Ariz. Admin. Code § R18-2-313 - Existing Source Emission Monitoring
A. Every source subject to an existing source
performance standard as specified in this Chapter shall install, calibrate,
operate, and maintain all monitoring equipment necessary for continuously
monitoring the pollutants and other gases specified in this Section for the
applicable source category.
1. Applicability.
a. Fossil-fuel fired steam generators, as
specified in subsection (C)(1), shall be monitored for opacity, nitrogen oxides
emissions, sulfur dioxide emissions, and oxygen or carbon dioxide.
b. Fluid bed catalytic cracking unit catalyst
regenerators, as specified in subsection (C)(4), shall be monitored for
opacity.
c. Sulfuric acid plants,
as specified in subsection (C)(3)of this Section, shall be monitored for sulfur
dioxide emissions.
d. Nitric acid
plants, as specified in subsection (C)(2), shall be monitored for nitrogen
oxides emissions.
2.
Emission monitoring shall not be required when the source of emissions is not
operating.
3. Variations.
a. Unless otherwise prohibited by the Act,
the Director may approve, on a case-by-case basis, alternative monitoring
requirements different from the provisions of this Section if the installation
of a continuous emission monitoring system cannot be implemented by a source
due to physical plant limitations or extreme economic reasons. Alternative
monitoring procedures shall be specified by the Director on a case-by-case
basis and shall include, as a minimum, annual manual stack tests for the
pollutants identified for each type of source in this Section. Extreme economic
reasons shall mean that the requirements of this Section would cause the source
to be unable to continue in business.
b. Alternative monitoring requirements may be
prescribed when installation of a continuous emission monitoring system or
monitoring device specified by this Section would not provide accurate
determinations of emissions (e.g., condensed, uncombined water vapor may
prevent an accurate determination of opacity using commercially available
continuous emission monitoring systems).
c. Alternative monitoring requirements may be
prescribed when the affected facility is infrequently operated (e.g., some
affected facilities may operate less than one month per year).
4. Monitoring system malfunction:
A temporary exemption from the monitoring and reporting requirements of this
Section may be provided during any period of monitoring system malfunction,
provided that the source owner or operator demonstrates that the malfunction
was unavoidable and is being repaired expeditiously.
B. Installation and performance testing
required under this Section shall be completed and monitoring and recording
shall commence within 18 months of the effective date of this
Section.
C. Minimum monitoring
requirements:
1. Fossil-fuel fired steam
generators: Each fossil-fuel fired steam generator, except as provided in the
following subsections, with an annual average capacity factor of greater than
30%, as reported to the Federal Power Commission for calendar year 1976, or as
otherwise demonstrated to the Department by the owner or operator, shall
conform with the following monitoring requirements when such facility is
subject to an emission standard for the pollutant in question.
a. A continuous emission monitoring system
for the measurement of opacity which meets the performance specifications of
this Section shall be installed, calibrated, maintained, and operated in
accordance with the procedures of this Section by the owner or operator of any
such steam generator of greater than 250 million Btu per hour heat input except
where:
i. Gaseous fuel is the only fuel
burned; or
ii. Oil or a mixture of
gas and oil are the only fuels burned and the source is able to comply with the
applicable particulate matter and opacity regulations without utilization of
particulate matter collection equipment, and where the source has never been
found to be in violation through any administrative or judicial proceedings, or
accepted responsibility for any violation of any visible emission
standard.
b. A
continuous emission monitoring system for the measurement of sulfur dioxide
which meets the performance specifications of this Section shall be installed,
calibrated, using sulfur dioxide calibration gas mixtures or other gas mixtures
approved by the Director, maintained and operated on any fossil-fuel fired
steam generator of greater than 250 million Btu per hour heat input which has
installed sulfur dioxide pollutant control equipment.
