For Group 1 storage vessels complying with Sec.  63.660:
    (i) An internal floating roof meeting the specifications of
Sec. Sec.  63.1063(a)(1)(i) and (b);
    (ii) An external floating roof meeting the specifications of Sec.
63.1063(a)(1)(ii), (a)(2), and (b);
    (iii) An external floating roof converted to an internal floating
roof meeting the specifications of Sec.  63.1063(a)(1)(i) and (b); or
    (iv) A closed-vent system to a control device that reduces organic
HAP emissions by 95 percent, or to an outlet concentration of 20 parts
per million by volume (ppmv).
    (v) For purposes of emissions averaging, these four technologies
are considered equivalent.
    (2) For all other storage vessels:
    (i) An internal floating roof meeting the specifications of Sec.
63.119(b) of subpart G except for Sec.  63.119(b)(5) and (b)(6);
    (ii) An external floating roof meeting the specifications of Sec.
63.119(c) of subpart G except for Sec.  63.119(c)(2);
    (iii) An external floating roof converted to an internal floating
roof meeting the specifications of Sec.  63.119(d) of subpart G except
for Sec.  63.119(d)(2); or
    (iv) A closed-vent system to a control device that reduces organic
HAP emissions by 95 percent, or to an outlet concentration of 20 parts
per million by volume.
    (v) For purposes of emissions averaging, these four technologies
are considered equivalent.
* * * * *
    Total steam means the total of all steam that is supplied to a
flare and includes, but is not limited to, lower steam, center steam
and upper steam.
    Upper steam means the portion of assist steam introduced via
nozzles located on the exterior perimeter of the upper end of the flare
tip.
* * * * *
0
15. Section 63.642 is amended by:
0
a. Adding paragraph (b);
0
b. Revising paragraph (d)(3);

0
c. Revising paragraph (e);
0
d. Revising paragraph (i);
0
e. Revising paragraph (k) introductory text;
0
f. Revising paragraph (k)(1);
0
g. Revising paragraph (l) introductory text;
0
h. Revising paragraph (l)(2); and
0
i. Adding paragraph (n).
    The revisions and additions read as follows:

Sec.  63.642  General standards.

* * * * *
    (b) The emission standards set forth in this subpart shall apply at
all times.
* * * * *
    (d) * * *
    (3) Performance tests shall be conducted at maximum representative
operating capacity for the process. During the performance test, an
owner or operator shall operate the control device at either maximum or
minimum representative operating conditions for monitored control
device parameters, whichever results in lower emission reduction. An
owner or operator shall not conduct a performance test during startup,
shutdown, periods when the control device is bypassed or periods when
the process, monitoring equipment or control device is not operating
properly. The owner/operator may not conduct performance tests during
periods of malfunction. The owner or operator must record the process
information that is necessary to document operating conditions during
the test and include in such record an explanation to support that the
test was conducted at maximum representative operating capacity. Upon
request, the owner or operator shall make available to the
Administrator such records as may be necessary to determine the
conditions of performance tests.
* * * * *
    (e) All applicable records shall be maintained as specified in
Sec.  63.655(i).
* * * * *
    (i) The owner or operator of an existing source shall demonstrate
compliance with the emission standard in paragraph (g) of this section
by following the procedures specified in paragraph (k) of this section
for all emission points, or by following the emissions averaging
compliance approach specified in paragraph (l) of this section for
specified emission points and the procedures specified in paragraph
(k)(1) of this section.
* * * * *
    (k) The owner or operator of an existing source may comply, and the
owner or operator of a new source shall comply, with the applicable
provisions in Sec. Sec.  63.643 through 63.645, 63.646 or 63.660,
63.647, 63.650, and 63.651, as specified in Sec.  63.640(h).
    (1) The owner or operator using this compliance approach shall also
comply with the requirements of Sec. Sec.  63.648 and/or 63.649 or
63.661, 63.654, 63.655, 63.657, 63.658, 63.670 and 63.671, as
applicable.
* * * * *
    (l) The owner or operator of an existing source may elect to
control some of the emission points within the source to different
levels than specified under Sec. Sec.  63.643 through 63.645, 63.646 or
63.660, 63.647, 63.650, and 63.651, as applicable according to Sec.
63.640(h), by using an emissions averaging compliance approach as long
as the overall emissions for the source do not exceed the emission
level specified in paragraph (g) of this section. The owner or operator
using emissions averaging shall meet the requirements in paragraphs
(l)(1) and (2) of this section.
* * * * *
    (2) Comply with the requirements of Sec. Sec.  63.648 and/or 63.649
or 63.661, 63.654, 63.652, 63.653, 63.655, 63.657, 63.658, 63.670 and
63.671, as applicable.
* * * * *
    (n) At all times, the owner or operator must operate and maintain
any affected source, including associated air pollution control
equipment and monitoring equipment, in a manner consistent with safety
and good air pollution control practices for minimizing emissions. The
general duty to minimize emissions does not require the owner operator
to make any further efforts to reduce emissions if levels required by
the applicable standard have been achieved. Determination of whether a
source is operating in compliance with operation and maintenance
requirements will be based on information available to the
Administrator which may include, but is not limited to, monitoring
results, review of operation and maintenance procedures, review of
operation and maintenance records, and inspection of the source.
0
16. Section 63.643 is amended by revising paragraph (a)(1) to read as
follows:

Sec.  63.643  Miscellaneous process vent provisions.

    (a) * * *
    (1) Reduce emissions of organic HAP's using a flare. On and after
[THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL RULE
AMENDMENTS IN THE FEDERAL REGISTER], the flare shall meet the
requirements of Sec.  63.670. Prior to [THE DATE 3 YEARS AFTER THE DATE
OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER],
the flare shall meet the requirements of Sec.  63.11(b) of subpart A or
the requirements of Sec.  63.670.
* * * * *
0
17. Section 63.644 is amended by:
0
a. Revising paragraph (a) introductory text;
0
b. Revising paragraph (a)(2); and
0
c. Revising paragraph (c).
    The revisions read as follows:

Sec.  63.644  Monitoring provisions for miscellaneous process vents.

    (a) Except as provided in paragraph (b) of this section, each owner
or operator of a Group 1 miscellaneous process vent that uses a
combustion device to comply with the requirements in Sec.  63.643(a)
shall install the monitoring equipment specified in paragraph (a)(1),
(a)(2), (a)(3), or (a)(4) of this section, depending on the type of
combustion device used. All monitoring equipment shall be installed,
calibrated, maintained, and operated according to manufacturer's
specifications or other written procedures that provide adequate
assurance that the equipment will monitor accurately and must meet the
applicable minimum accuracy, calibration and quality control
requirements specified in table 13 of this subpart.
* * * * *
    (2) Where a flare is used prior to [THE DATE 3 YEARS AFTER THE DATE
OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER], a
device (including but not limited to a thermocouple, an ultraviolet
beam sensor, or an infrared sensor) capable of continuously detecting
the presence of a pilot flame is required, or the requirements of Sec.
63.670 shall be met. Where a flare is used on and after [THE DATE 3
YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN THE
FEDERAL REGISTER], the requirements of Sec.  63.670 shall be met.
* * * * *
    (c) The owner or operator of a Group 1 miscellaneous process vent
using a vent system that contains bypass lines that could divert a vent
stream away from the control device used to comply with paragraph (a)
of this section shall comply with either paragraph (c)(1) or (2) of
this section. Use of the bypass at any time to divert a Group 1
miscellaneous process vent stream is an emissions standards violation.
Equipment such as low leg drains and equipment subject to Sec.  63.648
are not subject to this paragraph.

    (1) Install, operate, calibrate, and maintain a continuous
parameter monitoring system for flow, as specified in paragraphs
(c)(1)(i) through (iii) of this section.
    (i) Install a continuous parameter monitoring system for flow at
the entrance to any bypass line. The continuous parameter monitoring
system must record the volume of the gas stream that bypassed the
control device and must meet the applicable minimum accuracy,
calibration and quality control requirements specified in table 13 of
this subpart.
    (ii) Equip the continuous parameter monitoring system for flow with
an alarm system that will alert an operator immediately and
automatically when flow is detected in the bypass line. Locate the
alarm such that an operator can easily detect and recognize the alert.
    (iii) Reports and records shall be generated as specified in Sec.
63.655(g) and (i).
    (2) Secure the bypass line valve in the non-diverting position with
a car-seal or a lock-and-key type configuration. A visual inspection of
the seal or closure mechanism shall be performed at least once every
month to ensure that the valve is maintained in the non-diverting
position and that the vent stream is not diverted through the bypass
line.
* * * * *
0
18. Section 63.645 is amended by revising paragraphs (e)(1) and (f)(2)
to read as follows:

Sec.  63.645  Test methods and procedures for miscellaneous process
vents.

* * * * *
    (e) * * *
    (1) Methods 1 or 1A of 40 CFR part 60, Appendix A-1, as
appropriate, shall be used for selection of the sampling site. For
vents smaller than 0.10 meter in diameter, sample at the center of the
vent.
* * * * *
    (f) * * *
    (2) The gas volumetric flow rate shall be determined using Methods
2, 2A, 2C, 2D, or 2F of 40 CFR part 60, Appendix A-1 or Method 2G of 40
CFR part 60, Appendix A-2, as appropriate.
* * * * *
0
19. Section 63.646 is amended by:
0
a. Adding introductory text to Sec.  63.646; and
0
b. Revising paragraph (b)(2).
    The revisions and additions read as follows:

Sec.  63.646  Storage vessel provisions.

    Upon a demonstration of compliance with the standards in Sec.
63.660 by the compliance dates specified in Sec.  63.640(h), the
standards in this section shall no longer apply.
* * * * *
    (b) * * *
    (2) When an owner or operator and the Administrator do not agree on
whether the annual average weight percent organic HAP in the stored
liquid is above or below 4 percent for a storage vessel at an existing
source or above or below 2 percent for a storage vessel at a new
source, an appropriate method (based on the type of liquid stored) as
published by EPA or a consensus-based standards organization shall be
used. Consensus-based standards organizations include, but are not
limited to, the following: ASTM International (100 Barr Harbor Drive,
P.O. Box CB700, West Conshohocken, Pennsylvania 19428-B2959, (800) 262-
1373, http://www.astm.org), the American National Standards Institute
(ANSI, 1819 L Street NW., 6th Floor, Washington, DC 20036, (202) 293-
8020, http://www.ansi.org), the American Gas Association (AGA, 400
North Capitol Street NW., 4th Floor, Washington, DC 20001, (202) 824-
7000, http://www.aga.org), the American Society of Mechanical Engineers
(ASME, Three Park Avenue, New York, NY 10016-5990,<PHONE_NUMBER>,
http://www.asme.org), the American Petroleum Institute (API, 1220 L
Street NW., Washington, DC 20005-4070,<PHONE_NUMBER>, http://www.api.org), and the North American Energy Standards Board (NAESB, 801
Travis Street, Suite 1675, Houston, TX 77002,<PHONE_NUMBER>, http://www.naesb.org).
* * * * *
0
20. Section 63.647 is amended by:
0
a. Revising paragraph (a);
0
b. Redesignating paragraph (c) as paragraph (d); and
0
c. Adding paragraph (c).
    The revisions and additions read as follows:

Sec.  63.647  Wastewater provisions.

