[Title 40 CFR ]
[Code of Federal Regulations (annual edition) - July 1, 2003 Edition]
[From the U.S. Government Printing Office]
[[Page i]]
40
Parts 50 to 51
Revised as of July 1, 2003
Protection of Environment
Containing a codification of documents of general
applicability and future effect
As of July 1, 2003
With Ancillaries
Published by
Office of the Federal Register
National Archives and Records
Administration
A Special Edition of the Federal Register
[[Page ii]]
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[[Page iii]]
Table of Contents
Page
Explanation................................................. v
Title 40:
Chapter I--Environmental Protection Agency 3
Finding Aids:
Material Incorporated by Reference...................... 515
Table of CFR Titles and Chapters........................ 517
Alphabetical List of Agencies Appearing in the CFR...... 535
List of CFR Sections Affected........................... 545
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Cite this Code: CFR
To cite the regulations in
this volume use title,
part and section number.
Thus, 40 CFR 50.1 refers
to title 40, part 50,
section 1.
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[[Page v]]
EXPLANATION
The Code of Federal Regulations is a codification of the general and
permanent rules published in the Federal Register by the Executive
departments and agencies of the Federal Government. The Code is divided
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parts covering specific regulatory areas.
Each volume of the Code is revised at least once each calendar year
and issued on a quarterly basis approximately as follows:
Title 1 through Title 16.................................as of January 1
Title 17 through Title 27..................................as of April 1
Title 28 through Title 41...................................as of July 1
Title 42 through Title 50................................as of October 1
The appropriate revision date is printed on the cover of each
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[[Page vi]]
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(a) The incorporation will substantially reduce the volume of
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(b) The matter incorporated is in fact available to the extent
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(c) The incorporating document is drafted and submitted for
publication in accordance with 1 CFR part 51.
Properly approved incorporations by reference in this volume are
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What if the material incorporated by reference cannot be found? If
you have any problem locating or obtaining a copy of material listed in
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the revision dates of the 50 CFR titles.
[[Page vii]]
REPUBLICATION OF MATERIAL
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Raymond A. Mosley,
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Office of the Federal Register.
July 1, 2003.
[[Page ix]]
THIS TITLE
Title 40--Protection of Environment is composed of twenty-nine
volumes. The parts in these volumes are arranged in the following order:
parts 1-49, parts 50-51, part 52 (52.01-52.1018), part 52 (52.1019-End),
parts 53-59, part 60 (60.1-End), part 60 (Appendices), parts 61-62, part
63 (63.1-63.599), part 63 (63.600-1-63.1199), part 63 (63.1200-63.1439),
part 63 (63.1440-End) parts 64-71, parts 72-80, parts 81-85, part 86
(86.1-86.599-99) part 86 (86.600-1-End), parts 87-99, parts 100-135,
parts 136-149, parts 150-189, parts 190-259, parts 260-265, parts 266-
299, parts 300-399, parts 400-424, parts 425-699, parts 700-789, and
part 790 to End. The contents of these volumes represent all current
regulations codified under this title of the CFR as of July 1, 2003.
Chapter I--Environmental Protection Agency appears in all twenty-
nine volumes. An alphabetical Listing of Pesticide Chemicals Index
appears in parts 150-189. Regulations issued by the Council on
Environmental Quality appear in the volume containing part 790 to End.
The OMB control numbers for title 40 appear in Sec. 9.1 of this chapter.
[[Page x]]
[[Page 1]]
TITLE 40--PROTECTION OF ENVIRONMENT
(This book contains parts 50 to 51)
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Part
chapter i--Environmental Protection Agency (Continued)...... 50
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CHAPTER I--ENVIRONMENTAL PROTECTION AGENCY (CONTINUED)
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SUBCHAPTER C--AIR PROGRAMS
Part Page
50 National primary and secondary ambient air
quality standards....................... 5
51 Requirements for preparation, adoption, and
submittal of implementation plans....... 129
[[Page 5]]
SUBCHAPTER C--AIR PROGRAMS
PART 50--NATIONAL PRIMARY AND SECONDARY AMBIENT AIR QUALITY STANDARDS--Table
of Contents
Sec.
50.1 Definitions.
50.2 Scope.
50.3 Reference conditions.
50.4 National primary ambient air quality standards for sulfur oxides
(sulfur dioxide).
50.5 National secondary ambient air quality standard for sulfur oxides
(sulfur dioxide).
50.6 National primary and secondary ambient air quality standards for
PM10.
50.7 National primary and secondary ambient air quality standards for
particulate matter.
50.8 National primary ambient air quality standards for carbon
monoxide.
50.9 National 1-hour primary and secondary ambient air quality
standards for ozone.
50.10 National 8-hour primary and secondary ambient air quality
standards for ozone.
50.11 National primary and secondary ambient air quality standards for
nitrogen dioxide.
50.12 National primary and secondary ambient air quality standards for
lead.
Appendix A to Part 50--Reference Method for the Determination of Sulfur
Dioxide in the Atmosphere (Pararosaniline Method)
Appendix B to Part 50--Reference Method for the Determination of
Suspended Particulate Matter in the Atmosphere (High-Volume
Method)
Appendix C to Part 50--Measurement Principle and Calibration Procedure
for the Measurement of Carbon Monoxide in the Atmosphere (Non-
Dispersive Infrared Photometry)
Appendix D to Part 50--Measurement Principle and Calibration Procedure
for the Measurement of Ozone in the Atmosphere
Appendix E to Part 50 [Reserved]
Appendix F to Part 50--Measurement Principle and Calibration Procedure
for the Measurement of Nitrogen Dioxide in the Atmosphere (Gas
Phase Chemiluminescence)
Appendix G to Part 50--Reference Method for the Determination of Lead in
Suspended Particulate Matter Collected From Ambient Air
Appendix H to Part 50--Interpretation of the 1-Hour Primary and
Secondary National Ambient Air Quality Standards for Ozone
Appendix I to Part 50--Interpretation of the 8-Hour Primary and
Secondary National Ambient Air Quality Standards for Ozone
Appendix J to Part 50--Reference Method for the Determination of
Particulate Matter as PM10 in the Atmosphere
Appendix K to Part 50--Interpretation of the National Ambient Air
Quality Standards for Particulate Matter
Appendix L to Part 50--Reference Method for the Determination of Fine
Particulate Matter as PM2.5 in the Atmosphere
Appendix M to Part 50--Reference Method for the Determination of
Particulate Matter as PM10 in the Atmosphere
Appendix N to Part 50--Interpretation of the National Ambient Air
Quality Standards for Particulate Matter
Authority: 42 U.S.C. 7401, et seq.
Source: 36 FR 22384, Nov. 25, 1971, unless otherwise noted.
Sec. 50.1 Definitions.
(a) As used in this part, all terms not defined herein shall have
the meaning given them by the Act.
(b) Act means the Clean Air Act, as amended (42 U.S.C. 1857-18571,
as amended by Pub. L. 91-604).
(c) Agency means the Environmental Protection Agency.
(d) Administrator means the Administrator of the Environmental
Protection Agency.
(e) Ambient air means that portion of the atmosphere, external to
buildings, to which the general public has access.
(f) Reference method means a method of sampling and analyzing the
ambient air for an air pollutant that is specified as a reference method
in an appendix to this part, or a method that has been designated as a
reference method in accordance with part 53 of this chapter; it does not
include a method for which a reference method designation has been
cancelled in accordance with Sec. 53.11 or Sec. 53.16 of this chapter.
(g) Equivalent method means a method of sampling and analyzing the
ambient air for an air pollutant that has been designated as an
equivalent method in accordance with part 53 of this chapter; it does
not include a method for which an equivalent method designation has
[[Page 6]]
been cancelled in accordance with Sec. 53.11 or Sec. 53.16 of this
chapter.
(h) Traceable means that a local standard has been compared and
certified either directly or via not more than one intermediate
standard, to a primary standard such as a National Bureau of Standards
Standard Reference Material (NBS SRM), or a USEPA/NBS-approved Certified
Reference Material (CRM).
(i) Indian country is as defined in 18 U.S.C. 1151.
[36 FR 22384, Nov. 25, 1971, as amended at 41 FR 11253, Mar. 17, 1976;
48 FR 2529, Jan. 20, 1983; 63 FR 7274, Feb. 12, 1998]
Sec. 50.2 Scope.
(a) National primary and secondary ambient air quality standards
under section 109 of the Act are set forth in this part.
(b) National primary ambient air quality standards define levels of
air quality which the Administrator judges are necessary, with an
adequate margin of safety, to protect the public health. National
secondary ambient air quality standards define levels of air quality
which the Administrator judges necessary to protect the public welfare
from any known or anticipated adverse effects of a pollutant. Such
standards are subject to revision, and additional primary and secondary
standards may be promulgated as the Administrator deems necessary to
protect the public health and welfare.
(c) The promulgation of national primary and secondary ambient air
quality standards shall not be considered in any manner to allow
significant deterioration of existing air quality in any portion of any
State or Indian country.
(d) The proposal, promulgation, or revision of national primary and
secondary ambient air quality standards shall not prohibit any State or
Indian country from establishing ambient air quality standards for that
State or area under a tribal CAA program or any portion thereof which
are more stringent than the national standards.
[36 FR 22384, Nov. 25, 1971, as amended at 63 FR 7274, Feb. 12, 1998]
Sec. 50.3 Reference conditions.
All measurements of air quality that are expressed as mass per unit
volume (e.g., micrograms per cubic meter) other than for the particulate
matter (PM10 and PM2.5) standards contained in
Sec. 50.7 shall be corrected to a reference temperature of 25 deg.C and
a reference pressure of 760 millimeters of mercury (1,013.2 millibars).
Measurements of PM10 and PM2.5 for purposes of
comparison to the standards contained in Sec. 50.7 shall be reported
based on actual ambient air volume measured at the actual ambient
temperature and pressure at the monitoring site during the measurement
period.
[62 FR 38711, July 18, 1997]
Sec. 50.4 National primary ambient air quality standards for sulfur oxides
(sulfur dioxide).
(a) The level of the annual standard is 0.030 parts per million
(ppm), not to be exceeded in a calendar year. The annual arithmetic mean
shall be rounded to three decimal places (fractional parts equal to or
greater than 0.0005 ppm shall be rounded up).
(b) The level of the 24-hour standard is 0.14 parts per million
(ppm), not to be exceeded more than once per calendar year. The 24-hour
averages shall be determined from successive nonoverlapping 24-hour
blocks starting at midnight each calendar day and shall be rounded to
two decimal places (fractional parts equal to or greater than 0.005 ppm
shall be rounded up).
(c) Sulfur oxides shall be measured in the ambient air as sulfur
dioxide by the reference method described in appendix A to this part or
by an equivalent method designated in accordance with part 53 of this
chapter.
(d) To demonstrate attainment, the annual arithmetic mean and the
second-highest 24-hour averages must be based upon hourly data that are
at least 75 percent complete in each calendar quarter. A 24-hour block
average shall be considered valid if at least 75 percent of the hourly
averages for the 24-hour period are available. In the event that only
18, 19, 20, 21, 22, or 23 hourly averages are available, the 24-hour
block average shall be computed as the sum of the available hourly
[[Page 7]]
averages using 18, 19, etc. as the divisor. If fewer than 18 hourly
averages are available, but the 24-hour average would exceed the level
of the standard when zeros are substituted for the missing values,
subject to the rounding rule of paragraph (b) of this section, then this
shall be considered a valid 24-hour average. In this case, the 24-hour
block average shall be computed as the sum of the available hourly
averages divided by 24.
[61 FR 25579, May 22, 1996]
Sec. 50.5 National secondary ambient air quality standard for sulfur oxides
(sulfur dioxide).
(a) The level of the 3-hour standard is 0.5 parts per million (ppm),
not to be exceeded more than once per calendar year. The 3-hour averages
shall be determined from successive nonoverlapping 3-hour blocks
starting at midnight each calendar day and shall be rounded to 1 decimal
place (fractional parts equal to or greater than 0.05 ppm shall be
rounded up).
(b) Sulfur oxides shall be measured in the ambient air as sulfur
dioxide by the reference method described in appendix A of this part or
by an equivalent method designated in accordance with part 53 of this
chapter.
(c) To demonstrate attainment, the second-highest 3-hour average
must be based upon hourly data that are at least 75 percent complete in
each calendar quarter. A 3-hour block average shall be considered valid
only if all three hourly averages for the 3-hour period are available.
If only one or two hourly averages are available, but the 3-hour average
would exceed the level of the standard when zeros are substituted for
the missing values, subject to the rounding rule of paragraph (a) of
this section, then this shall be considered a valid 3-hour average. In
all cases, the 3-hour block average shall be computed as the sum of the
hourly averages divided by 3.
[61 FR 25580, May 22, 1996]
Sec. 50.6 National primary and secondary ambient air quality standards for
PM10.
(a) The level of the national primary and secondary 24-hour ambient
air quality standards for particulate matter is 150 micrograms per cubic
meter ([mu]g/m\3\), 24-hour average concentration. The standards are
attained when the expected number of days per calendar year with a 24-
hour average concentration above 150 [mu]g/m\3\, as determined in
accordance with appendix K to this part, is equal to or less than one.
(b) The level of the national primary and secondary annual standards
for particulate matter is 50 micrograms per cubic meter ([mu]g/m\3\),
annual arithmetic mean. The standards are attained when the expected
annual arithmetic mean concentration, as determined in accordance with
appendix K to this part, is less than or equal to 50 [mu]g/m\3\.
