[Title 40 CFR 60.105]
[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 J - Standards of Performance for Petroleum Refineries]
[Sec. 60.105 - Monitoring of emissions and operations.]
[From the U.S. Government Printing Office]
40PROTECTION OF ENVIRONMENT62009-07-012009-07-01falseMonitoring of emissions and operations.60.105Sec. 60.105PROTECTION OF ENVIRONMENTENVIRONMENTAL PROTECTION AGENCY (CONTINUED)AIR PROGRAMS (CONTINUED)STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES--Standards of Performance for Petroleum Refineries
Sec. 60.105 Monitoring of emissions and operations.
(a) Continuous monitoring systems shall be installed, calibrated,
maintained, and operated by the owner or operator subject to the
provisions of this subpart as follows:
(1) For fluid catalytic cracking unit catalyst regenerators subject
to Sec. 60.102(a)(2), an instrument for continuously monitoring and
recording the opacity of emissions into the atmosphere. The instrument
shall be spanned at 60, 70, or 80 percent opacity.
(2) For fluid catalytic cracking unit catalyst regenerators subject
to Sec. 60.103(a), an instrument for continuously monitoring and
recording the concentration by volume (dry basis) of CO emissions into
the atmosphere, except as provided in paragraph (a)(2) (ii) of this
section.
(i) The span value for this instrument is 1,000 ppm CO.
(ii) A CO continuous monitoring system need not be installed if the
owner or operator demonstrates that the average CO emissions are less
than 50 ppm (dry basis) and also files a written request for exemption
to the Administrator and receives such an exemption. The demonstration
shall consist of continuously monitoring CO emissions for 30 days using
an instrument that shall meet the requirements of Performance
Specification 4 of appendix B of this part. 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 and employ the sample
conditioning system of Method 10A, the alternative relative accuracy
test procedure in Sec. 10.1 of Performance Specification 2 may be used
in place of the relative accuracy test.
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(3) For fuel gas combustion devices subject to Sec. 60.104(a)(1),
either an instrument for continuously monitoring and recording the
concentration by volume (dry basis, zero percent excess air) of
SO2 emissions into the atmosphere or monitoring as provided
in paragraph (a)(4) of this section). The monitor shall include an
oxygen monitor for correcting the data for excess.
(i) The span values for this monitor are 50 ppm SO2 and
25 percent oxygen (O2).
(ii) The SO2 monitoring level equivalent to the
H2S standard under Sec. 60.104(a)(1) shall be 20 ppm (dry
basis, zero percent excess air).
(iii) The performance evaluations for this SO2 monitor
under Sec. 60.13(c) shall use Performance Specification 2. Methods 6 or
6C and 3 or 3A shall be used for conducting the relative accuracy
evaluations. Method 6 samples 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.
(iv) 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.
(4) Instead of the SO2 monitor in paragraph (a)(3) of
this section for fuel gas combustion devices subject to Sec.
60.104(a)(1), an instrument for continuously monitoring and recording
the concentration (dry basis) of H2S in fuel gases before
being burned in any fuel gas combustion device.
(i) The span value for this instrument is 425 mg/dscm
H2S.
(ii) 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.
(iii) The performance evaluations for this H2S monitor
under Sec. 60.13(c) shall use Performance Specification 7. Method 11,
15, 15A, or 16 shall be used for conducting the relative accuracy
evaluations.
(iv) The owner or operator of a fuel gas combustion device is not
required to comply with paragraph (a)(3) or (4) of this section for fuel
gas streams that are exempt under Sec. 60.104(a)(1) and fuel gas
streams combusted in a fuel gas combustion device that are inherently
low in sulfur content. Fuel gas streams meeting one of the requirements
in paragraphs (a)(4)(iv)(A) through (D) of this section will be
considered inherently low in sulfur content. If the composition of a
fuel gas stream changes such that it is no longer exempt under Sec.
60.104(a)(1) or it no longer meets one of the requirements in paragraphs
(a)(4)(iv)(A) through (D) of this section, the owner or operator must
begin continuous monitoring under paragraph (a)(3) or (4) of this
section within 15 days of the change.
(A) Pilot gas for heaters and flares.
(B) 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.
(C) Fuel gas streams produced in process units that are intolerant
to sulfur contamination, such as fuel gas streams produced in the
hydrogen plant, the catalytic reforming unit, the isomerization unit,
and HF alkylation process units.
