K3 = Material balance and conversion factor, 0.0994 (kg-min)/(hr-
dscm-%) [0.00624 (lb-min)/(hr-dscf-%)].

    (iv) During the performance test, the volumetric flow rate of
exhaust gas from catalyst regenerator (Qr) before any emission control
or energy recovery system that burns auxiliary fuel is measured using
Method 2 of Appendix A-1 to part 60.
    (v) For subsequent calculations of coke burn-off rates or exhaust
gas flow rates, the volumetric flow rate of Qr is calculated using
average exhaust gas concentrations as measured by the monitors in Sec.
60.105a(b)(2), if applicable, using Equation 5 of this section:

[GRAPHIC] [TIFF OMITTED] TR24JN08.004

Where:

Qr = Volumetric flow rate of exhaust gas from FCCU regenerator or
fluid coking burner before any emission control or energy recovery
system that burns auxiliary fuel, dscm/min (dscf/min);
Qa = Volumetric flow rate of air to FCCU regenerator or fluid coking
burner, as determined from the unit's control room instrumentation,
dscm/min (dscf/min);
Qoxy = Volumetric flow rate of O2 enriched air to FCCU regenerator
or fluid coking unit, as determined from the unit's control room
instrumentation, dscm/min (dscf/min);
%CO2 = Carbon dioxide concentration in FCCU regenerator or fluid
coking burner exhaust, percent by volume (dry basis);
%CO = CO concentration FCCU regenerator or fluid coking burner
exhaust, percent by volume (dry basis). When no auxiliary fuel is
burned and a continuous CO monitor is not required in accordance
with Sec.  60.105a(g)(3), assume %CO to be zero;
%O2 = O2 concentration in FCCU regenerator or fluid coking burner
exhaust, percent by volume (dry basis); and
%Ooxy = O2 concentration in O2 enriched air stream inlet
to the FCCU regenerator or fluid coking burner, percent by volume
(dry basis).

    (5) Method 6, 6A, or 6C of Appendix A-4 to part 60 for moisture
content and for the concentration of SO2; the duration of each test run
must be no less than 4 hours. The method ANSI/ASME PTC 19.10-1981,
``Flue and Exhaust Gas Analyses,'' (incorporated by reference--see
Sec.  60.17) is an acceptable alternative to EPA Method 6 or 6A of
Appendix A-4 to part 60.
    (6) Method 7, 7A, 7C, 7D, or 7E of Appendix A-4 to part 60 for
moisture content and for the concentration of NOX calculated as
nitrogen dioxide (NO2); the duration of each test run must be no less
than 4 hours. The method ANSI/ASME PTC 19.10-1981, ``Flue and Exhaust
Gas Analyses,'' (incorporated by reference--see Sec.  60.17) is an
acceptable alternative to EPA Method 7 or 7C of Appendix A-4 to part
60.
    (7) Method 10, 10A, or 10B of Appendix A-4 to part 60 for moisture
content and for the concentration of CO. The sampling time for each run
must be 60 minutes.
    (8) The owner or operator shall adjust PM, NOX, SO2, and CO
pollutant concentrations to 0 percent excess air or 0 percent O2 using
Equation 6 of this section:

[GRAPHIC] [TIFF OMITTED] TR24JN08.005

Where:

Cadj = pollutant concentration adjusted to 0 percent excess air or
O2, parts per million (ppm) or g/dscm;
Cmeas = pollutant concentration measured on a dry basis, ppm or g/
dscm;
20.9c = 20.9 percent O2-0.0 percent O2 (defined O2 correction
basis), percent;
20.9 = O2 concentration in air, percent; and
%O2 = O2 concentration measured on a dry basis, percent.

    (e) The owner or operator of a FCCU or FCU that is controlled by an
electrostatic precipitator or wet scrubber and that is subject to
control device operating parameter limits in Sec.  60.102a(c) shall
establish the limits based on the performance test results according to
the following procedures:
    (1) Reduce the parameter monitoring data to hourly averages for
each test run;
    (2) Determine the hourly average operating limit for each required
parameter as the average of the three test runs.
    (f) The owner or operator of an FCCU or FCU that uses cyclones to
comply with the PM limit in Sec.  60.102a(b)(1) and elects to comply
with the COMS alternative monitoring option in Sec.  60.105a(d) shall
establish a site-specific opacity operating limit according to the
procedures in paragraphs (f)(1) through (3) of this section.
    (1) Collect COMS data every 10 seconds during the entire period of
the PM performance test and reduce the data to 6-minute averages.
    (2) Determine and record the hourly average opacity from all the 6-
minute averages.
    (3) Compute the site-specific limit using Equation 7 of this
section:
[GRAPHIC] [TIFF OMITTED] TR24JN08.006

Where:

Opacity limit = Maximum permissible hourly average opacity, percent,
or 10 percent, whichever is greater;
Opacityst = Hourly average opacity measured during the source test
runs, percent; and
PMEmRst = PM emission rate measured during the source test, lb/1,000
lbs coke burn.

    (g) The owner or operator of a FCCU or FCU that is exempt from the
requirement to install and operate a CO CEMS pursuant to Sec.
60.105a(h)(3) and that is subject to control device operating parameter
limits in Sec.  60.102a(c) shall establish the limits based on the
performance test results

using the procedures in paragraphs (g)(1) and (2) of this section.
    (1) Reduce the temperature and O2 concentrations from the parameter
monitoring systems to hourly averages for each test run.
    (2) Determine the operating limit for temperature and O2
concentrations as the average of the average temperature and O2
concentration for the three test runs.
    (h) The owner or operator shall determine compliance with the SO2
and H2S emissions limits for sulfur recovery plants in Sec. Sec.
60.102a(f)(1)(i), 60.102a(f)(1)(iii), 60.102a(f)(1)(iii),
60.102a(f)(2)(i), and 60.102a(f)(2)(iii) and the reduced sulfur
compounds and H2S emissions limits for sulfur recovery plants in Sec.
60.102a(f)(1)(ii) and Sec.  60.102a(f)(2)(ii) using the following
methods and procedures:
    (1) Method 1 of Appendix A-1 to part 60 for sample and velocity
traverses.
    (2) Method 2 of Appendix A-1 to part 60 for velocity and volumetric
flow rate.
    (3) Method 3, 3A, or 3B of Appendix A-2 to part 60 for gas
analysis. The method ANSI/ASME PTC 19.10-1981, ``Flue and Exhaust Gas
Analyses,'' (incorporated by reference--see Sec.  60.17) is an
acceptable alternative to EPA Method 3B of Appendix A-2 to part 60.
    (4) Method 6, 6A, or 6C of Appendix A-4 to part 60 to determine the
SO2 concentration. The method ANSI/ASME PTC 19.10-1981, ``Flue and
Exhaust Gas Analyses,'' (incorporated by reference--see Sec.  60.17) is
an acceptable alternative to EPA Method 6 or 6A of Appendix A-4 to part
60.
    (5) Method 15 or 15A of Appendix A-5 to part 60 or Method 16 of
Appendix A-6 to part 60 to determine the reduced sulfur compounds and
H2S concentrations. The method ANSI/ASME PTC 19.10-1981, ``Flue and
Exhaust Gas Analyses,'' (incorporated by reference--see Sec.  60.17) is
an acceptable alternative to EPA Method 15A of Appendix A-5 to part 60.
    (i) Each run consists of 16 samples taken over a minimum of 3
hours.
    (ii) The owner or operator shall calculate the average H2S
concentration after correcting for moisture and O2 as the arithmetic
average of the H2S concentration for each sample during the run (ppmv,
dry basis, corrected to 0 percent excess air).
    (iii) The owner or operator shall calculate the SO2 equivalent for
each run after correcting for moisture and O2 as the arithmetic average
of the SO2 equivalent of reduced sulfur compounds for each sample
during the run (ppmv, dry basis, corrected to 0 percent excess air).
    (iv) The owner or operator shall use Equation 6 of this section to
adjust pollutant concentrations to 0 percent O2 or 0 percent excess
air.
    (i) The owner or operator shall determine compliance with the SO2
and NOX emissions limits in Sec.  60.102a(g) for a fuel gas combustion
device according to the following test methods and procedures:
    (1) Method 1 of Appendix A-1 to part 60 for sample and velocity
traverses;
    (2) Method 2 of Appendix A-1 to part 60 for velocity and volumetric
flow rate;
    (3) Method 3, 3A, or 3B of Appendix A-2 to part 60 for gas
analysis. The method ANSI/ASME PTC 19.10-1981, ``Flue and Exhaust Gas
Analyses,'' (incorporated by reference--see Sec.  60.17) is an
acceptable alternative to EPA Method 3B of Appendix A-2 to part 60;
    (4) Method 6, 6A, or 6C of Appendix A-4 to part 60 to determine the
SO2 concentration. The method ANSI/ASME PTC 19.10-1981,
``Flue and Exhaust Gas Analyses,'' (incorporated by reference--see
Sec.  60.17) is an acceptable alternative to EPA Method 6 or 6A of
Appendix A-4 to part 60.
    (i) The performance test consists of 3 valid test runs; the
duration of each test run must be no less than 1 hour.
    (ii) If a single fuel gas combustion device having a common source
of fuel gas is monitored as allowed under Sec.  60.107a(a)(1)(v), only
one performance test is required. That is, performance tests are not
required when a new affected fuel gas combustion device is added to a
common source of fuel gas that previously demonstrated compliance.
    (5) Method 7, 7A, 7C, 7D, or 7E of Appendix A-4 to part 60 for
moisture content and for the concentration of NOX calculated as NO2;
the duration of each test run must be no less than 4 hours. The method
ANSI/ASME PTC 19.10-1981, ``Flue and Exhaust Gas Analyses,''
(incorporated by reference--see Sec.  60.17) is an acceptable
alternative to EPA Method 7 or 7C of Appendix A-4 to part 60.
    (j) The owner or operator shall determine compliance with the H2S
emissions limit in Sec.  60.102a(g) for a fuel gas combustion device
according to the following test methods and procedures:
    (1) Method 1 of Appendix A-1 to part 60 for sample and velocity
traverses;
    (2) Method 2 of Appendix A-1 to part 60 for velocity and volumetric
flow rate;
    (3) Method 3, 3A, or 3B of Appendix A-2 to part 60 for gas
analysis. The method ANSI/ASME PTC 19.10-1981, ``Flue and Exhaust Gas
Analyses,'' (incorporated by reference--see Sec.  60.17) is an
acceptable alternative to EPA Method 3B of Appendix A-2 to part 60;
    (4) Method 11, 15, or 15A of Appendix A-5 to part 60 or Method 16
of Appendix A-6 to part 60 for determining the H2S
concentration for affected plants using an H2S monitor as
specified in Sec.  60.107a(a)(2). The method ANSI/ASME PTC 19.10-1981,
``Flue and Exhaust Gas Analyses,'' (incorporated by reference--see
Sec.  60.17) is an acceptable alternative to EPA Method 15A of Appendix
A-5 to part 60. The owner or operator may demonstrate compliance based
on the mixture used in the fuel gas combustion device or for each
individual fuel gas stream used in the fuel gas combustion device.
    (i) For Method 11 of Appendix A-5 to part 60, the sampling time and
sample volume must be at least 10 minutes and 0.010 dscm (0.35 dscf).
Two samples of equal sampling times must be taken at about 1-hour
intervals. The arithmetic average of these two samples constitutes a
run. For most fuel gases, sampling times exceeding 20 minutes may
result in depletion of the collection solution, although fuel gases
containing low concentrations of H2S may necessitate sampling for
longer periods of time.
    (ii) For Method 15 of Appendix A-5 to part 60, at least three
injects over a 1-hour period constitutes a run.
    (iii) For Method 15A of Appendix A-5 to part 60, a 1-hour sample
constitutes a run. The method ANSI/ASME PTC 19.10-1981, ``Flue and
Exhaust Gas Analyses,'' (incorporated by reference--see Sec.  60.17) is
an acceptable alternative to EPA Method 15A of Appendix A-5 to part 60.
    (iv) If monitoring is conducted at a single point in a common
source of fuel gas as allowed under Sec.  60.107a(a)(2)(iv), only one
performance test is required. That is, performance tests are not
required when a new affected fuel gas combustion device is added to a
common source of fuel gas that previously demonstrated compliance.