(c) For the purpose of determining attainment of the primary and
secondary standards, particulate matter shall be measured in the ambient
air as PM10 (particles with an aerodynamic diameter less than
or equal to a nominal 10 micrometers) by:
(1) A reference method based on appendix J and designated in
accordance with part 53 of this chapter, or
(2) An equivalent method designated in accordance with part 53 of
this chapter.
[52 FR 24663, July 1, 1987, as amended at 62 FR 38711, July 18, 1997; 65
FR 80779, Dec. 22, 2000]
Sec. 50.7 National primary and secondary ambient air quality standards
for particulate matter.
(a) The national primary and secondary ambient air quality standards
for particulate matter are:
(1) 15.0 micrograms per cubic meter ([mu]g/m\3\) annual arithmetic
mean concentration, and 65 [mu]g/m\3\ 24-hour average concentration
measured in the ambient air as PM2.5 (particles with an
aerodynamic diameter less than or equal to a nominal 2.5 micrometers) by
either:
(i) A reference method based on appendix L of this part and
designated in accordance with part 53 of this chapter; or
(ii) An equivalent method designated in accordance with part 53 of
this chapter.
[[Page 8]]
(2) 50 micrograms per cubic meter ([mu]g/m\3\) annual arithmetic
mean concentration, and 150 [mu]g/m\3\ 24-hour average concentration
measured in the ambient air as PM10 (particles with an
aerodynamic diameter less than or equal to a nominal 10 micrometers) by
either:
(i) A reference method based on appendix M of this part and
designated in accordance with part 53 of this chapter; or
(ii) An equivalent method designated in accordance with part 53 of
this chapter.
(b) The annual primary and secondary PM2.5 standards are
met when the annual arithmetic mean concentration, as determined in
accordance with appendix N of this part, is less than or equal to 15.0
micrograms per cubic meter.
(c) The 24-hour primary and secondary PM2.5 standards are
met when the 98th percentile 24-hour concentration, as
determined in accordance with appendix N of this part, is less than or
equal to 65 micrograms per cubic meter.
(d) The annual primary and secondary PM10 standards are
met when the annual arithmetic mean concentration, as determined in
accordance with appendix N of this part, is less than or equal to 50
micrograms per cubic meter.
(e) The 24-hour primary and secondary PM10 standards are
met when the 99th percentile 24-hour concentration, as
determined in accordance with appendix N of this part, is less than or
equal to 150 micrograms per cubic meter.
[62 FR 38711, July 18, 1997]
Sec. 50.8 National primary ambient air quality standards for carbon monoxide.
(a) The national primary ambient air quality standards for carbon
monoxide are:
(1) 9 parts per million (10 milligrams per cubic meter) for an 8-
hour average concentration not to be exceeded more than once per year
and
(2) 35 parts per million (40 milligrams per cubic meter) for a 1-
hour average concentration not to be exceeded more than once per year.
(b) The levels of carbon monoxide in the ambient air shall be
measured by:
(1) A reference method based on appendix C and designated in
accordance with part 53 of this chapter, or
(2) An equivalent method designated in accordance with part 53 of
this chapter.
(c) An 8-hour average shall be considered valid if at least 75
percent of the hourly average for the 8-hour period are available. In
the event that only six (or seven) hourly averages are available, the 8-
hour average shall be computed on the basis of the hours available using
six (or seven) as the divisor.
(d) When summarizing data for comparision with the standards,
averages shall be stated to one decimal place. Comparison of the data
with the levels of the standards in parts per million shall be made in
terms of integers with fractional parts of 0.5 or greater rounding up.
[50 FR 37501, Sept. 13, 1985]
Sec. 50.9 National 1-hour primary and secondary ambient air quality
standards for ozone.
(a) The level of the national 1-hour primary and secondary ambient
air quality standards for ozone measured by a reference method based on
appendix D to this part and designated in accordance with part 53 of
this chapter, is 0.12 parts per million (235 [mu]g/m\3\). The standard
is attained when the expected number of days per calendar year with
maximum hourly average concentrations above 0.12 parts per million (235
[mu]g/m\3\) is equal to or less than 1, as determined by appendix H to
this part.
(b) The 1-hour standards set forth in this section will remain
applicable to all areas notwithstanding the promulgation of 8-hour ozone
standards under Sec. 50.10. In addition, after the 8-hour standard has
become fully enforceable under part D of title I of the CAA and subject
to no further legal challenge, the 1-hour standards set forth in this
section will no longer apply to an area once EPA determines that the
area has
[[Page 9]]
air quality meeting the 1-hour standard. Area designations and
classifications with respect to the 1-hour standards are codified in 40
CFR part 81.
[62 FR 38894, July 18, 1997, as amended at 65 FR 45200, July 20, 2000]
Effective Date Note: At 68 FR 38163, June 26, 2003, Sec. 50.9 was
amended by adding paragraph (c), effective August 25, 2003. For the
convenience of the user, the added text is set forth as follows.
Sec. 50.9 National 1-hour primary and secondary ambient air quality
standards for ozone.
* * * * *
(c) EPA's authority under paragraph (b) of this section to determine
that the 1-hour standard no longer applies to an area based on a
determination that the area has attained the 1-hour standard is stayed
until such time as EPA issues a final rule revising or reinstating such
authority and considers and addresses in such rulemaking any comments
concerning (1) which, if any, implementation activities for a revised
ozone standard (including but not limited to designation and
classification of areas) would need to occur before EPA would determine
that the 1-hour ozone standard no longer applies to an area, and (2) the
effect of revising the ozone NAAQS on the existing 1-hour ozone
designations.
Sec. 50.10 National 8-hour primary and secondary ambient air quality
standards for ozone.
(a) The level of the national 8-hour primary and secondary ambient
air quality standards for ozone, measured by a reference method based on
appendix D to this part and designated in accordance with part 53 of
this chapter, is 0.08 parts per million (ppm), daily maximum 8-hour
average.
(b) The 8-hour primary and secondary ozone ambient air quality
standards are met at an ambient air quality monitoring site when the
average of the annual fourth-highest daily maximum 8-hour average ozone
concentration is less than or equal to 0.08 ppm, as determined in
accordance with appendix I to this part.
[62 FR 38894, July 18, 1997]
Sec. 50.11 National primary and secondary ambient air quality standards for
nitrogen dioxide.
(a) The level of the national primary ambient air quality standard
for nitrogen dioxide is 0.053 parts per million (100 micrograms per
cubic meter), annual arithmetic mean concentration.
(b) The level of national secondary ambient air quality standard for
nitrogen dioxide is 0.053 parts per million (100 micrograms per cubic
meter), annual arithmetic mean concentration.
(c) The levels of the standards shall be measured by:
(1) A reference method based on appendix F and designated in
accordance with part 53 of this chapter, or
(2) An equivalent method designated in accordance with part 53 of
this chapter.
(d) The standards are attained when the annual arithmetic mean
concentration in a calendar year is less than or equal to 0.053 ppm,
rounded to three decimal places (fractional parts equal to or greater
than 0.0005 ppm must be rounded up). To demonstrate attainment, an
annual mean must be based upon hourly data that are at least 75 percent
complete or upon data derived from manual methods that are at least 75
percent complete for the scheduled sampling days in each calendar
quarter.
[50 FR 25544, June 19, 1985]
Sec. 50.12 National primary and secondary ambient air quality standards
for lead.
National primary and secondary ambient air quality standards for
lead and its compounds, measured as elemental lead by a reference method
based on appendix G to this part, or by an equivalent method, are: 1.5
micrograms per cubic meter, maximum arithmetic mean averaged over a
calendar quarter.
(Secs. 109, 301(a) Clean Air Act as amended (42 U.S.C. 7409, 7601(a)))
[43 FR 46258, Oct. 5, 1978]
Appendix A to Part 50--Reference Method for the Determination of Sulfur
Dioxide in the Atmosphere (Pararosaniline Method)
1.0 Applicability.
[[Page 10]]
1.1 This method provides a measurement of the concentration of
sulfur dioxide (SO2) in ambient air for determining
compliance with the primary and secondary national ambient air quality
standards for sulfur oxides (sulfur dioxide) as specified in Sec. 50.4
and Sec. 50.5 of this chapter. The method is applicable to the
measurement of ambient SO2 concentrations using sampling
periods ranging from 30 minutes to 24 hours. Additional quality
assurance procedures and guidance are provided in part 58, appendixes A
and B, of this chapter and in references 1 and 2.
2.0 Principle.
2.1 A measured volume of air is bubbled through a solution of 0.04 M
potassium tetrachloromercurate (TCM). The SO2 present in the
air stream reacts with the TCM solution to form a stable
monochlorosulfonatomercurate(3) complex. Once formed, this complex
resists air oxidation(4, 5) and is stable in the presence of strong
oxidants such as ozone and oxides of nitrogen. During subsequent
analysis, the complex is reacted with acid-bleached pararosaniline dye
and formaldehyde to form an intensely colored pararosaniline methyl
sulfonic acid.(6) The optical density of this species is determined
spectrophotometrically at 548 nm and is directly related to the amount
of SO2 collected. The total volume of air sampled, corrected
to EPA reference conditions (25 deg.C, 760 mm Hg [101 kPa]), is
determined from the measured flow rate and the sampling time. The
concentration of SO2 in the ambient air is computed and
expressed in micrograms per standard cubic meter ([mu]g/std m\3\).
3.0 Range.
3.1 The lower limit of detection of SO2 in 10 mL of TCM
is 0.75 [mu]g (based on collaborative test results).(7) This represents
a concentration of 25 [mu]g SO2/m\3\ (0.01 ppm) in an air
sample of 30 standard liters (short-term sampling) and a concentration
of 13 [mu]g SO2/m\3\ (0.005 ppm) in an air sample of 288
standard liters (long-term sampling). Concentrations less than 25 [mu]g
SO2/m\3\ can be measured by sampling larger volumes of
ambient air; however, the collection efficiency falls off rapidly at low
concentrations.(8, 9) Beer's law is adhered to up to 34 [mu]g of
SO2 in 25 mL of final solution. This upper limit of the
analysis range represents a concentration of 1,130 [mu]g SO2/
m\3\ (0.43 ppm) in an air sample of 30 standard liters and a
concentration of 590 [mu]g SO2/m\3\ (0.23 ppm) in an air
sample of 288 standard liters. Higher concentrations can be measured by
collecting a smaller volume of air, by increasing the volume of
absorbing solution, or by diluting a suitable portion of the collected
sample with absorbing solution prior to analysis.
4.0 Interferences.
4.1 The effects of the principal potential interferences have been
minimized or eliminated in the following manner: Nitrogen oxides by the
addition of sulfamic acid,(10, 11) heavy metals by the addition of
ethylenediamine tetracetic acid disodium salt (EDTA) and phosphoric
acid,(10, 12) and ozone by time delay.(10) Up to 60 [mu]g Fe (III), 22
[mu]g V (V), 10 [mu]g Cu (II), 10 [mu]g Mn (II), and 10 [mu]g Cr (III)
in 10 mL absorbing reagent can be tolerated in the procedure.(10) No
significant interference has been encountered with 2.3 [mu]g
NH3.(13)
5.0 Precision and Accuracy.
5.1 The precision of the analysis is 4.6 percent (at the 95 percent
confidence level) based on the analysis of standard sulfite samples.(10)
5.2 Collaborative test results (14) based on the analysis of
synthetic test atmospheres (SO2 in scrubbed air) using the
24-hour sampling procedure and the sulfite-TCM calibration procedure
show that:
The replication error varies linearly with concentration from
2.5 [mu]g/m\3\ at concentrations of 100 [mu]g/m\3\ to
7 [mu]g/m\3\ at concentrations of 400 [mu]g/m\3\.
The day-to-day variability within an individual laboratory
(repeatability) varies linearly with concentration from 18.1
[mu]g/m\3\ at levels of 100 [mu]g/m\3\ to 50.9 [mu]g/m\3\ at
levels of 400 [mu]g/m\3\.
The day-to-day variability between two or more laboratories
(reproducibility) varies linearly with concentration from
36.9 [mu]g/m\3\ at levels of 100 [mu]g/m\3\ to
103.5 [mu] g/m\3\ at levels of 400 [mu]g/m\3\.
The method has a concentration-dependent bias, which becomes
significant at the 95 percent confidence level at the high concentration
level. Observed values tend to be lower than the expected SO2
concentration level.
6.0 Stability.
6.1 By sampling in a controlled temperature environment of
15 deg.10 deg.C, greater than 98.9 percent of the
SO2-TCM complex is retained at the completion of sampling.
(15) If kept at 5 deg.C following the completion of sampling, the
collected sample has been found to be stable for up to 30 days.(10) The
presence of EDTA enhances the stability of SO2 in the TCM
solution and the rate of decay is independent of the concentration of
SO2.(16)
7.0 Apparatus.
7.1 Sampling.
7.1.1 Sample probe: A sample probe meeting the requirements of
section 7 of 40 CFR part 58, appendix E (Teflon[reg] or glass with
residence time less than 20 sec.) is used to transport ambient air to
the sampling train location. The end of the probe should be designed or
oriented to preclude the sampling of precipitation, large particles,
etc. A suitable probe can be constructed from Teflon[reg] tubing
connected to an inverted funnel.