(D) Other fuel gas streams that an owner or operator demonstrates
are low-sulfur according to the procedures in paragraph (b) of this
section.
(5) For Claus sulfur recovery plants with oxidation control systems
or reduction control systems followed by incineration subject to Sec.
60.104(a)(2)(i), an instrument for continuously monitoring and recording
the concentration (dry basis, zero percent excess air) of 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 500 ppm SO2 and
25 percent O2.
(ii) The performance evaluations for this SO2 monitor
under Sec. 60.13(c) shall
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use Performance Specification 2. Methods 6 or 6C and 3 or 3A shall be
used for conducting the relative accuracy evaluations.
(6) For Claus sulfur recovery plants with reduction control systems
not followed by incineration subject to Sec. 60.104(a)(2)(ii), an
instrument for continuously monitoring and recording the concentration
of reduced sulfur 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 450 ppm reduced sulfur and
25 percent O2.
(ii) The performance evaluations for this reduced sulfur (and
O2) monitor under Sec. 60.13(c) shall use Performance
Specification 5 of appendix B of this part(and Performance Specification
3 of appendix B of this partfor the O2 analyzer). Methods 15
or 15A and Method 3 shall be used for conducting the relative accuracy
evaluations. If Method 3 yields O2 concentrations below 0.25
percent during the performance specification test, the O2
concentration may be assumed to be zero and the reduced sulfur CEMS need
not include an O2 monitor.
(7) In place of the reduced sulfur monitor under paragraph (a)(6) of
this section, an instrument using an air or O2 dilution and
oxidation system to convert the reduced sulfur to SO2 for
continuously monitoring and recording the concentration (dry basis, zero
percent excess air) of the resultant SO2. The monitor shall
include an oxygen monitor for correcting the data for excess oxygen.
(i) The span values for this monitor are 375 ppm SO2 and
25 percent O2.
(ii) For reporting purposes, the SO2 exceedance level for
this monitor is 250 ppm (dry basis, zero percent excess air).
(iii) The performance evaluations for this SO2 (and
O2) monitor under Sec. 60.13(c) shall use Performance
Specification 5. Methods 15 or 15A and Method 3 shall be used for
conducting the relative accuracy evaluations.
(8) An instrument for continuously monitoring and recording
concentrations of SO2 in the gases at both the inlet and
outlet of the SO2 control device from any fluid catalytic
cracking unit catalyst regenerator for which the owner or operator seeks
to comply specifically with the 90 percent reduction option under Sec.
60.104(b)(1).
(i) The span value of the inlet monitor shall be set at 125 percent
of the maximum estimated hourly potential SO2 emission
concentration entering the control device, and the span value of the
outlet monitor shall be set at 50 percent of the maximum estimated
hourly potential SO2 emission concentration entering the
control device.
(ii) The performance evaluations for these SO2 monitors
under Sec. 60.13(c) shall use Performance Specification 2. Methods 6 or
6C and 3 or 3A shall be used for conducting the relative accuracy
evaluations.
(9) An instrument for continuously monitoring and recording
concentrations of SO2 in the gases discharged into the
atmosphere from any fluid catalytic cracking unit catalyst regenerator
for which the owner or operator seeks to comply specifically with the 50
ppmv emission limit under Sec. 60.104 (b)(1).
(i) The span value of the monitor shall be set at 50 percent of the
maximum hourly potential SO2 emission concentration of the
control device.
(ii) The performance evaluations for this SO2 monitor
under Sec. 60.13 (c) shall use Performance Specification 2. Methods 6
or 6C and 3 or 3A shall be used for conducting the relative accuracy
evaluations.
(10) An instrument for continuously monitoring and recording
concentrations of oxygen (O2) in the gases at both the inlet
and outlet of the sulfur dioxide control device (or the outlet only if
specifically complying with the 50 ppmv standard) from any fluid
catalytic cracking unit catalyst regenerator for which the owner or
operator has elected to comply with Sec. 60.104(b)(1). The span of this
continuous monitoring system shall be set at 10 percent.
(11) The continuous monitoring systems under paragraphs (a)(8),
(a)(9), and (a)(10) of this section are operated and data recorded
during all periods of operation of the affected facility including
periods of startup, shutdown, or malfunction, except for continuous
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monitoring system breakdowns, repairs, calibration checks, and zero and
span adjustments.
