and for each Group 1 storage vessel subject to this subpart, the
information specified in paragraphs (f)(1)(i)(A)(1) through (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. Sec.  63.645 and
63.116(a) of subpart G or Sec.  63.670(h), as applicable; and
* * * * *
    (vii) For pressure relief devices in organic HAP service subject to
the requirements in Sec.  63.648(j)(3)(i) and (ii), this report shall
include the information specified in paragraphs (f)(1)(vii)(A) and (B)
of this section.
    (A) A description of the monitoring system to be implemented,
including the relief devices 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.
    (B) A description of the prevention measures to be implemented for
each affected pressure relief device.
    (viii) For each delayed coking unit, identification of whether the
unit is an existing affected source or a new affected source and
whether monitoring will be conducted as specified in Sec.  63.657(b) or
(c).
    (2) If initial performance tests are required by Sec. Sec.  63.643
through 63.653, the Notification of Compliance Status report shall
include one complete test report for each test method used for a
particular source. On and after February 1, 2016, 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 (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. * * *
    (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 (14) 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 paragraphs (g)(1)

through (7) of this section or paragraphs (g)(9) through (14) 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 (g) if the reports contain the information required by
paragraphs (g)(1) through (14) of this section.
    (1) For storage vessels, Periodic Reports shall include the
information specified for Periodic Reports in paragraphs (g)(2) through
(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)(A)(3) 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.
    (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 (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) through (C) 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), (4), (5), or (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 (4) of subpart G.
    (3) A description of any seal condition specified in Sec.
63.120(b)(5) or (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 (c)(2)(iv)(B) of subpart WW
shall, in the next Periodic Report, submit the documentation required
by those paragraphs.
    (4) [Reserved]
    (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 (v) 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 (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 January 30, 2019 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 and shall include: Identification of the flare that does not
meet the general requirements specified in Sec.  63.11(b) of subpart A,
and reasons the flare did not meet the general requirements specified
in Sec.  63.11(b) of subpart A.
    (iv) If a flare is used on or after the date for which compliance
with the requirements in Sec.  63.670 is elected, which can be no later
than January 30, 2019, 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) * * *
    (i) * * *
    (D) For data compression systems under paragraph (h)(5)(iii) of
this section, an operating day when the monitor operated for less than
75 percent of the operating hours or a day when less than 18 monitoring
values were recorded.
* * * * *
    (iii) For periods in closed vent systems when a Group 1
miscellaneous process vent stream was detected in the bypass line or
diverted from the control device and either directly to the atmosphere
or to a control device that does not comply with the requirements in
Sec.  63.643(a), report the date, time, duration, estimate of the
volume of gas, the concentration of organic HAP in the gas and the
resulting mass emissions of organic HAP that bypassed the control
device. For periods when the flow indicator is not operating, report
the date, time, and duration.
    (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 pressure relief devices subject to the requirements Sec.
63.648(j), Periodic Reports must include the information specified in
paragraphs (g)(10)(i) through (iii) of this section.
    (i) For pressure relief devices in organic HAP gas or vapor
service, pursuant to Sec.  63.648(j)(1), report any instrument reading
of 500 ppm or greater.
    (ii) For pressure relief devices in organic HAP gas or vapor
service subject to Sec.  63.648(j)(2), report confirmation that any
monitoring required to be done during the reporting period to show
compliance was conducted.
    (iii) For pressure relief devices in organic HAP service subject to
Sec.  63.648(j)(3), report each pressure release to the atmosphere,
including duration of the pressure release and estimate of the mass
quantity of each organic HAP released, and the results of any root
cause analysis and corrective action analysis completed during the
reporting period, including the corrective actions implemented during
the reporting period and, if applicable, the implementation schedule
for planned corrective actions to be implemented subsequent to the
reporting period.
    (11) For flares subject to Sec.  63.670, Periodic Reports must
include the information specified in paragraphs (g)(11)(i) through (iv)
of this section.
    (i) Records as specified in paragraph (i)(9)(i) of this section for
each 15-minute block during which there was at least one minute when
regulated material is routed to a flare and no pilot flame is present.
    (ii) Visible emission records as specified in paragraph
(i)(9)(ii)(C) 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 net heating value
operating parameter(s) determined following the methods in Sec.
63.670(k) through (n) as applicable.
    (iv) For flaring events meeting the criteria in Sec.  63.670(o)(3):
    (A) The start and stop time and date of the flaring event.
    (B) The length of time for which emissions were visible from the
flare during the event.
    (C) The periods of time that the flare tip velocity exceeds the
maximum flare tip velocity determined using the methods in Sec.
63.670(d)(2) and the maximum 15-minute block average flare tip velocity
recorded during the event.
    (D) Results of the root cause and corrective actions analysis
completed during the reporting period, including the corrective actions
implemented during the reporting period and, if applicable, the
implementation schedule for planned corrective actions to be
implemented subsequent to the reporting period.
    (12) For delayed coking units, the Periodic Report must include the
information specified in paragraphs (g)(12)(i) through (iv) of this
section.
    (i) For existing source delayed coking units, any 60-cycle average
exceeding the applicable limit in Sec.  63.657(a)(1).
    (ii) For new source delayed coking units, any direct venting event

exceeding the applicable limit in Sec.  63.657(a)(2).
    (iii) The total number of double quenching events performed during
the reporting period.
    (iv) For each double quenching draining event when the drain water
temperature exceeded 210 [deg]F, report the drum, date, time, the coke
drum vessel pressure or temperature, as applicable, when pre-vent
draining was initiated, and the maximum drain water temperature during
the pre-vent draining period.
    (13) For maintenance vents subject to the requirements in Sec.
63.643(c), Periodic Reports must include the information specified in
paragraphs (g)(13)(i) through (iv) of this section for any release
exceeding the applicable limits in Sec.  63.643(c)(1). For the purposes
of this reporting requirement, owners or operators complying with Sec.
63.643(c)(1)(iv) must report each venting event for which the lower
explosive limit is 20 percent or greater.
    (i) Identification of the maintenance vent and the equipment served
by the maintenance vent.
    (ii) The date and time the maintenance vent was opened to the
atmosphere.
    (iii) The lower explosive limit, vessel pressure, or mass of VOC in
the equipment, as applicable, at the start of atmospheric venting. If
the 5 psig vessel pressure option in Sec.  63.643(c)(1)(ii) was used
and active purging was initiated while the lower explosive limit was 10
percent or greater, also include the lower explosive limit of the
vapors at the time active purging was initiated.
    (iv) An estimate of the mass of organic HAP released during the
entire atmospheric venting event.
    (14) 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 (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), (a)(3), or
(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 (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.
* * * * *
    (5) * * *
    (iii) An owner or operator may use an automated data compression
recording system that does not record monitored operating parameter
values at a set frequency (for example, once every hour) but records
all values that meet set criteria for variation from previously
recorded values.
    (A) The system shall be designed to:
    (1) Measure the operating parameter value at least once every hour.
    (2) Record at least 24 values each day during periods of operation.
    (3) Record the date and time when monitors are turned off or on.
    (4) Recognize unchanging data that may indicate the monitor is not
functioning properly, alert the operator, and record the incident.
    (5) Compute daily average values of the monitored operating
parameter based on recorded data.
    (B) You must maintain a record of the description of the monitoring
system and data compression recording system including the criteria
used to determine which monitored values are recorded and retained, the
method for calculating daily averages, and a demonstrations that they
system meets all criteria of paragraph (h)(5)(iii)(A) of this section.
* * * * *
    (8) For fenceline monitoring systems subject to Sec.  63.658,
within 45 calendar days after the end of each quarterly reporting
period covered by the periodic report, each owner or operator shall
submit the following information to the EPA's Compliance and Emissions
Data Reporting Interface (CEDRI). (CEDRI can be accessed through the
EPA's Central Data Exchange (CDX) (https://cdx.epa.gov/). 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
period during the quarterly 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 annual average concentration difference
([Delta]c) values for benzene for the quarterly 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 February 1, 2016, if required to submit the
results of a performance test or CEMS performance evaluation, the owner
or operator shall submit the results 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 following the procedure specified
in either paragraph (h)(9)(i)(A) or (B) of this section.
    (A) For data collected using test methods supported by the EPA's
Electronic Reporting Tool (ERT) as listed on the EPA's ERT Web site
(http://www.epa.gov/ttn/chief/ert/index.html) at the time of the test,
the owner or operator must submit the results of the performance test
to the EPA via the CEDRI. (CEDRI can be accessed through the EPA's
CDX.) Performance test data must be submitted in a file format
generated through the use of the EPA's ERT or an alternate electronic
file format consistent with the extensible markup language (XML) schema
listed on the EPA's ERT Web site. 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 or an
alternate electronic file consistent with the XML schema listed on the
EPA's ERT Web site, including information claimed to be CBI, on a
compact disc, flash drive or other commonly used electronic storage
media to the EPA. The electronic storage media must be clearly marked
as CBI and mailed to U.S. EPA/OAQPS/