7.1.2 Absorber--short-term sampling: An all glass midget impinger
having a solution capacity of 30 mL and a stem clearance of
41
[[Page 11]]
mm from the bottom of the vessel is used for sampling periods of 30
minutes and 1 hour (or any period considerably less than 24 hours). Such
an impinger is shown in Figure 1. These impingers are commercially
available from distributors such as Ace Glass, Incorporated.
7.1.3 Absorber--24-hour sampling: A polypropylene tube 32 mm in
diameter and 164 mm long (available from Bel Art Products, Pequammock,
NJ) is used as the absorber. The cap of the absorber must be a
polypropylene cap with two ports (rubber stoppers are unacceptable
because the absorbing reagent can react with the stopper to yield
erroneously high SO2 concentrations). A glass impinger stem,
6 mm in diameter and 158 mm long, is inserted into one port of the
absorber cap. The tip of the stem is tapered to a small diameter orifice
(0.40.1 mm) such that a No. 79 jeweler's drill bit will pass
through the opening but a No. 78 drill bit will not. Clearance from the
bottom of the absorber to the tip of the stem must be 62 mm.
Glass stems can be fabricated by any reputable glass blower or can be
obtained from a scientific supply firm. Upon receipt, the orifice test
should be performed to verify the orifice size. The 50 mL volume level
should be permanently marked on the absorber. The assembled absorber is
shown in Figure 2.
7.1.4 Moisture trap: A moisture trap constructed of a glass trap as
shown in Figure 1 or a polypropylene tube as shown in Figure 2 is placed
between the absorber tube and flow control device to prevent entrained
liquid from reaching the flow control device. The tube is packed with
indicating silica gel as shown in Figure 2. Glass wool may be
substituted for silica gel when collecting short-term samples (1 hour or
less) as shown in Figure 1, or for long term (24 hour) samples if flow
changes are not routinely encountered.
7.1.5 Cap seals: The absorber and moisture trap caps must seal
securely to prevent leaks during use. Heat-shrink material as shown in
Figure 2 can be used to retain the cap seals if there is any chance of
the caps coming loose during sampling, shipment, or storage.
[[Page 12]]
[[Page 13]]
[[Page 14]]
7.1.6 Flow control device: A calibrated rotameter and needle valve
combination capable of maintaining and measuring air flow to within
2 percent is suitable for short-term sampling but may not be
used for long-term sampling. A critical orifice can be used for
regulating flow rate for both long-term and short-term sampling. A 22-
gauge hypodermic needle 25 mm long may be used as a critical orifice to
yield a flow rate of approximately 1 L/min for a 30-minute sampling
period. When sampling for 1 hour, a 23-gauge hypodermic needle 16 mm in
length will provide a flow rate of approximately 0.5 L/min. Flow control
for a 24-hour sample may be provided by a 27-gauge hypodermic needle
critical orifice that is 9.5 mm in length. The flow rate should be in
the range of 0.18 to 0.22 L/min.
7.1.7 Flow measurement device: Device calibrated as specified in
9.4.1 and used to measure sample flow rate at the monitoring site.
7.1.8 Membrane particle filter: A membrane filter of 0.8 to 2 [mu]m
porosity is used to protect the flow controller from particles during
long-term sampling. This item is optional for short-term sampling.
7.1.9 Vacuum pump: A vacuum pump equipped with a vacuum gauge and
capable of maintaining at least 70 kPa (0.7 atm) vacuum differential
across the flow control device at the specified flow rate is required
for sampling.
7.1.10 Temperature control device: The temperature of the absorbing
solution during sampling must be maintained at 15 deg. 10
deg.C. As soon as possible following sampling and until analysis, the
temperature of the collected sample must be maintained at 5 deg.
5 deg.C. Where an extended period of time may elapse before
the collected sample can be moved to the lower storage temperature, a
collection temperature near the lower limit of the 15 10
deg.C range should be used to minimize losses during this period.
Thermoelectric coolers specifically designed for this temperature
control are available commercially and normally operate in the range of
5 deg. to 15 deg.C. Small refrigerators can be modified to provide the
required temperature control; however, inlet lines must be insulated
from the lower temperatures to prevent condensation when sampling under
humid conditions. A small heating pad may be necessary when sampling at
low temperatures (<7 deg.C) to prevent the absorbing solution from
freezing.(17)
7.1.11 Sampling train container: The absorbing solution must be
shielded from light during and after sampling. Most commercially
available sampler trains are enclosed in a light-proof box.
7.1.12 Timer: A timer is recommended to initiate and to stop
sampling for the 24-hour period. The timer is not a required piece of
equipment; however, without the timer a technician would be required to
start and stop the sampling manually. An elapsed time meter is also
recommended to determine the duration of the sampling period.
7.2 Shipping.
7.2.1 Shipping container: A shipping container that can maintain a
temperature of 5 deg. 5 deg.C is used for transporting the
sample from the collection site to the analytical laboratory. Ice
coolers or refrigerated shipping containers have been found to be
satisfactory. The use of eutectic cold packs instead of ice will give a
more stable temperature control. Such equipment is available from Cole-
Parmer Company, 7425 North Oak Park Avenue, Chicago, IL 60648.
7.3 Analysis.
7.3.1 Spectrophotometer: A spectrophotometer suitable for
measurement of absorbances at 548 nm with an effective spectral
bandwidth of less than 15 nm is required for analysis. If the
spectrophotometer reads out in transmittance, convert to absorbance as
follows:
[GRAPHIC] [TIFF OMITTED] TC08NO91.000
where:
A = absorbance, and
T = transmittance (0<[gE]T<1).
A standard wavelength filter traceable to the National Bureau of
Standards is used to verify the wavelength calibration according to the
procedure enclosed with the filter. The wavelength calibration must be
verified upon initial receipt of the instrument and after each 160 hours
of normal use or every 6 months, whichever occurs first.
7.3.2 Spectrophotometer cells: A set of 1-cm path length cells
suitable for use in the visible region is used during analysis. If the
cells are unmatched, a matching correction factor must be determined
according to Section 10.1.
7.3.3 Temperature control device: The color development step during
analysis must be conducted in an environment that is in the range of
20 deg. to 30 deg.C and controlled to 1 deg.C. Both
calibration and sample analysis must be performed under identical
conditions (within 1 deg.C). Adequate temperature control may be
obtained by means of constant temperature baths, water baths with manual
temperature control, or temperature controlled rooms.
7.3.4 Glassware: Class A volumetric glassware of various capacities
is required for preparing and standardizing reagents and standards and
for dispensing solutions during analysis. These included pipets,
volumetric flasks, and burets.
7.3.5 TCM waste receptacle: A glass waste receptacle is required for
the storage of spent TCM solution. This vessel should be stoppered and
stored in a hood at all times.
8.0 Reagents.
8.1 Sampling.
[[Page 15]]
8.1.1 Distilled water: Purity of distilled water must be verified by
the following procedure:(18)
Place 0.20 mL of potassium permanganate solution (0.316 g/L),
500 mL of distilled water, and 1mL of concentrated sulfuric acid in a
chemically resistant glass bottle, stopper the bottle, and allow to
stand.
If the permanganate color (pink) does not disappear completely
after a period of 1 hour at room temperature, the water is suitable for
use.
If the permanganate color does disappear, the water can be
purified by redistilling with one crystal each of barium hydroxide and
potassium permanganate in an all glass still.
8.1.2 Absorbing reagent (0.04 M potassium tetrachloromercurate
[TCM]): Dissolve 10.86 g mercuric chloride, 0.066 g EDTA, and 6.0 g
potassium chloride in distilled water and dilute to volume with
distilled water in a 1,000-mL volumetric flask. (Caution: Mercuric
chloride is highly poisonous. If spilled on skin, flush with water
immediately.) The pH of this reagent should be between 3.0 and 5.0 (10)
Check the pH of the absorbing solution by using pH indicating paper or a
pH meter. If the pH of the solution is not between 3.0 and 5.0, dispose
of the solution according to one of the disposal techniques described in
Section 13.0. The absorbing reagent is normally stable for 6 months. If
a precipitate forms, dispose of the reagent according to one of the
procedures described in Section 13.0.
8.2 Analysis.
8.2.1 Sulfamic acid (0.6%): Dissolve 0.6 g sulfamic acid in 100 mL
distilled water. Perpare fresh daily.
8.2.2 Formaldehyde (0.2%): Dilute 5 mL formaldehyde solution (36 to
38 percent) to 1,000 mL with distilled water. Prepare fresh daily.
8.2.3 Stock iodine solution (0.1 N): Place 12.7 g resublimed iodine
in a 250-mL beaker and add 40 g potassium iodide and 25 mL water. Stir
until dissolved, transfer to a 1,000 mL volumetric flask and dilute to
volume with distilled water.
8.2.4 Iodine solution (0.01 N): Prepare approximately 0.01 N iodine
solution by diluting 50 mL of stock iodine solution (Section 8.2.3) to
500 mL with distilled water.
8.2.5 Starch indicator solution: Triturate 0.4 g soluble starch and
0.002 g mercuric iodide (preservative) with enough distilled water to
form a paste. Add the paste slowly to 200 mL of boiling distilled water
and continue boiling until clear. Cool and transfer the solution to a
glass stopperd bottle.
8.2.6 1 N hydrochloric acid: Slowly and while stirring, add 86 mL of
concentrated hydrochloric acid to 500 mL of distilled water. Allow to
cool and dilute to 1,000 mL with distilled water.
8.2.7 Potassium iodate solution: Accurately weigh to the nearest 0.1
mg, 1.5 g (record weight) of primary standard grade potassium iodate
that has been previously dried at 180 deg.C for at least 3 hours and
cooled in a dessicator. Dissolve, then dilute to volume in a 500-mL
volumetric flask with distilled water.
8.2.8 Stock sodium thiosulfate solution (0.1 N): Prepare a stock
solution by dissolving 25 g sodium thiosulfate (Na2
S2 O3/5H2 O) in 1,000 mL freshly
boiled, cooled, distilled water and adding 0.1 g sodium carbonate to the
solution. Allow the solution to stand at least 1 day before
standardizing. To standardize, accurately pipet 50 mL of potassium
iodate solution (Section 8.2.7) into a 500-mL iodine flask and add 2.0 g
of potassium iodide and 10 mL of 1 N HCl. Stopper the flask and allow to
stand for 5 minutes. Titrate the solution with stock sodium thiosulfate
solution (Section 8.2.8) to a pale yellow color. Add 5 mL of starch
solution (Section 8.2.5) and titrate until the blue color just
disappears. Calculate the normality (Ns) of the stock sodium
thiosulfate solution as follows:
[GRAPHIC] [TIFF OMITTED] TC08NO91.001
where:
M = volume of thiosulfate required in mL, and
W = weight of potassium iodate in g (recorded weight in Section 8.2.7).
[GRAPHIC] [TIFF OMITTED] TC08NO91.002
8.2.9 Working sodium thiosulfate titrant (0.01 N): Accurately pipet
100 mL of stock sodium thiosulfate solution (Section 8.2.8) into a
1,000-mL volumetric flask and dilute to volume with freshly boiled,
cooled, distilled water. Calculate the normality of the working sodium
thiosulfate titrant (NT) as follows:
[GRAPHIC] [TIFF OMITTED] TC08NO91.003
8.2.10 Standardized sulfite solution for the preparation of working
sulfite-TCM solution: Dissolve 0.30 g sodium metabisulfite
(Na2 S2 O5) or 0.40 g sodium sulfite
(Na2 SO3) in 500 mL of recently boiled, cooled,
distilled water. (Sulfite solution is unstable; it is therefore
important to use water of the highest purity to minimize this
instability.) This solution contains the equivalent of 320 to 400 [mu]g
SO2/mL. The actual concentration of the solution is
determined by adding excess iodine and back-titrating with standard
sodium thiosulfate solution. To back-titrate, pipet 50 mL of the 0.01 N
iodine solution (Section 8.2.4) into each of two 500-mL iodine flasks (A
and B). To flask A (blank) add 25 mL distilled water, and to flask B
(sample)
[[Page 16]]
pipet 25 mL sulfite solution. Stopper the flasks and allow to stand for
5 minutes. Prepare the working sulfite-TCM solution (Section 8.2.11)
immediately prior to adding the iodine solution to the flasks. Using a
buret containing standardized 0.01 N thiosulfate titrant (Section
8.2.9), titrate the solution in each flask to a pale yellow color. Then
add 5 mL starch solution (Section 8.2.5) and continue the titration
until the blue color just disappears.
8.2.11 Working sulfite-TCM solution: Accurately pipet 5 mL of the
standard sulfite solution (Section 8.2.10) into a 250-mL volumetric
flask and dilute to volume with 0.04 M TCM. Calculate the concentration
of sulfur dioxide in the working solution as follows:
[GRAPHIC] [TIFF OMITTED] TC08NO91.004
where:
A = volume of thiosulfate titrant required for the blank, mL;
B = volume of thiosulfate titrant required for the sample, mL;
NT = normality of the thiosulfate titrant, from equation (3);
32,000 = milliequivalent weight of SO2, [mu]g;
25 = volume of standard sulfite solution, mL; and
0.02 = dilution factor.
This solution is stable for 30 days if kept at 5 deg.C. (16) If not
kept at 5 deg.C, prepare fresh daily.