Sec.  60.105a  Monitoring of emissions and operations for fluid
catalytic cracking units (FCCU) and fluid coking units (FCU).

    (a) FCCU and FCU subject to PM emissions limit. Each owner or
operator subject to the provisions of this subpart shall monitor each
FCCU and FCU subject to the PM emissions limit in Sec.  60.102a(b)(1)
according to the requirements in paragraph (b), (c), (d), or (e) of
this section.
    (b) Control device operating parameters. Each owner or operator of
a FCCU or FCU subject to the PM per coke burn-off emissions limit in
Sec.  60.102a(b)(1) shall comply with the requirements in paragraphs
(b)(1) through (3) of this section.

    (1) The owner or operator shall install, operate, and maintain
continuous parameter monitor systems (CPMS) to measure and record
operating parameters for each control device according to the
requirements in paragraph (b)(1)(i) through (iii) of this section.
    (i) For units controlled using an electrostatic precipitator, the
owner or operator shall use CPMS to measure and record the hourly
average total power input and secondary voltage to the entire system.
    (ii) For units controlled using a wet scrubber, the owner or
operator shall use CPMS to measure and record the hourly average
pressure drop, liquid feed rate, and exhaust gas flow rate. As an
alternative to a CPMS, the owner or operator must comply with the
requirements in either paragraph (b)(1)(ii)(A) or (B) of this section.
    (A) As an alterative to pressure drop, the owner or operator of a
jet ejector type wet scrubber or other type of wet scrubber equipped
with atomizing spray nozzles must conduct a daily check of the air or
water pressure to the spray nozzles and record the results of each
check.
    (B) As an alternative to exhaust gas flow rate, the owner or
operator shall comply with the approved alternative for monitoring
exhaust gas flow rate in 40 CFR 63.1573(a) of the National Emission
Standards for Hazardous Air Pollutants for Petroleum Refineries:
Catalytic Cracking Units, Catalytic Reforming Units, and Sulfur
Recovery Units.
    (iii) The owner or operator shall install, operate, and maintain
each CPMS according to the manufacturer's specifications and
requirements.
    (iv) The owner or operator shall determine and record the average
coke burn-off rate and hours of operation for each FCCU or FCU using
the procedures in Sec.  60.104a(d)(4)(iii).
    (v) If you use a control device other than an electrostatic
precipitator, wet scrubber, fabric filter, or cyclone, you may request
approval to monitor parameters other than those required in paragraph
(b)(1) of this section by submitting an alternative monitoring plan to
the Administrator. The request must include the information in
paragraphs (b)(1)(v)(A) through (E) of this section.
    (A) A description of each affected facility and the parameter(s) to
be monitored to determine whether the affected facility will
continuously comply with the emission limitations and an explanation of
the criteria used to select the parameter(s).
    (B) A description of the methods and procedures that will be used
to demonstrate that the parameter(s) can be used to determine whether
the affected facility will continuously comply with the emission
limitations and the schedule for this demonstration. The owner or
operator must certify that an operating limit will be established for
the monitored parameter(s) that represents the conditions in existence
when the control device is being properly operated and maintained to
meet the emission limitation.
    (C) The frequency and content of the recordkeeping, recording, and
reporting, if monitoring and recording are not continuous. The owner or
operator also must include the rationale for the proposed monitoring,
recording, and reporting requirements.
    (D) Supporting calculations.
    (E) Averaging time for the alternative operating parameter.
    (2) For use in determining the coke burn-off rate for an FCCU or
FCU, the owner or operator shall install, operate, calibrate, and
maintain an instrument for continuously monitoring the concentrations
of CO2, O2 (dry basis), and if needed, CO in the
exhaust gases prior to any control or energy recovery system that burns
auxiliary fuels.
    (i) The owner or operator shall install, operate, and maintain each
monitor according to Performance Specification 3 of Appendix B to part
60.
    (ii) The owner or operator shall conduct performance evaluations of
each CO2, O2, and CO monitor according to the
requirements in Sec.  60.13(c) and Performance Specification 3 of
Appendix B to part 60. The owner or operator shall use Method 3 of
Appendix A-3 to part 60 for conducting the relative accuracy
evaluations.
    (iii) The owner or operator shall comply with the quality assurance
requirements of procedure 1 of Appendix F to part 60, including
quarterly accuracy determinations for CO2 and CO monitors,
annual accuracy determinations for O2 monitors, and daily
calibration drift tests.
    (c) Bag leak detection systems. Each owner or operator shall
install, operate, and maintain a bag leak detection system for each
baghouse or similar fabric filter control device that is used to comply
with the PM per coke burn-off emissions limit in Sec.  60.102a(b)(1)
for an FCCU or FCU according to paragraph (c)(1) of this section;
prepare and operate by a site-specific monitoring plan according to
paragraph (c)(2) of this section; take action according to paragraph
(c)(3) of this section; and record information according to paragraph
(c)(4) of this section.
    (1) Each bag leak detection system must meet the specifications and
requirements in paragraphs (c)(1)(i) through (viii) of this section.
    (i) The bag leak detection system must be certified by the
manufacturer to be capable of detecting PM emissions at concentrations
of 0.00044 grains per actual cubic foot or less.
    (ii) The bag leak detection system sensor must provide output of
relative PM loadings. The owner or operator shall continuously record
the output from the bag leak detection system using electronic or other
means (e.g., using a strip chart recorder or a data logger).
    (iii) The bag leak detection system must be equipped with an alarm
system that will sound when the system detects an increase in relative
particulate loading over the alarm set point established according to
paragraph (c)(1)(iv) of this section, and the alarm must be located
such that it can be heard by the appropriate plant personnel.
    (iv) In the initial adjustment of the bag leak detection system,
the owner or operator must establish, at a minimum, the baseline output
by adjusting the sensitivity (range) and the averaging period of the
device, the alarm set points, and the alarm delay time.
    (v) Following initial adjustment, the owner or operator shall not
adjust the averaging period, alarm set point, or alarm delay time
without approval from the Administrator or delegated authority except
as provided in paragraph (c)(1)(vi) of this section.
    (vi) Once per quarter, the owner or operator may adjust the
sensitivity of the bag leak detection system to account for seasonal
effects, including temperature and humidity, according to the
procedures identified in the site-specific monitoring plan required by
paragraph (c)(2) of this section.
    (vii) The owner or operator shall install the bag leak detection
sensor downstream of the baghouse and upstream of any wet scrubber.
    (viii) Where multiple detectors are required, the system's
instrumentation and alarm may be shared among detectors.
    (2) The owner or operator shall develop and submit to the
Administrator for approval a site-specific monitoring plan for each
baghouse and bag leak detection system. The owner or operator shall
operate and maintain each baghouse and bag leak detection system
according to the site-specific monitoring plan at all times. Each
monitoring plan must describe the items in paragraphs (c)(2)(i) through
(vii) of this section.