CORE CBI Office, Attention: Group Leader, Measurement Policy Group, MD
C404-02, 4930 Old Page Rd., Durham, NC 27703. The same ERT or alternate
file with the CBI omitted must be submitted to the EPA via the EPA's
CDX as described earlier in this paragraph (h)(9)(i)(A).
    (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 at the time of the
test, 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
following the procedure specified in either paragraph (h)(9)(ii)(A) or
(B) of this section.
    (A) For performance evaluations of continuous monitoring systems
measuring relative accuracy test audit (RATA) pollutants that are
supported by the EPA's ERT as listed on the EPA's ERT Web site at the
time of the evaluation, the owner or operator must submit the results
of the performance evaluation to the EPA via the CEDRI. (CEDRI can be
accessed through the EPA's CDX.) Performance evaluation data must be
submitted in a file format generated through the use of the EPA's ERT
or an alternate file format consistent with the XML schema listed on
the EPA's ERT Web site. 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 or an alternate electronic file consistent with the XML
schema listed on the EPA's ERT Web site, including information claimed
to be CBI, on a compact disc, flash drive or other commonly used
electronic storage media to the EPA. The electronic storage media must
be clearly marked as CBI and mailed to U.S. EPA/OAQPS/CORE CBI Office,
Attention: Group Leader, Measurement Policy Group, MD C404-02, 4930 Old
Page Rd., Durham, NC 27703. The same ERT or alternate file with the CBI
omitted must be submitted to the EPA via the EPA's CDX as described
earlier in this paragraph (h)(9)(ii)(A).
    (B) For any performance evaluations of continuous monitoring
systems measuring RATA pollutants that are not supported by the EPA's
ERT as listed on the EPA's ERT Web site at the time of the evaluation,
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 (12) 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 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
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 or Sec.  63.998, as applicable.
    (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 either
directly to the atmosphere or to a control device that does not comply
with the requirements in Sec.  63.643(a), 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 periods when
flow was detected in the bypass line, including the date and time and
the duration of the flow in the bypass line. For each flow event, the
owner or operator shall maintain records sufficient to determine
whether or not the detected flow included flow of a Group 1
miscellaneous process vent stream requiring control. For periods when
the Group 1 miscellaneous process vent stream requiring control is
diverted from the control device and released either directly to the
atmosphere or to a control device that does not comply with the
requirements in Sec.  63.643(a), 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 using process knowledge and engineering estimates.
    (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 mass
emissions of organic HAP from the Group 1 miscellaneous process vent
stream requiring control that bypassed the control device or records
sufficient to demonstrate that there was no flow of a Group 1
miscellaneous process vent stream requiring control during the period.
    (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
specified in paragraphs (i)(7)(i) through (iii) of this section.
    (i) The average pressure or temperature, as applicable, 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.
    (ii) If complying with the 60-cycle rolling average, each 60-cycle
rolling average pressure or temperature, as applicable, considering all
coke drum venting events in the existing affected source.
    (iii) For double-quench cooling cycles:

    (A) The date, time and duration of each pre-vent draining event.
    (B) The pressure or temperature of the coke drum vessel, as
applicable, for the 15 minute period prior to the pre-vent draining.
    (C) The drain water temperature at 1-minute intervals from the
start of pre-vent draining to the complete closure of the drain valve.
    (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 (x) of this section on an ongoing basis.
    (i) Coordinates of all passive monitors, including replicate
samplers and field blanks, and if applicable, 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) Sampling period average temperature and 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 period and the two samples used to determine it,
whether background correction was used, and the annual average [Delta]c
calculated after each sampling period.
    (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.
    (x) If a near-field source correction is used as provided in Sec.
63.658(i), records of hourly meteorological data, including
temperature, barometric pressure, wind speed and wind direction,
calculated daily unit vector wind direction and daily sigma theta, and
other records specified in the site-specific monitoring plan.
    (9) For each flare subject to Sec.  63.670, each owner or operator
shall keep the records specified in paragraphs (i)(9)(i) through (xii)
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 each 15-minute block during
which there was at least one minute that no pilot flame is present when
regulated material is routed to a flare for a minimum of 5 years.
    (ii) Retain records of daily visible emissions observations or
video surveillance images required in Sec.  63.670(h) as specified in
the paragraphs (i)(9)(ii)(A) through (C), as applicable, for a minimum
of 3 years.
    (A) If visible emissions observations are performed using Method 22
at 40 CFR part 60, appendix A-7, 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.
    (B) If video surveillance camera is used, the record must include
all video surveillance images recorded, with time and date stamps.
    (C) For each 2 hour period for which visible emissions are observed
for more than 5 minutes in 2 consecutive hours, the record must include
the date and time of the 2 hour period and an estimate of the
cumulative number of minutes in the 2 hour period for which emissions
were visible.
    (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 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 (n), as
applicable.
    (vi) [Reserved]
    (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) Records when the flow of vent gas exceeds the smokeless
capacity of the flare, including start and stop time and dates of the
flaring event.
    (xi) Records of the root cause analysis and corrective action
analysis conducted as required in Sec.  63.670(o)(3), including an
identification of the affected facility, the date and duration of the
event, a statement noting whether the event resulted from the same root
cause(s) identified in a previous analysis and either a description of
the recommended corrective action(s) or an explanation of why
corrective action is not necessary under Sec.  63.670(o)(5)(i).
    (xii) For any corrective action analysis for which implementation
of corrective actions are required in Sec.  63.670(o)(5), a description
of the corrective action(s) completed within the first 45 days
following the discharge and, for action(s) not already completed, a
schedule for implementation, including proposed commencement and
completion dates.
    (10) [Reserved]
    (11) For each pressure relief device subject to the pressure
release management work practice standards in Sec.  63.648(j)(3), the
owner or operator shall keep the records specified in paragraphs
(i)(11)(i) through (iii) of this section.
    (i) Records of the prevention measures implemented as required in
Sec.  63.648(j)(3)(ii), if applicable.

    (ii) Records of the number of releases during each calendar year
and the number of those releases for which the root cause was
determined to be a force majeure event. Keep these records for the
current calendar year and the past five calendar years.
    (iii) For each release to the atmosphere, the owner or operator
shall keep the records specified in paragraphs (i)(11)(iii)(A) through
(D) of this section.
    (A) The start and end time and date of each pressure release to the
atmosphere.
    (B) Records of any data, assumptions, and calculations used to
estimate of the mass quantity of each organic HAP released during the
event.
    (C) Records of the root cause analysis and corrective action
analysis conducted as required in Sec.  63.648(j)(3)(iii), including an
identification of the affected facility, the date and duration of the
event, a statement noting whether the event resulted from the same root
cause(s) identified in a previous analysis and either a description of
the recommended corrective action(s) or an explanation of why
corrective action is not necessary under Sec.  63.648(j)(7)(i).
    (D) For any corrective action analysis for which implementation of
corrective actions are required in Sec.  63.648(j)(7), a description of
the corrective action(s) completed within the first 45 days following
the discharge and, for action(s) not already completed, a schedule for
implementation, including proposed commencement and completion dates.
    (12) For each maintenance vent opening subject to the requirements
in Sec.  63.643(c), the owner or operator shall keep the applicable
records specified in (i)(12)(i) through (v) of this section.
    (i) The owner or operator shall maintain standard site procedures
used to deinventory equipment for safety purposes (e.g., hot work or
vessel entry procedures) to document the procedures used to meet the
requirements in Sec.  63.643(c). The current copy of the procedures
shall be retained and available on-site at all times. Previous versions
of the standard site procedures, is applicable, shall be retained for
five years.
    (ii) If complying with the requirements of Sec.  63.643(c)(1)(i)
and the lower explosive limit at the time of the vessel opening exceeds
10 percent, identification of the maintenance vent, the process units
or equipment associated with the maintenance vent, the date of
maintenance vent opening, and the lower explosive limit at the time of
the vessel opening.
    (iii) If complying with the requirements of Sec.  63.643(c)(1)(ii)
and either the vessel pressure at the time of the vessel opening
exceeds 5 psig or the lower explosive limit at the time of the active
purging was initiated exceeds 10 percent, identification of the
maintenance vent, the process units or equipment associated with the
maintenance vent, the date of maintenance vent opening, the pressure of
the vessel or equipment at the time of discharge to the atmosphere and,
if applicable, the lower explosive limit of the vapors in the equipment
when active purging was initiated.
    (iv) If complying with the requirements of Sec.  63.643(c)(1)(iii),
identification of the maintenance vent, the process units or equipment
associated with the maintenance vent, the date of maintenance vent
opening, and records used to estimate the total quantity of VOC in the
equipment at the time the maintenance vent was opened to the atmosphere
for each applicable maintenance vent opening.
    (v) If complying with the requirements of Sec.  63.643(c)(1)(iv),
identification of the maintenance vent, the process units or equipment
associated with the maintenance vent, records documenting the lack of a
pure hydrogen supply, the date of maintenance vent opening, and the
lower explosive limit of the vapors in the equipment at the time of
discharge to the atmosphere for each applicable maintenance vent
opening.