8.2.12 Purified pararosaniline (PRA) stock solution (0.2% nominal):
8.2.12.1 Dye specifications--
The dye must have a maximum absorbance at a wavelength of 540
nm when assayed in a buffered solution of 0.1 M sodium acetate-acetic
acid;
The absorbance of the reagent blank, which is temperature
sensitive (0.015 absorbance unit/ deg.C), must not exceed 0.170 at 22
deg.C with a 1-cm optical path length when the blank is prepared
according to the specified procedure;
The calibration curve (Section 10.0) must have a slope equal to
0.0300.002 absorbance unit/[mu]g SO2 with a 1-cm
optical path length when the dye is pure and the sulfite solution is
properly standardized.
8.2.12.2 Preparation of stock PRA solution-- A specially purified
(99 to 100 percent pure) solution of pararosaniline, which meets the
above specifications, is commercially available in the required 0.20
percent concentration (Harleco Co.). Alternatively, the dye may be
purified, a stock solution prepared, and then assayed according to the
procedure as described below.(10)
8.2.12.3 Purification procedure for PRA--
1. Place 100 mL each of 1-butanol and 1 N HCl in a large separatory
funnel (250-mL) and allow to equilibrate. Note: Certain batches of 1-
butanol contain oxidants that create an SO2 demand. Before
using, check by placing 20 mL of 1-butanol and 5 mL of 20 percent
potassium iodide (KI) solution in a 50-mL separatory funnel and shake
thoroughly. If a yellow color appears in the alcohol phase, redistill
the 1-butanol from silver oxide and collect the middle fraction or
purchase a new supply of 1-butanol.
2. Weigh 100 mg of pararosaniline hydrochloride dye (PRA) in a small
beaker. Add 50 mL of the equilibrated acid (drain in acid from the
bottom of the separatory funnel in 1.) to the beaker and let stand for
several minutes. Discard the remaining acid phase in the separatory
funnel.
3. To a 125-mL separatory funnel, add 50 mL of the equilibrated 1-
butanol (draw the 1-butanol from the top of the separatory funnel in
1.). Transfer the acid solution (from 2.) containing the dye to the
funnel and shake carefully to extract. The violet impurity will transfer
to the organic phase.
4. Transfer the lower aqueous phase into another separatory funnel,
add 20 mL of equilibrated 1-butanol, and extract again.
5. Repeat the extraction procedure with three more 10-mL portions of
equilibrated 1-butanol.
6. After the final extraction, filter the acid phase through a
cotton plug into a 50-mL volumetric flask and bring to volume with 1 N
HCl. This stock reagent will be a yellowish red.
7. To check the purity of the PRA, perform the assay and adjustment
of concentration (Section 8.2.12.4) and prepare a reagent blank (Section
11.2); the absorbance of this reagent blank at 540 nm should be less
than 0.170 at 22 deg.C. If the absorbance is greater than 0.170 under
these conditions, further extractions should be performed.
8.2.12.4 PRA assay procedure-- The concentration of pararosaniline
hydrochloride (PRA) need be assayed only once after purification. It is
also recommended that commercial solutions of pararosaniline be assayed
when first purchased. The assay procedure is as follows:(10)
1. Prepare 1 M acetate-acetic acid buffer stock solution with a pH
of 4.79 by dissolving
[[Page 17]]
13.61 g of sodium acetate trihydrate in distilled water in a 100-mL
volumetric flask. Add 5.70 mL of glacial acetic acid and dilute to
volume with distilled water.
2. Pipet 1 mL of the stock PRA solution obtained from the
purification process or from a commercial source into a 100-mL
volumetric flask and dilute to volume with distilled water.
3. Transfer a 5-mL aliquot of the diluted PRA solution from 2. into
a 50-mL volumetric flask. Add 5mL of 1 M acetate-acetic acid buffer
solution from 1. and dilute the mixture to volume with distilled water.
Let the mixture stand for 1 hour.
4. Measure the absorbance of the above solution at 540 nm with a
spectrophotometer against a distilled water reference. Compute the
percentage of nominal concentration of PRA by
[GRAPHIC] [TIFF OMITTED] TC08NO91.005
where:
A = measured absorbance of the final mixture (absorbance units);
W = weight in grams of the PRA dye used in the assay to prepare 50 mL of
stock solution (for example, 0.100 g of dye was used to prepare 50 mL of
solution in the purification procedure; when obtained from commercial
sources, use the stated concentration to compute W; for 98% PRA, W=.098
g.); and
K = 21.3 for spectrophotometers having a spectral bandwidth of less than
15 nm and a path length of 1 cm.
8.2.13 Pararosaniline reagent: To a 250-mL volumetric flask, add 20
mL of stock PRA solution. Add an additional 0.2 mL of stock solution for
each percentage that the stock assays below 100 percent. Then add 25 mL
of 3 M phosphoric acid and dilute to volume with distilled water. The
reagent is stable for at least 9 months. Store away from heat and light.
9.0 Sampling Procedure.
9.1 General Considerations. Procedures are described for short-term
sampling (30-minute and 1-hour) and for long-term sampling (24-hour).
Different combinations of absorbing reagent volume, sampling rate, and
sampling time can be selected to meet special needs. For combinations
other than those specifically described, the conditions must be adjusted
so that linearity is maintained between absorbance and concentration
over the dynamic range. Absorbing reagent volumes less than 10 mL are
not recommended. The collection efficiency is above 98 percent for the
conditions described; however, the efficiency may be substantially lower
when sampling concentrations below 25[mu][gamma]SO2/
m\3\.(8,9)
9.2 30-Minute and 1-Hour Sampling. Place 10 mL of TCM absorbing
reagent in a midget impinger and seal the impinger with a thin film of
silicon stopcock grease (around the ground glass joint). Insert the
sealed impinger into the sampling train as shown in Figure 1, making
sure that all connections between the various components are leak tight.
Greaseless ball joint fittings, heat shrinkable Teflon[reg]
tubing, or Teflon[reg] tube fittings may be used to attain
leakfree conditions for portions of the sampling train that come into
contact with air containing SO2. Shield the absorbing reagent
from direct sunlight by covering the impinger with aluminum foil or by
enclosing the sampling train in a light-proof box. Determine the flow
rate according to Section 9.4.2. Collect the sample at 10.10
L/min for 30-minute sampling or 0.5000.05 L/min for 1-hour
sampling. Record the exact sampling time in minutes, as the sample
volume will later be determined using the sampling flow rate and the
sampling time. Record the atmospheric pressure and temperature.
9.3 24-Hour Sampling. Place 50 mL of TCM absorbing solution in a
large absorber, close the cap, and, if needed, apply the heat shrink
material as shown in Figure 3. Verify that the reagent level is at the
50 mL mark on the absorber. Insert the sealed absorber into the sampling
train as shown in Figure 2. At this time verify that the absorber
temperature is controlled to 1510 deg.C. During sampling,
the absorber temperature must be controlled to prevent decomposition of
the collected complex. From the onset of sampling until analysis, the
absorbing solution must be protected from direct sunlight. Determine the
flow rate according to Section 9.4.2. Collect the sample for 24 hours
from midnight to midnight at a flow rate of 0.2000.020 L/
min. A start/stop timer is helpful for initiating and stopping sampling
and an elapsed time meter will be useful for determining the sampling
time.
[[Page 18]]
9.4 Flow Measurement.
9.4.1 Calibration: Flow measuring devices used for the on-site flow
measurements required in 9.4.2 must be calibrated against a reliable
flow or volume standard such as an NBS traceable bubble flowmeter or
calibrated wet test meter. Rotameters or critical orifices used in the
sampling train may be calibrated, if desired, as a quality control
check, but such calibration shall not replace the on-site flow
measurements required by 9.4.2. In-line rotameters, if they are to be
calibrated, should be calibrated in situ, with the appropriate volume of
solution in the absorber.
9.4.2 Determination of flow rate at sampling site: For short-term
samples, the standard flow rate is determined at the sampling site at
the initiation and completion of sample collection with a calibrated
flow measuring device connected to the inlet of the absorber. For 24-
hour samples, the standard flow rate is determined at the time the
absorber is placed in the sampling train and again when the absorber is
removed from the train for shipment to the analytical laboratory with a
calibrated flow measuring device connected to the inlet of the sampling
train. The flow rate determination must be made with all components of
the sampling system in operation (e.g., the absorber temperature
controller and any sample box heaters must also be operating). Equation
6 may be used to determine the standard flow rate when a calibrated
positive displacement meter is used as the flow measuring device. Other
types of calibrated flow measuring devices may also be used to determine
the flow rate at the sampling site provided that the user applies any
appropriate corrections to devices for which output is dependent on
temperature or pressure.
[[Page 19]]
[GRAPHIC] [TIFF OMITTED] TC08NO91.006
where:
Qstd = flow rate at standard conditions, std L/min (25 deg.C
and 760 mm Hg);
Qact = flow rate at monitoring site conditions, L/min;
Pb = barometric pressure at monitoring site conditions, mm Hg
or kPa;
RH = fractional relative humidity of the air being measured;
PH2O = vapor pressure of water at the temperature
of the air in the flow or volume standard, in the same units as
Pb, (for wet volume standards only, i.e., bubble flowmeter or
wet test meter; for dry standards, i.e., dry test meter,
PH2O=0);
Pstd = standard barometric pressure, in the same units as
Pb (760 mm Hg or 101 kPa); and
Tmeter = temperature of the air in the flow or volume
standard, deg.C (e.g., bubble flowmeter).
If a barometer is not available, the following equation may be used
to determine the barometric pressure:
[GRAPHIC] [TIFF OMITTED] TC08NO91.007
where:
H = sampling site elevation above sea level in meters.
If the initial flow rate (Qi) differs from the flow rate
of the critical orifice or the flow rate indicated by the flowmeter in
the sampling train (Qc) by more than 5 percent as determined
by equation (8), check for leaks and redetermine Qi.
[GRAPHIC] [TIFF OMITTED] TC08NO91.008
Invalidate the sample if the difference between the initial
(Qi) and final (Qf) flow rates is more than 5
percent as determined by equation (9):
[GRAPHIC] [TIFF OMITTED] TC08NO91.009
9.5 Sample Storage and Shipment. Remove the impinger or absorber
from the sampling train and stopper immediately. Verify that the
temperature of the absorber is not above 25 deg.C. Mark the level of
the solution with a temporary (e.g., grease pencil) mark. If the sample
will not be analyzed within 12 hours of sampling, it must be stored at
5 deg. 5 deg.C until analysis. Analysis must occur within
30 days. If the sample is transported or shipped for a period exceeding
12 hours, it is recommended that thermal coolers using eutectic ice
packs, refrigerated shipping containers, etc., be used for periods up to
48 hours. (17) Measure the temperature of the absorber solution when the
shipment is received. Invalidate the sample if the temperature is above
10 deg.C. Store the sample at 5 deg. 5 deg.C until it is
analyzed.
10.0 Analytical Calibration.
10.1 Spectrophotometer Cell Matching. If unmatched spectrophotometer
cells are used, an absorbance correction factor must be determined as
follows:
1. Fill all cells with distilled water and designate the one that
has the lowest absorbance at 548 nm as the reference. (This reference
cell should be marked as such and continually used for this purpose
throughout all future analyses.)
2. Zero the spectrophotometer with the reference cell.
3. Determine the absorbance of the remaining cells (Ac)
in relation to the reference cell and record these values for future
use. Mark all cells in a manner that adequately identifies the
correction.
The corrected absorbance during future analyses using each cell is
determining as follows:
[GRAPHIC] [TIFF OMITTED] TC08NO91.010
where:
A = corrected absorbance,
Aobs = uncorrected absorbance, and
Ac = cell correction.
10.2 Static Calibration Procedure (Option 1). Prepare a dilute
working sulfite-TCM solution by diluting 10 mL of the working sulfite-
TCM solution (Section 8.2.11) to 100 mL with TCM absorbing reagent.
Following the table below, accurately pipet the indicated volumes of the
sulfite-TCM solutions into a series of 25-mL volumetric flasks. Add TCM
absorbing reagent as indicated to bring the volume in each flask to 10
mL.
[[Page 20]]
------------------------------------------------------------------------
Volume of
sulfite- Volume of Total
Sulfite-TCM solution TCM TCM, mL [mu]g SO2
solution (approx.*
------------------------------------------------------------------------
Working................................ 4.0 6.0 28.8
Working................................ 3.0 7.0 21.6
Working................................ 2.0 8.0 14.4
Dilute working......................... 10.0 0.0 7.2
Dilute working......................... 5.0 5.0 3.6
0.0 10.0 0.0
------------------------------------------------------------------------
*Based on working sulfite-TCM solution concentration of 7.2 [mu]g SO2/
mL; the actual total [mu]g SO2 must be calculated using equation 11
below.
To each volumetric flask, add 1 mL 0.6% sulfamic acid (Section
8.2.1), accurately pipet 2 mL 0.2% formaldehyde solution (Section
8.2.2), then add 5 mL pararosaniline solution (Section 8.2.13). Start a
laboratory timer that has been set for 30 minutes. Bring all flasks to
volume with recently boiled and cooled distilled water and mix
thoroughly. The color must be developed (during the 30-minute period) in
a temperature environment in the range of 20 deg. to 30 deg.C, which is
controlled to 1 deg.C. For increased precision, a constant
temperature bath is recommended during the color development step. After
30 minutes, determine the corrected absorbance of each standard at 548
nm against a distilled water reference (Section 10.1). Denote this
absorbance as (A). Distilled water is used in the reference cell rather
than the reagant blank because of the temperature sensitivity of the
reagent blank. Calculate the total micrograms SO2 in each
solution:
[GRAPHIC] [TIFF OMITTED] TC08NO91.011
where:
VTCM/SO2 = volume of sulfite-TCM solution used, mL;
CTCM/SO2 = concentration of sulfur dioxide in the working
sulfite-TCM, [mu]g SO2/mL (from equation 4); and
D = dilution factor (D = 1 for the working sulfite-TCM solution; D = 0.1
for the diluted working sulfite-TCM solution).