    (i) Installation of the bag leak detection system;
    (ii) Initial and periodic adjustment of the bag leak detection
system, including how the alarm set-point will be established;
    (iii) Operation of the bag leak detection system, including quality
assurance procedures;
    (iv) How the bag leak detection system will be maintained,
including a routine maintenance schedule and spare parts inventory
list;
    (v) How the bag leak detection system output will be recorded and
stored;
    (vi) Procedures as specified in paragraph (c)(3) of this section.
In approving the site-specific monitoring plan, the Administrator or
delegated authority may allow owners and operators more than 3 hours to
alleviate a specific condition that causes an alarm if the owner or
operator identifies in the monitoring plan this specific condition as
one that could lead to an alarm, adequately explains why it is not
feasible to alleviate this condition within 3 hours of the time the
alarm occurs, and demonstrates that the requested time will ensure
alleviation of this condition as expeditiously as practicable; and
    (vii) How the baghouse system will be operated and maintained,
including monitoring of pressure drop across baghouse cells and
frequency of visual inspections of the baghouse interior and baghouse
components such as fans and dust removal and bag cleaning mechanisms.
    (3) For each bag leak detection system, the owner or operator shall
initiate procedures to determine the cause of every alarm within 1 hour
of the alarm. Except as provided in paragraph (c)(2)(vi) of this
section, the owner or operator shall alleviate the cause of the alarm
within 3 hours of the alarm by taking whatever action(s) are necessary.
Actions may include, but are not limited to the following:
    (i) Inspecting the baghouse for air leaks, torn or broken bags or
filter media, or any other condition that may cause an increase in
particulate emissions;
    (ii) Sealing off defective bags or filter media;
    (iii) Replacing defective bags or filter media or otherwise
repairing the control device;
    (iv) Sealing off a defective baghouse compartment;
    (v) Cleaning the bag leak detection system probe or otherwise
repairing the bag leak detection system; or
    (vi) Shutting down the process producing the particulate emissions.
    (4) The owner or operator shall maintain records of the information
specified in paragraphs (c)(4)(i) through (iii) of this section for
each bag leak detection system.
    (i) Records of the bag leak detection system output;
    (ii) Records of bag leak detection system adjustments, including
the date and time of the adjustment, the initial bag leak detection
system settings, and the final bag leak detection system settings; and
    (iii) The date and time of all bag leak detection system alarms,
the time that procedures to determine the cause of the alarm were
initiated, the cause of the alarm, an explanation of the actions taken,
the date and time the cause of the alarm was alleviated, and whether
the alarm was alleviated within 3 hours of the alarm.
    (d) Continuous emissions monitoring systems (CEMS). An owner or
operator subject to the PM concentration emission limit (in gr/dscf) in
Sec.  60.102a(b)(1) for an FCCU or FCU shall install, operate,
calibrate, and maintain an instrument for continuously monitoring and
recording the concentration (0 percent excess air) of PM in the exhaust
gases prior to release to the atmosphere. The monitor must include an
O2 monitor for correcting the data for excess air.
    (1) The owner or operator shall install, operate, and maintain each
PM monitor according to Performance Specification 11 of appendix B to
part 60. The span value of this PM monitor is 0.08 gr/dscf PM.
    (2) The owner or operator shall conduct performance evaluations of
each PM monitor according to the requirements in Sec.  60.13(c) and
Performance Specification 11 of appendix B to part 60. The owner or
operator shall use EPA Methods 5 or 5I of Appendix A-3 to part 60 or
Method 17 of Appendix A-6 to part 60 for conducting the relative
accuracy evaluations.
    (3) The owner or operator shall install, operate, and maintain each
O2 monitor according to Performance Specification 3 of
appendix B to part 60. The span value of this O2 monitor
must be selected between 10 and 25 percent, inclusive.
    (4) The owner or operator shall conduct performance evaluations of
each O2 monitor according to the requirements in Sec.
60.13(c) and Performance Specification 3 of Appendix B to part 60.
Method 3, 3A, or 3B of Appendix A-2 to part 60 shall be used for
conducting the relative accuracy evaluations. The method ANSI/ASME PTC
19.10-1981, ``Flue and Exhaust Gas Analyses,'' (incorporated by
reference--see Sec.  60.17) is an acceptable alternative to EPA Method
3B of Appendix A-2 to part 60.
    (5) The owner or operator shall comply with the quality assurance
requirements of Procedure 2 of Appendix B to part 60 for each PM CEMS
and Procedure 1 of Appendix F to part 60 for each O2
monitor, including quarterly accuracy determinations for each PM
monitor, annual accuracy determinations for each O2 monitor,
and daily calibration drift tests.
    (e) Alternative monitoring option for FCCU and FCU--COMS. Each
owner or operator of an FCCU or FCU that uses cyclones to comply with
the PM emission limit in Sec.  60.102a(b)(1) shall monitor the opacity
of emissions according to the requirements in paragraphs (e)(1) through
(3) of this section.
    (1) The owner or operator shall install, operate, and maintain an
instrument for continuously monitoring and recording the opacity of
emissions from the FCCU or the FCU exhaust vent.
    (2) The owner or operator shall install, operate, and maintain each
COMS according to Performance Specification 1 of Appendix B to part 60.
The instrument shall be spanned at 20 to 60 percent opacity.
    (3) The owner or operator shall conduct performance evaluations of
each COMS according to Sec.  60.13(c) and Performance Specification 1
of Appendix B to part 60.
    (f) FCCU and FCU subject to NOX limit. Each owner or operator
subject to the NOX emissions limit in Sec.  60.102a(b)(2)
for an FCCU or FCU shall install, operate, calibrate, and maintain an
instrument for continuously monitoring and recording the concentration
by volume (dry basis, 0 percent excess air) of NOX emissions
into the atmosphere. The monitor must include an O2 monitor
for correcting the data for excess air.
    (1) The owner or operator shall install, operate, and maintain each
NOX monitor according to Performance Specification 2 of
Appendix B to part 60. The span value of this NOX monitor is
200 ppmv NOX.
    (2) The owner or operator shall conduct performance evaluations of
each NOX monitor according to the requirements in Sec.
60.13(c) and Performance Specification 2 of Appendix B to part 60. The
owner or operator shall use Methods 7, 7A, 7C, 7D, or 7E of Appendix A-
4 to part 60 for conducting the relative accuracy evaluations. The
method ANSI/ASME PTC 19.10-1981, ``Flue and Exhaust Gas

Analyses,'' (incorporated by reference--see Sec.  60.17) is an
acceptable alternative to EPA Method 7 or 7C of Appendix A-4 to part
60.
    (3) The owner or operator shall install, operate, and maintain each
O2 monitor according to Performance Specification 3 of
Appendix B to part 60. The span value of this O2 monitor
must be selected between 10 and 25 percent, inclusive.
    (4) The owner or operator shall conduct performance evaluations of
each O2 monitor according to the requirements in Sec.
60.13(c) and Performance Specification 3 of Appendix B to part 60.
Method 3, 3A, or 3B of Appendix A-2 to part 60 shall be used for
conducting the relative accuracy evaluations. The method ANSI/ASME PTC
19.10-1981, ``Flue and Exhaust Gas Analyses,'' (incorporated by
reference--see Sec.  60.17) is an acceptable alternative to EPA Method
3B of Appendix A-2 to part 60.
    (5) The owner or operator shall comply with the quality assurance
requirements of Procedure 1 of Appendix F to part 60 for each
NOX and O2 monitor, including quarterly accuracy
determinations for NOX monitors, annual accuracy
determinations for O2 monitors, and daily calibration drift
tests.
    (g) FCCU and FCU subject to SO2 limit. The owner or operator
subject to the SO2 emissions limit in Sec.  60.102a(b)(3)
for an FCCU or an FCU shall install, operate, calibrate, and maintain
an instrument for continuously monitoring and recording the
concentration by volume (dry basis, corrected to 0 percent excess air)
of SO2 emissions into the atmosphere. The monitor shall
include an O2 monitor for correcting the data for excess
air.
    (1) The owner or operator shall install, operate, and maintain each
SO2 monitor according to Performance Specification 2 of
Appendix B to part 60. The span value of this SO2 monitor is
200 ppmv SO2.
    (2) The owner or operator shall conduct performance evaluations of
each SO2 monitor according to the requirements in Sec.
60.13(c) and Performance Specification 2 of Appendix B to part 60. The
owner or operator shall use Methods 6, 6A, or 6C of Appendix A-4 to
part 60 for conducting the relative accuracy evaluations. The method
ANSI / ASME PTC 19.10-1981, ``Flue and Exhaust Gas Analyses,''
(incorporated by reference--see Sec.  60.17) is an acceptable
alternative to EPA Method 6 or 6A of Appendix A-4 to part 60.
    (3) The owner or operator shall install, operate, and maintain each
O2 monitor according to Performance Specification 3 of
Appendix B to part 60. The span value of this O2 monitor
must be selected between 10 and 25 percent, inclusive.
    (4) The owner or operator shall conduct performance evaluations of
each O2 monitor according to the requirements in Sec.
60.13(c) and Performance Specification 3 of Appendix B to part 60.
Method 3, 3A, or 3B of Appendix A-2 to part 60 shall be used for
conducting the relative accuracy evaluations. The method ANSI/ASME PTC
19.10-1981, ``Flue and Exhaust Gas Analyses,'' (incorporated by
reference--see Sec.  60.17) is an acceptable alternative to EPA Method
3B of Appendix A-2 to part 60.
    (5) The owner or operator shall comply with the quality assurance
requirements in Procedure 1 of Appendix F to part 60 for each
SO2 and O2 monitor, including quarterly accuracy
determinations for SO2 monitors, annual accuracy
determinations for O2 monitors, and daily calibration drift
tests.
    (h) FCCU and fluid coking units subject to CO emissions limit.
Except as specified in paragraph (h)(3) of this section, the owner or
operator shall install, operate, calibrate, and maintain an instrument
for continuously monitoring and recording the concentration by volume
(dry basis) of CO emissions into the atmosphere from each FCCU and FCU
subject to the CO emissions limit in Sec.  60.102a(b)(4).
    (1) The owner or operator shall install, operate, and maintain each
CO monitor according to Performance Specification 4 or 4A of Appendix B
to part 60. The span value for this instrument is 1,000 ppm CO.
    (2) The owner or operator shall conduct performance evaluations of
each CO monitor according to the requirements in Sec.  60.13(c) and
Performance Specification 4 or 4A of Appendix B to part 60. The owner
or operator shall use Methods 10, 10A, or 10B of Appendix A-4 to part
60 for conducting the relative accuracy evaluations.
    (3) A CO CEMS need not be installed if the owner or operator
demonstrates that all hourly average CO emissions are and will remain
less than 50 ppmv (dry basis) corrected to 0 percent excess air. The
Administrator may revoke this exemption from monitoring upon a
determination that CO emissions on an hourly average basis have
exceeded 50 ppmv (dry basis) corrected to 0 percent excess air, in
which case a CO CEMS shall be installed within 180 days.
    (i) The demonstration shall consist of continuously monitoring CO
emissions for 30 days using an instrument that meets the requirements
of Performance Specification 4 or 4A of Appendix B to part 60. The span
value shall be 100 ppm CO instead of 1,000 ppm, and the relative
accuracy limit shall be 10 percent of the average CO emissions or 5 ppm
CO, whichever is greater. For instruments that are identical to Method
10 of Appendix A-4 to part 60 and employ the sample conditioning system
of Method 10A of Appendix A-4 to part 60, the alternative relative
accuracy test procedure in section 10.1 of Performance Specification 2
of Appendix B to part 60 may be used in place of the relative accuracy
test.
    (ii) The owner or operator must submit the following information to
the Administrator:
    (A) The measurement data specified in paragraph (h)(3)(i) of this
section along with all other operating data known to affect CO
emissions; and
    (B) Descriptions of the CPMS for exhaust gas temperature and
O2 monitor required in paragraph (h)(4) of this section and
operating limits for those parameters to ensure combustion conditions
remain similar to those that exist during the demonstration period.
    (iii) The effective date of the exemption from installation and
operation of a CO CEMS is the date of submission of the information and
data required in paragraph (h)(3)(ii) of this section.
    (4) The owner or operator of a FCCU or FCU that is exempted from
the requirement to install and operate a CO CEMS in paragraph (h)(3) of
this section shall install, operate, calibrate, and maintain CPMS to
measure and record the operating parameters in paragraph (h)(4)(i) or
(ii) of this section. The owner or operator shall install, operate, and
maintain each CPMS according to the manufacturer's specifications.
    (i) For a FCCU or FCU with no post-combustion control device, the
temperature and O2 concentration of the exhaust gas stream
exiting the unit.
    (ii) For a FCCU or FCU with a post-combustion control device, the
temperature and O2 concentration of the exhaust gas stream
exiting the control device.
    (i) Excess emissions. For the purpose of reports required by Sec.
60.7(c), periods of excess emissions for a FCCU or FCU subject to the
emissions limitations in Sec.  60.102a(b) are defined as specified in
paragraphs (i)(1) through (6) of this section. Note: Determine all
averages, except for opacity, as the arithmetic average of the
applicable 1-hour averages, e.g., determine the rolling 3-hour average
as the arithmetic average of three contiguous 1-hour averages.