0
28. Section 63.656 is amended by revising paragraph (c)(1) to read as
follows:

Sec.  63.656  Implementation and enforcement.

* * * * *
    (c) * * *
    (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 63.660, 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.
* * * * *

0
29. Section 63.657 is added to read as follows:

Sec.  63.657  Delayed coking unit decoking operation standards.

    (a) Except as provided in paragraphs (e) and (f) of this section,
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 or temperature measured at the top of the coke drum or in the
overhead line of the coke drum as near as practical to the coke drum
meets the applicable limits specified in paragraph (a)(1) or (2) of
this section prior to venting to the atmosphere, draining or deheading
the coke drum at the end of the cooling cycle.
    (1) For delayed coking units at an existing affected source, meet
either:
    (i) An average vessel pressure of 2 psig determined on a rolling
60-event average; or
    (ii) An average vessel temperature of 220 degrees Fahrenheit
determined on a rolling 60-event average.
    (2) For delayed coking units at a new affected source, meet either:
    (i) A vessel pressure of 2.0 psig for each decoking event; or
    (ii) A vessel temperature of 218 degrees Fahrenheit for each
decoking event.
    (b) Each owner or operator of a delayed coking unit complying with
the pressure limits in paragraph (a)(1)(i) or (a)(2)(i) of this section
shall install, operate, calibrate, and maintain a monitoring system, as
specified in paragraphs (b)(1) through (5) of this section, to
determine the coke drum vessel pressure.
    (1) The pressure monitoring system must be in a representative
location (at the top of the coke drum or in the overhead line as near
as practical to the coke drum) that minimizes or eliminates pulsating
pressure, vibration, and, to the extent practical, internal and
external corrosion.
    (2) The pressure monitoring system must be capable of measuring a
pressure of 2.0 psig within 0.5 psig.
    (3) The pressure monitoring system must be verified annually or at
the frequency recommended by the instrument manufacturer. The pressure
monitoring system must be verified following any period of more than 24
hours throughout which the pressure exceeded the maximum rated pressure
of the sensor, or the data recorder was off scale.
    (4) All components of the pressure monitoring system must be
visually inspected for integrity, oxidation and galvanic corrosion
every 3 months, unless the system has a redundant pressure sensor.
    (5) The output of the pressure monitoring system must be reviewed

daily to ensure that the pressure readings fluctuate as expected
between operating and cooling/decoking cycles to verify the pressure
taps are not plugged. Plugged pressure taps must be unplugged or
otherwise repaired prior to the next operating cycle.
    (c) Each owner or operator of a delayed coking unit complying with
the temperature limits in paragraph (a)(1)(ii) or (a)(2)(ii) of this
section shall install, operate, calibrate, and maintain a continuous
parameter monitoring system to measure the coke drum vessel temperature
(at the top of the coke drum or in the overhead line as near as
practical to the coke drum) according to the requirements specified in
table 13 of this subpart.
    (d) The owner or operator of a delayed coking unit shall determine
the coke drum vessel pressure or temperature, as applicable, on a 5-
minute rolling average basis while the coke drum is vented to the
closed blowdown system and shall use the last complete 5-minute rolling
average pressure or temperature just prior to initiating steps to
isolate the coke drum prior to venting, draining or deheading to
demonstrate compliance with the requirements in paragraph (a) of this
section. Pressure or temperature 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 or
temperature for the purpose of compliance with the requirements in
paragraph (a) of this section.
    (e) The owner or operator of a delayed coking unit using the
``water overflow'' method of coke cooling must hardpipe the overflow
water or otherwise prevent exposure of the overflow water to the
atmosphere when transferring the overflow water to the overflow water
storage tank whenever the coke drum vessel temperature exceeds 220
degrees Fahrenheit. The overflow water storage tank may be an open or
fixed-roof tank provided that a submerged fill pipe (pipe outlet below
existing liquid level in the tank) is used to transfer overflow water
to the tank. The owner or operator of a delayed coking unit using the
``water overflow'' method of coke cooling shall determine the coke drum
vessel temperature as specified in paragraphs (c) and (d) of this
section regardless of the compliance method used to demonstrate
compliance with the requirements in paragraph (a) of this section.
    (f) The owner or operator of a delayed coking unit may partially
drain a coke drum prior to achieving the applicable limits in paragraph
(a) of this section in order to double-quench a coke drum that did not
cool adequately using the normal cooling process steps provided that
the owner or operator meets the conditions in paragraphs (f)(1) and (2)
of this section.
    (1) The owner or operator shall install, operate, calibrate, and
maintain a continuous parameter monitoring system to measure the drain
water temperature at the bottom of the coke drum or in the drain line
as near as practical to the coke drum according to the requirements
specified in table 13 of this subpart.
    (2) The owner or operator must maintain the drain water temperature
below 210 degrees Fahrenheit during the partial drain associated with
the double-quench event.

0
30. 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 and paragraphs (b) through (k)
of this section.
    (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.
    (1) As it pertains to this subpart, known sources of VOCs, as used
in Section <IP_ADDRESS> in Method 325A of appendix A of this part for siting
passive monitors means a wastewater treatment unit, process unit, or
any emission source requiring control according to the requirements of
this subpart, including marine vessel loading operations. For marine
loading operations that are located offshore, one passive monitor
should be sited on the shoreline adjacent to the dock.
    (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 plan, 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 period and at
least two field blanks per sampling period, 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 collect and record meteorological
data according to the applicable requirements in paragraphs (d)(1)
through (3) of this section.
    (1) If a near-field source correction is used as provided in
paragraph (i)(1) of this section or if an alternative test method is
used that provides time-resolved measurements, the owner or operator
shall:
    (i) Use an on-site meteorological station in accordance with
Section 8.3 of Method 325A of appendix A of this part.
    (ii) Collect and record hourly average meteorological data,
including temperature, barometric pressure, wind speed and wind
direction and calculate daily unit vector wind direction and daily
sigma theta.
    (2) For cases other than those specified in paragraph (d)(1) of
this section, the owner or operator shall collect and record sampling
period average temperature and barometric pressure using either an on-
site meteorological station in accordance with Section 8.3 of Method
325A of appendix A of this part or, alternatively, using data from a
United States Weather Service (USWS) meteorological station provided
the USWS meteorological station is within 40 kilometers (25 miles) of
the refinery.
    (3) If an on-site meteorological station is used, the owner or
operator shall follow the calibration and standardization procedures
for meteorological measurements in EPA-454/B-08-002 (incorporated by
reference--see Sec.  63.14).
    (e) The owner of operator shall use a sampling period and sampling
frequency as specified in paragraphs (e)(1) through (3) of this
section.
    (1) Sampling period. A 14-day sampling period shall be used, unless
a shorter sampling period is determined to be necessary under paragraph
(g) or (i) of this section. A sampling period is defined as the period
during which sampling tube is deployed at a specific sampling location
with the diffusive

