[Title 40 CFR 60.45]
[Code of Federal Regulations (annual edition) - July 1, 2003 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 D - Standards of Performance for Fossil-Fuel-Fired Steam]
[Sec. 60.45 - Emission and fuel monitoring.]
[From the U.S. Government Printing Office]
40PROTECTION OF ENVIRONMENT62003-07-012003-07-01falseEmission and fuel monitoring.60.45Sec. 60.45PROTECTION OF ENVIRONMENTENVIRONMENTAL PROTECTION AGENCY (CONTINUED)AIR PROGRAMS (CONTINUED)STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCESStandards of Performance for Fossil-Fuel-Fired Steam
Sec. 60.45 Emission and fuel monitoring.
(a) Each owner or operator shall install, calibrate, maintain, and
operate continuous monitoring systems for measuring the opacity of
emissions, sulfur dioxide emissions, nitrogen oxides emissions, and
either oxygen or carbon dioxide except as provided in paragraph (b) of
this section.
(b) Certain of the continuous monitoring system requirements under
paragraph (a) of this section do not apply to owners or operators under
the following conditions:
(1) For a fossil fuel-fired steam generator that burns only gaseous
fossil fuel, continuous monitoring systems for measuring the opacity of
emissions and sulfur dioxide emissions are not required.
(2) For a fossil fuel-fired steam generator that does not use a flue
gas desulfurization device, a continuous monitoring system for measuring
sulfur dioxide emissions is not required if the owner or operator
monitors sulfur dioxide emissions by fuel sampling and analysis.
(3) Notwithstanding Sec. 60.13(b), installation of a continuous
monitoring system for nitrogen oxides may be delayed until after the
initial performance tests under Sec. 60.8 have been conducted. If the
owner or operator demonstrates during the performance test that
emissions of nitrogen oxides are less than 70 percent of the applicable
standards in Sec. 60.44, a continuous monitoring system for measuring
nitrogen oxides emissions is not required. If the initial performance
test results show that nitrogen oxide emissions are greater than 70
percent of the applicable standard, the owner or operator shall install
a continuous monitoring system for nitrogen oxides within one year after
the date of the initial performance tests under Sec. 60.8 and comply
with all other applicable monitoring requirements under this part.
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(4) If an owner or operator does not install any continuous
monitoring systems for sulfur oxides and nitrogen oxides, as provided
under paragraphs (b)(1) and (b)(3) or paragraphs (b)(2) and (b)(3) of
this section a continuous monitoring system for measuring either oxygen
or carbon dioxide is not required.
(c) For performance evaluations under Sec. 60.13(c) and calibration
checks under Sec. 60.13(d), the following procedures shall be used:
(1) Methods 6, 7, and 3B, as applicable, shall be used for the
performance evaluations of sulfur dioxide and nitrogen oxides continuous
monitoring systems. Acceptable alternative methods for Methods 6, 7, and
3B are given in Sec. 60.46(d).
(2) Sulfur dioxide or nitric oxide, as applicable, shall be used for
preparing calibration gas mixtures under Performance Specification 2 of
appendix B to this part.
(3) For affected facilities burning fossil fuel(s), the span value
for a continuous monitoring system measuring the opacity of emissions
shall be 80, 90, or 100 percent and for a continuous monitoring system
measuring sulfur oxides or nitrogen oxides the span value shall be
determined as follows:
[In parts per million]
------------------------------------------------------------------------
Span value for Span value for
Fossil fuel sulfur dioxide nitrogen oxides
------------------------------------------------------------------------
Gas............................... (\1\ ) 500
Liquid............................ 1,000 500
Solid............................. 1,500 1000
Combinations...................... 1,000y+1,500z 500(x+y )+1,000z
------------------------------------------------------------------------
\1\ Not applicable.
where:
x=the fraction of total heat input derived from gaseous fossil fuel, and
y=the fraction of total heat input derived from liquid fossil fuel, and
z=the fraction of total heat input derived from solid fossil fuel.
(4) All span values computed under paragraph (c)(3) of this section
for burning combinations of fossil fuels shall be rounded to the nearest
500 ppm.
(5) For a fossil fuel-fired steam generator that simultaneously
burns fossil fuel and nonfossil fuel, the span value of all continuous
monitoring systems shall be subject to the Administrator's approval.
