New Mexico Administrative Code
Title 20 - ENVIRONMENTAL PROTECTION
Chapter 11 - ALBUQUERQUE - BERNALILLO COUNTY AIR QUALITY CONTROL BOARD
Part 46 - SULFUR DIOXIDE EMISSIONS INVENTORY REQUIREMENTS; WESTERN BACKSTOP SULFUR DIOXIDE TRADING PROGRAM
Section 20.11.46.21 - PROTOCOL WEB 1: SO[2] MONITORING OF FUEL GAS COMBUSTION DEVICES
Universal Citation: 20 NM Admin Code 20.11.46.21
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 Paragraph (2) and
Paragraph (3) of Subsection B of 20.11.46.21 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% 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% of the
span; and
(v) use EPA Test Method
15A or 16, or an approved alternative test method to determine total reduced
sulfur emissions; these are the reference methods for the relative accuracy
test; and the relative accuracy test shall include a bias test in accordance
with Paragraph (3) of Subsection D of 20.11.46.21 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
SO2 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 SO2 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); and
K = 1.660 x 10-7 (lb/scf)/ppmv.
(2) As an alternative to using a CFGMS as
required by Paragraph (1) of Subsection B of 20.11.46.21 NMAC, fuel gas
combustion devices having a common source of fuel gas may be monitored with an
SO2 CEMS and flow CEMS and (if necessary) a moisture
monitoring system at only one location, if the CEMS monitoring at that location
is representative of the SO2 emission rate (lb
SO2/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 20.11.46.21 NMAC, and the fuel gas
combustion device monitored by a CEMS shall have separate fuel metering.
(a) Each CEMS for SO2
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
SO2 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 SO2 emissions in lb/hr from applicable fuel gas combustion devices;
Em = SO2 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; and
Qm = Fuel gas flow rate (scf/hr) to the CEMS-monitored fuel gas combustion device.
(3) As an additional alternative to using a
CFGMS as required by Paragraph (1) of Subsection B of 20.11.46.21 NMAC, fuel
gas combustion devices having a common source of fuel gas may be monitored with
an SO2 - diluent CEMS at only one location, if the CEMS
monitoring at that location is representative of the SO2
emission rate (lb SO2/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 20.11.46.21 NMAC, with separate fuel metering for the
CEMS-monitored fuel gas combustion device.
(a) Each SO2 - diluent
CEMS shall comply with the applicable provisions for SO2
monitors and diluent monitors in 40 CFR Part 75, and shall use the procedures
in Section 3 of Appendix F to 40 CFR Part 75 for determining
SO2 emission rate (lb/mmBtu) by substituting the term
SO2 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
SO2 hourly 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 SO2 emissions in lbs/hr from applicable fuel gas combustion devices;
Em = SO2 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); and
106 = Conversion from Btu to million Btu.
(d) The owner
or operator shall calculate total SO2 mass 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.
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 20.11.46.21 NMAC for each
CFGMS;
(2) each CEMS for
SO2 and flow or each SO2-diluent
CEMS shall comply with the testing and calibration requirements specified in
40 CFR
75.20 and Appendices A and B, except that
each SO2-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. A quality-assurance and quality control (QA/QC) plan shall be developed and implemented for each:
(1) CEMS
for SO2 and flow or the
SO2-diluent CEMS in compliance with Sections 1, 1.1, and
1.2 of Appendix B of 40 CFR Part 75.
(2) 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)
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; and 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, and 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; and 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; and 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. For any period in which valid data are not being recorded by a(n)
(1)
SO2 CEMS or flow CEMS specified in 20.11.46.21 NMAC,
missing or invalid data shall be replaced with substitute data in accordance
with the requirements in Subpart D of 40 CFR Part 75.
(2) SO2-diluent CEMS
specified in 20.11.46.21 NMAC, missing or invalid data shall be replaced with
substitute data on a rate basis (lb/mmBtu) in accordance with the requirements
for SO2 monitors in Subpart D of 40 CFR Part
75.
(3) Continuous fuel flow meter
or for fuel gas GCV sampling and analysis specified in 20.11.46.21 NMAC,
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) CFGMS as specified in
20.11.46.21 NMAC, 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 20.11.46.16 NMAC, the owner or operator shall meet the following additional requirements:
(1) the monitoring plan shall identify each
group of units that is monitored by a single monitoring system under
20.11.46.21 NMAC, and the plan shall designate an identifier for the group of
units for emissions reporting purposes; and 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 Paragraph (3) of Subsection B of 20.11.46.21 NMAC are used,
provide documentation and an explanation to demonstrate that the
SO2 emission rate from the monitored unit is
representative of the rate from non-monitored units.
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