    (1) If a CPMS is used according to Sec.  60.105a(b)(1), all 3-hour
periods during which the average PM control device operating
characteristics, as measured by the continuous monitoring systems under
Sec.  60.105a(b)(1), fall below the levels established during the
performance test.
    (2) If a PM CEMS is used according to Sec.  60.105a(d), all 7-day
periods during which the average PM emission rate, as measured by the
continuous PM monitoring system under Sec.  60.105a(d) exceeds 0.040
gr/dscf corrected to 0 percent excess air for a modified or
reconstructed FCCU, 0.020 gr/dscf corrected to 0 percent excess air for
a newly constructed FCCU, or 0.040 gr/dscf for an affected fluid coking
unit.
    (3) If a COMS is used according to Sec.  60.105a(e), all 3-hour
periods during which the average opacity, as measured by the COMS under
Sec.  60.105a(e), exceeds the site-specific limit established during
the most recent performance test.
    (4) All rolling 7-day periods during which the average
concentration of NOX as measured by the NOX CEMS
under Sec.  60.105a(f) exceeds 80 ppmv for an affected FCCU or FCU.
    (5) Except as provided in paragraph (i)(7) of this section, all
rolling 7-day periods during which the average concentration of
SO2 as measured by the SO2 CEMS under Sec.
60.105a(g) exceeds 50 ppmv, and all rolling 365-day periods during
which the average concentration of SO2 as measured by the
SO2 CEMS exceeds 25 ppmv.
    (6) All 1-hour periods during which the average CO concentration as
measured by the CO continuous monitoring system under Sec. 1A60.105a(h)
exceeds 500 ppmv or, if applicable, all 1-hour periods during which the
average temperature and O2 concentration as measured by the
continuous monitoring systems under Sec.  60.105a(h)(4) fall below the
operating limits established during the performance test.

Sec.  60.106a  Monitoring of emissions and operations for sulfur
recovery plants.

    (a) The owner or operator of a sulfur recovery plant that is
subject to the emissions limits in Sec.  60.102a(f)(1) or Sec.
60.102a(f)(2) shall:
    (1) For sulfur recovery plants subject to the SO2
emission limit in Sec.  60.102a(f)(1)(i) or Sec.  60.102a(f)(2)(i), the
owner or operator shall install, operate, calibrate, and maintain an
instrument for continuously monitoring and recording the concentration
(dry basis, zero percent excess air) of any SO2 emissions
into the atmosphere. The monitor shall include an oxygen monitor for
correcting the data for excess air.
    (i) The span values for this monitor are two times the applicable
SO2 emission limit and between 10 and 25 percent
O2, inclusive.
    (ii) The owner or operator shall install, operate, and maintain
each SO2 CEMS according to Performance Specification 2 of
Appendix B to part 60.
    (iii) The owner or operator shall conduct performance evaluations
of each SO2 monitor according to the requirements in Sec.
60.13(c) and Performance Specification 2 of Appendix B to part 60. The
owner or operator shall use Methods 6 or 6C of Appendix A-4 to part 60
and Method 3 or 3A of Appendix A-2 of part 60 for conducting the
relative accuracy evaluations. The method ANSI/ASME PTC 19.10-1981,
``Flue and Exhaust Gas Analyses,'' (incorporated by reference--see
Sec.  60.17) is an acceptable alternative to EPA Method 6.
    (2) For sulfur recovery plants that are subject to the reduced
sulfur compound and H2S emission limit in Sec.
60.102a(f)(1)(ii) or Sec.  60.102a(f)(2)(ii), the owner or operator
shall install, operate, calibrate, and maintain an instrument for
continuously monitoring and recording the concentration of reduced
sulfur, H2S, and O2 emissions into the
atmosphere. The reduced sulfur emissions shall be calculated as
SO2 (dry basis, zero percent excess air).
    (i) The span values for this monitor are two times the applicable
reduced sulfur emission limit, two times the H2S emission
limit, and between 10 and 25 percent O2, inclusive.
    (ii) The owner or operator shall install, operate, and maintain
each reduced sulfur CEMS according to Performance Specification 5 of
Appendix B to part 60.
    (iii) The owner or operator shall conduct performance evaluations
of each reduced sulfur monitor according to the requirements in Sec.
60.13(c) and Performance Specification 5 of Appendix B to part 60. The
owner or operator shall use Methods 15 or 15A of Appendix A-5 to part
60 for conducting the relative accuracy evaluations. The method ANSI/
ASME PTC 19.10-1981, ``Flue and Exhaust Gas Analyses,'' (incorporated
by reference--see Sec.  60.17) is an acceptable alternative to EPA
Method 15A of Appendix A-5 to part 60.
    (iv) The owner or operator shall install, operate, and maintain
each H2S CEMS according to Performance Specification 7 of
Appendix B to part 60.
    (v) The owner or operator shall conduct performance evaluations of
each reduced sulfur monitor according to the requirements in Sec.
60.13(c) and Performance Specification 5 of Appendix B to part 60. The
owner or operator shall use Methods 11, 15, or 15A of Appendix A-5 to
part 60 or Method 16 of Appendix A-6 to part 60 for conducting the
relative accuracy evaluations. The method ANSI/ASME PTC 19.10-1981,
``Flue and Exhaust Gas Analyses,'' (incorporated by reference--see
Sec.  60.17) is an acceptable alternative to EPA Method 15A of Appendix
A-5 to part 60.
    (vi) The owner or operator shall install, operate, and maintain
each O2 monitor according to Performance Specification 3 of
Appendix B to part 60.
    (vii) The span value for the O2 monitor must be selected
between 10 and 25 percent, inclusive.
    (viii) The owner or operator shall conduct performance evaluations
for the O2 monitor according to the requirements of Sec.
60.13(c) and Performance Specification 3 of Appendix B to part 60. The
owner or operator shall use Methods 3, 3A, or 3B of Appendix A-2 to
part 60 for conducting the relative accuracy evaluations. The method
ANSI/ASME PTC 19.10-1981, ``Flue and Exhaust Gas Analyses,''
(incorporated by reference--see Sec.  60.17) is an acceptable
alternative to EPA Method 3B of Appendix A-2 to part 60.
    (ix) The owner or operator shall comply with the applicable quality
assurance procedures of Appendix F to part 60 for each monitor,
including annual accuracy determinations for each O2
monitor, and daily calibration drift determinations.
    (3) In place of the reduced sulfur monitor required in paragraph
(a)(2) of this section, the owner or operator shall install, calibrate,
operate, and maintain an instrument using an air or O2
dilution and oxidation system to convert any reduced sulfur to
SO2 for continuously monitoring and recording the
concentration (dry basis, 0 percent excess air) of the total resultant
SO2. The monitor must include an O2 monitor for
correcting the data for excess O2.
    (i) The span value for this monitor is two times the applicable
SO2 emission limit.
    (ii) The owner or operator shall conduct performance evaluations of
each SO2 monitor according to the requirements in Sec.
60.13(c) and Performance Specification 5 of Appendix B to part 60. The
owner or operator shall use Methods 15 or 15A of

Appendix A-5 to part 60 for conducting the relative accuracy
evaluations. The method ANSI/ASME PTC 19.10-1981, ``Flue and Exhaust
Gas Analyses,'' (incorporated by reference--see Sec.  60.17) is an
acceptable alternative to EPA Method 15A of Appendix A-5 to part 60.
    (iii) The owner or operator shall install, operate, and maintain
each O2 monitor according to Performance Specification 3 of
Appendix B to part 60.
    (iv) The span value for the O2 monitor must be selected
between 10 and 25 percent, inclusive.
    (v) The owner or operator shall conduct performance evaluations for
the O2 monitor according to the requirements of Sec.
60.13(c) and Performance Specification 3 of Appendix B to part 60. The
owner or operator shall use Methods 3, 3A, or 3B of Appendix A-2 to
part 60 for conducting the relative accuracy evaluations. The method
ANSI/ASME PTC 19.10-1981, ``Flue and Exhaust Gas Analyses,''
(incorporated by reference--see Sec.  60.17) is an acceptable
alternative to EPA Method 3B of Appendix A-2 to part 60.
    (vi) The owner or operator shall comply with the applicable quality
assurance procedures of Appendix F to part 60 for each monitor,
including quarterly accuracy determinations for each SO2
monitor, annual accuracy determinations for each O2 monitor,
and daily calibration drift determinations.
    (b) Excess emissions. For the purpose of reports required by Sec.
60.7(c), periods of excess emissions for sulfur recovery plants subject
to the emissions limitations in Sec.  60.102a(f) are defined as
specified in paragraphs (b)(1) through (3) of this section. Note:
Determine all averages as the arithmetic average of the applicable 1-
hour averages, e.g., determine the rolling 12-hour average as the
arithmetic average of 12 contiguous 1-hour averages.
    (1) All 12-hour periods during which the average concentration of
SO2 as measured by the SO2 continuous monitoring
system required under paragraph (a)(1) of this section exceeds the
applicable emission limit (dry basis, zero percent excess air); or
    (2) All 12-hour periods during which the average concentration of
reduced sulfur (as SO2) as measured by the reduced sulfur
continuous monitoring system required under paragraph (a)(2) of this
section exceeds the applicable emission limit; or
    (3) All 12-hour periods during which the average concentration of
H2S as measured by the H2S continuous monitoring
system required under paragraph (a)(2) of this section exceeds the
applicable emission limit (dry basis, 0 percent excess air).

Sec.  60.107a  Monitoring of emissions and operations for fuel gas
combustion devices.

