[Title 40 CFR 60.107a]
[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. 60.107a - Monitoring of emissions and operations for fuel gas combustion devices.]
[From the U.S. Government Printing Office]
40PROTECTION OF ENVIRONMENT62009-07-012009-07-01falseMonitoring of emissions and operations for fuel gas combustion devices.60.107aSec. 60.107aPROTECTION OF ENVIRONMENTENVIRONMENTAL PROTECTION AGENCY (CONTINUED)AIR PROGRAMS (CONTINUED)STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES--Standards of Performance for Petroleum Refineries for Which
Sec. 60.107a 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
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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.
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(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
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(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
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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.