    (a) Except as provided in paragraphs (b) and (c) of this section,
each owner or operator of a Group 1 wastewater stream shall comply with
the requirements of Sec. Sec.  61.340 through 61.355 of this chapter
for each process wastewater stream that meets the definition in Sec.
63.641.
* * * * *
    (c) If a flare is used as a control device, on and after [THE DATE
3 YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN
THE FEDERAL REGISTER], the flare shall meet the requirements of Sec.
63.670. Prior to [THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE
FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER], the flare shall meet
the applicable requirements of part 61, subpart FF of this chapter, or
the requirements of Sec.  63.670.
* * * * *
0
21. Section 63.648 is amended by:
0
a. Revising paragraph (a) introductory text;
0
b. Adding paragraphs (a)(3) and (4);
0
c. Revising paragraph (c) introductory text;
0
d. Revising paragraph (c)(2)(ii);
0
e. Adding paragraphs (c)(11) and (12); and
0
f. Adding paragraph (j).
    The revisions and additions read as follows:

Sec.  63.648  Equipment leak standards.

    (a) Each owner or operator of an existing source subject to the
provisions of this subpart shall comply with the provisions of part 60,
subpart VV of this chapter and paragraph (b) of this section except as
provided in paragraphs (a)(1), (a)(2), and (c) through (i) of this
section. Each owner or operator of a new source subject to the
provisions of this subpart shall comply with subpart H of this part
except as provided in paragraphs (c) through (i) of this section. As an
alternative to the monitoring requirements of part 60, subpart VV of
this chapter or subpart H of this part, as applicable, the owner or
operator may elect to monitor equipment leaks following the provisions
in Sec.  63.661.
* * * * *
    (3) On and after [THE DATE OF PUBLICATION OF THE FINAL RULE
AMENDMENTS IN THE FEDERAL REGISTER], for the purpose of complying with
the requirements of Sec.  60.482-6(a)(2) of this chapter, the term
``seal'' or ``sealed'' means that instrument monitoring of the open-
ended valve or line conducted according to the method specified in
Sec.  60.485(b) and, as applicable, Sec.  60.485(c) of this chapter
indicates no readings of 500 parts per million or greater.
    (4) If a flare is used as a control device, on and after [THE DATE
3 YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN
THE FEDERAL REGISTER], the flare shall meet the requirements of Sec.
63.670. Prior to [THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE
FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER], the flare shall meet
the applicable requirements of part 60, subpart VV of this chapter, or
the requirements of Sec.  63.670.
* * * * *

    (c) In lieu of complying with the existing source provisions of
paragraph (a) in this section, an owner or operator may elect to comply
with the requirements of Sec. Sec.  63.161 through 63.169, 63.171,
63.172, 63.175, 63.176, 63.177, 63.179, and 63.180 of subpart H of this
part except as provided in paragraphs (c)(1) through (c)(12) and (e)
through (i) of this section.
* * * * *
    (2) * * *
    (ii) If an owner or operator elects to monitor connectors according
to the provisions of Sec.  63.649, paragraphs (b), (c), or (d), then
the owner or operator shall monitor valves at the frequencies specified
in table 9 of this subpart. If an owner or operator elects to comply
with Sec.  63.649, the owner or operator cannot also elect to comply
with Sec.  63.661.
* * * * *
    (11) On and after [THE DATE OF PUBLICATION OF THE FINAL RULE
AMENDMENTS IN THE FEDERAL REGISTER], for the purpose of complying with
the requirements of Sec.  63.167(a)(2), the term ``seal'' or ``sealed''
means that instrument monitoring of the open-ended valve or line
conducted according to the method specified in Sec.  63.180(b) and, as
applicable, Sec.  63.180(c) of this chapter indicates no readings of
500 parts per million or greater.
    (12) If a flare is used as a control device, on and after [THE DATE
3 YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN
THE FEDERAL REGISTER], the flare shall meet the requirements of Sec.
63.670. Prior to [THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE
FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER], the flare shall meet
the applicable requirements of Sec. Sec.  63.172 and 63.180, or the
requirements of Sec.  63.670.
* * * * *
    (j) Except as specified in paragraph (j)(4) of this section, the
owner or operator must comply with the requirements specified in
paragraphs (j)(1) and (2) of this section for relief valves in organic
HAP gas or vapor service instead of the pressure relief device
requirements of Sec.  60.482-4 or Sec.  63.165, as applicable. Except
as specified in paragraph (j)(4) of this section, the owner or operator
must also comply with the requirements specified in paragraph (j)(3) of
this section for all relief valves in organic HAP service.
    (1) Operating requirements. Except during a pressure release,
operate each relief valve in organic HAP gas or vapor service with an
instrument reading of less than 500 ppm above background as detected by
Method 21 of 40 CFR part 60, Appendix A-7.
    (2) Pressure release requirements. For relief valves in organic HAP
gas or vapor service, the owner or operator must comply with either
paragraph (j)(2)(i) or (ii) of this section following a pressure
release.
    (i) If the relief valve does not consist of or include a rupture
disk, conduct instrument monitoring, as specified in Sec.  60.485(b) or
Sec.  63.180(c), as applicable, no later than 5 calendar days after the
relief valve returns to organic HAP gas or vapor service following a
pressure release to verify that the relief valve is operating with an
instrument reading of less than 500 ppm.
    (ii) If the relief valve consists of or includes a rupture disk,
install a replacement disk as soon as practicable after a pressure
release, but no later than 5 calendar days after the pressure release.
The owner or operator must also conduct instrument monitoring, as
specified in Sec.  60.485(b) or Sec.  63.180(c), as applicable, no
later than 5 calendar days after the relief valve returns to organic
HAP gas or vapor service following a pressure release to verify that
the relief valve is operating with an instrument reading of less than
500 ppm.
    (3) Pressure release management. Except as specified in paragraph
(j)(4) of this section, emissions of organic HAP may not be discharged
to the atmosphere from relief valves in organic HAP service, and on or
before [THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL
RULE AMENDMENTS IN THE FEDERAL REGISTER], the owner or operator shall
comply with the requirements specified in paragraphs (j)(3)(i) and (ii)
of this section for all relief valves in organic HAP service.
    (i) The owner or operator must equip each relief valve in organic
HAP service with a device(s) or use a monitoring system that is capable
of: (1) Identifying the pressure release; (2) recording the time and
duration of each pressure release; and (3) notifying operators
immediately that a pressure release is occurring. The device or
monitoring system may be either specific to the pressure relief device
itself or may be associated with the process system or piping,
sufficient to indicate a pressure release to the atmosphere. Examples
of these types of devices and systems include, but are not limited to,
a rupture disk indicator, magnetic sensor, motion detector on the
pressure relief valve stem, flow monitor, or pressure monitor.
    (ii) If any relief valve in organic HAP service vents or releases
to atmosphere as a result of a pressure release event, the owner or
operator must calculate the quantity of organic HAP released during
each pressure release event and report this quantity as required in
Sec.  63.655(g)(10)(iii). Calculations may be based on data from the
relief valve monitoring alone or in combination with process parameter
monitoring data and process knowledge.
    (4) Relief valves routed to a control device. If all releases and
potential leaks from a relief valve in organic HAP service are routed
through a closed vent system to a control device, the owner or operator
is not required to comply with paragraphs (j)(1), (2) or (3) (if
applicable) of this section. Both the closed vent system and control
device (if applicable) must meet the requirements of Sec.  63.644. When
complying with this paragraph, all references to ``Group 1
miscellaneous process vent'' in 63.644 mean ``relief valve.''
0
22. Section 63.650 is amended by revising paragraph (a) and adding
paragraph (d) to read as follows:

Sec.  63.650  Gasoline loading rack provisions.

    (a) Except as provided in paragraphs (b) through (d) of this
section, each owner or operator of a Group 1 gasoline loading rack
classified under Standard Industrial Classification code 2911 located
within a contiguous area and under common control with a petroleum
refinery shall comply with subpart R, Sec. Sec.  63.421, 63.422(a)
through (c) and (e), 63.425(a) through (c) and (i), 63.425(e) through
(h), 63.427(a) and (b), and 63.428(b), (c), (g)(1), (h)(1) through (3),
and (k).
* * * * *
    (d) If a flare is used as a control device, on and after [THE DATE
3 YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN
THE FEDERAL REGISTER], the flare shall meet the requirements of Sec.
63.670. Prior to [THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE
FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER], the flare shall meet
the applicable requirements of subpart R of this part, or the
requirements of Sec.  63.670.
0
23. Section 63.651 is amended by revising paragraph (a) and adding
paragraph (e) to read as follows:

Sec.  63.651  Marine tank vessel loading operation provisions.

    (a) Except as provided in paragraphs (b) through (e) of this
section, each owner or operator of a marine tank vessel loading
operation located at a petroleum refinery shall comply with

the requirements of Sec. Sec.  63.560 through 63.568.
* * * * *
    (e) If a flare is used as a control device, on and after [THE DATE
3 YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN
THE FEDERAL REGISTER], the flare shall meet the requirements of Sec.
63.670. Prior to [THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE
FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER], the flare shall meet
the applicable requirements of subpart Y of this part, or the
requirements of Sec.  63.670.
0
24. Section 63.652 is amended by:
0
a. Revising paragraph (a);
0
b. Removing and reserving paragraph (f)(2);
0
c. Revising paragraph (g)(2)(iii)(B)(1);
0
d. Revising paragraph (h)(3);
0
e. Revising paragraph (k) introductory text; and
0
f. Revising paragraph (k)(3).
    The revisions and additions read as follows:

Sec.  63.652  Emissions averaging provisions.

    (a) This section applies to owners or operators of existing sources
who seek to comply with the emission standard in Sec.  63.642(g) by
using emissions averaging according to Sec.  63.642(l) rather than
following the provisions of Sec. Sec.  63.643 through 63.645, 63.646 or
63.660, 63.647, 63.650, and 63.651. Existing marine tank vessel loading
operations located at the Valdez Marine Terminal source may not comply
with the standard by using emissions averaging.
* * * * *
    (g) * * *
    (2) * * *
    (iii) * * *
    (B) * * *
    (1) The percent reduction shall be measured according to the
procedures in Sec.  63.116 of subpart G if a combustion control device
is used. For a flare meeting the criteria in Sec.  63.116(a) of subpart
G or Sec.  63.670 of this subpart, as applicable, or a boiler or
process heater meeting the criteria in Sec.  63.645(d) of this subpart
or Sec.  63.116(b) of subpart G, the percentage of reduction shall be
98 percent. If a noncombustion control device is used, percentage of
reduction shall be demonstrated by a performance test at the inlet and
outlet of the device, or, if testing is not feasible, by a control
design evaluation and documented engineering calculations.
* * * * *
    (h) * * *
    (3) Emissions from storage vessels shall be determined as specified
in Sec.  63.150(h)(3) of subpart G, except as follows:
    (i) For storage vessels complying with Sec.  63.646:
    (A) All references to Sec.  63.119(b) in Sec.  63.150(h)(3) of
subpart G shall be replaced with: Sec.  63.119(b) or Sec.  63.119(b)
except for Sec.  63.119(b)(5) and (b)(6).
    (B) All references to Sec.  63.119(c) in Sec.  63.150(h)(3) of
subpart G shall be replaced with: Sec.  63.119(c) or Sec.  63.119(c)
except for Sec.  63.119(c)(2).
    (C) All references to Sec.  63.119(d) in Sec.  63.150(h)(3) of
subpart G shall be replaced with: Sec.  63.119(d) or Sec.  63.119(d)
except for Sec.  63.119(d)(2).
    (ii) For storage vessels complying with Sec.  63.660:
    (A) Sections 63.1063(a)(1)(i), (a)(2), and (b) or Sec. Sec.
63.1063(a)(1)(i) and (b) shall apply instead of Sec.  63.119(b) in
Sec.  63.150(h)(3) of subpart G.
    (B) Sections 63.1063(a)(1)(ii), (a)(2), and (b) shall apply instead
of Sec.  63.119(c) in Sec.  63.150(h)(3) of subpart G.
    (C) Sections 63.1063(a)(1)(i), (a)(2), and (b) or Sec. Sec.
63.1063(a)(1)(i) and (b) shall apply instead of Sec.  63.119(d) in
Sec.  63.150(h)(3) of subpart G.
* * * * *
    (k) The owner or operator shall demonstrate that the emissions from
the emission points proposed to be included in the average will not
result in greater hazard or, at the option of the State or local
permitting authority, greater risk to human health or the environment
than if the emission points were controlled according to the provisions
in Sec. Sec.  63.643 through 63.645, 63.646 or 63.660, 63.647, 63.650,
and 63.651, as applicable.
* * * * *
    (3) An emissions averaging plan that does not demonstrate an
equivalent or lower hazard or risk to the satisfaction of the State or
local permitting authority shall not be approved. The State or local
permitting authority may require such adjustments to the emissions
averaging plan as are necessary in order to ensure that the average
will not result in greater hazard or risk to human health or the
environment than would result if the emission points were controlled
according to Sec. Sec.  63.643 through 63.645, 63.646 or 63.660,
63.647, 63.650, and 63.651, as applicable.
* * * * *
0
25. Section 63.653 is amended by:
0
a. Revising paragraph (a) introductory text;
0
b. Revising paragraphs (a)(3)(i) and (ii); and
0
c. Revising paragraph (a)(7).
    The revisions read as follows:

Sec.  63.653  Monitoring, recordkeeping, and implementation plan for
emissions averaging.