    (a) Fuel gas combustion devices subject to SO2 or H2S limit. The
owner or operator of a fuel gas combustion device that is subject to
the requirements in Sec.  60.102a(g) shall comply with the requirements
in paragraph (a)(1) of this section for SO2 emissions or
paragraph (a)(2) of this section for H2S emissions.
    (1) The owner or operator of a fuel gas combustion device subject
to the SO2 emissions limits in Sec.  60.102a(g)(1)(i) shall
install, operate, calibrate, and maintain an instrument for
continuously monitoring and recording the concentration (dry basis, 0
percent excess air) of SO2 emissions into the atmosphere.
The monitor must include an O2 monitor for correcting the
data for excess air.
    (i) The owner or operator shall install, operate, and maintain each
SO2 monitor according to Performance Specification 2 of
Appendix B to part 60. The span value for the SO2 monitor is
50 ppm SO2.
    (ii) The owner or operator shall conduct performance evaluations
for the SO2 monitor according to the requirements of Sec.
60.13(c) and Performance Specification 2 of Appendix B to part 60. The
owner or operator shall use Methods 6, 6A, or 6C of Appendix A-4 to
part 60 for conducting the relative accuracy evaluations. The method
ANSI/ASME PTC 19.10-1981, ``Flue and Exhaust Gas Analyses,''
(incorporated by reference--see Sec.  60.17) is an acceptable
alternative to EPA Method 6 or 6A of Appendix A-4 to part 60. Samples
taken by Method 6 of Appendix A-4 to part 60 shall be taken at a flow
rate of approximately 2 liters/min for at least 30 minutes. The
relative accuracy limit shall be 20 percent or 4 ppm, whichever is
greater, and the calibration drift limit shall be 5 percent of the
established span value.
    (iii) The owner or operator shall install, operate, and maintain
each O2 monitor according to Performance Specification 3 of
Appendix B to part 60. The span value for the O2 monitor
must be selected between 10 and 25 percent, inclusive.
    (iv) The owner or operator shall conduct performance evaluations
for the O2 monitor according to the requirements of Sec.
60.13(c) and Performance Specification 3 of Appendix B to part 60. The
owner or operator shall use Methods 3, 3A, or 3B of Appendix A-2 to
part 60 for conducting the relative accuracy evaluations. The method
ANSI/ASME PTC 19.10-1981, ``Flue and Exhaust Gas Analyses,''
(incorporated by reference--see Sec.  60.17) is an acceptable
alternative to EPA Method 3B of Appendix A-2 to part 60.
    (v) The owner or operator shall comply with the applicable quality
assurance procedures in Appendix F to part 60, including quarterly
accuracy determinations for SO2 monitors, annual accuracy
determinations for O2 monitors, and daily calibration drift
tests.
    (vi) Fuel gas combustion devices having a common source of fuel gas
may be monitored at only one location (i.e., after one of the
combustion devices), if monitoring at this location accurately
represents the SO2 emissions into the atmosphere from each
of the combustion devices.
    (2) The owner or operator of a fuel gas combustion device subject
to the H2S concentration limits in Sec.  60.102a(g)(1)(ii)
shall install, operate, calibrate, and maintain an instrument for
continuously monitoring and recording the concentration by volume (dry
basis) of H2S in the fuel gases before being burned in any
fuel gas combustion device.
    (i) The owner or operator shall install, operate, and maintain each
H2S monitor according to Performance Specification 7 of
Appendix B to part 60. The span value for this instrument is 320 ppmv
H2S.
    (ii) The owner or operator shall conduct performance evaluations
for each H2S monitor according to the requirements of Sec.
60.13(c) and Performance Specification 7 of Appendix B to part 60. The
owner or operator shall use Method 11, 15, or 15A of Appendix A-5 to
part 60 or Method 16 of Appendix A-6 to part 60 for conducting the
relative accuracy evaluations. The method ANSI/ASME PTC 19.10-1981,
``Flue and Exhaust Gas Analyses,'' (incorporated by reference--see
Sec.  60.17) is an acceptable alternative to EPA Method 15A of Appendix
A-5 to part 60.
    (iii) The owner or operator shall comply with the applicable
quality assurance procedures in Appendix F to part 60 for each
H2S monitor.
    (iv) Fuel gas combustion devices having a common source of fuel gas
may be monitored at only one location, if monitoring at this location
accurately represents the concentration of H2S in the fuel
gas being burned.
    (3) The owner or operator of a fuel gas combustion device is not
required to comply with paragraph (a)(1) or (2) of this section for
fuel gas streams that are

exempt under Sec.  60.102a(h) and fuel gas streams combusted in a
process heater or other fuel gas combustion device that are inherently
low in sulfur content. Fuel gas streams meeting one of the requirements
in paragraphs (a)(3)(i) through (iv) of this section will be considered
inherently low in sulfur content.
    (i) Pilot gas for heaters and flares.
    (ii) Fuel gas streams that meet a commercial-grade product
specification for sulfur content of 30 ppmv or less. In the case of a
liquefied petroleum gas (LPG) product specification in the pressurized
liquid state, the gas phase sulfur content should be evaluated assuming
complete vaporization of the LPG and sulfur containing-compounds at the
product specification concentration.
    (iii) Fuel gas streams produced in process units that are
intolerant to sulfur contamination, such as fuel gas streams produced
in the hydrogen plant, catalytic reforming unit, isomerization unit,
and HF alkylation process units.
    (iv) Other fuel gas streams that an owner or operator demonstrates
are low-sulfur according to the procedures in paragraph (b) of this
section.
    (4) If the composition of an exempt fuel gas stream changes, the
owner or operator must follow the procedures in paragraph (b)(3) of
this section.
    (b) Exemption from H2S monitoring requirements for low-sulfur fuel
gas streams. The owner or operator of a fuel gas combustion device may
apply for an exemption from the H2S monitoring requirements
in paragraph (a)(2) of this section for a fuel gas stream that is
inherently low in sulfur content. A fuel gas stream that is
demonstrated to be low-sulfur is exempt from the monitoring
requirements of paragraphs (a)(1) and (2) of this section until there
are changes in operating conditions or stream composition.
    (1) The owner or operator shall submit to the Administrator a
written application for an exemption from monitoring. The application
must contain the following information:
    (i) A description of the fuel gas stream/system to be considered,
including submission of a portion of the appropriate piping diagrams
indicating the boundaries of the fuel gas stream/system, and the
affected fuel gas combustion device(s) to be considered;
    (ii) A statement that there are no crossover or entry points for
sour gas (high H2S content) to be introduced into the fuel
gas stream/system (this should be shown in the piping diagrams);
    (iii) An explanation of the conditions that ensure low amounts of
sulfur in the fuel gas stream (i.e., control equipment or product
specifications) at all times;
    (iv) The supporting test results from sampling the requested fuel
gas stream/system demonstrating that the sulfur content is less than 5
ppm H2S. Sampling data must include, at minimum, 2 weeks of
daily monitoring (14 grab samples) for frequently operated fuel gas
streams/systems; for infrequently operated fuel gas streams/systems,
seven grab samples must be collected unless other additional
information would support reduced sampling. The owner or operator shall
use detector tubes (``length-of-stain tube'' type measurement)
following the ``Gas Processors Association Standard 2377-86, Test for
Hydrogen Sulfide and Carbon Dioxide in Natural Gas Using Length of
Stain Tubes,'' 1986 Revision (incorporated by reference--see Sec.
60.17), with ranges 0-10/0-100 ppm (N = 10/1) to test the applicant
fuel gas stream for H2S; and
    (v) A description of how the 2 weeks (or seven samples for
infrequently operated fuel gas streams/systems) of monitoring results
compares to the typical range of H2S concentration (fuel
quality) expected for the fuel gas stream/system going to the affected
fuel gas combustion device (e.g., the 2 weeks of daily detector tube
results for a frequently operated loading rack included the entire
range of products loaded out, and, therefore, should be representative
of typical operating conditions affecting H2S content in the
fuel gas stream going to the loading rack flare).
    (2) The effective date of the exemption is the date of submission
of the information required in paragraph (b)(1) of this section.
    (3) 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
(b)(3)(i), (b)(3)(ii), or (b)(3)(iii) of this section.
    (i) If the operation change results in a sulfur content that is
still within the range of concentrations included in the original
application, the owner or operator shall conduct an H2S test
on a grab sample and record the results as proof that the concentration
is still within the range.
    (ii) If the operation change results in a sulfur content that is
outside the range of concentrations included in the original
application, the owner or operator may submit new information following
the procedures of paragraph (b)(1) of this section within 60 days (or
within 30 days after the seventh grab sample is tested for infrequently
operated process units).
    (iii) If the operation change results in a sulfur content that is
outside the range of concentrations included in the original
application, and the owner or operator chooses not to submit new
information to support an exemption, the owner or operator must begin
H2S monitoring using daily stain sampling to demonstrate
compliance. The owner or operator must begin monitoring according to
the requirements in paragraphs (a)(1) or (a)(2) of this section as soon
as practicable but in no case later than 180 days after the operation
change. During daily stain tube sampling, a daily sample exceeding 162
ppmv is an exceedance of the 3-hour H2S concentration limit.
The owner or operator must determine a rolling 365-day average using
the stain sampling results; an average H2S concentration of
5 ppmv must be used for days prior to the operation change.
    (c) Process heaters subject to NOX limit. The owner or operator of
a process heater subject to the NOX emission limit in Sec.
60.102a(g)(2) shall install, operate, calibrate, and maintain an
instrument for continuously monitoring and recording the concentration
(dry basis, 0 percent excess air) of NOX emissions into the
atmosphere. The monitor must include an O2 monitor for
correcting the data for excess air.
    (1) The owner or operator shall install, operate, and maintain each
NOX monitor according to Performance Specification 2 of
Appendix B to part 60. The span value of this NOX monitor is
200 ppmv NOX.
    (2) The owner or operator shall conduct performance evaluations of
each NOX monitor according to the requirements in Sec.
60.13(c) and Performance Specification 2 of Appendix B to part 60. The
owner or operator shall use Methods 7, 7A, 7C, 7D, or 7E of Appendix A-
4 to part 60 for conducting the relative accuracy evaluations. The
method ANSI/ASME PTC 19.10-1981, ``Flue and Exhaust Gas Analyses,''
(incorporated by reference--see Sec.  60.17) is an acceptable
alternative to EPA Method 7 or 7C of Appendix A-4 to part 60.
    (3) The owner or operator shall install, operate, and maintain each
O2 monitor according to Performance Specification 3 of
Appendix B to part 60. The span value of this O2 monitor
must be selected between 10 and 25 percent, inclusive.
    (4) The owner or operator shall conduct performance evaluations of
each O2 monitor according to the requirements in Sec.
60.13(c) and