sampling end cap in-place and does not include the time required to
analyze the sample. For the purpose of this subpart, a 14-day sampling
period may be no shorter than 13 calendar days and no longer than 15
calendar days, but the routine sampling period shall be 14 calendar
days.
    (2) Base sampling frequency. Except as provided in paragraph (e)(3)
of this section, the frequency of sample collection shall be once each
contiguous 14-day sampling period, such that the beginning of the next
14-day sampling period begins immediately upon the completion of the
previous 14-day sampling period.
    (3) Alternative sampling frequency for burden reduction. When an
individual monitor consistently achieves results at or below 0.9 [mu]g/
m\3\, the owner or operator may elect to use the applicable minimum
sampling frequency specified in paragraphs (e)(3)(i) through (v) of
this section for that monitoring site. When calculating [Delta]c for
the monitoring period when using this alternative for burden reduction,
zero shall be substituted for the sample result for the monitoring site
for any period where a sample is not taken.
    (i) If every sample at a monitoring site is at or below 0.9 [mu]g/
m3 for 2 years (52 consecutive samples), every other
sampling period can be skipped for that monitoring site, i.e., sampling
will occur approximately once per month.
    (ii) If every sample at a monitoring site that is monitored at the
frequency specified in paragraph (e)(3)(i) of this section is at or
below 0.9 [mu]g/m3 for 2 years (i.e., 26 consecutive
``monthly'' samples), five 14-day sampling periods can be skipped for
that monitoring site following each period of sampling, i.e., sampling
will occur approximately once per quarter.
    (iii) If every sample at a monitoring site that is monitored at the
frequency specified in paragraph (e)(3)(ii) of this section is at or
below 0.9 [mu]g/m3 for 2 years (i.e., 8 consecutive
quarterly samples), twelve 14-day sampling periods can be skipped for
that monitoring site following each period of sampling, i.e., sampling
will occur twice a year.
    (iv) If every sample at a monitoring site that is monitored at the
frequency specified in paragraph (e)(3)(iii) of this section is at or
below 0.9 [mu]g/m3 for an 2 years (i.e., 4 consecutive semi-
annual samples), only one sample per year is required for that
monitoring site. For yearly sampling, samples shall occur at least 10
months but no more than 14 months apart.
    (v) If at any time a sample for a monitoring site that is monitored
at the frequency specified in paragraphs (e)(3)(i) through (iv) of this
section returns a result that is above 0.9 [mu]g/m\3\, the sampling
site must return to the original sampling requirements of contiguous
14-day sampling periods with no skip periods for one quarter (six 14-
day sampling periods). If every sample collected during this quarter is
at or below 0.9 [mu]g/m3 , the owner or operator may revert
back to the reduced monitoring schedule applicable for that monitoring
site prior to the sample reading exceeding 0.9 [mu]g/m3 If
any sample collected during this quarter is above 0.9 [mu]g/m\3\, that
monitoring site must return to the original sampling requirements of
contiguous 14-day sampling periods with no skip periods for a minimum
of two years. The burden reduction requirements can be used again for
that monitoring site once the requirements of paragraph (e)(3)(i) of
this section are met again, i.e., after 52 contiguous 14-day samples
with no results above 0.9 [mu]g/m3 .
    (f) Within 45 days of completion of each sampling period, the owner
or operator shall determine whether the results are above or below the
action level as follows:
    (1) The owner or operator shall determine the facility impact on
the benzene concentration ([Delta]c) for each 14-day sampling period
according to either paragraph (f)(1)(i) or (ii) of this section, as
applicable.
    (i) Except when near-field source correction is used as provided in
paragraph (i) of this section, the owner or operator shall determine
the highest and lowest sample results for benzene concentrations from
the sample pool and calculate [Delta]c as the difference in these
concentrations. The owner or operator shall adhere to the following
procedures when one or more samples for the sampling period 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) When near-field source correction is used as provided in
paragraph (i) of this section, 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 calculate the annual average
[Delta]c based on the average of the 26 most recent 14-day sampling
periods. The owner or operator shall update this annual average value
after receiving the results of each subsequent 14-day sampling period.
    (3) The action level for benzene is 9 micrograms per cubic meter
([mu]g/m3) on an annual average basis. If the annual average [Delta]c
value for benzene is less than or equal to 9 [mu]g/m\3\, the
concentration is below the action level. If the annual average [Delta]c
value for benzene is 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 annual average [Delta]c and no longer than 50 days
after completion of the sampling period, the owner or operator shall
initiate a root cause analysis to determine the cause of such
exceedance and to determine appropriate corrective action, such as
those described in paragraphs (g)(1) through (4) of this section. The
root cause analysis and initial corrective action analysis shall be
completed and initial corrective actions taken 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 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 periods for Methods 325A and
325B of appendix A of this part, or using active sampling techniques).
    (h) If, upon completion of the corrective action analysis and
corrective actions such as those described in paragraph (g) of this
section, the [Delta]c value for the next 14-day sampling period for
which the sampling start time begins after the completion of the
corrective actions is greater than 9 [mu]g/m\3\ or if all corrective
action measures identified require more than 45 days to implement, 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 receiving the analytical results
indicating that the [Delta]c value for the 14-day sampling period
following the completion of the initial corrective action is greater
than 9 [mu]g/m\3\ or, if no initial corrective actions were identified,
no later than 60 days following the completion of the corrective action
analysis required in paragraph (g) of this section.
    (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. The
procedures in Section 12 of Method 325A of appendix A of this part are
not required, but may be used, if applicable, when determining near-
field source contributions.
    (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 the near-field source or sources that are expected to
contribute to the 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 or a monitoring station other than
a passive diffusive tube monitoring station is proposed, provide a
detailed description of the measurement methods, measurement frequency,
and recording frequency 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
(i)(2)(i) through (iii) of this section.
    (i) For each monitoring location, calculate [Delta]ci
using the following equation.

[Delta]ci = MFCi - 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 included in the site-specific monitoring
plan, [mu]g/m\3\. If no additional measurements are 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 period 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 the method detection
limit, 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
the method detection limit, 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 for a site-specific monitoring plan. Factors that the
Administrator 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, the adequacy of the
description of the measurement and

recording frequency proposed and the adequacy of the rationale for
using the alternative monitoring frequency.
    (j) The owner or operator shall comply with the applicable
recordkeeping and reporting requirements in Sec.  63.655(h) and (i).
    (k) As outlined in Sec.  63.7(f), the owner or operator may submit
a request for an alternative test method. At a minimum, the request
must follow the requirements outlined in paragraphs (k)(1) through (7)
of this section.
    (1) The alternative method may be used in lieu of all or a partial
number of passive samplers required in Method 325A of appendix A of
this part.
    (2) The alternative method must be validated according to Method
301 in appendix A of this part or contain performance based procedures
and indicators to ensure self-validation.
    (3) The method detection limit must nominally be at least an order
of magnitude below the action level, i.e., 0.9 [micro]g/m3
benzene. The alternate test method must describe the procedures used to
provide field verification of the detection limit.
    (4) The spatial coverage must be equal to or better than the
spatial coverage provided in Method 325A of appendix A of this part.
    (i) For path average concentration open-path instruments, the
physical path length of the measurement shall be no more than a passive
sample footprint (the spacing that would be provided by the sorbent
traps when following Method 325A). For example, if Method 325A requires
spacing monitors A and B 610 meters (2000 feet) apart, then the
physical path length limit for the measurement at that portion of the
fenceline shall be no more than 610 meters (2000 feet).
    (ii) For range resolved open-path instrument or approach, the
instrument or approach must be able to resolve an average concentration
over each passive sampler footprint within the path length of the
instrument.
    (iii) The extra samplers required in Sections <IP_ADDRESS> of Method
325A may be omitted when they fall within the path length of an open-
path instrument.
    (5) At a minimum, non-integrating alternative test methods must
provide a minimum of one cycle of operation (sampling, analyzing, and
data recording) for each successive 15-minute period.
    (6) For alternative test methods capable of real time measurements
(less than a 5 minute sampling and analysis cycle), the alternative
test method may allow for elimination of data points corresponding to
outside emission sources for purpose of calculation of the high point
for the two week average. The alternative test method approach must
have wind speed, direction and stability class of the same time
resolution and within the footprint of the instrument.
    (7) For purposes of averaging data points to determine the [Delta]c
for the 14-day average high sample result, all results measured under
the method detection limit must use the method detection limit. For
purposes of averaging data points for the 14-day average low sample
result, all results measured under the method detection limit must use
zero.

0
31. 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 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, WW, or SS of this part.
The definitions of ``Group 1 storage vessel'' (paragraph (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, (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).
    (b) A floating roof storage vessel complying with the requirements
of subpart WW of this part may comply with the control option specified
in paragraph (b)(1) of this section and, if equipped with a ladder
having at least one slotted leg, shall comply with one of the control
options as described in paragraph (b)(2) of this section.
    (1) In addition to the options presented in Sec. Sec.
63.1063(a)(2)(viii)(A) and (B) and 63.1064, a floating roof storage
vessel may comply with Sec.  63.1063(a)(2)(vii) using a flexible
enclosure device and either a gasketed or welded cap on the top of the
guidepole.
    (2) Each opening through a floating roof for a ladder having at
least one slotted leg shall be equipped with one of the configurations
specified in paragraphs (b)(2)(i) through (iii) of this section.
    (i) A pole float in the slotted leg and pole wipers for both legs.
The wiper or seal of the pole float must be at or above the height of
the pole wiper.
    (ii) A ladder sleeve and pole wipers for both legs of the ladder.
    (iii) A flexible enclosure device and either a gasketed or welded
cap on the top of the slotted leg.
    (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 February 1, 2016.
    (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 February 1, 2016.
    (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 uncontrolled fixed roof storage vessel that commenced
construction on or before June 30, 2014, and that meets the definition
of ``Group 1 storage vessel'', paragraph (2), in Sec.  63.641 but not
the definition of ``Group 1 storage vessel'', paragraph (1), in Sec.
63.641, the requirements of Sec.  63.982 and/or Sec.  63.1062 do not
apply until the next time the storage vessel is completely emptied and
degassed, or January 30, 2026, 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 (i)(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.
63.983(a)(3)(i) or (ii) for each closed vent system that contains
bypass lines that could divert a vent stream either directly to the
atmosphere or to a control device that does not comply with the
requirements in subpart SS of this part. Except as provided in
paragraphs (i)(2)(i) and (ii) of this section, use of the bypass at any
time to divert a Group 1 storage vessel to either directly to the
atmosphere or to a control device that does not comply with the
requirements in subpart SS of this part is an emissions standards
violation. Equipment such as low leg drains and equipment subject to
Sec.  63.648 are not subject to this paragraph (i)(2).
    (i) If planned routine maintenance of the control device cannot be
performed during periods that storage vessel emissions are vented to
the control device or when the storage vessel is taken out of service
for inspections or other planned maintenance reasons, the owner or
operator may bypass the control device.
    (ii) Periods for which storage vessel control device may be
bypassed for planned routine maintenance of the control device shall
not exceed 240 hours per calendar year.
    (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 Sec.
63.984(a)(1) does not apply.