c. A continuous emission monitoring system
for the measurement of nitrogen oxides which meets the performance
specification of this Section shall be installed, calibrated using nitric oxide
calibration gas mixtures or other gas mixtures approved by the Director,
maintained and operated on fossil-fuel fired steam generators of greater than
1000 million Btu per hour heat input when such facility is located in an air
quality control region where the Director has specifically determined that a
control strategy for nitrogen dioxide is necessary to attain the ambient air
quality standard specified in
R18-2-205, unless the source owner
or operator demonstrates during source compliance tests as required by the
Department that such a source emits nitrogen oxides at levels 30% or more below
the emission standard within this Chapter.
d. A continuous emission monitoring system
for the measurement of the percent oxygen or carbon dioxide which meets the
performance specifications of this Section shall be installed, calibrated,
operated, and maintained on fossil-fuel fired steam generators where
measurements of oxygen or carbon dioxide in the flue gas are required to
convert either sulfur dioxide or nitrogen oxides continuous emission monitoring
data, or both, to units of the emission standard within this Chapter.
2. Nitric acid plants: Each nitric
acid plant of greater than 300 tons per day production capacity, the production
capacity being expressed as 100% acid located in an air quality control region
where the Director has specifically determined that a control strategy for
nitrogen dioxide is necessary to attain the ambient air quality standard
specified in
R18-2-205, shall install,
calibrate using nitrogen dioxide calibration gas mixtures, maintain, and
operate a continuous emission monitoring system for the measurement of nitrogen
oxides which meets the performance specifications of this Section for each
nitric acid producing facility within such plant.
3. Sulfuric acid plants: Each sulfuric acid
plant as defined in
R18-2-101, of greater than 300
tons per day production capacity, the production being expressed as 100% acid,
shall install, calibrate using sulfur dioxide calibration gas mixtures or other
gas mixtures approved by the Director, maintain and operate a continuous
emission monitoring system for the measurement of sulfur dioxide which meets
the performance specifications of this Section for each sulfuric acid producing
facility within such a plant.
4.
Fluid bed catalytic cracking unit catalyst regenerators at petroleum
refineries. Each catalyst regenerator for fluid bed catalytic cracking units of
greater than 20,000 barrels per day fresh-feed capacity shall install,
calibrate, maintain and operate a continuous emission monitoring system for the
measurement of opacity which meets the performance specifications of this
Section for each regenerator within such refinery.
D. Minimum specifications: Owners or
operators of monitoring equipment installed to comply with this Section shall
demonstrate compliance with the following performance specifications.
1. The performance specifications set forth
in Appendix B of 40 CFR 60 are incorporated herein by reference and shall be
used by the Director to determine acceptability of monitoring equipment
installed pursuant to this Section. However where reference is made to the
Administrator in Appendix B of 40 CFR 60, the Director may allow the use of
either the state-approved reference method or the federally approved reference
method as published in 40 CFR 60. The performance specifications to be used
with each type of monitoring system are listed below.
a. Continuous emission monitoring systems for
measuring opacity shall comply with performance specification 1.
b. Continuous emission monitoring systems for
measuring nitrogen oxides shall comply with performance specification
2.
c. Continuous emission
monitoring systems for measuring sulfur dioxide shall comply with performance
specification 2.
d. Continuous
emission monitoring systems for measuring sulfur dioxide shall comply with
performance specification 3.
e.
Continuous emission monitoring systems for measuring carbon dioxide shall
comply with performance specification 3.
2. Calibration gases: Span and zero gases
shall be traceable to National Bureau of Standards reference gases whenever
these reference gases are available. Every six months from date of manufacture,
span and zero gases shall be reanalyzed by conducting triplicate analyses using
the reference methods in Appendix A of 40 CFR 60 (Chapter 1) as amended: For
sulfur dioxide, use Reference Method 6; for nitrogen oxides, use Reference
method 7; and for carbon dioxide or oxygen, use Reference Method 3. The gases
may be analyzed at less frequent intervals if longer shelf lives are guaranteed
by the manufacturer.
3. Cycling
time: Time includes the total time required to sample, analyze, and record an
emission measurement.
a. Continuous emission
monitoring systems for measuring opacity shall complete a minimum of one cycle
of sampling and analyzing for each successive six-minute period.
b. Continuous emission monitoring systems for
measuring oxides of nitrogen, carbon dioxide, oxygen, or sulfur dioxide shall
complete a minimum of one cycle of operation (sampling, analyzing, and date
recording) for each successive 15-minute period.