Performance Specification 3 of Appendix B to part 60. Method 3, 3A, or
3B of Appendix A-2 to part 60 shall be used for conducting the relative
accuracy evaluations. The method ANSI/ASME PTC 19.10-1981, ``Flue and
Exhaust Gas Analyses,'' (incorporated by reference--see Sec.  60.17) is
an acceptable alternative to EPA Method 3B of Appendix A-2 to part 60.
    (5) The owner or operator shall comply with the quality assurance
requirements in Procedure 1 of Appendix F to part 60 for each
NOX and O2 monitor, including quarterly accuracy
determinations for NOX monitors, annual accuracy
determinations for O2 monitors, and daily calibration drift
tests.
    (6) The owner or operator of a process heater that has a rated
heating capacity of less than 100 MMBtu and is equipped with low-
NOX burners (LNB) or ultra low-NOX burners (ULNB)
is not subject to the monitoring requirements in paragraphs (c)(1)
through (5) of this section. The owner or operator of such a process
heater must conduct biennial performance tests to demonstrate
compliance.
    (d) Sulfur monitoring for affected flares. The owner or operator of
an affected flare subject to Sec.  60.103a(b) shall install, operate,
calibrate, and maintain an instrument for continuously monitoring and
recording the concentration of reduced sulfur in flare gas. The owner
or operator of a modified flare shall install this instrument by no
later than 1 year after the flare becomes an affected flare subject to
this subpart.
    (1) The owner or operator shall install, operate, and maintain each
reduced sulfur CEMS according to Performance Specification 5 of
Appendix B to part 60.
    (2) The owner or operator shall conduct performance evaluations of
each reduced sulfur monitor according to the requirements in Sec.
60.13(c) and Performance Specification 5 of Appendix B to part 60. The
owner or operator shall use Methods 15 or 15A of Appendix A-5 to part
60 for conducting the relative accuracy evaluations. The method ANSI/
ASME PTC 19.10-1981, ``Flue and Exhaust Gas Analyses,'' (incorporated
by reference--see Sec.  60.17) is an acceptable alternative to EPA
Method 15A of Appendix A-5 to part 60.
    (3) The owner or operator shall comply with the applicable quality
assurance procedures in Appendix F to part 60 for each reduced sulfur
monitor.
    (e) Flow monitoring for flares. The owner or operator of an
affected flare subject to Sec.  60.102a(g)(3) shall install, operate,
calibrate, and maintain CPMS to measure and record the exhaust gas flow
rate. The owner or operator of a modified flare shall install this
instrument by no later than 1 year after the flare becomes an affected
flare subject to this subpart.
    (1) The CPMS must be able to correct for the temperature and
pressure of the system and output flow in standard conditions as
defined in Sec.  60.2.
    (2) The owner or operator shall install, operate, and maintain each
CPMS according to the manufacturer's specifications and requirements.
    (f) Excess emissions. For the purpose of reports required by Sec.
60.7(c), periods of excess emissions for fuel gas combustion devices
subject to the emissions limitations in Sec.  60.102a(g) are defined as
specified in paragraphs (f)(1) through (4) of this section. Note:
Determine all averages as the arithmetic average of the applicable 1-
hour averages, e.g., determine the rolling 3-hour average as the
arithmetic average of three contiguous 1-hour averages.
    (1) All rolling 3-hour periods during which the average
concentration of SO2 as measured by the SO2
continuous monitoring system required under paragraph (a)(1) of this
section exceeds 20 ppmv, and all rolling 365-day periods during which
the average concentration as measured by the SO2 continuous
monitoring system required under paragraph (a)(1) of this section
exceeds 8 ppmv; or
    (2) All rolling 3-hour periods during which the average
concentration of H2S as measured by the H2S
continuous monitoring system required under paragraph (a)(2) of this
section exceeds 162 ppmv, all days in which the concentration of
H2S as measured by daily stain tube sampling required under
paragraph (b)(3)(iii) of this section exceeds 162 ppmv, and all rolling
365-day periods during which the average concentration as measured by
the H2S continuous monitoring system under paragraph (a)(2)
of this section exceeds 60 ppmv.
    (3) All rolling 24-hour periods during which the average
concentration of NOX as measured by the NOX
continuous monitoring system required under paragraph (c) of this
section exceeds 40 ppmv.
    (4) All rolling 30-day periods during which the average flow rate
to an affected flare as measured by the monitoring system required
under paragraph (e) of this section exceeds 250,000 scfd.

Sec.  60.108a  Recordkeeping and reporting requirements.

    (a) Each owner or operator subject to the emissions limitations in
Sec.  60.102a shall comply with the notification, recordkeeping, and
reporting requirements in Sec.  60.7 and other requirements as
specified in this section.
    (b) Each owner or operator subject to an emissions limitation in
Sec.  60.102a shall notify the Administrator of the specific monitoring
provisions of Sec. Sec.  60.105a, 60.106a, and 60.107a with which the
owner or operator seeks to comply. Notification shall be submitted with
the notification of initial startup required by Sec.  60.7(a)(3).
    (c) The owner or operator shall maintain the following records:
    (1) A copy of the flare management plan and each root cause
analysis of a discharge;
    (2) Records of information to document conformance with bag leak
detection system operation and maintenance requirements in Sec.
60.105a(c).
    (3) Records of bag leak detection system alarms and actions
according to Sec.  60.105a(c).
    (4) For each FCCU and fluid coking unit subject to the monitoring
requirements in Sec.  60.105a(b)(1), records of the average coke burn-
off rate and hours of operation.
    (5) For each fuel gas stream to which one of the exemptions listed
in Sec.  60.107a(a)(3) applies, records of the specific exemption
determined to apply for each fuel stream. If the owner or operator
applies for the exemption described in Sec.  60.107a(a)(3)(iv), the
owner or operator must keep a copy of the application as well as the
letter from the Administrator granting approval of the application.
    (6) The owner or operator shall record and maintain records of
discharges greater than 500 lb/day SO2 from any affected
fuel gas combustion device or sulfur recovery plant and discharges to
an affected flare in excess of 500,000 scfd. These records shall
include:
    (i) A description of the discharge.
    (ii) For discharges greater than 500 lb/day SO2, the
date and time the discharge was first identified and the duration of
the discharge.
    (iii) The measured or calculated cumulative quantity of gas
discharged over the discharge duration. If the discharge duration
exceeds 24 hours, record the discharge quantity for each 24-hour
period. Engineering calculations are allowed for fuel gas combustion
devices other than flares.
    (iv) For discharges greater than 500 lb/day SO2, the
measured or estimated

concentration of H2S, TRS and SO2 of the stream
discharged. Process knowledge can be used to make these estimates for
fuel gas combustion devices other than flares.
    (v) For discharges greater than 500 lb/day SO2, the
cumulative quantity of H2S and SO2 released into
the atmosphere. For releases controlled by flares, assume 99 percent
conversion of reduced sulfur to SO2. For other fuel gas
combustion devices, assume 99 percent conversion of H2S to
SO2.
    (vi) Results of any root-cause analysis conducted as required in
Sec.  60.103a(a)(4) and Sec.  60.103a(b).
    (d) Each owner or operator subject to this subpart shall submit an
excess emissions report for all periods of excess emissions according
to the requirements of Sec.  60.7(c) except that the report shall
contain the information specified in paragraphs (d)(1) through (7) of
this section.
    (1) The date that the exceedance occurred;
    (2) An explanation of the exceedance;
    (3) Whether the exceedance was concurrent with a startup, shutdown,
or malfunction of an affected facility or control system; and
    (4) A description of the action taken, if any.
    (5) A root-cause summary report that provides the information
described in paragraph (e)(6) of this section for all discharges for
which a root-cause analysis was required by Sec.  60.103a(a)(4) and
Sec.  60.103a(b).
    (6) For any periods for which monitoring data are not available,
any changes made in operation of the emission control system during the
period of data unavailability which could affect the ability of the
system to meet the applicable emission limit. Operations of the control
system and affected facility during periods of data unavailability are
to be compared with operation of the control system and affected
facility before and following the period of data unavailability.
    (7) A written statement, signed by a responsible official,
certifying the accuracy and completeness of the information contained
in the report.

Sec.  60.109a  Delegation of authority.

    (a) This subpart can be implemented and enforced by the U.S. EPA or
a delegated authority such as a State, local, or tribal agency. You
should contact your U.S. EPA Regional Office to find out if this
subpart is delegated to a State, local, or tribal agency within your
State.
    (b) In delegating implementation and enforcement authority of this
subpart to a State, local, or tribal agency, the approval authorities
contained in paragraphs (b)(1) through (3) of this section are retained
by the Administrator of the U.S. EPA and are not transferred to the
State, local, or tribal agency.
    (1) Approval of a major change to test methods under Sec.  60.8(b).
A ``major change to test method'' is defined in 40 CFR 63.90.
    (2) Approval of a major change to monitoring under Sec.  60.13(i).
A ``major change to monitoring'' is defined in 40 CFR 63.90.
    (3) Approval of a major change to recordkeeping/reporting under
Sec.  60.7(b) through (f). A ``major change to recordkeeping/
reporting'' is defined in 40 CFR 63.90.

[FR Doc. E8-13498 Filed 6-23-08; 8:45 am]

BILLING CODE 6560-50-P


[Federal Register Volume 88, Number 127 (Wednesday, July 5, 2023)]
[Notices]
[Pages 42935-42938]
[FR Doc No: 2023-14192]

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ENVIRONMENTAL PROTECTION AGENCY

[EPA-HQ-OPP-2023-0069; FRL-10579-05-OCSPP]

Receipt of a Pesticide Petition Filed for Residues of Pesticide
Chemicals in or on Various Commodities (May 2023)

AGENCY: Environmental Protection Agency (EPA).

ACTION: Notice of filing of petition and request for comment.

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SUMMARY: This document announces the Agency's receipt of an initial
filing of a pesticide petition requesting the establishment or
modification of regulations for residues of pesticide chemicals in or
on various commodities.

DATES: Comments must be received on or before August 4, 2023.

ADDRESSES: Submit your comments, identified by docket identification
(ID) number EPA-HQ-OPP-2023-0069, through the Federal eRulemaking
Portal at https://www.regulations.gov. Follow the online instructions
for submitting comments. Do not submit electronically any information
you consider to be Confidential Business Information (CBI) or other
information whose disclosure is restricted by statute. Additional
instructions on commenting and visiting the docket, along with more
information about dockets generally, is available at https://www.epa.gov/dockets.

FOR FURTHER INFORMATION CONTACT: Anne Overstreet, Biopesticides and
Pollution Prevention Division (BPPD) (7511M), main telephone number:
202-566-2425, email address: [email protected]; or Charles Smith,
Registration Division (RD) (7505T), main telephone number: (202) 566-
2427, email address: [email protected]. The mailing address for each
contact person is Office of Pesticide Programs, Environmental
Protection Agency, 1200 Pennsylvania Ave. NW, Washington, DC 20460-
0001. As part of the mailing address, include the contact person's
name, division, and mail code. The division to contact is listed at the
end of each application summary.

SUPPLEMENTARY INFORMATION:

I. General Information

A. Does this action apply to me?

    You may be potentially affected by this action if you are an
agricultural producer, food manufacturer, or pesticide manufacturer.
The following list of North American Industrial Classification System
(NAICS) codes is not intended to be exhaustive, but rather provides a
guide to help readers determine whether this document applies to them.
Potentially affected entities may include:
     Crop production (NAICS code 111).
     Animal production (NAICS code 112).
     Food manufacturing (NAICS code 311).
     Pesticide manufacturing (NAICS code 32532).