0
32. Section 63.670 is added to read as follows:

Sec.  63.670  Requirements for flare control devices.

    On or before January 30, 2019, 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) [Reserved]
    (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. Each 15-minute block during which there is at
least one minute where no pilot flame is present when regulated
material is routed to the flare is a deviation of the standard.
Deviations in different 15-minute blocks from the same event are
considered separate deviations. The owner or operator shall monitor for
the presence of a pilot flame as specified in paragraph (g) of this
section.
    (c) Visible emissions. The owner or operator shall specify the
smokeless design capacity of each flare and operate with no visible
emissions, except for periods not to exceed a total of 5 minutes during
any 2 consecutive hours, when regulated material is routed to the flare
and the flare vent gas flow rate is less than the smokeless design
capacity of the flare. The owner or operator shall monitor for visible
emissions from the flare as specified in paragraph (h) of this section.
    (d) Flare tip velocity. For each flare, the owner or operator shall
comply with either paragraph (d)(1) or (2) of this section, provided
the appropriate monitoring systems are in-place, whenever regulated
material is routed to the flare for at least 15-minutes and the flare
vent gas flow rate is less than the smokeless design capacity of the
flare.
    (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. The owner or operator shall monitor Vtipusing
the procedures specified in paragraphs (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. The owner or operator
shall monitor Vtip using the procedures specified in paragraphs (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] TR01DE15.008

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) Combustion zone operating limits. For each flare, the owner or
operator shall operate the flare to maintain the net heating value of
flare combustion zone gas (NHVcz) at or above 270 British
thermal units per standard cubic feet (Btu/scf) determined on a 15-
minute block period basis when regulated material is routed to the
flare for at least 15-minutes. The owner or operator shall monitor and
calculate NHVcz as specified in paragraph (m) of this
section.
    (f) Dilution operating limits for flares with perimeter assist air.
For each flare actively receiving perimeter assist air, the owner or
operator shall operate the flare to maintain the net heating value
dilution parameter (NHVdil) at or above 22 British thermal units per
square foot (Btu/ft2) determined on a 15-minute block period
basis when regulated material is being routed to the flare for at least
15-minutes. The owner or operator shall monitor and calculate
NHVdil as specified in paragraph (n) of this section.

    (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 using either the methods in paragraph (h)(1) of this section
or, alternatively, the methods in paragraph (h)(2) of this section. The
owner or operator must record and report any instances where visible
emissions are observed for more than 5 minutes during any 2 consecutive
hours as specified in Sec.  63.655(g)(11)(ii).
    (1) At least once per day, conduct visible emissions observations
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 or until 5-minutes of visible emissions are
observed.
    (2) Use a video surveillance camera to continuously record (at
least one frame every 15 seconds with time and date stamps) images of
the flare flame and a reasonable distance above the flare flame at an
angle suitable for visual emissions observations. The owner or operator
must provide real-time video surveillance camera output to the control
room or other continuously manned location where the camera images may
be viewed at any time.
    (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 as well as any supplemental natural gas
used. Different flow monitoring methods may be used to measure
different gaseous streams that make up the flare vent gas provided that
the flow rates of all gas streams that contribute to the flare vent gas
are determined. 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 both used,
the owner or operator shall install, operate, calibrate, and maintain a
monitoring system capable of separately measuring, calculating, and
recording the volumetric flow rate of premix assist air and perimeter
assist air used with the flare. Continuously monitoring fan speed or
power and using fan curves is an acceptable method for continuously
monitoring assist air flow rates.
    (1) The flow rate monitoring systems must be able to correct for
the temperature and pressure of the system and output parameters in
standard conditions (i.e., a temperature of 20 [deg]C
(68[emsp14][deg]F) and a pressure of 1 atmosphere).
    (2) Mass flow monitors may be used for determining volumetric flow
rate of flare vent gas provided the molecular weight of the flare vent
gas is determined using compositional analysis as specified in
paragraph (j) of this section so that the mass flow rate can be
converted to volumetric flow at standard conditions using the following
equation.
[GRAPHIC] [TIFF OMITTED] TR01DE15.009

Where:

Qvol = Volumetric flow rate, standard cubic feet per
second.
Qmass = Mass flow rate, pounds per second.
385.3 = Conversion factor, standard cubic feet per pound-mole.
MWt = Molecular weight of the gas at the flow monitoring location,
pounds per pound-mole.

    (3) Mass flow monitors may be used for determining volumetric flow
rate of assist air or assist steam. Use equation in paragraph (i)(2) of
this section to convert mass flow rates to volumetric flow rates. Use a
molecular weight of 18 pounds per pound-mole for assist steam and use a
molecular weight of 29 pounds per pound-mole for assist air.
    (4) Continuous pressure/temperature monitoring system(s) and
appropriate engineering calculations may be used in lieu of a
continuous volumetric flow monitoring systems provided the molecular
weight of the gas is known. For assist steam, use a molecular weight of
18 pounds per pound-mole. For assist air, use a molecular weight of 29
pounds per pound-mole. For flare vent gas, molecular weight must be
determined using compositional analysis as specified in paragraph (j)
of this section.
    (j) Flare vent gas composition monitoring. The owner or operator
shall determine the concentration of individual components in the flare
vent gas using either the methods provided in paragraph (j)(1) or (2)
of this section, to assess compliance with the operating limits in
paragraph (e) of this section and, if applicable, paragraphs (d) and
(f) of this section. Alternatively, the owner or operator may elect to
directly monitor the net heating value of the flare vent gas following
the methods provided in paragraphs (j)(3) of this section and, if
desired, may directly measure the hydrogen concentration in the flare
vent gas following the methods provided in paragraphs (j)(4) of this
section. The owner or operator may elect to use different monitoring
methods for different gaseous streams that make up the flare vent gas
using different methods provided the composition or net heating value
of all gas streams that contribute to the flare vent gas are
determined.
    (1) Except as provided in paragraphs (j)(5) and (6) of this
section, the owner or operator shall install, operate, calibrate, and
maintain a monitoring system capable of continuously measuring (i.e.,
at least once every 15-minutes), calculating, and recording the
individual component concentrations present in the flare vent gas.
    (2) Except as provided in paragraphs (j)(5) and (6) of this
section, the owner or operator shall install, operate, and maintain a
grab sampling system capable of collecting an evacuated canister sample
for subsequent compositional analysis at least once every eight hours
while there is flow of regulated material to the flare. Subsequent
compositional analysis of the samples must be performed according to
Method 18 of 40 CFR part 60, appendix A-6, ASTM D6420-99 (Reapproved
2010), ASTM D1945-03 (Reapproved 2010), ASTM D1945-14 or ASTM UOP539-12
(all incorporated by reference--see Sec.  63.14).
    (3) Except as provided in paragraphs (j)(5) and (6) of this
section, the owner or operator shall install, operate, calibrate, and
maintain a calorimeter capable of continuously measuring, calculating,
and recording NHVvg at standard conditions.
    (4) If the owner or operator uses a continuous net heating value
monitor according to paragraph (j)(3) of this section, the owner or
operator may, at their discretion, install, operate, calibrate, and
maintain a monitoring