A calibration equation is determined using the method of linear
least squares (Section 12.1). The total micrograms SO2
contained in each solution is the x variable, and the corrected
absorbance (eq. 10) associated with each solution is the y variable. For
the calibration to be valid, the slope must be in the range of 0.030
0.002 absorbance unit/[mu]g SO2, the intercept as
determined by the least squares method must be equal to or less than
0.170 absorbance unit when the color is developed at 22 deg.C (add
0.015 to this 0.170 specification for each deg.C above 22 deg.C) and
the correlation coefficient must be greater than 0.998. If these
criteria are not met, it may be the result of an impure dye and/or an
improperly standardized sulfite-TCM solution. A calibration factor
(Bs) is determined by calculating the reciprocal of the slope
and is subsequently used for calculating the sample concentration
(Section 12.3).
10.3 Dynamic Calibration Procedures (Option 2). Atmospheres
containing accurately known concentrations of sulfur dioxide are
prepared using permeation devices. In the systems for generating these
atmospheres, the permeation device emits gaseous SO2 at a
known, low, constant rate, provided the temperature of the device is
held constant (0.1 deg.C) and the device has been
accurately calibrated at the temperature of use. The SO2
permeating from the device is carried by a low flow of dry carrier gas
to a mixing chamber where it is diluted with SO2-free air to
the desired concentration and supplied to a vented manifold. A typical
system is shown schematically in Figure 4 and this system and other
similar systems have been described in detail by O'Keeffe and Ortman;
(19) Scaringelli, Frey, and Saltzman, (20) and Scaringelli, O'Keeffe,
Rosenberg, and Bell. (21) Permeation devices may be prepared or
purchased and in both cases must be traceable either to a National
Bureau of Standards (NBS) Standard Reference Material (SRM 1625, SRM
1626, SRM 1627) or to an NBS/EPA-approved commercially available
Certified Reference Material (CRM). CRM's are described in Reference 22,
and a list of CRM sources is available from the address shown for
Reference 22. A recommended protocol for certifying a permeation device
to an NBS SRM or CRM is given in Section 2.0.7 of Reference 2. Device
permeation rates of 0.2 to 0.4 [mu]g/min, inert gas flows of about 50
mL/min, and dilution air flow rates from 1.1 to 15 L/min conveniently
yield standard atmospheres in the range of 25 to 600 [mu]g
SO2/m\3\ (0.010 to 0.230 ppm).
10.3.1 Calibration Option 2A (30-minute and 1-hour samples):
Generate a series of six standard atmospheres of SO2 (e.g.,
0, 50, 100, 200, 350, 500, 750 [mu]g/m\3\) by adjusting the dilution
flow rates appropriately. The concentration of SO2 in each
atmosphere is calculated as follows:
[GRAPHIC] [TIFF OMITTED] TR31AU93.014
where:
[[Page 21]]
Ca = concentration of SO2 at standard conditions,
[mu]g/m\3\;
Pr = permeation rate, [mu]g/min;
Qd = flow rate of dilution air, std L/min; and
Qp = flow rate of carrier gas across permeation device, std
L/min.
[[Page 22]]
Be sure that the total flow rate of the standard exceeds the flow
demand of the sample train, with the excess flow vented at atmospheric
pressure. Sample each atmosphere using similar apparatus as shown in
Figure 1 and under the same conditions as field sampling (i.e., use same
absorbing reagent volume and sample same volume of air at an equivalent
flow rate). Due to the length of the sampling periods required, this
method is not recommended for 24-hour sampling. At the completion of
sampling, quantitatively transfer the contents of each impinger to one
of a series of 25-mL volumetric flasks (if 10 mL of absorbing solution
was used) using small amounts of distilled water for rinse (<5mL). If
10 mL of absorbing solution was used, bring the absorber
solution in each impinger to orginal volume with distilled H2
O and pipet 10-mL portions from each impinger into a series of 25-mL
volumetric flasks. If the color development steps are not to be started
within 12 hours of sampling, store the solutions at 5 deg.
5 deg.C. Calculate the total micrograms SO2 in each solution
as follows:
[GRAPHIC] [TIFF OMITTED] TR31AU93.015
where:
Ca = concentration of SO2 in the standard
atmosphere, [mu]g/m\3\ ;
Os = sampling flow rate, std L/min;
t=sampling time, min;
Va = volume of absorbing solution used for color development
(10 mL); and
Vb = volume of absorbing solution used for sampling, mL.
Add the remaining reagents for color development in the same manner
as in Section 10.2 for static solutions. Calculate a calibration
equation and a calibration factor (Bg) according to Section
10.2, adhering to all the specified criteria.
10.3.2 Calibration Option 2B (24-hour samples): Generate a standard
atmosphere containing approximately 1,050 [mu]g SO2/m\3\ and
calculate the exact concentration according to equation 12. Set up a
series of six absorbers according to Figure 2 and connect to a common
manifold for sampling the standard atmosphere. Be sure that the total
flow rate of the standard exceeds the flow demand at the sample
manifold, with the excess flow vented at atmospheric pressure. The
absorbers are then allowed to sample the atmosphere for varying time
periods to yield solutions containing 0, 0.2, 0.6, 1.0, 1.4, 1.8, and
2.2 [mu]g SO2/mL solution. The sampling times required to
attain these solution concentrations are calculated as follows:
[GRAPHIC] [TIFF OMITTED] TR31AU93.016
where:
t = sampling time, min;
Vb = volume of absorbing solution used for sampling (50 mL);
Cs = desired concentration of SO2 in the absorbing
solution, [mu]g/mL;
Ca = concentration of the standard atmosphere calculated
according to equation 12, [mu]g/m\3\ ; and
Qs = sampling flow rate, std L/min.
At the completion of sampling, bring the absorber solutions to
original volume with distilled water. Pipet a 10-mL portion from each
absorber into one of a series of 25-mL volumetric flasks. If the color
development steps are not to be started within 12 hours of sampling,
store the solutions at 5 deg. 5 deg.C. Add the remaining
reagents for color development in the same manner as in Section 10.2 for
static solutions. Calculate the total [mu]g SO2 in each
standard as follows:
[GRAPHIC] [TIFF OMITTED] TR31AU93.017
where:
Va = volume of absorbing solution used for color development
(10 mL).
All other parameters are defined in equation 14.
Calculate a calibration equation and a calibration factor
(Bt) according to Section 10.2 adhering to all the specified
criteria.
11.0 Sample Preparation and Analysis.
11.1 Sample Preparation. Remove the samples from the shipping
container. If the shipment period exceeded 12 hours from the completion
of sampling, verify that the temperature is below 10 deg.C. Also,
compare the solution level to the temporary level mark on the absorber.
If either the temperature is above 10 deg.C or there was significant
loss (more than 10 mL) of the sample during shipping, make an
appropriate notation in the record and invalidate the sample. Prepare
the samples for analysis as follows:
1. For 30-minute or 1-hour samples: Quantitatively transfer the
entire 10 mL amount of absorbing solution to a 25-mL volumetric flask
and rinse with a small amount (<5 mL) of distilled water.
2. For 24-hour samples: If the volume of the sample is less than the
original 50-mL volume (permanent mark on the absorber), adjust the
volume back to the original volume with distilled water to compensate
for water lost to evaporation during sampling. If the final volume is
greater than the original volume, the volume must be measured using a
graduated cylinder. To analyze, pipet 10 mL
[[Page 23]]
of the solution into a 25-mL volumetric flask.
11.2 Sample Analysis. For each set of determinations, prepare a
reagent blank by adding 10 mL TCM absorbing solution to a 25-mL
volumetric flask, and two control standards containing approximately 5
and 15 [mu]g SO2, respectively. The control standards are
prepared according to Section 10.2 or 10.3. The analysis is carried out
as follows:
1. Allow the sample to stand 20 minutes after the completion of
sampling to allow any ozone to decompose (if applicable).
2. To each 25-mL volumetric flask containing reagent blank, sample,
or control standard, add 1 mL of 0.6% sulfamic acid (Section 8.2.1) and
allow to react for 10 min.
3. Accurately pipet 2 mL of 0.2% formaldehyde solution (Section
8.2.2) and then 5 mL of pararosaniline solution (Section 8.2.13) into
each flask. Start a laboratory timer set at 30 minutes.
4. Bring each flask to volume with recently boiled and cooled
distilled water and mix thoroughly.
5. During the 30 minutes, the solutions must be in a temperature
controlled environment in the range of 20 deg. to 30 deg.C maintained
to 1 deg.C. This temperature must also be within 1 deg.C
of that used during calibration.
6. After 30 minutes and before 60 minutes, determine the corrected
absorbances (equation 10) of each solution at 548 nm using 1-cm optical
path length cells against a distilled water reference (Section 10.1).
(Distilled water is used as a reference instead of the reagent blank
because of the sensitivity of the reagent blank to temperature.)
7. Do not allow the colored solution to stand in the cells because a
film may be deposited. Clean the cells with isopropyl alcohol after use.
8. The reagent blank must be within 0.03 absorbance units of the
intercept of the calibration equation determined in Section 10.
11.3 Absorbance range. If the absorbance of the sample solution
ranges between 1.0 and 2.0, the sample can be diluted 1:1 with a portion
of the reagent blank and the absorbance redetermined within 5 minutes.
Solutions with higher absorbances can be diluted up to sixfold with the
reagent blank in order to obtain scale readings of less than 1.0
absorbance unit. However, it is recommended that a smaller portion (<10
mL) of the original sample be reanalyzed (if possible) if the sample
requires a dilution greater than 1:1.
11.4 Reaqent disposal. All reagents containing mercury compounds
must be stored and disposed of using one of the procedures contained in
Section 13. Until disposal, the discarded solutions can be stored in
closed glass containers and should be left in a fume hood.
12.0 Calculations.
12.1 Calibration Slope, Intercept, and Correlation Coefficient. The
method of least squares is used to calculate a calibration equation in
the form of:
[GRAPHIC] [TIFF OMITTED] TC08NO91.012
where:
y = corrected absorbance,
m = slope, absorbance unit/[mu]g SO2,
x = micrograms of SO2,
b = y intercept (absorbance units).
The slope (m), intercept (b), and correlation coefficient (r) are
calculated as follows:
[GRAPHIC] [TIFF OMITTED] TR31AU93.018
[GRAPHIC] [TIFF OMITTED] TR31AU93.019
[GRAPHIC] [TIFF OMITTED] TR31AU93.020
where n is the number of calibration points.
A data form (Figure 5) is supplied for easily organizing calibration
data when the slope, intercept, and correlation coefficient are
calculated by hand.
12.2 Total Sample Volume. Determine the sampling volume at standard
conditions as follows:
[GRAPHIC] [TIFF OMITTED] TR31AU93.021
where:
Vstd = sampling volume in std L,
Qi = standard flow rate determined at the initiation of
sampling in std L/min,
Qf = standard flow rate determined at the completion of
sampling is std L/min, and
t = total sampling time, min.
12.3 Sulfur Dioxide Concentration. Calculate and report the
concentration of each sample as follows:
[GRAPHIC] [TIFF OMITTED] TR31AU93.022
where:
A = corrected absorbance of the sample solution, from equation (10);
Ao = corrected absorbance of the reagent blank, using
equation (10);
Bx = calibration factor equal to Bs,
Bg, or Bt depending on the calibration procedure
used, the reciprocal of the slope of the calibration equation;
Va = volume of absorber solution analyzed, mL;
Vb = total volume of solution in absorber (see 11.1-2), mL;
and
Vstd = standard air volume sampled, std L (from Section
12.2).
[[Page 24]]
Data Form
[For hand calculations]
----------------------------------------------------------------------------------------------------------------
Absor- bance
Calibration point no. Micro- grams So2 units
----------------------------------------------------------------------------------------------------------------
(x) (y) x2 xy y2
1............................. ................. ................. ................. ................ .....
2............................. ................. ................. ................. ................ .....
3............................. ................. ................. ................. ................ .....
4............................. ................. ................. ................. ................ .....
5............................. ................. ................. ................. ................ .....
6............................. ................. ................. ................. ................ .....
----------------------------------------------------------------------------------------------------------------
[Sigma] x=------ [Sigma] y=------ [Sigma] x\2\=------ [Sigma]xy------
[Sigma]y\2\------
n=------ (number of pairs of coordinates.)
________________________________________________________________________
Figure 5. Data form for hand calculations.
12.4 Control Standards. Calculate the analyzed micrograms of
SO2 in each control standard as follows:
[GRAPHIC] [TIFF OMITTED] TC08NO91.070
where:
Cq = analyzed [mu]g SO2 in each control standard,
A = corrected absorbance of the control standard, and
Ao = corrected absorbance of the reagent blank.