4. Monitor location: All continuous emission
monitoring systems or monitoring devices shall be installed such that
representative measurements of emissions of process parameter (i.e., oxygen, or
carbon dioxide) from the affected facility are obtained. Additional guidance
for location of continuous emission monitoring systems to obtain representative
samples are contained in the applicable performance specifications of Appendix
B of 40 CFR 60.
5. Combined
effluents: When the effluents from two or more affected facilities of similar
design and operating characteristics are combined before being released to the
atmosphere through more than one point, separate monitors shall be
installed.
6. Zero and drift:
Owners or operators of all continuous emission monitoring systems installed in
accordance with the requirements of this Section shall record the zero and span
drift in accordance with the method prescribed by the manufacturer's
recommended zero and span check at least once daily, using calibration gases
specified in subsection (C) as applicable, unless the manufacturer has
recommended adjustments at shorter intervals, in which case such
recommendations shall be followed; shall adjust the zero span whenever the
24-hour zero drift or 24-hour calibration drift limits of the applicable
performance specifications in Appendix B of Part 60, Chapter 1, Title 40 CFR
are exceeded.
7. Span: Instrument
span should be approximately 200% of the expected instrument data display
output corresponding to the emission standard for the source.
E. Minimum data requirement: The
following subsections set forth the minimum data reporting requirements for
sources employing continuous monitoring equipment as specified in this Section.
These periodic reports do not relieve the source operator from the reporting
requirements of
R18-2-310.01 .
1. The owners or operators of facilities
required to install continuous emission monitoring systems shall submit to the
Director a written report of excess emissions for each calendar quarter and the
nature and cause of the excess emissions, if known. The averaging period used
for data reporting shall correspond to the averaging period specified in the
emission standard for the pollutant source category in question. The required
report shall include, as a minimum, the data stipulated in this
subsection.
2. For opacity
measurements, the summary shall consist of the magnitude in actual percent
opacity of all six-minute opacity averages greater than any applicable
standards for each hour of operation of the facility. Average values may be
obtained by integration over the averaging period or by arithmetically
averaging a minimum of four equally spaced, instantaneous opacity measurements
per minute. Any time periods exempted shall be deleted before determining any
averages in excess of opacity standards.
3. For gaseous measurements the summary shall
consist of emission averages in the units of the applicable standard for each
averaging period during which the applicable standard was exceeded.
4. The date and time identifying each period
during which the continuous emission monitoring system was inoperative, except
for zero and span checks and the nature of system repair or adjustment shall be
reported. The Director may require proof of continuous emission monitoring
system performance whenever system repairs or adjustments have been
made.
5. When no excess emissions
have occurred and the continuous emission monitoring system(s) have not been
inoperative, repaired, or adjusted, such information shall be included in the
report.
6. Owners or operators of
affected facilities shall maintain a file of all information reported in the
quarterly summaries, and all other data collected either by the continuous
emission monitoring system or as necessary to convert monitoring data to the
units of the applicable standard for a minimum of two years from the date of
collection of such data or submission of such summaries.
F. Data reduction: Owners or operators of
affected facilities shall use the following procedures for converting
monitoring data to units of the standard where necessary.
1. For fossil-fuel fired steam generators the
following procedures shall be used to convert gaseous emission monitoring data
in parts per million to g/million cal (lb/million Btu) where necessary.
a. When the owner or operator of a
fossil-fuel fired steam generator elects under subsection (C)(1)(d) to measure
oxygen in the flue gases, the measurements of the pollutant concentration and
oxygen concentration shall each be on a consistent basis (wet or dry).
i. When measurements are on a wet basis,
except where wet scrubbers are employed or where moisture is otherwise added to
stack gases, the following conversion procedure shall be used:
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ii.