system capable of continuously measuring, calculating, and recording
the hydrogen concentration in the flare vent gas.
    (5) Direct compositional or net heating value monitoring is not
required for purchased (``pipeline quality'') natural gas streams. The
net heating value of purchased natural gas streams may be determined
using annual or more frequent grab sampling at any one representative
location. Alternatively, the net heating value of any purchased natural
gas stream can be assumed to be 920 Btu/scf.
    (6) Direct compositional or net heating value monitoring is not
required for gas streams that have been demonstrated to have consistent
composition (or a fixed minimum net heating value) according to the
methods in paragraphs (j)(6)(i) through (v) of this section.
    (i) The owner or operator shall submit to the Administrator a
written application for an exemption from monitoring. The application
must contain the following information:
    (A) A description of the flare gas stream/system to be considered,
including submission of a portion of the appropriate piping diagrams
indicating the boundaries of the flare gas stream/system and the
affected flare(s) to be considered;
    (B) A statement that there are no crossover or entry points to be
introduced into the flare gas stream/system (this should be shown in
the piping diagrams) prior to the point where the flow rate of the gas
streams is measured;
    (C) An explanation of the conditions that ensure that the flare gas
net heating value is consistent and, if flare gas net heating value is
expected to vary (e.g., due to product loading of different material),
the conditions expected to produce the flare gas with the lowest net
heating value;
    (D) The supporting test results from sampling the requested flare
gas stream/system for the net heating value. Sampling data must
include, at minimum, 2 weeks of daily measurement values (14 grab
samples) for frequently operated flare gas streams/systems; for
infrequently operated flare gas streams/systems, seven grab samples
must be collected unless other additional information would support
reduced sampling. If the flare gas stream composition can vary, samples
must be taken during those conditions expected to result in lowest net
heating value identified in paragraph (j)(6)(i)(C) of this section. The
owner or operator shall determine net heating value for the gas stream
using either gas composition analysis or net heating value monitor
(with optional hydrogen concentration analyzer) according to the method
provided in paragraph (l) of this section; and
    (E) A description of how the 2 weeks (or seven samples for
infrequently operated flare gas streams/systems) of monitoring results
compares to the typical range of net heating values expected for the
flare gas stream/system going to the affected flare (e.g., ``the
samples are representative of typical operating conditions of the flare
gas stream going to the loading rack flare'' or ``the samples are
representative of conditions expected to yield the lowest net heating
value of the flare gas stream going to the loading rack flare'').
    (F) The net heating value to be used for all flows of the flare
vent gas from the flare gas stream/system covered in the application. A
single net heating value must be assigned to the flare vent gas either
by selecting the lowest net heating value measured in the sampling
program or by determining the 95th percent confidence interval on the
mean value of all samples collected using the t-distribution statistic
(which is 1.943 for 7 grab samples or 1.771 for 14 grab samples).
    (ii) The effective date of the exemption is the date of submission
of the information required in paragraph (j)(6)(i) of this section.
    (iii) No further action is required unless refinery operating
conditions change in such a way that affects the exempt fuel gas
stream/system (e.g., the stream composition changes). If such a change
occurs, the owner or operator shall follow the procedures in paragraph
(j)(6)(iii)(A), (B), or (C) of this section.
    (A) If the operation change results in a flare vent gas net heating
value that is still within the range of net heating values included in
the original application, the owner or operator shall determine the net
heating value on a grab sample and record the results as proof that the
net heating value assigned to the vent gas stream in the original
application is still appropriate.
    (B) If the operation change results in a flare vent gas net heating
value that is lower than the net heating value assigned to the vent gas
stream in the original application, the owner or operator may submit
new information following the procedures of paragraph (j)(6)(i) of this
section within 60 days (or within 30 days after the seventh grab sample
is tested for infrequently operated process units).
    (C) If the operation change results in a flare vent gas net heating
value has greater variability in the flare gas stream/system such the
owner or operator chooses not to submit new information to support an
exemption, the owner or operator must begin monitoring the composition
or net heat content of the flare vent gas stream using the methods in
this section (i.e., grab samples every 8 hours until such time a
continuous monitor, if elected, is installed).
    (k) Calculation methods for cumulative flow rates and determining
compliance with Vtip operating limits. The owner or operator shall
determine Vtip on a 15-minute block average basis according
to the following requirements.
    (1) The owner or operator shall use design and engineering
principles to determine the unobstructed cross sectional area of the
flare tip. The unobstructed cross sectional area of the flare tip is
the total tip area that vent gas can pass through. This area does not
include any stability tabs, stability rings, and upper steam or air
tubes because flare vent gas does not exit through them.
    (2) The owner or operator shall determine the cumulative volumetric
flow of flare vent gas for each 15-minute block average period using
the data from the continuous flow monitoring system required in
paragraph (i) of this section according to the following requirements,
as applicable. If desired, the cumulative flow rate for a 15-minute
block period only needs to include flow during those periods when
regulated material is sent to the flare, but owners or operators may
elect to calculate the cumulative flow rates across the entire 15-
minute block period for any 15-minute block period where there is
regulated material flow to the flare.
    (i) Use set 15-minute time periods starting at 12 midnight to 12:15
a.m., 12:15 a.m. to 12:30 a.m. and so on concluding at 11:45 p.m. to
midnight when calculating 15-minute block average flow volumes.
    (ii) If continuous pressure/temperature monitoring system(s) and
engineering calculations are used as allowed under paragraph (i)(4) of
this section, the owner or operator shall, at a minimum, determine the
15-minute block average temperature and pressure from the monitoring
system and use those values to perform the engineering calculations to
determine the cumulative flow over the 15-minute block average period.
Alternatively, the owner or operator may divide the 15-minute block
average period into equal duration subperiods (e.g., three 5-minute
periods) and determine the average temperature and pressure for each
subperiod, perform engineering calculations to determine the flow for
each subperiod, then add the volumetric

flows for the subperiods to determine the cumulative volumetric flow of
vent gas for the 15-minute block average period.
    (3) The 15-minute block average Vtip shall be calculated
using the following equation.
[GRAPHIC] [TIFF OMITTED] TR01DE15.010

Where:

Vtip = Flare tip velocity, feet per second.
Qcum = Cumulative volumetric flow over 15-minute block
average period, actual cubic feet.
Area = Unobstructed area of the flare tip, square feet.
900 = Conversion factor, seconds per 15-minute block average.

    (4) If the owner or operator chooses to comply with paragraph
(d)(2) of this section, the owner or operator shall also determine the
net heating value of the flare vent gas following the requirements in
paragraphs (j) and (l) of this section and calculate Vmax
using the equation in paragraph (d)(2) of this section in order to
compare Vtip to Vmax on a 15-minute block average
basis.
    (l) Calculation methods for determining flare vent gas net heating
value. The owner or operator shall determine the net heating value of
the flare vent gas (NHVvg) based on the composition
monitoring data on a 15-minute block average basis according to the
following requirements.
    (1) If compositional analysis data are collected as provided in
paragraph (j)(1) or (2) of this section, the owner or operator shall
determine NHVvg of a specific sample by using the following
equation.
[GRAPHIC] [TIFF OMITTED] TR01DE15.011

Where:

NHVvg = Net heating value of flare vent gas, Btu/scf.
i = Individual component in flare vent gas.
n = Number of components in flare vent gas.
xi = Concentration of component i in flare vent gas,
volume fraction.
NHVi = Net heating value of component i according to
table 12 of this subpart, Btu/scf. If the component is not specified
in table 12 of this subpart, the heats of combustion may be
determined using any published values where the net enthalpy per
mole of offgas is based on combustion at 25 [deg]C and 1 atmosphere
(or constant pressure) with offgas water in the gaseous state, but
the standard temperature for determining the volume corresponding to
one mole of vent gas is 20 [deg]C.

    (2) If direct net heating value monitoring data are collected as
provided in paragraph (j)(3) of this section but a hydrogen
concentration monitor is not used, the owner or operator shall use the
direct output of the monitoring system(s) (in Btu/scf) to determine the
NHVvg for the sample.
    (3) If direct net heating value monitoring data are collected as
provided in paragraph (j)(3) of this section and hydrogen concentration
monitoring data are collected as provided in paragraph (j)(4) of this
section, the owner or operator shall use the following equation to
determine NHVvg for each sample measured via the net heating
value monitoring system.

NHVvg = NHVmeasured + 938xH2

Where:

NHVvg = Net heating value of flare vent gas, Btu/scf.

NHVmeasured = Net heating value of flare vent gas stream
as measured by the continuous net heating value monitoring system,
Btu/scf.
xH2 = Concentration of hydrogen in flare vent gas at the time the
sample was input into the net heating value monitoring system,
volume fraction.
938 = Net correction for the measured heating value of hydrogen
(1,212 - 274), Btu/scf.