(12) The owner or operator shall use the following procedures to
evaluate the continuous monitoring systems under paragraphs (a)(8),
(a)(9), and (a)(10) of this section.
(i) Method 3 or 3A and Method 6 or 6C for the relative accuracy
evaluations under the Sec. 60.13(e) performance evaluation.
(ii) appendix F, Procedure 1, including quarterly accuracy
determinations and daily calibration drift tests.
(13) When seeking to comply with Sec. 60.104(b)(1), when emission
data are not obtained because of continuous monitoring system
breakdowns, repairs, calibration checks and zero and span adjustments,
emission data will be obtained by using one of the following methods to
provide emission data for a minimum of 18 hours per day in at least 22
out of 30 rolling successive calendar days.
(i) The test methods as described in Sec. 60.106(k);
(ii) A spare continuous monitoring system; or
(iii) Other monitoring systems as approved by the Administrator.
(b) An owner or operator may demonstrate that a fuel gas stream
combusted in a fuel gas combustion device subject to Sec. 60.104(a)(1)
that is not specifically exempted in Sec. 60.105(a)(4)(iv) is
inherently low in sulfur. A fuel gas stream that is determined to be
low-sulfur is exempt from the monitoring requirements in paragraphs
(a)(3) and (4) 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
ppmv. 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 will follow the procedures in
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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) The average coke burn-off rate (Mg (tons) per hour) and hours of
operation shall be recorded daily for any fluid catalytic cracking unit
catalyst regenerator subject to Sec. 60.102, Sec. 60.103, or Sec.
60.104(b)(2).
(d) For any fluid catalytic cracking unit catalyst regenerator under
Sec. 60.102 that uses an incinerator-waste heat boiler to combust the
exhaust gases from the catalyst regenerator, the owner or operator shall
record daily the rate of combustion of liquid or solid fossil-fuels and
the hours of operation during which liquid or solid fossil-fuels are
combusted in the incinerator-waste heat boiler.
(e) For the purpose of reports under Sec. 60.7(c), periods of
excess emissions that shall be determined and reported are defined as
follows:
Note: All averages, except for opacity, shall be determined as the
arithmetic average of the applicable 1-hour averages, e.g., the rolling
3-hour average shall be determined as the arithmetic average of three
contiguous 1-hour averages.
(1) Opacity. All 1-hour periods that contain two or more 6-minute
periods during which the average opacity as measured by the continuous
monitoring system under Sec. 60.105(a)(1) exceeds 30 percent.
(2) Carbon monoxide. All 1-hour periods during which the average CO
concentration as measured by the CO continuous monitoring system under
Sec. 60.105(a)(2) exceeds 500 ppm.
(3) Sulfur dioxide from fuel gas combustion. (i) All rolling 3-hour
periods during which the average concentration of SO2 as
measured by the SO2 continuous monitoring system under Sec.
60.105(a)(3) exceeds 20 ppm (dry basis, zero percent excess air); or
(ii) All rolling 3-hour periods during which the average
concentration of H2S as measured by the H2S
continuous monitoring system under Sec. 60.105(a)(4) exceeds 230 mg/
dscm (0.10 gr/dscf).
(4) Sulfur dioxide from Claus sulfur recovery plants. (i) All 12-
hour periods during which the average concentration of SO2 as
measured by the SO2 continuous monitoring system under Sec.
60.105(a)(5) exceeds 250 ppm (dry basis, zero percent excess air); or
(ii) All 12-hour periods during which the average concentration of
reduced sulfur (as SO2) as measured by the reduced sulfur
continuous monitoring system under Sec. 60.105(a)(6) exceeds 300 ppm;
or
(iii) All 12-hour periods during which the average concentration of
SO2 as
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measured by the SO2 continuous monitoring system under Sec.
60.105(a)(7) exceeds 250 ppm (dry basis, zero percent excess air).
[39 FR 9315, Mar. 8, 1974, as amended at 40 FR 46259, Oct. 6, 1975; 42
FR 32427, June 24, 1977; 42 FR 39389, Aug. 4, 1977; 43 FR 10869, Mar.
15, 1978; 48 FR 23611, May 25, 1983; 50 FR 31701, Aug. 5, 1985; 54 FR
34028, Aug. 17, 1989; 55 FR 40175, Oct. 2, 1990; 65 FR 61754, Oct. 17,
2000; 73 FR 35866, June 24, 2008]