The difference between the true and analyzed values of the control
standards must not be greater than 1 [mu]g. If the difference is greater
than 1 [mu]g, the source of the discrepancy must be identified and
corrected.
12.5 Conversion of [mu]g/m\3\ to ppm (v/v). If desired, the
concentration of sulfur dioxide at reference conditions can be converted
to ppm SO2 (v/v) as follows:
[GRAPHIC] [TIFF OMITTED] TR31AU93.023
13.0 The TCM absorbing solution and any reagents containing mercury
compounds must be treated and disposed of by one of the methods
discussed below. Both methods remove greater than 99.99 percent of the
mercury.
13.1 Disposal of Mercury-Containing Solutions.
13.2 Method for Forming an Amalgam.
1. Place the waste solution in an uncapped vessel in a hood.
2. For each liter of waste solution, add approximately 10 g of
sodium carbonate until neutralization has occurred (NaOH may have to be
used).
3. Following neutralization, add 10 g of granular zinc or magnesium.
4. Stir the solution in a hood for 24 hours. Caution must be
exercised as hydrogen gas is evolved by this treatment process.
5. After 24 hours, allow the solution to stand without stirring to
allow the mercury amalgam (solid black material) to settle to the bottom
of the waste receptacle.
6. Upon settling, decant and discard the supernatant liquid.
7. Quantitatively transfer the solid material to a container and
allow to dry.
8. The solid material can be sent to a mercury reclaiming plant. It
must not be discarded.
13.3 Method Using Aluminum Foil Strips.
1. Place the waste solution in an uncapped vessel in a hood.
2. For each liter of waste solution, add approximately 10 g of
aluminum foil strips. If all the aluminum is consumed and no gas is
evolved, add an additional 10 g of foil. Repeat until the foil is no
longer consumed and allow the gas to evolve for 24 hours.
3. Decant the supernatant liquid and discard.
4. Transfer the elemental mercury that has settled to the bottom of
the vessel to a storage container.
5. The mercury can be sent to a mercury reclaiming plant. It must
not be discarded.
14.0 References for SO2 Method.
1. Quality Assurance Handbook for Air Pollution Measurement Systems,
Volume I, Principles. EPA-600/9-76-005, U.S. Environmental Protection
Agency, Research Triangle Park, NC 27711, 1976.
2. Quality Assurance Handbook for Air Pollution Measurement Systems,
Volume II, Ambient Air Specific Methods. EPA-600/4-77-027a, U.S.
Environmental Protection Agency, Research Triangle Park, NC 27711, 1977.
3. Dasqupta, P. K., and K. B. DeCesare. Stability of Sulfur Dioxide
in Formaldehyde and Its Anomalous Behavior in Tetrachloromercurate (II).
Submitted for publication in Atmospheric Environment, 1982.
4. West, P. W., and G. C. Gaeke. Fixation of Sulfur Dioxide as
Disulfitomercurate (II) and Subsequent Colorimetric Estimation. Anal.
Chem., 28:1816, 1956.
5. Ephraim, F. Inorganic Chemistry. P. C. L. Thorne and E. R.
Roberts, Eds., 5th Edition, Interscience, 1948, p. 562.
6. Lyles, G. R., F. B. Dowling, and V. J. Blanchard. Quantitative
Determination of Formaldehyde in the Parts Per Hundred Million
Concentration Level. J. Air. Poll. Cont. Assoc., Vol. 15(106), 1965.
7. McKee, H. C., R. E. Childers, and O. Saenz, Jr. Collaborative
Study of Reference Method for Determination of Sulfur Dioxide in the
Atmosphere (Pararosaniline Method). EPA-APTD-0903, U.S. Environmental
Protection Agency, Research Triangle Park, NC 27711, September 1971.
8. Urone, P., J. B. Evans, and C. M. Noyes. Tracer Techniques in
Sulfur--Air Pollution Studies Apparatus and Studies of Sulfur Dioxide
Colorimetric and Conductometric Methods. Anal. Chem., 37: 1104, 1965.
[[Page 25]]
9. Bostrom, C. E. The Absorption of Sulfur Dioxide at Low
Concentrations (pphm) Studied by an Isotopic Tracer Method. Intern. J.
Air Water Poll., 9:333, 1965.
10. Scaringelli, F. P., B. E. Saltzman, and S. A. Frey.
Spectrophotometric Determination of Atmospheric Sulfur Dioxide. Anal.
Chem., 39: 1709, 1967.
11. Pate, J. B., B. E. Ammons, G. A. Swanson, and J. P. Lodge, Jr.
Nitrite Interference in Spectrophotometric Determination of Atmospheric
Sulfur Dioxide. Anal. Chem., 37:942, 1965.
12. Zurlo, N., and A. M. Griffini. Measurement of the Sulfur Dioxide
Content of the Air in the Presence of Oxides of Nitrogen and Heavy
Metals. Medicina Lavoro, 53:330, 1962.
13. Rehme, K. A., and F. P. Scaringelli. Effect of Ammonia on the
Spectrophotometric Determination of Atmospheric Concentrations of Sulfur
Dioxide. Anal. Chem., 47:2474, 1975.
14. McCoy, R. A., D. E. Camann, and H. C. McKee. Collaborative Study
of Reference Method for Determination of Sulfur Dioxide in the
Atmosphere (Pararosaniline Method) (24-Hour Sampling). EPA-650/4-74-027,
U.S. Environmental Protection Agency, Research Triangle Park, NC 27711,
December 1973.
15. Fuerst, R. G. Improved Temperature Stability of Sulfur Dioxide
Samples Collected by the Federal Reference Method. EPA-600/4-78-018,
U.S. Environmental Protection Agency, Research Triangle Park, NC 27711,
April 1978.
16. Scaringelli, F. P., L. Elfers, D. Norris, and S. Hochheiser.
Enhanced Stability of Sulfur Dioxide in Solution. Anal. Chem., 42:1818,
1970.
17. Martin, B. E. Sulfur Dioxide Bubbler Temperature Study. EPA-600/
4-77-040, U.S. Environmental Protection Agency, Research Triangle Park,
NC 27711, August 1977.
18. American Society for Testing and Materials. ASTM Standards,
Water; Atmospheric Analysis. Part 23. Philadelphia, PA, October 1968, p.
226.
19. O'Keeffe, A. E., and G. C. Ortman. Primary Standards for Trace
Gas Analysis. Anal. Chem., 38:760, 1966.
20. Scaringelli, F. P., S. A. Frey, and B. E. Saltzman. Evaluation
of Teflon Permeation Tubes for Use with Sulfur Dioxide. Amer. Ind.
Hygiene Assoc. J., 28:260, 1967.
21. Scaringelli, F. P., A. E. O'Keeffe, E. Rosenberg, and J. P.
Bell, Preparation of Known Concentrations of Gases and Vapors With
Permeation Devices Calibrated Gravimetrically. Anal. Chem., 42:871,
1970.
22. A Procedure for Establishing Traceability of Gas Mixtures to
Certain National Bureau of Standards Standard Reference Materials. EPA-
600/7-81-010, U.S. Environmental Protection Agency, Environmental
Monitoring Systems Laboratory (MD-77), Research Triangle Park, NC 27711,
January 1981.
[47 FR 54899, Dec. 6, 1982; 48 FR 17355, Apr. 22, 1983]
Appendix B to Part 50--Reference Method for the Determination of
Suspended Particulate Matter in the Atmosphere (High-Volume Method)
1.0 Applicability.
1.1 This method provides a measurement of the mass concentration of
total suspended particulate matter (TSP) in ambient air for determining
compliance with the primary and secondary national ambient air quality
standards for particulate matter as specified in Sec. 50.6 and Sec. 50.7
of this chapter. The measurement process is nondestructive, and the size
of the sample collected is usually adequate for subsequent chemical
analysis. Quality assurance procedures and guidance are provided in part
58, appendixes A and B, of this chapter and in References 1 and 2.
2.0 Principle.
2.1 An air sampler, properly located at the measurement site, draws
a measured quantity of ambient air into a covered housing and through a
filter during a 24-hr (nominal) sampling period. The sampler flow rate
and the geometry of the shelter favor the collection of particles up to
25-50 [mu]m (aerodynamic diameter), depending on wind speed and
direction.(3) The filters used are specified to have a minimum
collection efficiency of 99 percent for 0.3 [mu]m (DOP) particles (see
Section 7.1.4).
2.2 The filter is weighed (after moisture equilibration) before and
after use to determine the net weight (mass) gain. The total volume of
air sampled, corrected to EPA standard conditions (25 deg.C, 760 mm Hg
[101 kPa]), is determined from the measured flow rate and the sampling
time. The concentration of total suspended particulate matter in the
ambient air is computed as the mass of collected particles divided by
the volume of air sampled, corrected to standard conditions, and is
expressed in micrograms per standard cubic meter ([mu]g/std m\3\). For
samples collected at temperatures and pressures significantly different
than standard conditions, these corrected concentrations may differ
substantially from actual concentrations (micrograms per actual cubic
meter), particularly at high elevations. The actual particulate matter
concentration can be calculated from the corrected concentration using
the actual temperature and pressure during the sampling period.
3.0 Range.
3.1 The approximate concentration range of the method is 2 to 750
[mu]g/std m3. The upper limit is determined by the point at
which the sampler can no longer maintain the specified
[[Page 26]]
flow rate due to the increased pressure drop of the loaded filter. This
point is affected by particle size distribution, moisture content of the
collected particles, and variability from filter to filter, among other
things. The lower limit is determined by the sensitivity of the balance
(see Section 7.10) and by inherent sources of error (see Section 6).
3.2 At wind speeds between 1.3 and 4.5 m/sec (3 and 10 mph), the
high-volume air sampler has been found to collect particles up to 25 to
50 [mu]m, depending on wind speed and direction.(3) For the filter
specified in Section 7.1, there is effectively no lower limit on the
particle size collected.
4.0 Precision.
4.1 Based upon collaborative testing, the relative standard
deviation (coefficient of variation) for single analyst precision
(repeatability) of the method is 3.0 percent. The corresponding value
for interlaboratory precision (reproducibility) is 3.7 percent.(4)
5.0 Accuracy.
5.1 The absolute accuracy of the method is undefined because of the
complex nature of atmospheric particulate matter and the difficulty in
determining the ``true'' particulate matter concentration. This method
provides a measure of particulate matter concentration suitable for the
purpose specified under Section 1.0, Applicability.
6.0 Inherent Sources of Error.
6.1 Airflow variation. The weight of material collected on the
filter represents the (integrated) sum of the product of the
instantaneous flow rate times the instantaneous particle concentration.
Therefore, dividing this weight by the average flow rate over the
sampling period yields the true particulate matter concentration only
when the flow rate is constant over the period. The error resulting from
a nonconstant flow rate depends on the magnitude of the instantaneous
changes in the flow rate and in the particulate matter concentration.
Normally, such errors are not large, but they can be greatly reduced by
equipping the sampler with an automatic flow controlling mechanism that
maintains constant flow during the sampling period. Use of a contant
flow controller is recommended.*
---------------------------------------------------------------------------
*At elevated altitudes, the effectiveness of automatic flow
controllers may be reduced because of a reduction in the maximum sampler
flow.
---------------------------------------------------------------------------
6.2 Air volume measurement. If the flow rate changes substantially
or nonuniformly during the sampling period, appreciable error in the
estimated air volume may result from using the average of the
presampling and postsampling flow rates. Greater air volume measurement
accuracy may be achieved by (1) equipping the sampler with a flow
controlling mechanism that maintains constant air flow during the
sampling period,* (2) using a calibrated, continuous flow rate recording
device to record the actual flow rate during the samping period and
integrating the flow rate over the period, or (3) any other means that
will accurately measure the total air volume sampled during the sampling
period. Use of a continuous flow recorder is recommended, particularly
if the sampler is not equipped with a constant flow controller.
6.3 Loss of volatiles. Volatile particles collected on the filter
may be lost during subsequent sampling or during shipment and/or storage
of the filter prior to the postsampling weighing.(5) Although such
losses are largely unavoidable, the filter should be reweighed as soon
after sampling as practical.
6.4 Artifact particulate matter. Artifact particulate matter can be
formed on the surface of alkaline glass fiber filters by oxidation of
acid gases in the sample air, resulting in a higher than true TSP
determination.(6 7) This effect usually occurs early in the sample
period and is a function of the filter pH and the presence of acid
gases. It is generally believed to account for only a small percentage
of the filter weight gain, but the effect may become more significant
where relatively small particulate weights are collected.
6.5 Humidity. Glass fiber filters are comparatively insensitive to
changes in relative humidity, but collected particulate matter can be
hygroscopic.(8) The moisture conditioning procedure minimizes but may
not completely eliminate error due to moisture.
6.6 Filter handling. Careful handling of the filter between the
presampling and postsampling weighings is necessary to avoid errors due
to loss of fibers or particles from the filter. A filter paper cartridge
or cassette used to protect the filter can minimize handling errors.
(See Reference 2, Section 2).
6.7 Nonsampled particulate matter. Particulate matter may be
deposited on the filter by wind during periods when the sampler is
inoperative. (9) It is recommended that errors from this source be
minimized by an automatic mechanical device that keeps the filter
covered during nonsampling periods, or by timely installation and
retrieval of filters to minimize the nonsampling periods prior to and
following operation.