    (4) Use set 15-minute time periods starting at 12 midnight to 12:15
a.m., 12:15 a.m. to 12:30 a.m. and so on concluding at 11:45 p.m. to
midnight when calculating 15-minute block averages.
    (5) When a continuous monitoring system is used as provided in
paragraph (j)(1) or (3) of this section and, if applicable, paragraph
(j)(4) of this section, the owner or operator may elect to determine
the 15-minute block average NHVvg using either the
calculation methods in paragraph (l)(5)(i) of this section or the
calculation methods in paragraph (l)(5)(ii) of this section. The owner
or operator may choose to comply using the calculation methods in
paragraph (l)(5)(i) of this section for some flares at the petroleum
refinery and comply using the calculation methods (l)(5)(ii) of this
section for other flares. However, for each flare, the owner or
operator must elect one calculation method that will apply at all
times, and use that method for all continuously monitored flare vent
streams associated with that flare. If the owner or operator intends to
change the calculation method that applies to a flare, the owner or
operator must notify the Administrator 30 days in advance of such a
change.
    (i) Feed-forward calculation method. When calculating
NHVvg for a specific 15-minute block:
    (A) Use the results from the first sample collected during an
event, (for periodic flare vent gas flow events) for the first 15-
minute block associated with that event.
    (B) If the results from the first sample collected during an event
(for periodic flare vent gas flow events) are not available until after
the second 15-minute block starts, use the results from the first
sample collected during an event for the second 15-minute block
associated with that event.
    (C) For all other cases, use the results that are available from
the most recent sample prior to the 15-minute block period for that 15-
minute block period for all flare vent gas steams. For the purpose of
this requirement, use the time that the results become available rather
than the time the sample was collected. For example, if a sample is
collected at 12:25 a.m. and the analysis is completed at 12:38 a.m.,
the results are available at 12:38 a.m. and these results would be used
to determine compliance during the 15-minute block period from 12:45
a.m. to 1:00 a.m.
    (ii) Direct calculation method. When calculating NHVvg
for a specific 15-minute block:
    (A) If the results from the first sample collected during an event
(for periodic flare vent gas flow events) are not available until after
the second 15-minute block starts, use the results from the first
sample collected during an event for the first 15-minute block
associated with that event.
    (B) For all other cases, use the arithmetic average of all
NHVvg measurement data results that become available during
a 15-minute block to calculate the 15-minute block average for that
period. For the purpose of this requirement, use the time that the
results become available rather than the time the sample was collected.
For example, if a sample is collected at 12:25 a.m. and the analysis is
completed at 12:38 a.m., the results are available at 12:38 a.m. and
these results would be used to determine compliance during the 15-
minute block period from 12:30 a.m. to 12:45 a.m.
    (6) When grab samples are used to determine flare vent gas
composition:
    (i) Use the analytical results from the first grab sample collected
for an event for all 15-minute periods from the start of the event
through the 15-minute block prior to the 15-minute block in which a
subsequent grab sample is collected.
    (ii) Use the results from subsequent grab sampling events for all
15 minute periods starting with the 15-minute block in which the sample
was collected and ending with the 15-minute block prior to the 15-
minute block in which the next grab sample is collected. For

the purpose of this requirement, use the time the sample was collected
rather than the time the analytical results become available.
    (7) If the owner or operator monitors separate gas streams that
combine to comprise the total flare vent gas flow, the 15-minute block
average net heating value shall be determined separately for each
measurement location according to the methods in paragraphs (l)(1)
through (6) of this section and a flow-weighted average of the gas
stream net heating values shall be used to determine the 15-minute
block average net heating value of the cumulative flare vent gas.
    (m) Calculation methods for determining combustion zone net heating
value. The owner or operator shall determine the net heating value of
the combustion zone gas (NHVcz) as specified in paragraph
(m)(1) or (2) of this section, as applicable.
    (1) Except as specified in paragraph (m)(2) of this section,
determine the 15-minute block average NHVcz based on the 15-
minute block average vent gas and assist gas flow rates using the
following equation. For periods when there is no assist steam flow or
premix assist air flow, NHVcz = NHVvg.
[GRAPHIC] [TIFF OMITTED] TR01DE15.012

Where:

NHVcz = Net heating value of combustion zone gas, Btu/
scf.
NHVvg = Net heating value of flare vent gas for the 15-
minute block period, Btu/scf.
Qvg = Cumulative volumetric flow of flare vent gas during
the 15-minute block period, scf.
Qs = Cumulative volumetric flow of total steam during the
15-minute block period, scf.
Qa,premix = Cumulative volumetric flow of premix assist
air during the 15-minute block period, scf.

    (2) Owners or operators of flares that use the feed-forward
calculation methodology in paragraph (l)(5)(i) of this section and that
monitor gas composition or net heating value in a location
representative of the cumulative vent gas stream and that directly
monitor supplemental natural gas flow additions to the flare must
determine the 15-minute block average NHVcz using the
following equation.
[GRAPHIC] [TIFF OMITTED] TR01DE15.013

Where:

NHVcz = Net heating value of combustion zone gas, Btu/
scf.
NHVvg = Net heating value of flare vent gas for the 15-
minute block period, Btu/scf.
Qvg = Cumulative volumetric flow of flare vent gas during
the 15-minute block period, scf.
QNG2 = Cumulative volumetric flow of supplemental natural
gas to the flare during the 15-minute block period, scf.
QNG1 = Cumulative volumetric flow of supplemental natural
gas to the flare during the previous 15-minute block period, scf.
For the first 15-minute block period of an event, use the volumetric
flow value for the current 15-minute block period, i.e.,
QNG1=QNG2.
NHVNG = Net heating value of supplemental natural gas to
the flare for the 15-minute block period determined according to the
requirements in paragraph (j)(5) of this section, Btu/scf.
Qs = Cumulative volumetric flow of total steam during the
15-minute block period, scf.
Qa,premix = Cumulative volumetric flow of premix assist
air during the 15-minute block period, scf.

    (n) Calculation methods for determining the net heating value
dilution parameter. The owner or operator shall determine the net
heating value dilution parameter (NHVdil) as specified in
paragraph (n)(1) or (2) of this section, as applicable.
    (1) Except as specified in paragraph (n)(2) of this section,
determine the 15-minute block average NHVdil based on the
15-minute block average vent gas and perimeter assist air flow rates
using the following equation only during periods when perimeter assist
air is used. For 15-minute block periods when there is no cumulative
volumetric flow of perimeter assist air, the 15-minute block average
NHVdil parameter does not need to be calculated.
[GRAPHIC] [TIFF OMITTED] TR01DE15.014

Where:

NHVdil = Net heating value dilution parameter, Btu/
ft2.
NHVvg = Net heating value of flare vent gas determined
for the 15-minute block period, Btu/scf.
Qvg = Cumulative volumetric flow of flare vent gas during
the 15-minute block period, scf.
Diam = Effective diameter of the unobstructed area of the flare tip
for flare vent gas flow, ft. Use the area as determined in paragraph
(k)(1) of this section and determine the diameter as
[GRAPHIC] [TIFF OMITTED] TR01DE15.015

Qs = Cumulative volumetric flow of total steam during the
15-minute block period, scf.
Qa,premix = Cumulative volumetric flow of premix assist
air during the 15-minute block period, scf.
Qa,perimeter = Cumulative volumetric flow of perimeter
assist air during the 15-minute block period, scf.

    (2) Owners or operators of flares that use the feed-forward
calculation methodology in paragraph (l)(5)(i) of this section and that
monitor gas composition or net heating value in a location
representative of the cumulative vent gas stream and that directly
monitor supplemental natural gas flow additions to the flare must
determine the 15-minute block average NHVdil using the
following equation only during periods when perimeter assist air is
used. For 15-minute block periods when there is no cumulative

volumetric flow of perimeter assist air, the 15-minute block average
NHVdil parameter does not need to be calculated.
[GRAPHIC] [TIFF OMITTED] TR01DE15.016

Where:

NHVdil = Net heating value dilution parameter, Btu/
ft2.
NHVvg = Net heating value of flare vent gas determined
for the 15-minute block period, Btu/scf.
Qvg = Cumulative volumetric flow of flare vent gas during
the 15-minute block period, scf.
QNG2 = Cumulative volumetric flow of supplemental natural
gas to the flare during the 15-minute block period, scf.
QNG1 = Cumulative volumetric flow of supplemental natural
gas to the flare during the previous 15-minute block period, scf.
For the first 15-minute block period of an event, use the volumetric
flow value for the current 15-minute block period, i.e.,
QNG1 =QNG2.
NHVNG = Net heating value of supplemental natural gas to
the flare for the 15-minute block period determined according to the
requirements in paragraph (j)(5) of this section, Btu/scf.
Diam = Effective diameter of the unobstructed area of the flare tip
for flare vent gas flow, ft. Use the area as determined in paragraph
(k)(1) of this section and determine the diameter as
[GRAPHIC] [TIFF OMITTED] TR01DE15.017

Qs = Cumulative volumetric flow of total steam during the
15-minute block period, scf.
Qa,premix = Cumulative volumetric flow of premix assist
air during the 15-minute block period, scf.
Qa,perimeter = Cumulative volumetric flow of perimeter
assist air during the 15-minute block period, scf.