(d) [Reserved]
(e) For any continuous monitoring system installed under paragraph
(a) of this section, the following conversion procedures shall be used
to convert the continuous monitoring data into units of the applicable
standards (ng/J, lb/million Btu):
(1) When a continuous monitoring system for measuring oxygen is
selected, the measurement of the pollutant concentration and oxygen
concentration shall each be on a consistent basis (wet or dry).
Alternative procedures approved by the Administrator shall be used when
measurements are on a wet basis. When measurements are on a dry basis,
the following conversion procedure shall be used:
E=CF[20.9/(20.9--percent O2)]
where:
E, C, F, and %O2 are determined under paragraph (f) of this
section.
(2) When a continuous monitoring system for measuring carbon dioxide
is selected, the measurement of the pollutant concentration and carbon
dioxide concentration shall each be on a consistent basis (wet or dry)
and the following conversion procedure shall be used:
E=CFc [100/percent CO2]
where:
E, C, Fc and %CO2 are determined under paragraph
(f) of this section.
(f) The values used in the equations under paragraphs (e) (1) and
(2) of this section are derived as follows:
(1) E=pollutant emissions, ng/J (lb/million Btu).
(2) C=pollutant concentration, ng/dscm (lb/dscf), determined by
multiplying the average concentration (ppm) for each one-hour period by
4.15x10 4 M ng/dscm per ppm (2.59x10- 9 M lb/dscf
per ppm) where M=pollutant molecular weight, g/g-mole (lb/lb-mole).
M=64.07 for sulfur dioxide and 46.01 for nitrogen oxides.
(3) %O2, %CO2=oxygen or carbon dioxide volume
(expressed as percent), determined with equipment specified under
paragraph (a) of this section.
(4) F, Fc=a factor representing a ratio of the volume of
dry flue gases generated to the calorific value of the fuel
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combusted (F), and a factor representing a ratio of the volume of carbon
dioxide generated to the calorific value of the fuel combusted
(Fc), respectively. Values of F and Fc are given
as follows:
(i) For anthracite coal as classified according to ASTM D388-77, 90,
91, 95, or 98a (incorporated by reference--see Sec. 60.17),
F=2,723x10-\17\ dscm/J (10,140 dscf/million Btu and
Fc=0.532x10 -\17\ scm CO2/J (1,980 scf
CO2/million Btu).
(ii) For subbituminous and bituminous coal as classified according
to ASTM D388-77, 90, 91, 95, or 98a (incorporated by reference--see
Sec. 60.17), F=2.637x10 -\7\ dscm/J (9,820 dscf/million Btu)
and Fc=0.486x10-\7\ scm CO2/J (1,810
scf CO2/million Btu).
(iii) For liquid fossil fuels including crude, residual, and
distillate oils, F=2.476x10-7 dscm/J (9,220 dscf/million Btu)
and Fc=0.384x10-7 scm CO2/J (1,430 scf
CO2/million Btu).
(iv) For gaseous fossil fuels, F=2.347x10- 7 dscm/J
(8,740 dscf/million Btu). For natural gas, propane, and butane fuels,
Fc=0.279x10- 7 scm CO2/J (1,040 scf
CO2/million Btu) for natural gas, 0.322x10- 7 scm
CO2/J (1,200 scf CO2/million Btu) for propane, and
0.338x10- 7 scm CO2/J (1,260 scf CO2/
million Btu) for butane.
(v) For bark F=2.589x10-7 dscm/J (9,640 dscf/million Btu)
and Fc=0.500x10-7 scm CO2/J (1,840 scf
CO 2/ million Btu). For wood residue other than bark
F=2.492x10-7 dscm/J (9,280 dscf/million Btu) and
Fc=0.494x10-7 scm CO2/J (1,860 scf
CO 2/ million Btu).
(vi) For lignite coal as classified according to ASTM D388-77, 90,
91, 95, or 98a (incorporated by reference--see Sec. 60.17),
F=2.659x10-\7\ dscm/J (9,900 dscf/million Btu) and
Fc=0.516x10 -\7\ scm CO2/J (1,920 scf
CO2/million Btu).