6.8 Timing errors. Samplers are normally controlled by clock timers
set to start and stop the sampler at midnight. Errors in the nominal
1,440-min sampling period may result from a power interruption during
the sampling period or from a discrepancy between the start or stop time
recorded on the filter information record and the actual start or stop
time of the sampler. Such discrepancies may be caused by (1) poor
resolution of the timer set-points, (2) timer error due to power
interruption, (3) missetting of
[[Page 27]]
the timer, or (4) timer malfunction. In general, digital electronic
timers have much better set-point resolution than mechanical timers, but
require a battery backup system to maintain continuity of operation
after a power interruption. A continuous flow recorder or elapsed time
meter provides an indication of the sampler run-time, as well as
indication of any power interruption during the sampling period and is
therefore recommended.
6.9 Recirculation of sampler exhaust. Under stagnant wind
conditions, sampler exhaust air can be resampled. This effect does not
appear to affect the TSP measurement substantially, but may result in
increased carbon and copper in the collected sample. (10) This problem
can be reduced by ducting the exhaust air well away, preferably
downwind, from the sampler.
7.0 Apparatus.
(See References 1 and 2 for quality assurance information.)
Note: Samplers purchased prior to the effective date of this
amendment are not subject to specifications preceded by ([dagger]).
7.1 Filter. (Filters supplied by the Environmental Protection Agency
can be assumed to meet the following criteria. Additional specifications
are required if the sample is to be analyzed chemically.)
7.1.1 Size: 20.3 0.2 x 25.4 0.2 cm
(nominal 8 x 10 in).
7.1.2 Nominal exposed area: 406.5 cm\2\ (63 in\2\).
7.1.3. Material: Glass fiber or other relatively inert,
nonhygroscopic material. (8)
7.1.4 Collection efficiency: 99 percent minimum as measured by the
DOP test (ASTM-2986) for particles of 0.3 [mu]m diameter.
7.1.5 Recommended pressure drop range: 42-54 mm Hg (5.6-7.2 kPa) at
a flow rate of 1.5 std m\3\/min through the nominal exposed area.
7.1.6 pH: 6 to 10. (11)
7.1.7 Integrity: 2.4 mg maximum weight loss. (11)
7.1.8 Pinholes: None.
7.1.9 Tear strength: 500 g minimum for 20 mm wide strip cut from
filter in weakest dimension. (See ASTM Test D828-60).
7.1.10 Brittleness: No cracks or material separations after single
lengthwise crease.
7.2 Sampler. The air sampler shall provide means for drawing the air
sample, via reduced pressure, through the filter at a uniform face
velocity.
7.2.1 The sampler shall have suitable means to:
a. Hold and seal the filter to the sampler housing.
b. Allow the filter to be changed conveniently.
c. Preclude leaks that would cause error in the measurement of the
air volume passing through the filter.
d. ([dagger]) Manually adjust the flow rate to accommodate
variations in filter pressure drop and site line voltage and altitude.
The adjustment may be accomplished by an automatic flow controller or by
a manual flow adjustment device. Any manual adjustment device must be
designed with positive detents or other means to avoid unintentional
changes in the setting.
---------------------------------------------------------------------------
([dagger]) See note at beginning of Section 7 of this appendix.
---------------------------------------------------------------------------
7.2.2 Minimum sample flow rate, heavily loaded filter: 1.1 m\3\/min
(39 ft\3\/min).[Dagger]
---------------------------------------------------------------------------
[Dagger] These specifications are in actual air volume units; to
convert to EPA standard air volume units, multiply the specifications by
(Pb/Pstd)(298/T) where Pb and T are the
barometric pressure in mm Hg (or kPa) and the temperature in K at the
sampler, and Pstd is 760 mm Hg (or 101 kPa).
---------------------------------------------------------------------------
7.2.3 Maximum sample flow rate, clean filter: 1.7 m\3\/min (60
ft\3\/min).[Dagger]
7.2.4 Blower Motor: The motor must be capable of continuous
operation for 24-hr periods.
7.3 Sampler shelter.
7.3.1 The sampler shelter shall:
a. Maintain the filter in a horizontal position at least 1 m above
the sampler supporting surface so that sample air is drawn downward
through the filter.
b. Be rectangular in shape with a gabled roof, similar to the design
shown in Figure 1.
c. Cover and protect the filter and sampler from precipitation and
other weather.
d. Discharge exhaust air at least 40 cm from the sample air inlet.
e. Be designed to minimize the collection of dust from the
supporting surface by incorporating a baffle between the exhaust outlet
and the supporting surface.
7.3.2 The sampler cover or roof shall overhang the sampler housing
somewhat, as shown in Figure 1, and shall be mounted so as to form an
air inlet gap between the cover and the sampler housing walls.
[dagger] This sample air inlet should be approximately
uniform on all sides of the sampler. [dagger] The area of the
sample air inlet must be sized to provide an effective particle capture
air velocity of between 20 and 35 cm/sec at the recommended operational
flow rate. The capture velocity is the sample air flow rate divided by
the inlet area measured in a horizontal plane at the lower edge of the
cover. [dagger] Ideally, the inlet area and operational flow
rate should be selected to obtain a capture air velocity of 25
2 cm/sec.
7.4 Flow rate measurement devices.
7.4.1 The sampler shall incorporate a flow rate measurement device
capable of indicating the total sampler flow rate. Two common types of
flow indicators covered in the calibration procedure are (1) an
electronic mass flowmeter and (2) an orifice or orifices
[[Page 28]]
located in the sample air stream together with a suitable pressure
indicator such as a manometer, or aneroid pressure gauge. A pressure
recorder may be used with an orifice to provide a continuous record of
the flow. Other types of flow indicators (including rotameters) having
comparable precision and accuracy are also acceptable.
7.4.2 [dagger] The flow rate measurement device must be capable of
being calibrated and read in units corresponding to a flow rate which is
readable to the nearest 0.02 std m\3\/min over the range 1.0 to 1.8 std
m\3\/min.
7.5 Thermometer, to indicate the approximate air temperature at the
flow rate measurement orifice, when temperature corrections are used.
7.5.1 Range: -40 deg. to +50 deg.C (223-323 K).
7.5.2 Resolution: 2 deg.C (2 K).
7.6 Barometer, to indicate barometric pressure at the flow rate
measurement orifice, when pressure corrections are used.
7.6.1 Range: 500 to 800 mm Hg (66-106 kPa).
7.6.2 Resolution: 5 mm Hg (0.67 kPa).
7.7 Timing/control device.
7.7.1 The timing device must be capable of starting and stopping the
sampler to obtain an elapsed run-time of 24 hr 1 hr (1,440
60 min).
7.7.2 Accuracy of time setting: 30 min, or better. (See
Section 6.8).
7.8 Flow rate transfer standard, traceable to a primary standard.
(See Section 9.2.)
7.8.1 Approximate range: 1.0 to 1.8 m\3\/min.
7.8.2 Resolution: 0.02 m\3\/min.
7.8.3 Reproducibility: 2 percent (2 times coefficient of
variation) over normal ranges of ambient temperature and pressure for
the stated flow rate range. (See Reference 2, Section 2.)
7.8.4 Maximum pressure drop at 1.7 std m\3\/min; 50 cm H2 O (5 kPa).
7.8.5 The flow rate transfer standard must connect without leaks to
the inlet of the sampler and measure the flow rate of the total air
sample.
7.8.6 The flow rate transfer standard must include a means to vary
the sampler flow rate over the range of 1.0 to 1.8 m\3\/min (35-64
ft\3\/min) by introducing various levels of flow resistance between the
sampler and the transfer standard inlet.
7.8.7 The conventional type of flow transfer standard consists of:
An orifice unit with adapter that connects to the inlet of the sampler,
a manometer or other device to measure orifice pressure drop, a means to
vary the flow through the sampler unit, a thermometer to measure the
ambient temperature, and a barometer to measure ambient pressure. Two
such devices are shown in Figures 2a and 2b. Figure 2a shows multiple
fixed resistance plates, which necessitate disassembly of the unit each
time the flow resistance is changed. A preferable design, illustrated in
Figure 2b, has a variable flow restriction that can be adjusted
externally without disassembly of the unit. Use of a conventional,
orifice-type transfer standard is assumed in the calibration procedure
(Section 9). However, the use of other types of transfer standards
meeting the above specifications, such as the one shown in Figure 2c,
may be approved; see the note following Section 9.1.
7.9 Filter conditioning environment
7.9.1 Controlled temperature: between 15 deg. and 30 deg.C with
less than 3 deg.C variation during equilibration period.
7.9.2 Controlled humidity: Less than 50 percent relative humidity,
constant within 5 percent.
7.10 Analytical balance.
7.10.1 Sensitivity: 0.1 mg.
7.10.2 Weighing chamber designed to accept an unfolded 20.3x25.4 cm
(8x10 in) filter.
7.11 Area light source, similar to X-ray film viewer, to backlight
filters for visual inspection.
7.12 Numbering device, capable of printing identification numbers on
the filters before they are placed in the filter conditioning
environment, if not numbered by the supplier.
8.0 Procedure.
(See References 1 and 2 for quality assurance information.)
8.1 Number each filter, if not already numbered, near its edge with
a unique identification number.
8.2 Backlight each filter and inspect for pinholes, particles, and
other imperfections; filters with visible imperfections must not be
used.
8.3 Equilibrate each filter in the conditioning environment for at
least 24-hr.
8.4 Following equilibration, weigh each filter to the nearest
milligram and record this tare weight (Wi) with the filter
identification number.
8.5 Do not bend or fold the filter before collection of the sample.
8.6 Open the shelter and install a numbered, preweighed filter in
the sampler, following the sampler manufacturer's instructions. During
inclement weather, precautions must be taken while changing filters to
prevent damage to the clean filter and loss of sample from or damage to
the exposed filter. Filter cassettes that can be loaded and unloaded in
the laboratory may be used to minimize this problem (See Section 6.6).
8.7 Close the shelter and run the sampler for at least 5 min to
establish run-temperature conditions.
8.8 Record the flow indicator reading and, if needed, the barometric
pressure (P 3) and the ambient temperature (T 3)
see NOTE following step 8.12). Stop the sampler. Determine the sampler
flow rate (see Section 10.1); if it is outside the acceptable range (1.1
to 1.7 m\3\/min [39-60 ft\3\/min]), use a different filter, or adjust
the sampler flow rate. Warning: Substantial flow adjustments may affect
the
[[Page 29]]
calibration of the orifice-type flow indicators and may necessitate
recalibration.
8.9 Record the sampler identification information (filter number,
site location or identification number, sample date, and starting time).
8.10 Set the timer to start and stop the sampler such that the
sampler runs 24-hrs, from midnight to midnight (local time).
8.11 As soon as practical following the sampling period, run the
sampler for at least 5 min to again establish run-temperature
conditions.
8.12 Record the flow indicator reading and, if needed, the
barometric pressure (P 3) and the ambient temperature (T
3).
Note: No onsite pressure or temperature measurements are necessary
if the sampler flow indicator does not require pressure or temperature
corrections (e.g., a mass flowmeter) or if average barometric pressure
and seasonal average temperature for the site are incorporated into the
sampler calibration (see step 9.3.9). For individual pressure and
temperature corrections, the ambient pressure and temperature can be
obtained by onsite measurements or from a nearby weather station.
Barometric pressure readings obtained from airports must be station
pressure, not corrected to sea level, and may need to be corrected for
differences in elevation between the sampler site and the airport. For
samplers having flow recorders but not constant flow controllers, the
average temperature and pressure at the site during the sampling period
should be estimated from weather bureau or other available data.
8.13 Stop the sampler and carefully remove the filter, following the
sampler manufacturer's instructions. Touch only the outer edges of the
filter. See the precautions in step 8.6.
8.14 Fold the filter in half lengthwise so that only surfaces with
collected particulate matter are in contact and place it in the filter
holder (glassine envelope or manila folder).
8.15 Record the ending time or elapsed time on the filter
information record, either from the stop set-point time, from an elapsed
time indicator, or from a continuous flow record. The sample period must
be 1,440 60 min. for a valid sample.
8.16 Record on the filter information record any other factors, such
as meteorological conditions, construction activity, fires or dust
storms, etc., that might be pertinent to the measurement. If the sample
is known to be defective, void it at this time.
8.17 Equilibrate the exposed filter in the conditioning environment
for at least 24-hrs.
8.18 Immediately after equilibration, reweigh the filter to the
nearest milligram and record the gross weight with the filter
identification number. See Section 10 for TSP concentration
calculations.
9.0 Calibration.
9.1 Calibration of the high volume sampler's flow indicating or
control device is necessary to establish traceability of the field
measurement to a primary standard via a flow rate transfer standard.
Figure 3a illustrates the certification of the flow rate transfer
standard and Figure 3b illustrates its use in calibrating a sampler flow
indicator. Determination of the corrected flow rate from the sampler
flow indicator, illustrated in Figure 3c, is addressed in Section 10.1
Note: The following calibration procedure applies to a conventional
orifice-type flow transfer standard and an orifice-type flow indicator
in the sampler (the most common types). For samplers using a pressure
recorder having a square-root scale, 3 other acceptable calibration
procedures are provided in Reference 12. Other types of transfer
standards may be used if the manufacturer or user provides an
appropriately modified calibration procedure that has been approved by
EPA under Section 2.8 of appendix C to part 58 of this chapter.
9.2 Certification of the flow rate transfer standard.
9.2.1 Equipment required: Positive displacement standard volume
meter traceable to the National Bureau of Standards (such as a Roots
meter or equivalent), stop-watch, manometer, thermometer, and barometer.