    (o) Emergency flaring provisions. The owner or operator of a flare
that has the potential to operate above its smokeless capacity under
any circumstance shall comply with the provisions in paragraphs (o)(1)
through (8) of this section.
    (1) Develop a flare management plan to minimize flaring during
periods of startup, shutdown, or emergency releases. The flare
management plan must include the information described in paragraphs
(o)(1)(i) through (vii) of this section.
    (i) A listing of all refinery process units, ancillary equipment,
and fuel gas systems connected to the flare for each affected flare.
    (ii) An assessment of whether discharges to affected flares from
these process units, ancillary equipment and fuel gas systems can be
minimized or prevented during periods of startup, shutdown, or
emergency releases. The flare minimization assessment must (at a
minimum) consider the items in paragraphs (o)(1)(ii)(A) through (C) of
this section. The assessment must provide clear rationale in terms of
costs (capital and annual operating), natural gas offset credits (if
applicable), technical feasibility, secondary environmental impacts and
safety considerations for the selected minimization alternative(s) or a
statement, with justifications, that flow reduction could not be
achieved. Based upon the assessment, each owner or operator of an
affected flare shall identify the minimization alternatives that it has
implemented by the due date of the flare management plan and shall
include a schedule for the prompt implementation of any selected
measures that cannot reasonably be completed as of that date.
    (A) Modification in startup and shutdown procedures to reduce the
quantity of process gas discharge to the flare.
    (B) Implementation of prevention measures listed for pressure
relief devices in Sec.  63.648(j)(5) for each pressure relief valve
that can discharge to the flare.
    (C) Installation of a flare gas recovery system or, for facilities
that are fuel gas rich, a flare gas recovery system and a co-generation
unit or combined heat and power unit.
    (iii) A description of each affected flare containing the
information in paragraphs (o)(1)(iii)(A) through (G) of this section.
    (A) A general description of the flare, including whether it is a
ground flare or elevated (including height), the type of assist system
(e.g., air, steam, pressure, non-assisted), whether the flare is used
on a routine basis or if it is only used during periods of startup,
shutdown or emergency release, and whether the flare is equipped with a
flare gas recovery system.
    (B) The smokeless capacity of the flare based on design conditions.
Note: A single value must be provided for the smokeless capacity of the
flare.
    (C) The maximum vent gas flow rate (hydraulic load capacity).
    (D) The maximum supplemental gas flow rate.
    (E) For flares that receive assist steam, the minimum total steam
rate and the maximum total steam rate.
    (F) For flares that receive assist air, an indication of whether
the fan/blower is single speed, multi-fixed speed (e.g., high, medium,
and low speeds), or variable speeds. For fans/blowers with fixed
speeds, provide the estimated assist air flow rate at each fixed speed.
For variable speeds, provide the design fan curve (e.g., air flow rate
as a function of power input).
    (G) Simple process flow diagram showing the locations of the flare
following components of the flare: Flare tip (date installed,
manufacturer, nominal and effective tip diameter, tip drawing);
knockout or surge drum(s) or pot(s) (including dimensions and design
capacities); flare header(s) and subheader(s); assist system; and
ignition system.
    (iv) Description and simple process flow diagram showing all gas
lines (including flare waste gas, purge or sweep gas (as applicable),
supplemental gas) that are associated with the flare. For purge, sweep,
supplemental gas, identify the type of gas used. Designate which lines
are exempt from composition or net heating value monitoring and why
(e.g., natural gas, gas streams that have been demonstrated to have
consistent composition, pilot gas). Designate which lines are monitored
and identify on the process flow diagram the location and type of each
monitor. Designate the pressure relief devices that are vented to the
flare.
    (v) For each flow rate, gas composition, net heating value or
hydrogen concentration monitor identified in paragraph (o)(1)(iv) of
this section, provide a detailed description of the manufacturer's
specifications, including, but not limited to, make, model, type,
range, precision, accuracy, calibration, maintenance and quality
assurance procedures.
    (vi) For each pressure relief valve vented to the flare identified
in paragraph (o)(1)(iv) of this section, provide a detailed description
of each pressure release valve, including type of relief device
(rupture disc, valve type) diameter of the relief valve, set pressure
of the relief valve and listing of the prevention measures implemented.
This

information may be maintained in an electronic database on-site and
does not need to be submitted as part of the flare management plan
unless requested to do so by the Administrator.
    (vii) Procedures to minimize or eliminate discharges to the flare
during the planned startup and shutdown of the refinery process units
and ancillary equipment that are connected to the affected flare,
together with a schedule for the prompt implementation of any
procedures that cannot reasonably be implemented as of the date of the
submission of the flare management plan.
    (2) Each owner or operator required to develop and implement a
written flare management plan as described in paragraph (o)(1) of this
section must submit the plan to the Administrator as described in
paragraphs (o)(2)(i) through (iii) of this section.
    (i) The owner or operator must develop and implement the flare
management plan no later than January 30, 2019 or at startup for a new
flare that commenced construction on or after February 1, 2016.
    (ii) The owner or operator must comply with the plan as submitted
by the date specified in paragraph (o)(2)(i) of this section. The plan
should be updated periodically to account for changes in the operation
of the flare, such as new connections to the flare or the installation
of a flare gas recovery system, but the plan need be re-submitted to
the Administrator only if the owner or operator alters the design
smokeless capacity of the flare. The owner or operator must comply with
the updated plan as submitted.
    (iii) All versions of the plan submitted to the Administrator 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>    (3) The owner or operator of a flare subject to this subpart shall
conduct a root cause analysis and a corrective action analysis for each
flow event that contains regulated material and that meets either the
criteria in paragraph (o)(3)(i) or (ii) of this section.
    (i) The vent gas flow rate exceeds the smokeless capacity of the
flare and visible emissions are present from the flare for more than 5
minutes during any 2 consecutive hours during the release event.
    (ii) The vent gas flow rate exceeds the smokeless capacity of the
flare and the 15-minute block average flare tip velocity exceeds the
maximum flare tip velocity determined using the methods in paragraph
(d)(2) of this section.
    (4) A root cause analysis and corrective action analysis must be
completed as soon as possible, but no later than 45 days after a flare
flow event meeting the criteria in paragraph (o)(3)(i) or (ii) of this
section. Special circumstances affecting the number of root cause
analyses and/or corrective action analyses are provided in paragraphs
(o)(4)(i) through (v) of this section.
    (i) You may conduct a single root cause analysis and corrective
action analysis for a single continuous flare flow event that meets
both of the criteria in paragraphs (o)(3)(i) and (ii) of this section.
    (ii) You may conduct a single root cause analysis and corrective
action analysis for a single continuous flare flow event regardless of
the number of 15-minute block periods in which the flare tip velocity
was exceeded or the number of 2 hour periods that contain more the 5
minutes of visible emissions.
    (iii) You may conduct a single root cause analysis and corrective
action analysis for a single event that causes two or more flares that
are operated in series (i.e., cascaded flare systems) to have a flow
event meeting the criteria in paragraph (o)(3)(i) or (ii) of this
section.
    (iv) You may conduct a single root cause analysis and corrective
action analysis for a single event that causes two or more flares to
have a flow event meeting the criteria in paragraph (o)(3)(i) or (ii)
of this section, regardless of the configuration of the flares, if the
root cause is reasonably expected to be a force majeure event, as
defined in this subpart.
    (v) Except as provided in paragraphs (o)(4)(iii) and (iv) of this
section, if more than one flare has a flow event that meets the
criteria in paragraph (o)(3)(i) or (ii) of this section during the same
time period, an initial root cause analysis shall be conducted
separately for each flare that has a flow event meeting the criteria in
paragraph (o)(3)(i) or (ii) of this section. If the initial root cause
analysis indicates that the flow events have the same root cause(s),
the initially separate root cause analyses may be recorded as a single
root cause analysis and a single corrective action analysis may be
conducted.
    (5) Each owner or operator of a flare required to conduct a root
cause analysis and corrective action analysis as specified in
paragraphs (o)(3) and (4) of this section shall implement the
corrective action(s) identified in the corrective action analysis in
accordance with the applicable requirements in paragraphs (o)(5)(i)
through (iii) of this section.
    (i) All corrective action(s) must be implemented within 45 days of
the event for which the root cause and corrective action analyses were
required or as soon thereafter as practicable. If an owner or operator
concludes that no corrective action should be implemented, the owner or
operator shall record and explain the basis for that conclusion no
later than 45 days following the event.
    (ii) For corrective actions that cannot be fully implemented within
45 days following the event for which the root cause and corrective
action analyses were required, the owner or operator shall develop an
implementation schedule to complete the corrective action(s) as soon as
practicable.
    (iii) No later than 45 days following the event for which a root
cause and corrective action analyses were required, the owner or
operator shall record the corrective action(s) completed to date, and,
for action(s) not already completed, a schedule for implementation,
including proposed commencement and completion dates.
    (6) The owner or operator shall determine the total number of
events for which a root cause and corrective action analyses was
required during the calendar year for each affected flare separately
for events meeting the criteria in paragraph (o)(3)(i) of this section
and those meeting the criteria in paragraph (o)(3)(ii) of this section.
For the purpose of this requirement, a single root cause analysis
conducted for an event that met both of the criteria in paragraphs