B. What should I consider as I prepare my comments for EPA?

    1. Submitting CBI. Do not submit this information to EPA through
regulations.gov or email. Clearly mark the part or all of the
information that you claim to be CBI. For CBI information in a disk or
CD-ROM that you mail to EPA, mark the outside of the disk or CD-ROM as
CBI and then identify electronically within the disk or CD-ROM the
specific information that is claimed as CBI. In addition to one
complete version of the comment that includes information claimed as
CBI, a copy of the comment that does not contain the information
claimed as CBI must be submitted for inclusion in the public docket.
Information so marked will not be disclosed except in

accordance with procedures set forth in 40 CFR part 2.
    2. Tips for preparing your comments. When preparing and submitting
your comments, see the commenting tips at https://www.epa.gov/dockets/comments.html.
    3. Environmental justice. EPA seeks to achieve environmental
justice, the fair treatment and meaningful involvement of any group,
including minority and/or low-income populations, in the development,
implementation, and enforcement of environmental laws, regulations, and
policies. To help address potential environmental justice issues, the
Agency seeks information on any groups or segments of the population
who, as a result of their location, cultural practices, or other
factors, may have atypical or disproportionately high and adverse human
health impacts or environmental effects from exposure to the pesticides
discussed in this document, compared to the general population.

II. What action is the Agency taking?

    EPA is announcing receipt of a pesticide petition filed under
section 408 of the Federal Food, Drug, and Cosmetic Act (FFDCA), 21
U.S.C. 346a, requesting the establishment or modification of
regulations in 40 CFR part 180 for residues of pesticide chemicals in
or on various food commodities. The Agency is taking public comment on
the request before responding to the petitioner. EPA is not proposing
any particular action at this time. EPA has determined that the
pesticide petition described in this document contains data or
information prescribed in FFDCA section 408(d)(2), 21 U.S.C.
346a(d)(2); however, EPA has not fully evaluated the sufficiency of the
submitted data at this time or whether the data supports granting of
the pesticide petition. After considering the public comments, EPA
intends to evaluate whether and what action may be warranted.
Additional data may be needed before EPA can make a final determination
on this pesticide petition.
    Pursuant to 40 CFR 180.7(f), a summary of the petition that is the
subject of this document, prepared by the petitioner, is included in a
docket EPA has created for this rulemaking. The docket for this
petition is available at https://www.regulations.gov.
    As specified in FFDCA section 408(d)(3), 21 U.S.C. 346a(d)(3), EPA
is publishing notice of the petition so that the public has an
opportunity to comment on this request for the establishment or
modification of regulations for residues of pesticides in or on food
commodities. Further information on the petition may be obtained
through the petition summary referenced in this unit.

A. Notice of Filing--Amended Tolerances for Non-Inerts

    1. PP 3E9059. EPA-HQ-OPP-2021-0624. Bayer CropScience, 800 N
Lindbergh Blvd., St. Louis, MO 63167, requests to amend the tolerance
in 40 CFR 180.3 for residues of the insecticide, tetraniliprole, 1-(3-
chloro-2-pyridinyl)-N-[4-cyano-2-methyl-6-
[(methylamino)carbonyl]phenyl]-3-[[5-(trifluoromethyl)-2H-tetrazol-2-
yl]methyl]-1H-pyrazole-5-carboxamide, in or on tea at 80 parts per
million (ppm). The high-performance liquid chromatography with tandem
mass spectrometry (HPLC/MS/MS) is used to measure and evaluate the
chemical tetraniliprole. Contact: RD.
    2. PP 2E9028. EPA-HQ-OPP-2022-0890. Interregional Research Project
Number 4 (IR-4), IR-4 Project Headquarters, North Carolina State
University, 1730 Varsity Drive, Venture IV, Suite 210, Raleigh, NC
27606, requests to amend 40 CFR 180.417 by removing the established
time-limited tolerance for residues of the herbicide, triclopyr, 2-
[(3,5,6-trichloro-2- pyridinyl)oxy]acetic acid, including its
metabolites and degradates, in or on sugarcane, cane at 40 ppm.
Contact: RD.
    3. PP 2E9045. EPA-HQ-OPP-2023-0080. IR-4, IR-4 Project
Headquarters, North Carolina State University, 1730 Varsity Drive,
Venture IV, Suite 210, Raleigh, NC 27606, requests to amend 40 CFR
180.649 by removing the established tolerances for residues of the
herbicide, saflufenacil, 2-chloro-5-[3,6-dihydro-3-methyl-2,6-dioxo-4-
(trifluoromethyl)-1(2H)-pyrimidinyl]-4-fluoro-N-[[methyl(1-
methylethyl)amino]sulfonyl]benzamide, and its metabolites N-[2-chloro-
5-(2,6-dioxo-4-(trifluoromethyl)-3,6-dihydro-1(2H)-pyrimidinyl)-4-
fluorobenzoyl]-N'-isopropylsulfamide and N-[4-chloro-2-fluoro-5
({(isopropylamino)sulfonyl]amino{time} carbonyl)phenylurea, calculated
as the stoichiometric equivalent of saflufenacil in or on the following
raw agricultural plant commodities: Barley, grain at 1 ppm; chia, seed
at 0.6 ppm; crop subgroup 20A; rapeseed subgroup at 0.45 ppm; fruit,
pome, group 10 at 0.03 ppm; fruit, pome, group 11 at 0.03 ppm; fruit,
stone, group 12 at 0.03 ppm; grain, cereal, group 15 (except barley and
wheat grain) at 0.03 ppm; nut, tree, group 14 at 0.03 ppm; pea and
bean, dried shelled, except soybean, subgroup 6C at 0.3 ppm; pea and
bean, succulent shelled, subgroup 6B at 0.03 ppm; pistachio at 0.03
ppm; vegetable, foliage of legume, group 7 (except pea, hay) at 0.1
ppm; vegetable, legume, edible podded, subgroup 6A at 0.03 ppm; and
wheat, grain at 0.6 ppm. IR-4 originally requested to remove the
established tolerance for rapeseed 20A at 0.45 ppm but withdrew that
request. Contact: RD.
    4. PP 3E9059. EPA-HQ-OPP-2021-0624. Bayer CropScience, 800 N
Lindbergh Blvd., St. Louis, MO 63167, requests to amend the tolerance
in 40 CFR 180.3 for residues of the insecticide, tetraniliprole, 1-(3-
chloro-2-pyridinyl)-N-[4-cyano-2-methyl-6-
[(methylamino)carbonyl]phenyl]-3-[[5-(trifluoromethyl)-2H-tetrazol-2-
yl]methyl]-1H-pyrazole-5-carboxamide, in or on tea at 80 ppm. The HPLC/
MS/MS is used to measure and evaluate the chemical tetraniliprole.
Contact: RD.

B. Notice of Filing--New Tolerance Exemptions for Inerts (Except PIPS)

    PP IN-11745. EPA-HQ-OPP-2023-0296. AgroFresh, 3 Spring House
Innovation Park, Suite 100, Lower Gwynedd, PA 19002, requests to
establish an exemption from the requirement of a tolerance for residues
of sodium nitrate (CAS Reg. No. 7631-99-4) when used as an inert
ingredient in pesticide formulations applied under 40 CFR 180.910. The
petitioner believes no analytical method is needed because it is not
required for an exemption from the requirement of a tolerance. Contact:
RD

C. Notice of Filing--New Tolerance Exemptions for Non-Inerts (Except
PIPS)

    1. PP 2F9027. EPA-HQ-OPP-2023-0255. BioWorks, Inc., 100 Rawson
Road, Suite 205, Victor, NY 14564, requests to establish an exemption
from the requirement of a tolerance in 40 CFR part 180 for residues of
the insecticide and miticide Beauveria bassiana strain BW149 in or on
all food and feed commodities. The petitioner believes no analytical
method is needed because the natural occurrence of the organism
indicates that exposure is expected regardless of treatment, the
magnitude of residues is expected to be at the same level as non-
treated commodities. Contact: BPPD.
    2. PP 3F9053. EPA-HQ-OPP-2023-0221. Agrotecnolog[iacute]as
Naturales S.L. Ctra.T-214, s/n Km 4,125 43762 Riera de Gai[agrave] La
Tarragona, Spain (c/o SciReg, Inc., 12733 Director's Loop, Woodbridge,
VA 22192), requests to establish an exemption from the requirement of a
tolerance in 40 CFR part 180 for residues of the fungicide Trichoderma
atroviride AT10 in or on all food commodities. The petitioner believes
no analytical method is needed because an exemption from the

requirement of a tolerance is being proposed. Contact: BPPD.

D. Notice of Filing--New Tolerances for Non-Inerts

    1. PP 1E8910. EPA-HQ-OPP-2022-0139. Corteva Agriscience, LLC, 9330
Zionsville Rd., Indianapolis, IN 46268, requests to establish
tolerances in 40 CFR part 180 for residues of the insecticide
methoxyfenozide in or on coffee at 0.15 ppm and sugarcane at 0.03 ppm,
and in the processed commodity sugarcane molasses at 0.1 ppm. The
Liquid Chromatography with Tandem Mass Spectrometry Detection (Method
GRM 02.25) is used to measure and evaluate the methoxyfenozide
residues. Contact: RD.
    2. PP 2E9045. EPA-HQ-OPP-2023-0080. IR-4 Project Headquarters,
North Carolina State University, 1730 Varsity Drive, Venture IV, Suite
210, Raleigh, NC 27606, requests to establish tolerances in 40 CFR
180.649 for residues of the herbicide saflufenacil, 2-chloro-5-[3,6-
dihydro-3-methyl-2,6-dioxo-4-(trifluoromethyl)-1(2H)-pyrimidinyl]-4-
fluoro-N-[[methyl(1-methylethyl)amino]sulfonyl]benzamide, and its
metabolites N-[2-chloro-5-(2,6-dioxo-4-(trifluoromethyl)-3,6-dihydro-
1(2H)-pyrimidinyl)-4-fluorobenzoyl]-N'-isopropylsulfamide and N-[4-
chloro-2-fluoro-5
({(isopropylamino)sulfonyl]amino{time} carbonyl)phenyl]urea, calculated
as the stoichiometric equivalent of saflufenacil in or on the following
raw agricultural plant commodities: Barley subgroup 15-22B at 1 ppm;
edible-podded bean subgroup 6-22A at 0.03 ppm; edible-podded pea
subgroup 6-22B at 0.03 ppm; field corn subgroup 15-22C at 0.03 ppm;
forage and hay of legumes vegetable group 7-22 (except pea, hay) at 0.1
ppm; forage, hay, stover, and straw of cereal grains group 16-22
(except barley and wheat and chia straw) at 0.1 ppm; fruit, citrus
group 10-10 at 0.03 ppm; fruit, pome group 11-10 at 0.03 ppm; fruit,
stone group 12-12 at 0.03 ppm; grain sorghum and millet subgroup 15-22E
at 0.03 ppm; mint, dried leaves at 0.04 ppm; and mint, fresh leaves at
0.04 ppm; nut, tree, group 14-12 at 0.03 ppm; pulses, dried shelled
bean, except soybean, subgroup 6-22E at 0.3 ppm; pulses, dried shelled
pea subgroup 6-22F at 0.3 ppm; rice subgroup 15-22F at 0.03 ppm;
succulent shelled bean subgroup 6-22C at 0.03 ppm; succulent shelled
pea subgroup 6-22D at 0.03 ppm; sweet corn subgroup 15-22D at 0.03 ppm;
and wheat subgroup 15-22A at 0.7 ppm. The submission originally
petitioned for a tolerance for rapeseed subgroup 20A at 0.6 ppm but was
withdrawn by IR-4. A High-Performance Liquid Chromatograph-Mass
Spectrometer (HPLC/MS/MS) was used to measure and evaluate the residues
of saflufenacil. Contact: RD.
    3. PP 2F9020. EPA-HQ-OPP-2023-0062. FMC Corporation, 2929 Walnut
Street, Philadelphia, PA 19104, requests to establish a tolerance in 40
CFR part 180 for residues of the fungicide. Fluindapyr in or on
soybean, forage at 15 ppm; soybean, hay at 30 ppm; soybean, hulls at
0.6 ppm; soybean, seed at 0.2 ppm. The HPLC/MS/MS method is used to
measure and evaluate the chemical fluindapyr. Contact: RD.

