New Mexico Administrative Code
Title 20 - ENVIRONMENTAL PROTECTION
Chapter 2 - AIR QUALITY (STATEWIDE)
Part 81 - WESTERN BACKSTOP SULFUR DIOXIDE TRADING PROGRAM
Section 20.2.81.111 - NMAC SULFUR DIOXIDE MONITORING OF FUEL GAS COMBUSTION DEVICES
Universal Citation: 20 NM Admin Code 20.2.81.111
Current through Register Vol. 35, No. 18, September 24, 2024
A. Applicability.
(1) The provisions of this protocol are
applicable to fuel gas combustion devices at petroleum refineries.
(2) Fuel gas combustion devices include
boilers, process heaters, and flares used to burn fuel gas generated at a
petroleum refinery.
(3) Fuel gas
means any gas which is generated and combusted at a petroleum refinery. Fuel
gas does not include:
(a) natural gas, unless
combined with other gases generated at a petroleum refinery;
(b) gases generated by a catalytic cracking
unit catalyst regenerator;
(c)
gases generated by fluid coking burners;
(d) gases combusted to produce sulfur or
sulfuric acid; or
(e) process upset
gases generated due to startup, shutdown, or malfunctions.
B. Monitoring Requirements.
(1) Except as provided in Paragraphs 2 and 3
of 20.2.81.111 NMAC, fuel gas combustion devices shall use a continuous fuel
gas monitoring system (CFGMS) to determine the total sulfur content (reported
as H2S) of the fuel gas mixture prior to combustion, and continuous fuel flow
meters to determine the amount of fuel gas burned.
(a) Fuel gas combustion devices having a
common source of fuel gas may be monitored for sulfur content at one location,
if monitoring at that location is representative of the sulfur content of the
fuel gas being burned in any fuel gas combustion device.
(b) The CFGMS shall meet the performance
requirements in Performance Specification 2 in Appendix B to 40 CFR Part 60,
and the following.
(i) Continuously monitor
and record the concentration by volume of total sulfur compounds in the gaseous
fuel reported as ppmv H2S.
(ii) Have the span value set so that the
majority of readings fall between 10 and 95 percent of the range.
(iii) Record negative values of zero drift,
for initial certification and daily calibration error tests.
(iv) Calibration drift shall be 5.0 percent
of the span.
(v) Methods 15A, 16,
or approved alternatives for total sulfur, are the reference methods for the
relative accuracy test. The relative accuracy test shall include a bias test in
accordance with Paragraph 3 of Subsection D of 20.2.81.111
NMAC.
(c) All continuous
fuel flow meters shall comply with the provisions of Section 2.1.5 of Appendix
D to 40 CFR Part 75.
(d) The hourly
mass sulfur dioxide emissions rate for all the fuel combustion devices
monitored by this approach shall be calculated using the following equation:
Et = (CS)(Qf)(K)
where: Et = Total sulfur dioxide emissions in lb/hr from applicable fuel gas combustion devices
CS = Sulfur content of the fuel gas as H2S(ppmv)
Qf = Fuel gas flow rate to the applicable fuel gas combustion devices (scf/hr)
K = 1.660 x 10-7 (lb/scf)/ppmv
(2) In place of a CFGMS in Paragraph 1 of
Subsection B of 20.2.81.111 NMAC, fuel gas combustion devices having a common
source of fuel gas may be monitored with an sulfur dioxide CEMS flow CEMS and
(if necessary) a moisture monitoring system at only one location, if the CEMS
monitoring at that location is representative of the sulfur dioxide emission
rate (lb sulfur dioxide/scf fuel gas burned) of all applicable fuel gas
combustion devices. Continuous fuel flow meters shall be used in accordance
with Paragraph 2 of Subsection B of 20.2.81.111 NMAC, and the fuel gas
combustion device monitored by a CEMS shall have separate fuel metering.
(a) Each CEMS for sulfur dioxide and flow,
and (if applicable) moisture, shall comply with the operating requirements,
performance specifications, and quality assurance requirements of 40 CFR Part
75.