    (a) For each emission point included in an emissions average, the
owner or operator shall perform testing, monitoring, recordkeeping, and
reporting equivalent to that required for Group 1 emission points
complying with Sec. Sec.  63.643 through 63.645, 63.646 or 63.660,
63.647, 63.650, and 63.651, as applicable. The specific requirements
for miscellaneous process vents, storage vessels, wastewater, gasoline
loading racks, and marine tank vessels are identified in paragraphs
(a)(1) through (7) of this section.
* * * * *
    (3) * * *
    (i) Perform the monitoring or inspection procedures in Sec.  63.646
and either Sec.  63.120 of subpart G or Sec.  63.1063 of subpart WW, as
applicable; and
    (ii) For closed vent systems with control devices, conduct an
initial design evaluation as specified in Sec.  63.646 and either Sec.
63.120(d) of subpart G or Sec.  63.985(b) of subpart SS, as applicable.
* * * * *
    (7) If an emission point in an emissions average is controlled
using a pollution prevention measure or a device or technique for which
no monitoring parameters or inspection procedures are specified in
Sec. Sec.  63.643 through 63.645, 63.646 or 63.660, 63.647, 63.650, and
63.651, as applicable, the owner or operator shall establish a site-
specific monitoring parameter and shall submit the information
specified in Sec.  63.655(h)(4) in the Implementation Plan.
* * * * *
0
26. Section 63.655 is amended by:
0
a. Revising paragraph (f) introductory text;
0
b. Revising paragraph (f)(1) introductory text;
0
c. Revising paragraph (f)(1)(i)(A) introductory text;
0
d. Revising paragraphs (f)(1)(i)(A)(2) and (3);
0
e. Revising paragraph (f)(1)(i)(B) introductory text;
0
f. Revising paragraph (f)(1)(i)(B)(2);
0
g. Revising paragraph (f)(1)(i)(D)(2);
0
h. Revising paragraph (f)(1)(iv) introductory text;
0
i. Revising paragraph (f)(1)(iv)(A);
0
j. Adding paragraph (f)(1)(vii);
0
k. Revising paragraph (f)(2) introductory text;
0
l. Revising paragraph (f)(3) introductory text;
0
m. Revising paragraph (f)(6);
0
n. Revising paragraph (g) introductory text;

0
o. Revising paragraphs (g)(1) through (5);
0
p. Revising paragraph (g)(6)(iii);
0
q. Revising paragraph (g)(7)(i);
0
r. Adding paragraphs (g)(10) through (13);
0
s. Removing and reserving paragraph (h)(1);
0
t. Revising paragraph (h)(2) introductory text;
0
u. Revising paragraph (h)(2)(i)(B);
0
v. Revising paragraph (h)(2)(ii);
0
w. Adding paragraphs (h)(8) and (9);
0
x. Adding paragraph (i) introductory text;
0
y. Revising paragraph (i)(1) introductory text;
0
z. Revising paragraph (i)(1)(ii);
0
aa. Adding paragraphs (i)(1)(v) and (vi);
0
bb. Redesignating paragraph (i)(4) and (5) as (i)(5) and (6)
respectively;
0
cc. Adding paragraph (i)(4);
0
dd. Revising newly redesignated paragraph (i)(5) introductory text; and
0
ee. Adding paragraphs (i)(7) through (11).
    The revisions and additions read as follows:

Sec.  63.655  Reporting and recordkeeping requirements.

* * * * *
    (f) Each owner or operator of a source subject to this subpart
shall submit a Notification of Compliance Status report within 150 days
after the compliance dates specified in Sec.  63.640(h) with the
exception of Notification of Compliance Status reports submitted to
comply with Sec.  63.640(l)(3) and for storage vessels subject to the
compliance schedule specified in Sec.  63.640(h)(2). Notification of
Compliance Status reports required by Sec.  63.640(l)(3) and for
storage vessels subject to the compliance dates specified in Sec.
63.640(h)(2) shall be submitted according to paragraph (f)(6) of this
section. This information may be submitted in an operating permit
application, in an amendment to an operating permit application, in a
separate submittal, or in any combination of the three. If the required
information has been submitted before the date 150 days after the
compliance date specified in Sec.  63.640(h), a separate Notification
of Compliance Status report is not required within 150 days after the
compliance dates specified in Sec.  63.640(h). If an owner or operator
submits the information specified in paragraphs (f)(1) through (f)(5)
of this section at different times, and/or in different submittals,
later submittals may refer to earlier submittals instead of duplicating
and resubmitting the previously submitted information. Each owner or
operator of a gasoline loading rack classified under Standard
Industrial Classification Code 2911 located within a contiguous area
and under common control with a petroleum refinery subject to the
standards of this subpart shall submit the Notification of Compliance
Status report required by subpart R of this part within 150 days after
the compliance dates specified in Sec.  63.640(h) of this subpart.
    (1) The Notification of Compliance Status report shall include the
information specified in paragraphs (f)(1)(i) through (f)(1)(vii) of
this section.
    (i) * * *
    (A) Identification of each storage vessel subject to this subpart,
and for each Group 1 storage vessel subject to this subpart, the
information specified in paragraphs (f)(1)(i)(A)(1) through
(f)(1)(i)(A)(3) of this section. This information is to be revised each
time a Notification of Compliance Status report is submitted for a
storage vessel subject to the compliance schedule specified in Sec.
63.640(h)(2) or to comply with Sec.  63.640(l)(3).
* * * * *
    (2) For storage vessels subject to the compliance schedule
specified in Sec.  63.640(h)(2) that are not complying with Sec.
63.646, the anticipated compliance date.
    (3) For storage vessels subject to the compliance schedule
specified in Sec.  63.640(h)(2) that are complying with Sec.  63.646
and the Group 1 storage vessels described in Sec.  63.640(l), the
actual compliance date.
    (B) If a closed vent system and a control device other than a flare
is used to comply with Sec.  63.646 or Sec.  63.660, the owner or
operator shall submit:
* * * * *
    (2) The design evaluation documentation specified in Sec.
63.120(d)(1)(i) of subpart G or Sec.  63.985(b)(1)(i) of subpart SS (as
applicable), if the owner or operator elects to prepare a design
evaluation; or
* * * * *
    (D) * * *
    (2) All visible emission readings, heat content determinations,
flow rate measurements, and exit velocity determinations made during
the compliance determination required by Sec.  63.120(e) of subpart G
or Sec.  63.987(b) of subpart SS or Sec.  63.670(h), as applicable; and
* * * * *
    (iv) For miscellaneous process vents controlled by flares, initial
compliance test results including the information in paragraphs
(f)(1)(iv)(A) and (B) of this section;
    (A) All visible emission readings, heat content determinations,
flow rate measurements, and exit velocity determinations made during
the compliance determination required by Sec.  63.645 of this subpart
and Sec.  63.116(a) of subpart G of this part or Sec.  63.670(h) of
this subpart, as applicable, and
* * * * *
    (vii) For relief valves in organic HAP service, a description of
the monitoring system to be implemented, including the relief valves
and process parameters to be monitored, and a description of the alarms
or other methods by which operators will be notified of a pressure
release.
    (2) If initial performance tests are required by Sec. Sec.  63.643
through 63.653 of this subpart, the Notification of Compliance Status
report shall include one complete test report for each test method used
for a particular source. On and after [THE DATE 3 YEARS AFTER THE DATE
OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER],
performance tests shall be submitted according to paragraph (h)(9) of
this section.
* * * * *
    (3) For each monitored parameter for which a range is required to
be established under Sec.  63.120(d) of subpart G or Sec.  63.985(b) of
subpart SS for storage vessels or Sec.  63.644 for miscellaneous
process vents, the Notification of Compliance Status report shall
include the information in paragraphs (f)(3)(i) through (f)(3)(iii) of
this section.
* * * * *
    (6) Notification of Compliance Status reports required by Sec.
63.640(l)(3) and for storage vessels subject to the compliance dates
specified in Sec.  63.640(h)(2) shall be submitted no later than 60
days after the end of the 6-month period during which the change or
addition was made that resulted in the Group 1 emission point or the
existing Group 1 storage vessel was brought into compliance, and may be
combined with the periodic report. Six-month periods shall be the same
6-month periods specified in paragraph (g) of this section. The
Notification of Compliance Status report shall include the information
specified in paragraphs (f)(1) through (f)(5) of this section. This
information may be submitted in an operating permit application, in an
amendment to an operating permit application, in a separate submittal,
as part of the periodic report, or in any combination of these four. If
the required information has been submitted before the date 60 days
after the end of the 6-month period in which the addition of the Group
1 emission