E. Notice of Filing--New Tolerances for Non-Inerts

    1. PP 1E8910. EPA-HQ-OPP-2022-0139. Corteva Agriscience, LLC, 9330
Zionsville Rd., Indianapolis, IN 46268, requests to establish
tolerances in 40 CFR part 180 for residues of the insecticide
methoxyfenozide in or on coffee at 0.15 ppm and sugarcane at 0.03 ppm,
and in the processed commodity sugarcane molasses at 0.1 ppm. The
Liquid Chromatography with Tandem Mass Spectrometry Detection (Method
GRM 02.25) is used to measure and evaluate the methoxyfenozide
residues. Contact: RD.
    2. PP 2E9028. EPA-HQ-OPP-2022-0890. IR-4, IR-4 Project
Headquarters, North Carolina State University, 1730 Varsity Drive,
Venture IV, Suite 210, Raleigh, NC 27606 to establish a tolerance in 40
CFR 180.417 for residues of the herbicide triclopyr, 2-[(3,5,6-
trichloro-2-pyridinyl)oxy]acetic acid, including its metabolites and
degradates, in or on sugarcane, cane at 0.04 ppm resulting from the
application of the butoxyethyl ester of triclopyr, triethylamine salt
of triclopyr, or choline salt of triclopyr. Gas chromatography and
HPLC/MS/MS methods are available for the enforcement of tolerances for
triclopyr residues of concern. Contact: RD.
    3. PP 2F9005. EPA-HQ-OPP-2022-0980. Bayer CropScience, 800 N
Lindbergh Blvd. St. Louis, MO 63167, requests to establish a tolerance
in 40 CFR part 180 for residues of the fungicide fluoxapiprolin (2-
[3,5-bis(difluoromethyl)-1H-pyrazol-1-yl]-1-[4-[4-[5-[2-chloro-6-
[(methylsulfonyl)oxy]phenyl]-4,5-dihydro-3-isoxazolyl]-2-thiazolyl]-1-
piperidinyl]ethenone) in or on: Tuberous and corm vegetables subgroup
1C at 0.01 ppm; onion, bulb subgroup 3-07A at 0.03 ppm; onion, green
subgroup 3-07B at 2.0 ppm; lettuce, head, at 0.8 ppm; leafy vegetable
group 4-16, except head lettuce at 5.0 ppm; brassica head and stem
vegetable group 5-16 at 0.8 ppm; fruiting vegetable group 8-10 at 0.06
ppm; cucurbit vegetable group 9 at 0.06 ppm; small fruit vine climbing
subgroup 13-07F, except fuzzy kiwifruit at 0.2 ppm; grape, raisin at
0.4 ppm; leafy petiole vegetable subgroup 22B at 1.5 ppm; and in or on
low growing berry subgroup 13-07G at 0.01 ppm in rotational crop. The
HPLC/MS/MS detector is used to measure and evaluate the chemical
fluoxapiprolin. Contact: RD.
    4. PP 2F9019. EPA-HQ-OPP-2022-0868. BASF Corporation, 26 Davis
Drive, P.O. Box 13528, Research Triangle Park, NC 27709, requests to
establish tolerances in 40 CFR 180.649(a)(1) for residues of the
herbicide saflufenacil, including its metabolites and degradates, in or
on corn, field, forage at 0.3 ppm, corn, field, milled byproducts at
0.125 ppm, and corn, field, stover at 5.0 ppm. Adequate enforcement
methodology liquid chromatography/mass spectrometry/mass spectrometry
(LC/MS/MS) methods for plant and livestock commodities are available to
enforce the tolerance expression. Contact: RD.
    5. PP 2F9019. EPA-HQ-OPP-2022-0868. BASF Corporation, 26 Davis
Drive, P.O. Box 13528, Research Triangle Park, NC 27709, requests to
amend the existing commodity definition in 40 CFR 180.649(a)(1) for
residues of the herbicide saflufenacil, including its metabolites and
degradates, in or on ``grain, cereal, forage, fodder and straw group 16
(except barley and wheat straw)'' to ``grain, cereal, forage, hay,
stover, and straw group 16-22 (except field corn forage, field corn
stover, barley straw, wheat straw, and chia straw)'' unchanged at 0.1
ppm. Adequate enforcement methodology (LC/MS/MS) methods for plant and
livestock commodities are available to enforce the tolerance
expression. Contact: RD.
    6. PP 3F9049. EPA-HQ-OPP-2022-0899. Syngenta Crop Protection, LLC,
P.O. Box 18300, Greensboro, NC 27419, requests to establish a tolerance
for residues of the insecticide spiropidion and its metabolite
SYN547305 in or on apple, dry pomace at 3 ppm; cattle, meat at 0.02
ppm; citrus fruit, crop group 10-10 at 2.0 ppm; cotton, gin byproducts
at 10 ppm; cottonseed, crop subgroup 20C at 0.6 ppm; cucumber at 2.0
ppm; fruit, pome, crop group 11-10 at 0.4 ppm; goat, meat at 0.02 ppm;
horse, meat at 0.02 ppm; orange, fruit, citrus oil at 60 ppm; sheep,
meat at 0.02 ppm; small fruit vine climbing, (except fuzzy kiwifruit),
crop subgroup 13-07F at 2 ppm; soybean at 3.0 ppm; vegetables, tuberous
and corm, crop group 1C at 1.5 ppm; vegetables, brassica, head and
stem, crop group 5-16 at 15 ppm; vegetables, cucurbit, crop group 9,

except cucumber at 0.9 ppm; vegetables, fruiting, crop group 8-10 at
1.5 ppm; vegetables, leafy, crop subgroup 4-16 at 15 ppm; and
vegetables, tuberous and corm, crop group 1C at 1.5 ppm. Syngenta Crop
Protection, LLC submitted a ``quick, easy, cheap, effective, rugged,
and safe'' (QuEChERS) multi-residue method that has been validated and
independently validated for post-registration monitoring of SYN546330
and SYN547305 for compliance with maximum residue levels (MRLs) and
import tolerances in plant commodities at an LOQ of 0.01 mg/kg.
QuEChERS multi-residue method has also been validated and independently
validated for SYN548430 and SYN547435. Radiovalidation of the residue
methods used for data generation in pre-registration studies (primary
crop and rotational crop) have been conducted within the metabolism
studies. For the QuEChERS multi-residue method, a separate
radiovalidation study was conducted with samples taken from the primary
crop metabolism studies. Contact: RD.
    7. PP 3F9050. EPA-HQ-OPP-2023-0280. ISK Biosciences Corporation,
7470 Auburn Road, Suite A, Concord, OH 44077, has requested to
establish a tolerance for the combined residues of the insecticide
flonicamid and its metabolites, TFNA, TFNA-AM, and TFNG, in or on the
raw agricultural commodities: Berry, low growing, subgroup 13-07G,
except strawberry, at 1.5 ppm; and strawberry at 2.0 ppm. Analytical
methodology has been developed to determine the residues of flonicamid
and its three major plant metabolites, TFNA, TFNG, and TFNA-AM in
various crops. The residue analytical method for the majority of crops
includes an initial extraction with acetonitrile (ACN)/deionized (DI)
water, followed by a liquid-liquid partition with ethyl acetate. The
residue method for wheat straw is similar, except that a C18 solid
phase extraction (SPE) is added prior to the liquid-liquid partition.
The final sample solution is quantitated using a liquid chromatograph
(LC) equipped with a reverse phase column and a triple quadruple mass
spectrometer (MS/MS). Contact: RD.
    Authority: 21 U.S.C. 346a.

    Dated: June 27, 2023.
Delores Barber,
Director, Information Technology and Resources Management Division,
Office of Program Support.
[FR Doc. 2023-14192 Filed 7-3-23; 8:45 am]
BILLING CODE 6560-50-P


[Federal Register Volume 80, Number 221 (Tuesday, November 17, 2015)]
[Notices]
[Page 71790]
[FR Doc No: 2015-29267]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

[Project No. 10309-001]

Darren K. Vaughn, Scott M. Fodor, Trust; Notice of Transfer of
Exemption

    1. By letter filed November 3, 2015, Darren K. Vaughn informed the
Commission that the exemption from licensing for the Flying W Project
No. 10309, originally issued July 21, 1987 \1\ has been transferred to
Scott M. Fodor, Trust. The name of the project has been changed from
Flying W to Scott M. Fodor, Trust. The project is located on an
irrigation pipe near Emmett in Valley County, Idaho. The transfer of an
exemption does not require Commission approval.
---------------------------------------------------------------------------

    \1\ 40 FERC ] 62,056 (1987), Order Granting Exemption from
Licensing (Conduit).
---------------------------------------------------------------------------

    2. Scott M. Fodor, Trust is now the exemptee of the Scott M. Fodor,
Trust Project, No. 10309. All correspondence should be forwarded to:
Scott M. Fodor, Trust, 10644 W. Coleman Road, Barryton, MI 49305.

    Dated: November 10, 2015.
Nathaniel J. Davis, Sr.,
Deputy Secretary.
[FR Doc. 2015-29267 Filed 11-16-15; 8:45 am]
BILLING CODE 6717-01-P