(b) All continuous fuel flow
meters shall comply with the provisions of Section 2.1.5 of Appendix D to 40
CFR Part 75.
(c) The sulfur dioxide
hourly mass emissions rate for all the fuel gas combustion devices monitored by
this approach shall be determined by the ratio of the amount of fuel gas burned
by the CEMS-monitored fuel gas combustion device to the total fuel gas burned
by all applicable fuel gas combustion devices using the following equation:
Et = (Em)(Qt)/(Qm)
where: Et = Total sulfur dioxide emissions in lb/hr from applicable fuel gas combustion devices.
Em = sulfur dioxide emissions in lb/hr from the CEMS-monitored fuel gas combustion device, calculated using Equation F-1 or (if applicable) F-2 in Appendix F to 40 CFR Part 75
Qt = Fuel gas flow rate (scf/hr) from applicable fuel gas combustion devices.
Qm = Fuel gas flow rate (scf/hr) to the CEMS-monitored fuel gas combustion device.
(3) In place of a CFGMS in Paragraph 1 of
Subsection B of 20.2.81.111 NMAC, fuel gas combustion devices having a common
source of fuel gas may be monitored with an sulfur dioxide - diluent CEMS at
only one location, if the CEMS monitoring at that location is representative of
the sulfur dioxide emission rate (lb sulfur dioxide/mmBtu) of all applicable
fuel gas combustion devices. If this option is selected, the owner or operator
shall conduct fuel gas sampling and analysis for gross calorific value (GCV),
and shall use continuous fuel flow metering in accordance with Paragraph 1 of
Subsection B of 20.2.81.111 NMAC, with separate fuel metering for the
CEMS-monitored fuel gas combustion device.
(a) Each sulfur dioxide -
diluent CEMS shall comply with the applicable provisions for sulfur
dioxide monitors and diluent monitors in 40 CFR Part 75, and shall use the
procedures in Section 3 of Appendix F to Part 75 for determining sulfur dioxide
emission rate (lb/mmBtu) by substituting the term sulfur dioxide for
nox in that section, and using a K factor of 1.660 x
10 - 7 (lb/scf) ppmv instead of the NOx
K factor.
(b) All
continuous fuel flow meters and fuel gas sampling and analysis for GCV to
determine the heat input ratio shall comply with the applicable provisions of
Section 2.1.5 and 2.3.4 of Appendix D to 40 CFR Part 75.
(c) The sulfur dioxidehourly mass emissions
rate for all the fuel gas combustion devices monitored by this approach shall
be determined by the ratio of the fuel gas heat input to the CEMS-monitored
fuel gas combustion device to the total fuel gas heat input to all applicable
fuel gas combustion devices using the following equation:
Et = (Em)(Qt)/(GCV) / 106
where: Et = Total sulfur dioxide emissions in lbs/hr from applicable fuel gas combustion devices.
Em = sulfur dioxide emissions in lb/mmBtu from the CEMS - monitored fuel gas combustion device.
Qt = Fuel gas flow rate (scf/hr) to the applicable fuel gas combustion devices.
GCV = Fuel Gross Calorific Value (Btu/scf)
106 = Conversion from Btu to million Btu
(d) The owner
or operator shall calculate total sulfur dioxidemass emissions for each
calendar quarter and each calendar year based on the emissions in lb/hr and
equations F-3 and F-4 in Appendix F to 40 CFR Part 75, Appendix F.
C. Certification and recertification requirements. All monitoring systems are subject to initial certification and recertification testing as follows.
(1) The owner or operator shall comply with
the initial testing and calibration requirements in performance specification 2
in Appendix B of 40 CFR Part 60 and Subparagraph b of Paragraph 1 of Subsection
B of 20.2.81.111 NMAC for each CFGMS.
(2) Each CEMS for sulfur dioxide and flow or
each sulfur dioxide-diluent CEMS shall comply with the testing and calibration
requirements specified in 40 CFR Part 75, Section 75.20 and appendices A and B,
except that each sulfur dioxide-diluent CEMS shall meet the relative accuracy
requirements for a NOx-diluent CEMS (lb/mmBtu).