point took place, a separate Notification of Compliance Status report
is not required within 60 days after the end of the 6-month period. If
an owner or operator submits the information specified in paragraphs
(f)(1) through (f)(5) of this section at different times, and/or in
different submittals, later submittals may refer to earlier submittals
instead of duplicating and resubmitting the previously submitted
information.
    (g) The owner or operator of a source subject to this subpart shall
submit Periodic Reports no later than 60 days after the end of each 6-
month period when any of the information specified in paragraphs (g)(1)
through (7) of this section or paragraphs (g)(9) through (12) of this
section is collected. The first 6-month period shall begin on the date
the Notification of Compliance Status report is required to be
submitted. A Periodic Report is not required if none of the events
identified in paragraph (g)(1) through (7) of this section or
paragraphs (g)(9) through (12) of this section occurred during the 6-
month period unless emissions averaging is utilized. Quarterly reports
must be submitted for emission points included in emission averages, as
provided in paragraph (g)(8) of this section. An owner or operator may
submit reports required by other regulations in place of or as part of
the Periodic Report required by this paragraph if the reports contain
the information required by paragraphs (g)(1) through (12) of this
section.
    (1) For storage vessels, Periodic Reports shall include the
information specified for Periodic Reports in paragraph (g)(2) through
(g)(5) of this section. Information related to gaskets, slotted
membranes, and sleeve seals is not required for storage vessels that
are part of an existing source complying with Sec.  63.646.
    (2) Internal floating roofs. (i) An owner or operator who elects to
comply with Sec.  63.646 by using a fixed roof and an internal floating
roof or by using an external floating roof converted to an internal
floating roof shall submit the results of each inspection conducted in
accordance with Sec.  63.120(a) of subpart G in which a failure is
detected in the control equipment.
    (A) For vessels for which annual inspections are required under
Sec.  63.120(a)(2)(i) or (a)(3)(ii) of subpart G, the specifications
and requirements listed in paragraphs (g)(2)(i)(A)(1) through (3) of
this section apply.
    (1) A failure is defined as any time in which the internal floating
roof is not resting on the surface of the liquid inside the storage
vessel and is not resting on the leg supports; or there is liquid on
the floating roof; or the seal is detached from the internal floating
roof; or there are holes, tears, or other openings in the seal or seal
fabric; or there are visible gaps between the seal and the wall of the
storage vessel.
    (2) Except as provided in paragraph (g)(2)(i)(C) of this section,
each Periodic Report shall include the date of the inspection,
identification of each storage vessel in which a failure was detected,
and a description of the failure. The Periodic Report shall also
describe the nature of and date the repair was made or the date the
storage vessel was emptied.
    (3) If an extension is utilized in accordance with Sec.
63.120(a)(4) of subpart G, the owner or operator shall, in the next
Periodic Report, identify the vessel; include the documentation
specified in Sec.  63.120(a)(4) of subpart G; and describe the date the
storage vessel was emptied and the nature of and date the repair was
made.
    (B) For vessels for which inspections are required under Sec.
63.120(a)(2)(ii), (a)(3)(i), or (a)(3)(iii) of subpart G (i.e.,
internal inspections), the specifications and requirements listed in
paragraphs (g)(2)(i)(B)(1) and (2) of this section apply.
    (1) A failure is defined as any time in which the internal floating
roof has defects; or the primary seal has holes, tears, or other
openings in the seal or the seal fabric; or the secondary seal (if one
has been installed) has holes, tears, or other openings in the seal or
the seal fabric; or, for a storage vessel that is part of a new source,
the gaskets no longer close off the liquid surface from the atmosphere;
or, for a storage vessel that is part of a new source, the slotted
membrane has more than a 10 percent open area.
    (2) Each Periodic Report shall include the date of the inspection,
identification of each storage vessel in which a failure was detected,
and a description of the failure. The Periodic Report shall also
describe the nature of and date the repair was made.
    (ii) An owner or operator who elects to comply with Sec.  63.660 by
using a fixed roof and an internal floating roof shall submit the
results of each inspection conducted in accordance with Sec.
63.1063(c)(1), (d)(1), and (d)(2) of subpart WW in which a failure is
detected in the control equipment. For vessels for which inspections
are required under Sec.  63.1063(c) and (d), the specifications and
requirements listed in paragraphs (g)(2)(ii)(A) through (g)(2)(ii)(C)
of this section apply.
    (A) A failure is defined in Sec.  63.1063(d)(1) of subpart WW.
    (B) Each Periodic Report shall include a copy of the inspection
record required by Sec.  63.1065(b) of subpart WW when a failure
occurs.
    (C) An owner or operator who elects to use an extension in
accordance with Sec.  63.1063(e)(2) of subpart WW shall, in the next
Periodic Report, submit the documentation required by Sec.
63.1063(e)(2).
    (3) External floating roofs. (i) An owner or operator who elects to
comply with Sec.  63.646 by using an external floating roof shall meet
the periodic reporting requirements specified in paragraphs
(g)(3)(i)(A) and (B) of this section.
    (A) The owner or operator shall submit, as part of the Periodic
Report, documentation of the results of each seal gap measurement made
in accordance with Sec.  63.120(b) of subpart G in which the seal and
seal gap requirements of Sec.  63.120(b)(3), (b)(4), (b)(5), or (b)(6)
of subpart G are not met. This documentation shall include the
information specified in paragraphs (g)(3)(i)(A)(1) through (4) of this
section.
    (1) The date of the seal gap measurement.
    (2) The raw data obtained in the seal gap measurement and the
calculations described in Sec.  63.120(b)(3) and (b)(4) of subpart G.
    (3) A description of any seal condition specified in Sec.
63.120(b)(5) or (b)(6) of subpart G that is not met.
    (4) A description of the nature of and date the repair was made, or
the date the storage vessel was emptied.
    (B) If an extension is utilized in accordance with Sec.
63.120(b)(7)(ii) or (b)(8) of subpart G, the owner or operator shall,
in the next Periodic Report, identify the vessel; include the
documentation specified in Sec.  63.120(b)(7)(ii) or (b)(8) of subpart
G, as applicable; and describe the date the vessel was emptied and the
nature of and date the repair was made.
    (C) The owner or operator shall submit, as part of the Periodic
Report, documentation of any failures that are identified during visual
inspections required by Sec.  63.120(b)(10) of subpart G. This
documentation shall meet the specifications and requirements in
paragraphs (g)(3)(i)(C)(1) and (2) of this section.
    (1) A failure is defined as any time in which the external floating
roof has defects; or the primary seal has holes or other openings in
the seal or the seal fabric; or the secondary seal has holes, tears, or
other openings in the seal or the seal fabric; or, for a storage vessel
that is part of a new source, the gaskets no longer close off the
liquid surface from the atmosphere; or, for a storage

vessel that is part of a new source, the slotted membrane has more than
10 percent open area.
    (2) Each Periodic Report shall include the date of the inspection,
identification of each storage vessel in which a failure was detected,
and a description of the failure. The Periodic Report shall also
describe the nature of and date the repair was made.
    (ii) An owner or operator who elects to comply with Sec.  63.660 by
using an external floating roof shall meet the periodic reporting
requirements specified in paragraphs (g)(3)(ii)(A) and (B) of this
section.
    (A) For vessels for which inspections are required under Sec.
63.1063(c)(2), (d)(1), and (d)(3) of subpart WW, the owner or operator
shall submit, as part of the Periodic Report, a copy of the inspection
record required by Sec.  63.1065(b) of subpart WW when a failure
occurs. A failure is defined in Sec.  63.1063(d)(1).
    (B) An owner or operator who elects to use an extension in
accordance with Sec.  63.1063(e)(2) or Sec.  63.1063(c)(2)(iv)(B) of
subpart WW shall, in the next Periodic Report, submit the documentation
required by those paragraphs.
    (4) An owner or operator who elects to comply with Sec.  63.646 or
Sec.  63.660 by using an external floating roof converted to an
internal floating roof shall comply with the periodic reporting
requirements of paragraph (g)(2)(i) of this section.
    (5) An owner or operator who elects to comply with Sec.  63.646 or
Sec.  63.660 by installing a closed vent system and control device
shall submit, as part of the next Periodic Report, the information
specified in paragraphs (g)(5)(i) through (g)(5)(iii) of this section,
as applicable.
    (i) The Periodic Report shall include the information specified in
paragraphs (g)(5)(i)(A) and (B) of this section for those planned
routine maintenance operations that would require the control device
not to meet the requirements of either Sec.  63.119(e)(1) or (e)(2) of
subpart G, Sec.  63.985(a) and (b) of subpart SS, or Sec.  63.670, as
applicable.
    (A) A description of the planned routine maintenance that is
anticipated to be performed for the control device during the next 6
months. This description shall include the type of maintenance
necessary, planned frequency of maintenance, and lengths of maintenance
periods.
    (B) A description of the planned routine maintenance that was
performed for the control device during the previous 6 months. This
description shall include the type of maintenance performed and the
total number of hours during those 6 months that the control device did
not meet the requirements of either Sec.  63.119(e)(1) or (2) of
subpart G, Sec.  63.985(a) and (b) of subpart SS, or Sec.  63.670, as
applicable, due to planned routine maintenance.
    (ii) If a control device other than a flare is used, the Periodic
Report shall describe each occurrence when the monitored parameters
were outside of the parameter ranges documented in the Notification of
Compliance Status report. The description shall include: Identification
of the control device for which the measured parameters were outside of
the established ranges, and causes for the measured parameters to be
outside of the established ranges.
    (iii) If a flare is used prior to [THE DATE 3 YEARS AFTER THE DATE
OF PUBLICATION OF THE FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER]
and prior to electing to comply with the requirements in Sec.  63.670,
the Periodic Report shall describe each occurrence when the flare does
not meet the general control device requirements specified in Sec.
63.11(b) of subpart A of this part and shall include: Identification of
the flare that does not meet the general requirements specified in
Sec.  63.11(b) of subpart A of this part, and reasons the flare did not
meet the general requirements specified in Sec.  63.11(b) of subpart A
of this part.
    (iv) If a flare is used on and after compliance with the
requirements in Sec.  63.670 is elected, which can be no later than
[THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE FINAL RULE
AMENDMENTS IN THE FEDERAL REGISTER], the Periodic Report shall include
the items specified in paragraph (g)(11) of this section.
    (v) An owner or operator who elects to comply with Sec.  63.660 by
installing an alternate control device as described in Sec.  63.1064 of
subpart WW shall submit, as part of the next Periodic Report, a written
application as described in Sec.  63.1066(b)(3) of subpart WW.
    (6) * * *
    (iii) For closed vent systems, include the records of periods when
vent stream flow was detected in the bypass line or diverted from the
control device, a flow indicator was not operating or a bypass of the
system was indicated, as specified in paragraph (i)(4) of this section.
    (7) * * *
    (i) Results of the performance test shall include the
identification of the source tested, the date of the test, the
percentage of emissions reduction or outlet pollutant concentration
reduction (whichever is needed to determine compliance) for each run
and for the average of all runs, and the values of the monitored
operating parameters.
* * * * *
    (10) For relief valves, Periodic Reports must include the
information specified in paragraphs (g)(10)(i) through (iii) of this
section.
    (i) For relief valves in organic HAP gas or vapor service, pursuant
to Sec.  63.648(j), report any instrument reading of 500 ppm or
greater, more than 5 days after the relief valve returns to service
after a pressure release.
    (ii) For relief valves in organic HAP gas or vapor service subject
to Sec.  63.648(j)(2), report confirmation that all monitoring to show
compliance was conducted within the reporting period.
    (iii) For relief valves in organic HAP service, report each
pressure release to the atmosphere, including duration of the pressure
release and estimate of quantity of substances released.
    (11) For flares subject to Sec.  63.670, Periodic Reports must
include the information specified in paragraphs (g)(11)(i) through
(iii) of this section.
    (i) Records as specified in paragraph (i)(9)(i) of this section for
each period when regulated material is routed to a flare and a pilot
flame is not present.
    (ii) Visible emission records as specified in paragraph (i)(9)(ii)
of this section for each period of 2 consecutive hours during which
visible emissions exceeded a total of 5 minutes.
    (iii) The 15-minute block periods for which the applicable
operating limits specified in Sec.  63.670(d) through (f) are not met.
Indicate the date and time for the period, the 15-minute block average
operating parameters determined following the methods in Sec.
63.670(k) through (o) as applicable, and an indication of whether the
three criteria in Sec.  63.670(e)(vi) were all met for that 15-minute
block period.
    (iv) Records as specified in paragraph (i)(9)(x) of this section
for each period when a halogenated vent stream as defined in Sec.
63.641 is discharged to the flare.
    (12) If a source fails to meet an applicable standard, report such
events in the Periodic Report. Report the number of failures to meet an
applicable standard. For each instance, report the date, time and
duration of each failure. For each failure the report must include a
list of the affected sources or equipment, an estimate of the quantity
of each regulated pollutant emitted over any emission limit, and a
description of the method used to estimate the emissions.
    (13) Any changes in the information provided in a previous
Notification of Compliance Status report.