(5) The owner or operator may use the following equation to
determine an F factor (dscm/J or dscf/million Btu) on a dry basis (if it
is desired to calculate F on a wet basis, consult the Administrator) or
Fc factor (scm CO2/J, or scf CO2/
million Btu) on either basis in lieu of the F or Fc factors
specified in paragraph (f)(4) of this section:
[GRAPHIC] [TIFF OMITTED] TC16NO91.001
(i) H, C, S, N, and O are content by weight of hydrogen, carbon,
sulfur, nitrogen, and oxygen (expressed as percent), respectively, as
determined on the same basis as GCV by ultimate analysis of the fuel
fired, using ASTM D3178-73 (Reapproved 1979), 89, or D3176-74 or 89
(solid fuels) or computed from results using ASTM D1137-53 or 75, D1945-
64, 76, 91, or 96 or D1946-77 or 90 (Reapproved 1994) (gaseous fuels) as
applicable. (These five methods are incorporated by reference--see
Sec. 60.17.)
(ii) GVC is the gross calorific value (kJ/kg, Btu/lb) of the fuel
combusted determined by the ASTM test methods D2015-77 for solid fuels
and D1826-77 for gaseous fuels as applicable. (These two methods are
incorporated by reference--see Sec. 60.17.)
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(iii) For affected facilities which fire both fossil fuels and
nonfossil fuels, the F or Fc value shall be subject to the
Administrator's approval.
(6) For affected facilities firing combinations of fossil fuels or
fossil fuels and wood residue, the F or Fc factors determined
by paragraphs (f)(4) or (f)(5) of this section shall be prorated in
accordance with the applicable formula as follows:
[GRAPHIC] [TIFF OMITTED] TC16NO91.002
where:
Xi=the fraction of total heat input derived from each type of
fuel (e.g. natural gas, bituminous coal, wood residue, etc.)
Fi or (Fc)i=the applicable F or Fc
factor for each fuel type determined in accordance with paragraphs
(f)(4) and (f)(5) of this section.
n=the number of fuels being burned in combination.
(g) Excess emission and monitoring system performance reports shall
be submitted to the Administrator semiannually for each six-month period
in the calendar year. All semiannual reports shall be postmarked by the
30th day following the end of each six-month period. Each excess
emission and MSP report shall include the information required in
Sec. 60.7(c). Periods of excess emissions and monitoring systems (MS)
downtime that shall be reported are defined as follows:
(1) Opacity. Excess emissions are defined as any six-minute period
during which the average opacity of emissions exceeds 20 percent
opacity, except that one six-minute average per hour of up to 27 percent
opacity need not be reported.
(i) For sources subject to the opacity standard of Sec. 60.42(b)(1),
excess emissions are defined as any six-minute period during which the
average opacity of emissions exceeds 35 percent opacity, except that one
six-minute average per hour of up to 42 percent opacity need not be
reported.
(ii) For sources subject to the opacity standard of
Sec. 60.42(b)(2), excess emissions are defined as any six-minute period
during which the average opacity of emissions exceeds 32 percent
opacity, except that one six-minute average per hour of up to 39 percent
opacity need not be reported.
(2) Sulfur dioxide. Excess emissions for affected facilities are
defined as:
(i) Any three-hour period during which the average emissions
(arithmetic average of three contiguous one-hour periods) of sulfur
dioxide as measured by a continuous monitoring system exceed the
applicable standard under Sec. 60.43.
(3) Nitrogen oxides. Excess emissions for affected facilities using
a continuous monitoring system for measuring nitrogen oxides are defined
as any three-hour period during which the average emissions (arithmetic
average of three contiguous one-hour periods) exceed the applicable
standards under Sec. 60.44.
[40 FR 46256, Oct. 6, 1975]
Editorial Note 1: For Federal Register citations affecting
Sec. 60.45, see the List of CFR Sections Affected, which appears in the
Finding Aids section of the printed volume and on GPO Access.
Editorial Note 2: At 65 FR 61752, Oct. 17, 2000,
Sec. 60.45(f)(5)(ii) was amended by revising the words ``ASTM D1826-77''
to read ``ASTM D1826-77 or 94.'' and by revising the words ``ASTM D2015-
77'' to read ``ASTM D2015-77 (Reapproved 1978), 96, or D5865-98.''
However, this amendment could not be incorporated because these words do
not exist in paragraph (f)(5)(ii).