(3) A continuous fuel flow meter shall comply
with certification requirements in Section 2.1.5 of Appendix D of 40 CFR Part
75.
D. Quality assurance/quality control requirements.
(1) A
quality assurance and quality control (QA/QC) plan shall be developed and
implemented for each CEMS for sulfur dioxide and flow or the sulfur
dioxide-diluent CEMS in compliance with Sections 1, 1.1, and 1.2 of Appendix B
of 40 CFR Part 75.
(2) A quality
assurance and quality control plan shall be developed and implemented for each
continuous fuel flow meter and fuel sampling and analysis in compliance with
Sections 1, 1.1, and 1.3 Appendix B of 40 CFR Part 75. The owner or operator
shall meet the requirements in Section 2.1.6 of Appendix D to 40 CFR Part 75,
and may use the procedures set forth in Section 2.1.7 of that
appendix.
(3) A quality assurance
and quality control plan shall be developed and implemented for each CFGMS in
compliance with Sections 1 and 1.1 of Appendix B to 40 CFR Part 75, and the
following.
(a) Perform a daily calibration
error test of each CFGMS at two gas concentrations, one low level and one high
level. Calculate the calibration error as described in Appendix A to 40 CFR
Part 75. An out of control period occurs whenever the error is greater than 5.0
percent of the span value.
(b) In
addition to the daily calibration error test, an additional calibration error
test shall be performed whenever a daily calibration error test is failed,
whenever a monitoring system is returned to service following repairs or
corrective actions that may affect the monitor measurements, or after making
manual calibration adjustments.
(c)
Perform a linearity test once every operating quarter. Calculate the linearity
as described in Appendix A to 40 CFR Part 75. An out of control period occurs
whenever the linearity error is greater than 5.0 percent of a reference value,
and the absolute value of the difference between average monitor response
values and a reference value is greater than 5.0 ppm.
(d) Perform a relative accuracy test audit
once every four operating quarters. Calculate the relative accuracy as
described in Appendix A to 40 CFR Part 75. An out of control period occurs
whenever the relative accuracy is greater than 20.0 percent of the mean value
of the reference method measurements.
(e) Using the results of the relative
accuracy test audit, conduct a bias test in accordance with Appendix A to 40
CFR Part 75, and calculate and apply a bias adjustment factor if
required.
E. Missing data procedures.
(1) For any period in
which valid data are not being recorded by an sulfur dioxide CEMS or flow CEMS
specified in this section, missing or invalid data shall be replaced with
substitute data in accordance with the requirements in subpart D of 40 CFR Part
75.
(2) For any period in which
valid data are not being recorded by an sulfur dioxide-diluent CEMS specified
in this section, missing or invalid data shall be replaced with substitute data
on a rate basis (lb/mmBtu) in accordance with the requirements for sulfur
dioxide monitors in subpart D of 40 CFR Part 75.
(3) For any period in which valid data are
not being recorded by a continuous fuel flow meter or for fuel gas GCV sampling
and analysis specified in this section, missing or invalid data shall be
replaced with substitute data in accordance with missing data requirements in
Section 2.4 of Appendix D to 40 CFR Part 75.
(4) For any period in which valid data are
not being recorded by the CFGMS specified in this section, hourly missing or
invalid data shall be replaced with substitute data in accordance with the
missing data requirements for units performing hourly gaseous fuel sulfur
sampling in Section 2.4 of Appendix D to 40 CFR Part 75.
F. Monitoring plan and reporting requirements. In addition to the general monitoring plan and reporting requirements of 20.2.81.106 NMAC, the owner or operator shall meet the following additional requirements.
(1) The
monitoring plan shall identify each group of units that are monitored by a
single monitoring system under this 20.2.81.111 NMAC, and the plan shall
designate an identifier for the group of units for emissions reporting
purposes. For purpose of submitting emissions reports, no apportionment of
emissions to the individual units within the group is required.
(2) If the provisions of Paragraph 2 or 3 of
Subsection B of 20.2.81.111 NMAC are used, provide documentation and an
explanation to demonstrate that the sulfur dioxide emission rate from the
monitored unit is representative of the rate from non-monitored
units.
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