    (h) * * *
    (2) For storage vessels, notifications of inspections as specified
in paragraphs (h)(2)(i) and (h)(2)(ii) of this section.
    (i) * * *
    (B) Except as provided in paragraph (h)(2)(i)(C) of this section,
if the internal inspection required by Sec.  63.120(a)(2), Sec.
63.120(a)(3), or Sec.  63.120(b)(10) of subpart G or Sec.
63.1063(d)(1) of subpart WW is not planned and the owner or operator
could not have known about the inspection 30 calendar days in advance
of refilling the vessel with organic HAP, the owner or operator shall
notify the Administrator at least 7 calendar days prior to refilling of
the storage vessel. Notification may be made by telephone and
immediately followed by written documentation demonstrating why the
inspection was unplanned. This notification, including the written
documentation, may also be made in writing and sent so that it is
received by the Administrator at least 7 calendar days prior to the
refilling.
* * * * *
    (ii) In order to afford the Administrator the opportunity to have
an observer present, the owner or operator of a storage vessel equipped
with an external floating roof shall notify the Administrator of any
seal gap measurements. The notification shall be made in writing at
least 30 calendar days in advance of any gap measurements required by
Sec.  63.120(b)(1) or (b)(2) of subpart G or Sec.  63.1062(d)(3) of
subpart WW. The State or local permitting authority can waive this
notification requirement for all or some storage vessels subject to the
rule or can allow less than 30 calendar days' notice.
* * * * *
    (8) For fenceline monitoring systems subject to Sec.  63.658,
within 45 calendar days after the end of each semiannual reporting
period, each owner or operator shall submit the following information
to the EPA's Compliance and Emissions Data Reporting Interface (CEDRI)
that is accessed through the EPA's Central Data Exchange (CDX)
(www.epa.gov/cdx). The owner or operator need not transmit this data
prior to obtaining 12 months of data.
    (i) Individual sample results for each monitor for each sampling
episode during the semiannual reporting period. For the first reporting
period and for any period in which a passive monitor is added or moved,
the owner or operator shall report the coordinates of all of the
passive monitor locations. The owner or operator shall determine the
coordinates using an instrument with an accuracy of at least 3 meters.
Coordinates shall be in decimal degrees with at least five decimal
places.
    (ii) The biweekly 12-month rolling average concentration difference
([Delta]c) values for benzene for the semiannual reporting period.
    (iii) Notation for each biweekly value that indicates whether
background correction was used, all measurements in the sampling period
were below detection, or whether an outlier was removed from the
sampling period data set.
    (9) On and after [THE DATE OF PUBLICATION OF THE FINAL RULE
AMENDMENTS IN THE FEDERAL REGISTER], if required to submit the results
of a performance test or CEMS performance evaluation, the owner or
operator shall submit the results using EPA's Electronic Reporting Tool
(ERT) according to the procedures in paragraphs (h)(9)(i) and (ii) of
this section.
    (i) Within 60 days after the date of completing each performance
test as required by this subpart, the owner or operator shall submit
the results of the performance tests according to the method specified
by either paragraph (h)(9)(i)(A) or (h)(9)(i)(B) of this section.
    (A) For data collected using test methods supported by the EPA's
ERT as listed on the EPA's ERT Web site (http://www.epa.gov/ttn/chief/ert/index.html), the owner or operator must submit the results of the
performance test to the CEDRI accessed through the EPA's CDX (http://cdx.epa.gov/epa_home.asp), unless the Administrator approves another
approach. Performance test data must be submitted in a file format
generated through the use of the EPA's ERT. If an owner or operator
claims that some of the performance test information being submitted is
confidential business information (CBI), the owner or operator must
submit a complete file generated through the use of the EPA's ERT,
including information claimed to be CBI, on a compact disc or other
commonly used electronic storage media (including, but not limited to,
flash drives) by registered letter to the EPA. The electronic media
must be clearly marked as CBI and mailed to U.S. EPA/OAQPS/CORE CBI
Office, Attention: WebFIRE Administrator, MD C404-02, 4930 Old Page
Rd., Durham, NC 27703. The same ERT file with the CBI omitted must be
submitted to the EPA via CDX as described earlier in this paragraph.
    (B) For data collected using test methods that are not supported by
the EPA's ERT as listed on the EPA's ERT Web site, the owner or
operator must submit the results of the performance test to the
Administrator at the appropriate address listed in Sec.  63.13.
    (ii) Within 60 days after the date of completing each CEMS
performance evaluation as required by this subpart, the owner or
operator must submit the results of the performance evaluation
according to the method specified by either paragraph (h)(9)(ii)(A) or
(h)(9)(ii)(B) of this section.
    (A) For data collection of relative accuracy test audit (RATA)
pollutants that are supported by the EPA's ERT as listed on the ERT Web
site, the owner or operator must submit the results of the performance
evaluation to the CEDRI that is accessed through the EPA's CDX, unless
the Administrator approves another approach. Performance evaluation
data must be submitted in a file format generated through the use of
the EPA's ERT. If an owner or operator claims that some of the
performance evaluation information being submitted is CBI, the owner or
operator must submit a complete file generated through the use of the
EPA's ERT, including information claimed to be CBI, on a compact disc
or other commonly used electronic storage media (including, but not
limited to, flash drives) by registered letter to the EPA. The
electronic media must be clearly marked as CBI and mailed to U.S. EPA/
OAQPS/CORE CBI Office, Attention: WebFIRE Administrator, MD C404-02,
4930 Old Page Rd., Durham, NC 27703. The same ERT file with the CBI
omitted must be submitted to the EPA via CDX as described earlier in
this paragraph.
    (B) For any performance evaluation data with RATA pollutants that
are not supported by the EPA's ERT as listed on the EPA's ERT Web site,
the owner or operator must submit the results of the performance
evaluation to the Administrator at the appropriate address listed in
Sec.  63.13.
    (i) Recordkeeping. Each owner or operator of a source subject to
this subpart shall keep copies of all applicable reports and records
required by this subpart for at least 5 years except as otherwise
specified in paragraphs (i)(1) through (11) of this section. All
applicable records shall be maintained in such a manner that they can
be readily accessed within 24 hours. Records may be maintained in hard
copy or computer-readable form including, but not limited to, on paper,
microfilm, computer, flash drive, floppy disk, magnetic tape, or
microfiche.
    (1) Each owner or operator subject to the storage vessel provisions
in Sec.  63.646 shall keep the records specified in Sec.  63.123 of
subpart G of this part except as specified in paragraphs (i)(1)(i)

through (iv) of this section. Each owner or operator subject to the
storage vessel provisions in Sec.  63.660 shall keep records as
specified in paragraphs (i)(1)(v) and (vi) of this section.
* * * * *
    (ii) All references to Sec.  63.122 in Sec.  63.123 of subpart G of
this part shall be replaced with Sec.  63.655(e).
* * * * *
    (v) Each owner or operator of a Group 1 storage vessel subject to
the provisions in Sec.  63.660 shall keep records as specified in Sec.
63.1065.
    (vi) Each owner or operator of a Group 2 storage vessel shall keep
the records specified in Sec.  63.1065(a) of subpart WW. If a storage
vessel is determined to be Group 2 because the weight percent total
organic HAP of the stored liquid is less than or equal to 4 percent for
existing sources or 2 percent for new sources, a record of any data,
assumptions, and procedures used to make this determination shall be
retained.
* * * * *
    (4) For each closed vent system that contains bypass lines that
could divert a vent stream away from the control device and to the
atmosphere, or cause air intrusion into the control device, the owner
or operator shall keep a record of the information specified in either
paragraph (i)(4)(i) or (ii) of this section, as applicable.
    (i) The owner or operator shall maintain records of any alarms
triggered because flow was detected in the bypass line, including the
date and time the alarm was triggered and the duration of the flow in
the bypass line. The owner or operator shall also maintain records of
all periods when the vent stream is diverted from the control device or
air intrudes into the control device. The owner or operator shall
include an estimate of the volume of gas, the concentration of organic
HAP in the gas and the resulting emissions of organic HAP that bypassed
the control device.
    (ii) Where a seal mechanism is used to comply with Sec.
63.644(c)(2), hourly records of flow are not required. In such cases,
the owner or operator shall record the date that the monthly visual
inspection of the seals or closure mechanisms is completed. The owner
or operator shall also record the occurrence of all periods when the
seal or closure mechanism is broken, the bypass line valve position has
changed or the key for a lock-and-key type lock has been checked out.
The owner or operator shall include an estimate of the volume of gas,
the concentration of organic HAP in the gas and the resulting emissions
of organic HAP that bypassed the control device.
    (5) The owner or operator of a heat exchange system subject to this
subpart shall comply with the recordkeeping requirements in paragraphs
(i)(5)(i) through (v) of this section and retain these records for 5
years.
* * * * *
    (7) Each owner or operator subject to the delayed coking unit
decoking operations provisions in Sec.  63.657 must maintain records of
the average pressure for the 5-minute period prior to venting to the
atmosphere, draining, or deheading the coke drum for each cooling cycle
for each coke drum.
    (8) For fenceline monitoring systems subject to Sec.  63.658, each
owner or operator shall keep the records specified in paragraphs
(i)(8)(i) through (ix) of this section on an ongoing basis.
    (i) Coordinates of all passive monitors, including replicate
samplers and field blanks, and the meteorological station. The owner or
operator shall determine the coordinates using an instrument with an
accuracy of at least 3 meters. The coordinates shall be in decimal
degrees with at least five decimal places.
    (ii) The start and stop times and dates for each sample, as well as
the tube identifying information.
    (iii) Daily unit vector wind direction, calculated daily sigma
theta, daily average temperature and daily average barometric pressure
measurements.
    (iv) For each outlier determined in accordance with Section 9.2 of
Method 325A of Appendix A of this part, the sampler location of and the
concentration of the outlier and the evidence used to conclude that the
result is an outlier.
    (v) For samples that will be adjusted for a background, the
location of and the concentration measured simultaneously by the
background sampler, and the perimeter samplers to which it applies.
    (vi) Individual sample results, the calculated [Delta]c for benzene
for each sampling episode and the two samples used to determine it,
whether background correction was used, and the 12-month rolling
average [Delta]c calculated after each sampling episode.
    (vii) Method detection limit for each sample, including co-located
samples and blanks.
    (viii) Documentation of corrective action taken each time the
action level was exceeded.
    (ix) Other records as required by Methods 325A and 325B of Appendix
A of this part.
    (9) For each flare subject to Sec.  63.670, each owner or operator
shall keep the records specified in paragraphs (i)(9)(i) through (vii)
of this section up-to-date and readily accessible, as applicable.
    (i) Retain records of the output of the monitoring device used to
detect the presence of a pilot flame as required in Sec.  63.670(b) for
a minimum of 2 years. Retain records of periods during which the pilot
flame is not present when regulated material is routed to a flare for a
minimum of 5 years.
    (ii) Daily visible emissions observations, as required in Sec.
63.670(c), as well as any observations required in Sec.  63.670(h). The
record must identify whether the visible emissions observation was
performed, the results of each observation, total duration of observed
visible emissions, and whether it was a 5-minute or 2-hour observation.
If the owner or operator performs visible emissions observations more
than one time during a day, the record must also identify the date and
time of day each visible emissions observation was performed.
    (iii) The 15-minute block average cumulative flows for flare vent
gas and, if applicable, total steam, perimeter assist air, and premix
assist air specified to be monitored under Sec.  63.670(i), along with
the date and time interval for the 15-minute block. If multiple
monitoring locations are used to determine cumulative vent gas flow,
total steam, perimeter assist air, and premix assist air, retain
records of the 15-minute block average flows for each monitoring
location for a minimum of 2 years, and retain the 15-minute block
average cumulative flows that are used in subsequent calculations for a
minimum of 5 years. If pressure and temperature monitoring is used,
retain records of the 15-minute block average temperature, pressure and
molecular weight of the flare vent gas or assist gas stream for each
measurement location used to determine the 15-minute block average
cumulative flows for a minimum of 2 years, and retain the 15-minute
block average cumulative flows that are used in subsequent calculations
for a minimum of 5 years.
    (iv) The flare vent gas compositions specified to be monitored
under Sec.  63.670(j). Retain records of individual component
concentrations from each compositional analyses for a minimum of 2
years. If NHVvg or total hydrocarbon analyzer is used,
retain records of the 15-minute block average values for a minimum of 5
years.
    (v) Each 15-minute block average operating parameter calculated
following the methods specified in Sec.  63.670(k) through (m), as
applicable.
    (vi) The 15-minute block average olefins, hydrogen, and olefins
plus