When measurements are on a wet basis and the water vapor content of the stack
gas is determined at least once every 15 minutes the following conversion
procedure shall be used:
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Use of this equation is contingent upon demonstrating the ability to accurately determine B(ws) such that any absolute error in B(ws) will not cause an error of more than ±1.5% in the term:
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iii.
When measurements are on a dry basis, the following conversation procedure
shall be used:
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b. When the owner or operator elects under
subsection (C)(1)(d) to measure carbon dioxide in the flue gases, the
measurement of the pollutant concentration and the carbon dioxide concentration
shall each be on a consistent basis (wet or dry) and the following conversion
procedure used;
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c.
The values used in the equations under subsection (F)(1) above are derived as
follows:
E(Q) = pollutant emission, g/million cal (lb/million Btu).
C = pollutant concentration, g/dscm (lb/dscf), determined by multiplying the average concentration (ppm) for each hourly period by 4.16 x 10-5 M g/dscm per ppm (2.64 x 10-9 M lb/dscf per ppm) where M = pollutant molecular weight, g/g-mole (lb/lb-mole), M = 64 for sulfur dioxide and 46 for oxides of nitrogen.
C(ws) = pollutant concentrations at stack conditions, g/wscm (lb/wscf), determined by multiplying the average concentration (ppm) for each one-hour period by 4.15 x 10-5 M lb/wscm per ppm) (2.59 x 10-5 M lb/wscf per ppm) where M = pollutant molecular weight, g/g mole (lb/lb mole). M = 64 for sulfur dioxide and 46 for nitrogen oxides.
%O(2),%CO(2) = Oxygen or carbon dioxide volume (expressed as percent) determined with equipment specified under subsection (D)(1)(d).
F,F(c) = A factor representing a ratio of the volume of dry flue gases generated to the calorific value of the fuel combusted (F), a factor representing a ratio of the volume of carbon dioxide generated to the calorific value of the fuel combusted (F(c)), respectively. Values of F and F(c) are given in 40 CFR 60.45(f) (Chapter 1).
F(w) = A factor representing a ratio of the volume of wet flue gases generated to the caloric value of the fuel combusted. Values of F(w) are given in Reference Method 19 of the Arizona Testing Manual.
B(wa) = Proportion by volume of water vapor in the ambient air. Approval may be given for determination of B(w)a by on-site instrumental measurement provided that the absolute accuracy of the measurement technique can be demonstrated to be within ± 0.7% water vapor. Estimation methods for B(wa) are given in Reference Method 19 of the Arizona Testing Manual.
B(ws) = Proportion by volume of water vapor in the stack gas.
2. For
sulfuric acid plants as defined in
R18-2-101, the owner or operator
shall:
a. Establish a conversion factor three
times daily according to the procedures of
40 CFR
60.84(b) (Chapter
1),
b. Multiply the conversion
factor by the average sulfur dioxide concentration in the flue gases to obtain
average sulfur dioxide emissions in Kg/metric ton (lb/short ton), and
c. Report the average sulfur dioxide emission
for each averaging period in excess of the applicable emission standard in the
quarterly summary.
3.
For nitric acid plants, the owner or operator shall:
a. Establish a conversion factor according to
the procedures of
40 CFR
60.73(b) (Chapter
1),
b. Multiply the conversion
factor by the average nitrogen oxides concentration in the flue gases to obtain
the nitrogen oxides emissions in the units of the applicable
standard,
c. Report the average
nitrogen oxides emission for each averaging period in excess of applicable
emission standard in the quarterly summary.
4. The Director may allow data reporting or
reduction procedures varying from those set forth in this Section if the owner
or operator of a source shows to the satisfaction of the Director that his
procedures are at least as accurate as those in this Section. Such procedures
may include but are not limited to the following:
a. Alternative procedures for computing
emission averages that do not require integration of data (e.g., some
facilities may demonstrate that the variability of their emissions is
sufficiently small to allow accurate reduction of data based upon computing
averages from equally spaced data points over the averaging period).
b. Alternative methods of converting
pollutant concentration measurements to the units of the emission
standards.
Notes
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