[Title 40 CFR 60.104a]
[Code of Federal Regulations (annual edition) - July 1, 2009 Edition]
[Title 40 - PROTECTION OF ENVIRONMENT]
[Chapter I - ENVIRONMENTAL PROTECTION AGENCY (CONTINUED)]
[Subchapter C - AIR PROGRAMS (CONTINUED)]
[Part 60 - STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES--]
[Subpart Ja - Standards of Performance for Petroleum Refineries for Which]
[Sec. 60.104a - Performance tests.]
[From the U.S. Government Printing Office]


40PROTECTION OF ENVIRONMENT62009-07-012009-07-01false60.104aSec. 60.104aPROTECTION OF ENVIRONMENTENVIRONMENTAL PROTECTION AGENCY (CONTINUED)AIR PROGRAMS (CONTINUED)STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES--Standards of Performance for Petroleum Refineries for Which
Sec. 60.104a  Performance tests.

    (a) The owner or operator shall conduct a performance test for each 
FCCU, FCU, sulfur recovery plant, and fuel gas combustion device to 
demonstrate initial compliance with each applicable emissions limit in 
Sec. 60.102a according to the requirements of Sec. 60.8. The 
notification requirements of Sec. 60.8(d) apply to the initial 
performance test and to subsequent performance tests required by 
paragraph (b) of this section (or as required by the Administrator), but 
does not apply to performance tests conducted for the purpose of 
obtaining supplemental data because of continuous monitoring system 
breakdowns, repairs, calibration checks, and zero and span adjustments.
    (b) The owner or operator of a FCCU or FCU that elects to monitor 
control device operating parameters according to the requirements in 
Sec. 60.105a(b), to use bag leak detectors according to the 
requirements in Sec. 60.105a(c), or to use COMS according to the 
requirements in Sec. 60.105a(e) shall conduct a PM performance test at 
least once every 12 months and furnish the Administrator a written 
report of the results of each test.
    (c) In conducting the performance tests required by this subpart (or 
as requested by the Administrator), the owner or operator shall use the 
test methods in 40 CFR part 60, Appendices A-1 through A-8 or other 
methods as specified in this section, except as provided in Sec. 
60.8(b).
    (d) The owner or operator shall determine compliance with the PM, 
NOX, SO2, and CO emissions limits in Sec. 60.102a(b) for FCCU and FCU 
using the following methods and procedures:
    (1) Method 1 of appendix A-1 to part 60 for sample and velocity 
traverses.

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    (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 5, 5B, or 5F of appendix A-3 to part 60 for determining 
PM emissions and associated moisture content from a FCCU or FCU without 
a wet scrubber subject to the emissions limit in Sec. 63.102a(b)(1). 
Use Method 5 or 5B of appendix A-3 to part 60 for determining PM 
emissions and associated moisture content from a FCCU or FCU with a wet 
scrubber subject to the emissions limit in Sec. 63.102a(b)(1).
    (i) The PM performance test consists of 3 valid test runs; the 
duration of each test run must be no less than 60 minutes.
    (ii) The emissions rate of PM (EPM) is computed for each 
run using Equation 3 of this section:
[GRAPHIC] [TIFF OMITTED] TR24JN08.002

Where:

E = Emission rate of PM, g/kg, lbs per 1,000 lbs (lb/1,000 lbs) of coke 
burn-off;
cs = Concentration of total PM, grams per dry standard cubic meter (g/
dscm), gr/dscf;
Qsd = Volumetric flow rate of effluent gas, dry standard cubic meters 
per hour, dry standard cubic feet per hour;
Rc = Coke burn-off rate, kilograms per hour (kg/hr), lbs per hour (lbs/
hr) coke; and
K = Conversion factor, 1.0 grams per gram (7,000 grains per lb).

    (iii) The coke burn-off rate (Rc) is computed for each run using 
Equation 4 of this section:
[GRAPHIC] [TIFF OMITTED] TR24JN08.003

Where:

Rc = Coke burn-off rate, kg/hr (lb/hr);
Qr = Volumetric flow rate of exhaust gas from FCCU regenerator or fluid 
coking burner before any emissions control or energy recovery system 
that burns auxiliary fuel, dry standard cubic meters per minute (dscm/
min), dry standard cubic feet per minute (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 in FCCU regenerator or fluid coking burner 
exhaust, percent by volume (dry basis);
%O2 = O2 concentration in FCCU regenerator or fluid coking 
burner exhaust, percent by volume (dry basis);
%Ooxy = O2 concentration in O2 enriched air stream inlet to the FCCU 
regenerator or fluid coking burner, percent by volume (dry basis);
K1 = Material balance and conversion factor, 0.2982 (kg-min)/(hr-dsc-%) 
[0.0186 (lb-min)/(hr-dscf-%)];
K2 = Material balance and conversion factor, 2.088 (kg-min)/(hr-dscm) 
[0.1303 (lb-min)/(hr-dscf)]; and
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:

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[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)

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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).

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    (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

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combustion device is added to a common source of fuel gas that 
previously demonstrated compliance.