hydrogen concentration in the combustion zone used to determine if the
criteria in Sec.  63.670(e)(4) are met. If process knowledge and
engineering calculations are used, retain records of the information
used in the assessment and records of all compositional analyses
required in Sec.  63.670(o)(ii). Identify all 15-minute block averages
for which all three criteria in Sec.  63.670(e)(4) are met or are
assumed to be met.
    (vii) All periods during which operating values are outside of the
applicable operating limits specified in Sec.  63.670(d) through (f)
when regulated material is being routed to the flare.
    (viii) All periods during which the owner or operator does not
perform flare monitoring according to the procedures in Sec.  63.670(g)
through (j).
    (ix) Records of periods when there is flow of vent gas to the
flare, but when there is no flow of regulated material to the flare,
including the start and stop time and dates of periods of no regulated
material flow.
    (x) All periods during which a halogenated vent stream, as defined
in Sec.  63.641, is discharged to the flare. Records shall include the
start time and date of the event, the end time and date of the event,
and an estimate of the cumulative flow of the halogenated vent stream
over the duration of the event.
    (10) If the owner or operator elects to comply with Sec.  63.661,
the owner or operator shall keep the records described in paragraphs
(i)(10)(i) through (v) of this section.
    (i) The equipment and process units for which the owner or operator
chooses to use the optical gas imaging instrument.
    (ii) All records required by part 60, Appendix K of this chapter,
as applicable.
    (iii) A video record to document the leak survey results. The video
record must include a time and date stamp for each monitoring event.
    (iv) Identification of the equipment screened and the time and date
of the screening.
    (v) Documentation of repairs attempted and repairs delayed. If
repair of a leak is confirmed using the optical gas imaging instrument,
then instead of the maximum instrument reading measured by Method 21 of
part 60, Appendix A-7 of this chapter, the owner or operator shall keep
a video record following repair to confirm the equipment is repaired.
    (11) Other records must be kept as specified in paragraphs
(i)(11)(i) through (iii) of this section.
    (i) In the event that an affected unit fails to meet an applicable
standard, record the number of failures. For each failure, record the
date, time and duration of each failure.
    (ii) For each failure to meet an applicable standard, record and
retain a list of the affected sources or equipment, an estimate of the
volume of each regulated pollutant emitted over any emission limit and
a description of the method used to estimate the emissions.
    (iii) Record actions taken to minimize emissions in accordance with
Sec.  63.642(n), and any corrective actions taken to return the
affected unit to its normal or usual manner of operation.
0
27. Section 63.656 is amended by:
0
a. Revising paragraph (c) introductory text;
0
b. Revising paragraph (c)(1); and
0
c. Adding paragraph (c)(5).
    The revisions and additions read as follows:

Sec.  63.656  Implementation and enforcement.

* * * * *
    (c) The authorities that cannot be delegated to state, local, or
Tribal agencies are as specified in paragraphs (c)(1) through (5) of
this section.
    (1) Approval of alternatives to the requirements in Sec. Sec.
63.640, 63.642(g) through (l), 63.643, 63.646 through 63.652, 63.654,
63.657 through 63.661, and 63.670. Where these standards reference
another subpart, the cited provisions will be delegated according to
the delegation provisions of the referenced subpart. Where these
standards reference another subpart and modify the requirements, the
requirements shall be modified as described in this subpart. Delegation
of the modified requirements will also occur according to the
delegation provisions of the referenced subpart.
* * * * *
    (5) Approval of the corrective action plan under Sec.  63.658(h).
0
28. Section 63.657 is added to read as follows:

Sec.  63.657  Delayed coking unit decoking operation standards.

    (a) Each owner or operator of a delayed coking unit shall
depressure each coke drum to a closed blowdown system until the coke
drum vessel pressure is 2 pounds per square inch gauge (psig) or less
prior to venting to the atmosphere, draining or deheading the coke drum
at the end of the cooling cycle.
    (b) Each owner or operator of a delayed coking unit shall install,
operate, calibrate, and maintain a continuous parameter monitoring
system to determine the coke drum vessel pressure. The pressure
monitoring system must be capable of measuring a pressure of 2 psig
within 0.5 psig.
    (c) The owner or operator of a delayed coking unit shall determine
the coke drum vessel pressure on a 5-minute rolling average basis while
the coke drum is vented to the closed blowdown system to demonstrate
compliance the requirement in paragraph (a) of this section. Pressure
readings after initiating steps to isolate the coke drum from the
closed blowdown system just prior to atmospheric venting, draining, or
deheading the coke drum shall not be used in determining the average
coke drum vessel pressure for the purpose of compliance with the
requirement in paragraph (a) of this section.
0
29. Section 63.658 is added to read as follows:

Sec.  63.658  Fenceline monitoring provisions.

    (a) The owner or operator shall conduct sampling along the facility
property boundary and analyze the samples in accordance with Methods
325A and 325B of Appendix A of this part.
    (b) The target analyte is benzene.
    (c) The owner or operator shall determine passive monitor locations
in accordance with Section 8.2 of Method 325A of Appendix A of this
part. General guidance for siting passive monitors can be found in EPA-
454/R-98-004, Quality Assurance Handbook for Air Pollution Measurement
Systems, Volume II: Part 1: Ambient Air Quality Monitoring Program
Quality System Development, August 1998 (incorporated by reference--see
Sec.  63.14). Alternatively, the owner or operator may elect to place
monitors at 2 kilometers intervals as measured along the property
boundary, provided additional monitors are located, if necessary, as
required in Section <IP_ADDRESS> in Method 325A of Appendix A of this part.
    (1) As it pertains to this subpart, known emission source, as used
in Section <IP_ADDRESS> in Method 325A of Appendix A of this part for siting
passive monitors means a wastewater treatment unit or a Group 1 storage
vessel.
    (2) The owner or operator may collect one or more background
samples if the owner or operator believes that an offsite upwind source
or an onsite source excluded under Sec.  63.640(g) may influence the
sampler measurements. If the owner or operator elects to collect one or
more background samples, the owner of operator must develop and submit
a site-specific monitoring plan for approval according to the
requirements in paragraph (i) of this section. Upon approval of the
site-specific monitoring plant, the background sampler(s) should be

operated co-currently with the routine samplers.
    (3) The owner or operator shall collect at least one co-located
duplicate sample for every 10 field samples per sampling episode and at
least two field blanks per sampling episode, as described in Section
9.3 in Method 325A of Appendix A of this part. The co-located
duplicates may be collected at any one of the perimeter sampling
locations.
    (4) The owner or operator shall follow the procedure in Section 9.6
of Method 325B of Appendix A of this part to determine the detection
limit of benzene for each sampler used to collect samples, background
samples (if the owner or operator elects to do so), co-located samples
and blanks.
    (d) The owner or operator shall use a dedicated meteorological
station in accordance with Section 8.3 of Method 325A of Appendix A of
this part.
    (1) The owner or operator shall collect and record hourly average
meteorological data, including wind speed, wind direction and
temperature.
    (2) The owner or operator shall follow the calibration and
standardization procedures for meteorological measurements in EPA-454/
B-08-002, Quality Assurance Handbook for Air Pollution Measurement
Systems, Volume IV: Meteorological Measurements, Version 2.0 (Final),
March 2008 (incorporated by reference--see Sec.  63.14).
    (e) The length of the sampling episode must be fourteen days,
unless a shorter sampling episode is determined to be necessary under
paragraph (g) or (i) of this section. A sampling episode is defined as
the period during which the owner or operator collects the sample and
does not include the time required to analyze the sample.
    (f) Within 30 days of completion of each sampling episode, the
owner or operator shall determine whether the results are above or
below the action level as follows:
    (1) For each sampling episode, the owner or operator shall
determine the highest and lowest sample results for benzene from the
sample pool and calculate the difference in concentration ([Delta]c).
    (i) The owner or operator shall adhere to the following procedures
when one or more samples for the sampling episode are below the method
detection limit for benzene:
    (A) If the lowest detected value of benzene is below detection, the
owner or operator shall use zero as the lowest sample result when
calculating [Delta]c.
    (B) If all sample results are below the method detection limit, the
owner or operator shall use the method detection limit as the highest
sample result.
    (ii) If the owner or operator identifies an offsite upwind source
or an onsite source excluded under Sec.  63.640(g) that contributes to
the benzene concentration at any passive monitor and collects
background samples according to an approved site-specific monitoring
plan, the owner or operator shall determine [Delta]c using the
calculation protocols outlined in the approved site-specific monitoring
plan and in paragraph (i) of this section.
    (2) The owner or operator shall average the [Delta]c values
collected over the twelve months prior to and including the most recent
sampling episode. The owner or operator shall update this value after
receiving the results of each sampling episode.
    (3) The action level for benzene is 9 micrograms per cubic meter
([mu]g/m\3\). If the 12-month rolling average [Delta]c value for
benzene is less than 9 [mu]g/m\3\, the concentration is below the
action level. If the 12-month rolling average [Delta]c value for
benzene is equal to or greater than 9 [mu]g/m\3\, the concentration is
above the action level, and the owner or operator shall conduct a root
cause analysis and corrective action in accordance with paragraph (g)
of this section.
    (g) Within 5 days of determining that the action level has been
exceeded for any 12-month rolling average and no longer than 35 days
after completion of the sampling episode, the owner or operator shall
initiate a root cause analysis to determine the cause of such
exceedance and to determine appropriate corrective action, as described
in paragraphs (g)(1) through (4) of this section. The root cause
analysis and corrective action analysis shall be completed no later
than 45 days after determining there is an exceedance. Root cause
analysis and corrective action may include, but is not limited to:
    (1) Leak inspection using Method 21 of part 60, Appendix A-7 of
this chapter and repairing any leaks found.
    (2) Leak inspection using optical gas imaging as specified in Sec.
63.661 and repairing any leaks found.
    (3) Visual inspection to determine the cause of the high benzene
emissions and implementing repairs to reduce the level of emissions.
    (4) Employing progressively more frequent sampling, analysis and
meteorology (e.g., using shorter sampling episodes for Methods 325A and
325B of Appendix A of this part, or using active sampling techniques),
or employing additional monitors to determine contributing offsite
sources.
    (h) If, upon completion of the corrective actions described in
paragraph (g) of this section, the action level is exceeded for the
next sampling episode following the completion of the corrective
action, the owner or operator shall develop a corrective action plan
that describes the corrective action(s) completed to date, additional
measures that the owner or operator proposes to employ to reduce
fenceline concentrations below the action level, and a schedule for
completion of these measures. The owner or operator shall submit the
corrective action plan to the Administrator within 60 days after
determining the action level was exceeded during the sampling episode
following the completion of the initial corrective action. The
Administrator shall approve or disapprove the plan in 90 days. The plan
shall be considered approved if the Administrator either approves the
plan in writing, or fails to disapprove the plan in writing. The 90-day
period shall begin when the Administrator receives the plan.
    (i) An owner or operator may request approval from the
Administrator for a site-specific monitoring plan to account for
offsite upwind sources or onsite sources excluded under Sec.  63.640(g)
according to the requirements in paragraphs (i)(1) through (4) of this
section.
    (1) The owner or operator shall prepare and submit a site-specific
monitoring plan and receive approval of the site-specific monitoring
plan prior to using the near-field source alternative calculation for
determining [Delta]c provided in paragraph (i)(2) of this section. The
site-specific monitoring plan shall include, at a minimum, the elements
specified in paragraphs (i)(1)(i) through (v) of this section.
    (i) Identification of the near-field source or sources. For onsite
sources, documentation that the onsite source is excluded under Sec.
63.640(g) and identification of the specific provision in Sec.
63.640(g) that applies to the source.
    (ii) Location of the additional monitoring stations that shall be
used to determine the uniform background concentration and the near-
field source concentration contribution.
    (iii) Identification of the fenceline monitoring locations impacted
by the near-field source. If more than one near-field source is
present, identify for each monitoring location, the near field source
or sources that are expected to contribute to fenceline concentration
at that monitoring location.
    (iv) A description of (including sample calculations illustrating)
the planned data reduction and calculations to determine the near-field
source

concentration contribution for each monitoring location.
    (v) If more frequent monitoring is proposed or if a monitoring
station other than a passive diffusive tub monitoring station is
proposed, provide a detailed description of the measurement methods,
measurement frequency, and recording frequency proposed for determining
the uniform background or near-field source concentration contribution.
    (2) When an approved site-specific monitoring plan is used, the
owner or operator shall determine [Delta]c for comparison with the 9
[mu]g/m\3\ action level using the requirements specified in paragraphs
(2)(i) through (iii) of this section.
    (i) For each monitoring location, calculate [Delta]ci
using the following equation.

[Delta]ci = MCFi - NFSi - UB

Where:

[Delta]ci = The fenceline concentration, corrected for
background, at measurement location i, micrograms per cubic meter
([mu]g/m\3\).
MFCi = The measured fenceline concentration at
measurement location i, [mu]g/m\3\.
NFSi = The near-field source contributing concentration
at measurement location i determined using the additional
measurements and calculation procedures included in the site-
specific monitoring plan, [mu]g/m\3\. For monitoring locations that
are not included in the site-specific monitoring plan as impacted by
a near-field source, use NFSi = 0 [mu]g/m\3\.
UB = The uniform background concentration determined using the
additional measurements specified included in the site-specific
monitoring plan, [mu]g/m\3\. If no additional measurement location
is specified in the site-specific monitoring plan for determining
the uniform background concentration, use UB = 0 [mu]g/m\3\.

    (ii) When one or more samples for the sampling episode are below
the method detection limit for benzene, adhere to the following
procedures:
    (A) If the benzene concentration at the monitoring location used
for the uniform background concentration is below detection, the owner
or operator shall use zero for UB for that monitoring period.
    (B) If the benzene concentration at the monitoring location(s) used
to determine the near-field source contributing concentration is below
detection, the owner or operator shall use zero for the monitoring
location concentration when calculating NFSi for that
monitoring period.
    (C) If a fenceline monitoring location sample result is below the
method detection limit, the owner or operator shall use the method
detection limit as the sample result.
    (iii) Determine [Delta]c for the monitoring period as the maximum
value of [Delta]ci from all of the fenceline monitoring
locations for that monitoring period.
    (3) The site-specific monitoring plan shall be submitted and
approved as described in paragraphs (i)(3)(i) through (iv) of this
section.
    (i) The site-specific monitoring plan must be submitted to the
Administrator for approval.
    (ii) The site-specific monitoring plan shall also be submitted to
the following address: U.S. Environmental Protection Agency, Office of
Air Quality Planning and Standards, Sector Policies and Programs
Division, U.S. EPA Mailroom (E143-01), Attention: Refinery Sector Lead,
109 T.W. Alexander Drive, Research Triangle Park, NC 27711. Electronic
copies in lieu of hard copies may also be submitted to
<EMAIL_ADDRESS>    (iii) The Administrator shall approve or disapprove the plan in 90
days. The plan shall be considered approved if the Administrator either
approves the plan in writing, or fails to disapprove the plan in
writing. The 90-day period shall begin when the Administrator receives
the plan.
    (iv) If the Administrator finds any deficiencies in the site-
specific monitoring plan and disapproves the plan in writing, the owner
or operator may revise and resubmit the site-specific monitoring plan
following the requirements in paragraphs (i)(3)(i) and (ii) of this
section. The 90-day period starts over with the resubmission of the
revised monitoring plan.
    (4) The approval by the Administrator of a site-specific monitoring
plan will be based on the completeness, accuracy and reasonableness of
the request process for a site-specific monitoring plan. Factors that
the EPA will consider in reviewing the request for a site-specific
monitoring plan include, but are not limited to, those described in
paragraphs (i)(4)(i) through (v) of this section.
    (i) The identification of the near-field source or sources. For
onsite sources, the documentation provided that the onsite source is
excluded under Sec.  63.640(g).
    (ii) The monitoring location selected to determine the uniform
background concentration or an indication that no uniform background
concentration monitor will be used.
    (iii) The location(s) selected for additional monitoring to
determine the near-field source concentration contribution.
    (iv) The identification of the fenceline monitoring locations
impacted by the near-field source or sources.
    (v) The appropriateness of the planned data reduction and
calculations to determine the near-field source concentration
contribution for each monitoring location.
    (vi) If more frequent monitoring is proposed or if a monitoring
station other than a passive diffusive tub monitoring station is
proposed, the adequacy of the description of the measurement methods,
measurement frequency, and recording frequency proposed and the
adequacy of the rationale for using the alternative monitoring
frequency or method.
    (j) The owner or operator shall comply with the applicable
recordkeeping and reporting requirements in Sec.  63.655(h) and (i).
0
30. Section 63.660 is added to read as follows:

Sec.  63.660  Storage vessel provisions.

    On and after the applicable compliance date for a Group 1 storage
vessel located at a new or existing source as specified in Sec.
63.640(h), the owner or operator of a Group 1 storage vessel that is
part of a new or existing source shall comply with the requirements in
subpart WW or subpart SS of this part according to the requirements in
paragraphs (a) through (i) of this section.
    (a) As used in this section, all terms not defined in Sec.  63.641
shall have the meaning given them in subpart A, subpart WW, or subpart
SS of this part. The definitions of ``Group 1 storage vessel'' (item 2)
and ``storage vessel'' in Sec.  63.641 shall apply in lieu of the
definition of ``storage vessel'' in Sec.  63.1061.
    (1) An owner or operator may use good engineering judgment or test
results to determine the stored liquid weight percent total organic HAP
for purposes of group determination. Data, assumptions, and procedures
used in the determination shall be documented.
    (2) When an owner or operator and the Administrator do not agree on
whether the annual average weight percent organic HAP in the stored
liquid is above or below 4 percent for a storage vessel at an existing
source or above or below 2 percent for a storage vessel at a new
source, an appropriate method (based on the type of liquid stored) as
published by EPA or a consensus-based standards organization shall be
used. Consensus-based standards organizations include, but are not
limited to, the following: ASTM International (100 Barr Harbor Drive,
P.O. Box CB700, West Conshohocken,

Pennsylvania 19428-B2959,<PHONE_NUMBER>, http://www.astm.org), the
American National Standards Institute (ANSI, 1819 L Street NW., 6th
Floor, Washington, DC 20036,<PHONE_NUMBER>, http://www.ansi.org), the
American Gas Association (AGA, 400 North Capitol Street NW., 4th Floor,
Washington, DC 20001,<PHONE_NUMBER>, http://www.aga.org), the American
Society of Mechanical Engineers (ASME, Three Park Avenue, New York, NY
10016-5990,<PHONE_NUMBER>, http://www.asme.org), the American
Petroleum Institute (API, 1220 L Street NW., Washington, DC 20005-4070,
(202) 682-8000, http://www.api.org), and the North American Energy
Standards Board (NAESB, 801 Travis Street, Suite 1675, Houston, TX
77002,<PHONE_NUMBER>, http://www.naesb.org).
    (b) In addition to the options presented in Sec. Sec.
63.1063(a)(2)(vii)(A), 63.1063(a)(2)(vii)(B), and 63.1064, an external
floating roof storage vessel may comply with Sec.  63.1063(a)(2)(vii)
using a flexible enclosure system as described in item 6 of Appendix I:
Acceptable Controls for Slotted Guidepoles Under the Storage Tank
Emissions Reduction Partnership Program (available at http://www.epa.gov/ttn/atw/petrefine/petrefpg.html).
    (c) For the purposes of this subpart, references shall apply as
specified in paragraphs (c)(1) through (6) of this section.
    (1) All references to ``the proposal date for a referencing
subpart'' and ``the proposal date of the referencing subpart'' in
subpart WW of this part mean June 30, 2014.
    (2) All references to ``promulgation of the referencing subpart''
and ``the promulgation date of the referencing subpart'' in subpart WW
of this part mean [THE DATE OF PUBLICATION OF THE FINAL RULE AMENDMENTS
IN THE FEDERAL REGISTER].
    (3) All references to ``promulgation date of standards for an
affected source or affected facility under a referencing subpart'' in
subpart SS of this part mean [THE DATE OF PUBLICATION OF THE FINAL RULE
AMENDMENTS IN THE FEDERAL REGISTER].
    (4) All references to ``the proposal date of the relevant standard
established pursuant to CAA section 112(f)'' in subpart SS of this part
mean June 30, 2014.
    (5) All references to ``the proposal date of a relevant standard
established pursuant to CAA section 112(d)'' in subpart SS of this part
mean July 14, 1994.
    (6) All references to the ``required control efficiency'' in
subpart SS of this part mean reduction of organic HAP emissions by 95
percent or to an outlet concentration of 20 ppmv.
    (d) For an existing storage vessel fixed roof that meets the
definition of Group 1 storage vessel (item 2) in Sec.  63.641 but not
the definition of Group 1 storage vessel (item 1) in Sec.  63.641, the
requirements of Sec.  63.1062 do not apply until the next time the
storage vessel is completely emptied and degassed, or [THE DATE 10
YEARS AFTER PUBLICATION OF THE FINAL RULE AMENDMENTS IN THE FEDERAL
REGISTER], whichever occurs first.
    (e) Failure to perform inspections and monitoring required by this
section shall constitute a violation of the applicable standard of this
subpart.
    (f) References in Sec.  63.1066(a) to initial startup notification
requirements do not apply.
    (g) References to the Notification of Compliance Status in Sec.
63.999(b) mean the Notification of Compliance Status required by Sec.
63.655(f).
    (h) References to the Periodic Reports in Sec. Sec.  63.1066(b) and
63.999(c) mean the Periodic Report required by Sec.  63.655(g).
    (i) Owners or operators electing to comply with the requirements in
subpart SS of this part for a Group 1 storage vessel must comply with
the requirements in paragraphs (c)(1) through (3) of this section.
    (1) If a flare is used as a control device, the flare shall meet
the requirements of Sec.  63.670 instead of the flare requirements in
Sec.  63.987.
    (2) If a closed vent system contains a bypass line, the owner or
operator shall comply with the provisions of either Sec.
63.985(a)(3)(i) or (ii) for each closed vent system that contains
bypass lines that could divert a vent stream to the atmosphere. Use of
the bypass at any time to divert a Group 1 storage vessel to the
atmosphere is an emissions standards violation. Equipment such as low
leg drains and equipment subject to Sec.  63.648 are not subject to
this paragraph.
    (3) If storage vessel emissions are routed to a fuel gas system or
process, the fuel gas system or process shall be operating at all times
when regulated emissions are routed to it. The exception in paragraph
Sec.  63.984(a)(1) does not apply.
0
31. Section 63.661 is added to read as follows:

Sec.  63.661  Alternative means of emission limitation: Monitoring
equipment leaks using optical gas imaging.

    (a) Applicability. The owner or operator may only use an optical
gas imaging instrument to screen for leaking equipment, as required by
Sec.  63.648, if the requirements in paragraphs (a)(1) through (3) of
this section are met.
    (1) The owner or operator may only use the optical gas imaging
instrument as an alternative to provisions in Sec.  63.648 that would
otherwise require monitoring according to Sec.  60.485(b) or Sec.
63.180(b)(1) through (5), as applicable. The owner or operator shall
continue to comply with all other requirements in Sec.  63.648 (e.g.,
weekly inspections of pumps; for relief valves, installation of a
device that is capable of identifying and recording the time and
duration of each pressure release, if applicable; sampling connection
system requirements).
    (2) The owner or operator must be in compliance with the fenceline
monitoring provisions of Sec.  63.658.
    (3) The optical gas imaging instrument must be able to meet all of
the criteria and requirements specified in part 60, Appendix K of this
chapter, and the owner or operator shall conduct monitoring according
to part 60, Appendix K of this chapter.
    (b) Compliance requirements. The owner or operator shall meet the
requirements of paragraphs (b)(1) through (3) of this section.
    (1) The owner or operator shall identify the equipment and process
units for which the optical gas imaging instrument will be used to
identify leaks.
    (2) The owner or operator shall repair leaking equipment as
required in the applicable section of part 60, subpart VV of this
chapter or subpart H of this part.
    (3) Monitoring to confirm repair of leaking equipment must be
conducted using the procedures referenced in paragraph (a)(2) of this
section.
    (c) Recordkeeping. The owner or operator shall comply with the
applicable requirements in Sec.  63.655(i).
0
32. Section 63.670 is added to read as follows:

Sec.  63.670  Requirements for flare control devices.

    On or before [THE DATE 3 YEARS AFTER THE DATE OF PUBLICATION OF THE
FINAL RULE AMENDMENTS IN THE FEDERAL REGISTER], the owner or operator
of a flare used as a control device for an emission point subject to
this subpart shall meet the applicable requirements for flares as
specified in paragraphs (a) through (q) of this section and the
applicable requirements in Sec.  63.671. The owner or operator may
elect to comply with the requirements of paragraph (r) of this section
in lieu of the requirements in paragraphs (d) through (f) of this
section, as applicable.
    (a) Halogenated vent streams. The owner or operator shall not use a
flare

to control halogenated vent streams as defined in Sec.  63.641.
    (b) Pilot flame presence. The owner or operator shall operate each
flare with a pilot flame present at all times when regulated material
is routed to the flare. The pilot system must be equipped with an
automated device to relight the pilot if extinguished. The owner or
operator shall monitor for the presence of a pilot flame as specified
in paragraph (g) of this section.
    (c) Visible emissions. Each flare must be designed for and operated
with no visible emissions, except for periods not to exceed a total of
5 minutes during any 2 consecutive hours. The owner or operator shall
monitor for visible emissions from the flare as specified in paragraph
(b) of this section.
    (d) Flare tip velocity. For each flare, the owner or operator shall
comply with either paragraph (d)(1) or (d)(2) of this section, provided
the appropriate monitoring systems are in-place. If a total hydrocarbon
analyzer is used for compositional analysis as allowed under section
(j)(4) of this section, then the owner or operator must comply with
paragraph (d)(1) of this section.
    (1) Except as provided in paragraph (d)(2) of this section, the
actual flare tip velocity (Vtip) must be less than 60 feet
per second when regulated material is being routed to the flare. The
owner or operator shall monitor Vtip using the procedures
specified in paragraph (i) and (k) of this section.
    (2) Vtip must be less than 400 feet per second and also
less than the maximum allowed flare tip velocity (Vmax) as
calculated according to the following equation at all times regulated
material is being routed to the flare. The owner or operator shall
monitor Vtip using the procedures specified in paragraph (i)
and (k) of this section and monitor gas composition and determine
NHVvg using the procedures specified in paragraphs (j) and
(l) of this section.
[GRAPHIC] [TIFF OMITTED] TP30JN14.005

Where:

Vmax = Maximum allowed flare tip velocity, ft/sec.
NHVvg = Net heating value of flare vent gas, as
determined by paragraph (l)(4) of this section, Btu/scf.
1,212 = Constant.
850 = Constant.

    (e) Target combustion zone gas properties. For each flare, the
owner or operator shall comply with the applicable requirements in
either paragraph (e)(1), (2), or (3) of this section. The owner or
operator may elect to comply with any of these applicable requirements
at any time (e.g., may elect to comply with the requirements in
paragraph (e)(1) during certain flow conditions and comply with the
requirements in paragraph (e)(2) or (e)(3) under different flow
conditions) provided that the owner or operator has the appropriate
monitoring equipment to determine compliance with the specified
requirement.
    (1) The net heating value of flare combustion zone gas
(NHVcz) must be greater than or equal to the target values
in paragraphs (e)(1)(i) or (ii), as applicable, when regulated material
is being routed to the flare. The owner or operator shall monitor and
calculate NHVcz as specified in paragraph (m) of this
section.
    (i) For flares meeting all three requirements in paragraph (e)(4)
of this section, the target NHVcz value is 380 British
thermal units per standard cubic feet (Btu/scf).
    (ii) For all flares other than those meeting all three requirements
in paragraph (e)(4) of this section, the target NHVcz value
is 270 Btu/scf.
    (2) The lower flammability limit of the combustion zone gas
(LFLcz) must be less than or equal to the target values in
paragraphs (e)(2)(i) or (ii), as applicable, when regulated material is
being routed to the flare. The owner or operator shall monitor and
calculate LFLcz as specified in paragraph (m) of this
section.
    (i) For flares meeting all three requirements in paragraph (e)(4)
of this section, the target LFLcz value is 0.11 volume
fraction.
    (ii) For all flares other than those meeting all three requirements
in paragraph (e)(4) of this section, the target LFLcz value
is 0.15 volume fraction.
    (3) The total volumetric fraction of hydrogen and combustible
organic components present in the combustion zone gas (Ccz),
as propane, must be greater than or equal to the target values in
paragraphs (e)(3)(i) or (ii), as applicable, when regulated material is
being routed to the flare. The owner or operator shall monitor and
calculate Ccz as specified in paragraph (m) of this section.
    (i) For flares meeting all three requirements in paragraph (e)(4)
of this section, the target Ccz value is 0.23 volume
fraction as propane.
    (ii) For all flares other than those meeting all three requirements
in paragraph (e)(4) of this section, the target Ccz value is
0.18 volume fraction as propane.
    (4) More stringent combustion zone gas target properties apply only
during those flare flow periods when all three conditions in paragraphs
(e)(4)(i) through (iii) simultaneously exist. The owner or operator
shall monitor and calculate hydrogen and cumulative olefin combustion
zone concentrations as specified in paragraph (o) of this section:
    (i) The concentration of hydrogen in the combustion zone is greater
than 1.2 percent by volume.
    (ii) The cumulative concentration of olefins in the combustion zone
is greater than 2.5 percent by volume.
    (iii) The cumulative concentration of olefins in the combustion
zone plus the concentration of hydrogen in the combustion zone is
greater than 7.4 percent by volume.
    (f) Target dilution parameters for flares with perimeter assist
air. For each flare actively receiving perimeter assist air, the owner
or operator shall comply with the applicable requirements in either
paragraph (f)(1), (2), or (3) of this section in addition to complying
with the target combustion zone gas properties as specified in
paragraph (e) of this section. The owner or operator may elect to
comply with any of these applicable requirements at any time (e.g., may
elect to comply with the requirements in paragraph (f)(1) during
certain flow conditions and comply with the requirements in paragraph
(f)(2) or (f)(3) under different flow conditions) provided that the
owner or operator has the appropriate monitoring equipment to determine
compliance with the specified requirement.
    (1) The net heating value dilution parameter (NHVdil)
must be greater than or equal to the target values in paragraphs
(f)(1)(i) or (ii), as applicable, when regulated material is being
routed to the flare. The owner or operator shall monitor and calculate
NHVdil as specified in paragraph (n) of this section.
    (i) For flares meeting all three requirements in paragraph (e)(4)
of this section, the target NHVdil value is 31

British thermal units per square foot (Btu/ft\2\).
    (ii) For all flares other than those meeting all three requirements
in paragraph (e)(4) of this section, the target NHVdil value
is 22 Btu/ft\2\.
    (2) The lower flammability limit dilution parameter
(LFLdil) must be less than or equal to the target values in
paragraphs (f)(2)(i) or (ii), as applicable, when regulated material is
being routed to the flare. The owner or operator shall monitor and
calculate LFLdil as specified in paragraph (n) of this
section.
    (i) For flares meeting all three requirements in paragraph (e)(4)
of this section, the target LFLdil value is 1.6 volume
fraction per foot (volume fraction/ft).
    (ii) For all flares other than those meeting all three requirements
in paragraph (e)(4) of this section, the target LFLdil value
is 2.2 volume fraction/ft.
    (3) The combustibles concentration dilution parameter
(Cdil) must be greater than or equal to the target values in
paragraphs (f)(3)(i) or (ii), as applicable, when regulated material is
being routed to the flare. The owner or operator shall monitor and
calculate Cdil as specified in paragraph (n) of this
section.
    (i) For flares meeting all three requirements in paragraph (e)(4)
of this section, the target Cdil value is 0.015 volume
fraction-ft.
    (ii) For all flares other than those meeting all three requirements
in paragraph (e)(4) of this section, the target Ccz value is
0.012 volume fraction-ft.
    (g) Pilot flame monitoring. The owner or operator shall
continuously monitor the presence of the pilot flame(s) using a device
(including, but not limited to, a thermocouple, ultraviolet beam
sensor, or infrared sensor) capable of detecting that the pilot
flame(s) is present.
    (h) Visible emissions monitoring. The owner or operator shall
monitor visible emissions while regulated materials are vented to the
flare. An initial visible emissions demonstration must be conducted
using an observation period of 2 hours using Method 22 at 40 CFR part
60, Appendix A-7. Subsequent visible emissions observations must be
conducted at a minimum of once per day using an observation period of 5
minutes using Method 22 at 40 CFR part 60, Appendix A-7. If at any time
the owner or operator sees visible emissions, even if the minimum
required daily visible emission monitoring has already been performed,
the owner or operator shall immediately begin an observation period of
5 minutes using Method 22 at 40 CFR part 60, Appendix A-7. If visible
emissions are observed for more than one continuous minute during any
5-minute observation period, the observation period using Method 22 at
40 CFR part 60, Appendix A-7 must be extended to 2 hours.
    (i) Flare vent gas, steam assist and air assist flow rate
monitoring. The owner or operator shall install, operate, calibrate,
and maintain a monitoring system capable of continuously measuring,
calculating, and recording the volumetric flow rate in the flare header
or headers that feed the flare. If assist air or assist steam is used,
the owner or operator shall install, operate, calibrate, and maintain a
monitoring system capable of continuously measuring, calculating, and
recording the volumetric flow rate of assist air and/or assist steam
used with the flare. If pre-mix assist air and perimeter assist are