9.2.2 Connect the flow rate transfer standard to the inlet of the
standard volume meter. Connect the manometer to measure the pressure at
the inlet of the standard volume meter. Connect the orifice manometer to
the pressure tap on the transfer standard. Connect a high-volume air
pump (such as a high-volume sampler blower) to the outlet side of the
standard volume meter. See Figure 3a.
9.2.3 Check for leaks by temporarily clamping both manometer lines
(to avoid fluid loss) and blocking the orifice with a large-diameter
rubber stopper, wide cellophane tape, or other suitable means. Start the
high-volume air pump and note any change in the standard volume meter
reading. The reading should remain constant. If the reading changes,
locate any leaks by listening for a whistling sound and/or retightening
all connections, making sure that all gaskets are properly installed.
9.2.4 After satisfactorily completing the leak check as described
above, unclamp both manometer lines and zero both manometers.
9.2.5 Achieve the appropriate flow rate through the system, either
by means of the variable flow resistance in the transfer standard or by
varying the voltage to the air pump. (Use of resistance plates as shown
in Figure 1a is discouraged because the above leak check must be
repeated each time a new resistance plate is installed.) At least five
different but constant flow rates, evenly distributed, with at least
three in the specified
[[Page 30]]
flow rate interval (1.1 to 1.7 m\3\/min [39-60 ft \3\/min]), are
required.
9.2.6 Measure and record the certification data on a form similar to
the one illustrated in Figure 4 according to the following steps.
9.2.7 Observe the barometric pressure and record as P1
(item 8 in Figure 4).
9.2.8 Read the ambient temperature in the vicinity of the standard
volume meter and record it as T1 (item 9 in Figure 4).
9.2.9 Start the blower motor, adjust the flow, and allow the system
to run for at least 1 min for a constant motor speed to be attained.
9.2.10 Observe the standard volume meter reading and simultaneously
start a stopwatch. Record the initial meter reading (Vi) in
column 1 of Figure 4.
9.2.11 Maintain this constant flow rate until at least 3 m\3\ of air
have passed through the standard volume meter. Record the standard
volume meter inlet pressure manometer reading as [Delta]P (column 5 in
Figure 4), and the orifice manometer reading as [Delta]H (column 7 in
Figure 4). Be sure to indicate the correct units of measurement.
9.2.12 After at least 3 m\3\ of air have passed through the system,
observe the standard volume meter reading while simultaneously stopping
the stopwatch. Record the final meter reading (Vf) in column
2 and the elapsed time (t) in column 3 of Figure 4.
9.2.13 Calculate the volume measured by the standard volume meter at
meter conditions of temperature and pressures as
Vm=Vf-Vi. Record in column 4 of Figure
4.
9.2.14 Correct this volume to standard volume (std m\3\) as follows:
[GRAPHIC] [TIFF OMITTED] TR31AU93.024
where:
Vstd = standard volume, std m\3\;
Vm = actual volume measured by the standard volume meter;
P1 = barometric pressure during calibration, mm Hg or kPa;
[Delta]P = differential pressure at inlet to volume meter, mm Hg or kPa;
Pstd = 760 mm Hg or 101 kPa;
Tstd = 298 K;
T1 = ambient temperature during calibration, K.
Calculate the standard flow rate (std m\3\/min) as follows:
[GRAPHIC] [TIFF OMITTED] TC08NO91.013
where:
Qstd = standard volumetric flow rate, std m\3\/min
t = elapsed time, minutes.
Record Qstd to the nearest 0.01 std m\3\/min in column 6
of Figure 4.
9.2.15 Repeat steps 9.2.9 through 9.2.14 for at least four
additional constant flow rates, evenly spaced over the approximate range
of 1.0 to 1.8 std m\3\/min (35-64 ft\3\/min).
9.2.16 For each flow, compute
[radic][Delta][Delta]H (P1/Pstd)(298/
T1)
(column 7a of Figure 4) and plot these value against Qstd as
shown in Figure 3a. Be sure to use consistent units (mm Hg or kPa) for
barometric pressure. Draw the orifice transfer standard certification
curve or calculate the linear least squares slope (m) and intercept (b)
of the certification curve:
[radic][Delta][Delta]H (P1/Pstd)(298/
T1)
=mQstd+b. See Figures 3 and 4. A certification graph should
be readable to 0.02 std m\3\/min.
9.2.17 Recalibrate the transfer standard annually or as required by
applicable quality control procedures. (See Reference 2.)
9.3 Calibration of sampler flow indicator.
Note: For samplers equipped with a flow controlling device, the flow
controller must be disabled to allow flow changes during calibration of
the sampler's flow indicator, or the alternate calibration of the flow
controller given in 9.4 may be used. For samplers using an orifice-type
flow indicator downstream of the motor, do not vary the flow rate by
adjusting the voltage or power supplied to the sampler.
9.3.1 A form similar to the one illustrated in Figure 5 should be
used to record the calibration data.
9.3.2 Connect the transfer standard to the inlet of the sampler.
Connect the orifice manometer to the orifice pressure tap, as
illustrated in Figure 3b. Make sure there are no leaks between the
orifice unit and the sampler.
9.3.3 Operate the sampler for at least 5 minutes to establish
thermal equilibrium prior to the calibration.
9.3.4 Measure and record the ambient temperature, T2, and
the barometric pressure, P2, during calibration.
9.3.5 Adjust the variable resistance or, if applicable, insert the
appropriate resistance plate (or no plate) to achieve the desired flow
rate.
9.3.6 Let the sampler run for at least 2 min to re-establish the
run-temperature conditions. Read and record the pressure drop across the
orifice ([Delta]H) and the sampler flow rate indication (I) in the
appropriate columns of Figure 5.
9.3.7 Calculate [radic][Delta][Delta]H(P2/
Pstd)(298/T2) and determine the flow rate at
standard conditions (Qstd) either graphically from the
certification curve or by calculating Qstd from the least
square slope and intercept of the transfer standard's transposed
certification curve: Qstd=1/m [radic][Delta]H(P2/
Pstd)(298/T2)-b. Record the value of
Qstd on Figure 5.
[[Page 31]]
9.3.8 Repeat steps 9.3.5, 9.3.6, and 9.3.7 for several additional
flow rates distributed over a range that includes 1.1 to 1.7 std m\3\/
min.
9.3.9 Determine the calibration curve by plotting values of the
appropriate expression involving I, selected from table 1, against
Qstd. The choice of expression from table 1 depends on the
flow rate measurement device used (see Section 7.4.1) and also on
whether the calibration curve is to incorporate geographic average
barometric pressure (Pa) and seasonal average temperature
(Ta) for the site to approximate actual pressure and
temperature. Where Pa and Ta can be determined for
a site for a seasonal period such that the actual barometric pressure
and temperature at the site do not vary by more than 60 mm
Hg (8 kPa) from Pa or 15 deg.C from
Ta, respectively, then using Pa and Ta
avoids the need for subsequent pressure and temperature calculation when
the sampler is used. The geographic average barometric pressure
(Pa) may be estimated from an altitude-pressure table or by
making an (approximate) elevation correction of -26 mm Hg (-3.46 kPa)
for each 305 m (1,000 ft) above sea level (760 mm Hg or 101 kPa). The
seasonal average temperature (Ta) may be estimated from
weather station or other records. Be sure to use consistent units (mm Hg
or kPa) for barometric pressure.
9.3.10 Draw the sampler calibration curve or calculate the linear
least squares slope (m), intercept (b), and correlation coefficient of
the calibration curve: [Expression from table 1]= mQstd+b.
See Figures 3 and 5. Calibration curves should be readable to 0.02 std
m\3\/min.
9.3.11 For a sampler equipped with a flow controller, the flow
controlling mechanism should be re-enabled and set to a flow near the
lower flow limit to allow maximum control range. The sample flow rate
should be verified at this time with a clean filter installed. Then add
two or more filters to the sampler to see if the flow controller
maintains a constant flow; this is particularly important at high
altitudes where the range of the flow controller may be reduced.
9.4 Alternate calibration of flow-controlled samplers. A flow-
controlled sampler may be calibrated solely at its controlled flow rate,
provided that previous operating history of the sampler demonstrates
that the flow rate is stable and reliable. In this case, the flow
indicator may remain uncalibrated but should be used to indicate any
relative change between initial and final flows, and the sampler should
be recalibrated more often to minimize potential loss of samples because
of controller malfunction.
9.4.1 Set the flow controller for a flow near the lower limit of the
flow range to allow maximum control range.
9.4.2 Install a clean filter in the sampler and carry out steps
9.3.2, 9.3.3, 9.3.4, 9.3.6, and 9.3.7.
9.4.3 Following calibration, add one or two additional clean filters
to the sampler, reconnect the transfer standard, and operate the sampler
to verify that the controller maintains the same calibrated flow rate;
this is particularly important at high altitudes where the flow control
range may be reduced.
[[Page 32]]
10.0 Calculations of TSP Concentration.
10.1 Determine the average sampler flow rate during the sampling
period according to either 10.1.1 or 10.1.2 below.
10.1.1 For a sampler without a continuous flow recorder, determine
the appropriate expression to be used from table 2 corresponding to the
one from table 1 used in step 9.3.9. Using this appropriate expression,
determine Qstd for the initial flow rate from the sampler
calibration curve, either graphically or from the transposed regression
equation:
Qstd =
1/m ([Appropriate expression from table 2]-b)
Similarly, determine Qstd from the final flow reading, and
calculate the average flow Qstd as one-half the sum of the
initial and final flow rates.
10.1.2 For a sampler with a continuous flow recorder, determine the
average flow rate device reading, I, for the period. Determine the
appropriate expression from table 2 corresponding to the one from table
1 used in step 9.3.9. Then using this expression and the average flow
rate reading, determine Qstd from the sampler calibration
curve, either graphically or from the transposed regression equation:
Qstd =
1/m ([Appropriate expression from table 2]-b)
If the trace shows substantial flow change during the sampling
period, greater accuracy may be achieved by dividing the sampling period
into intervals and calculating an average reading before determining
Qstd.
10.2 Calculate the total air volume sampled as:
V-Qstdx t
where:
V = total air volume sampled, in standard volume units, std m\3\/;
Qstd = average standard flow rate, std m\3\/min;
t = sampling time, min.
10.3 Calculate and report the particulate matter concentration as:
[GRAPHIC] [TIFF OMITTED] TR31AU93.025
where:
TSP = mass concentration of total suspended particulate matter, [mu]g/
std m\3\;
Wi = initial weight of clean filter, g;
Wf = final weight of exposed filter, g;
V = air volume sampled, converted to standard conditions, std m\3\,
10\6\ = conversion of g to [mu]g.
10.4 If desired, the actual particulate matter concentration (see
Section 2.2) can be calculated as follows:
(TSP)a=TSP (P3/Pstd)(298/T3)
where:
(TSP)a = actual concentration at field conditions, [mu]g/
m\3\;
[[Page 33]]
TSP = concentration at standard conditions, [mu]g/std m\3\;
P3 = average barometric pressure during sampling period, mm
Hg;
Pstd = 760 mn Hg (or 101 kPa);
T3 = average ambient temperature during sampling period, K.
11.0 References.
1. Quality Assurance Handbook for Air Pollution Measurement Systems,
Volume I, Principles. EPA-600/9-76-005, U.S. Environmental Protection
Agency, Research Triangle Park, NC 27711, 1976.
2. Quality Assurance Handbook for Air Pollution Measurement Systems,
Volume II, Ambient Air Specific Methods. EPA-600/4-77-027a, U.S.
Environmental Protection Agency, Research Triangle Park, NC 27711, 1977.
3. Wedding, J. B., A. R. McFarland, and J. E. Cernak. Large Particle
Collection Characteristics of Ambient Aerosol Samplers. Environ. Sci.
Technol. 11:387-390, 1977.
4. McKee, H. C., et al. Collaborative Testing of Methods to Measure
Air Pollutants, I. The High-Volume Method for Suspended Particulate
Matter. J. Air Poll. Cont. Assoc., 22 (342), 1972.
5. Clement, R. E., and F. W. Karasek. Sample Composition Changes in
Sampling and Analysis of Organic Compounds in Aerosols. The Intern. J.
Environ. Anal. Chem., 7:109, 1979.
6. Lee, R. E., Jr., and J. Wagman. A Sampling Anomaly in the
Determination of Atmospheric Sulfuric Concentration. Am. Ind. Hygiene
Assoc. J., 27:266, 1966.
7. Appel, B. R., et al. Interference Effects in Sampling Particulate
Nitrate in Ambient Air. Atmospheric Environment, 13:319, 1979.
8. Tierney, G. P., and W. D. Conner. Hygroscopic Effects on Weight
Determinations of Particulates Collected on Glass-Fiber Filters. Am.
Ind. Hygiene Assoc. J., 28:363, 1967.
9. Chahal, H. S., and D. J. Romano. High-Volume Sampling Effect of
Windborne Particulate Matter Deposited During Idle Periods. J. Air Poll.
Cont. Assoc., Vol. 26 (885), 1976.
10. Patterson, R. K. Aerosol Contamination from High-Volume Sampler
Exhaust. J. Air Poll. Cont. Assoc., Vol. 30 (169), 1980.
11. EPA Test Procedures for Determining pH and Integrity of High-
Volume Air Filters. QAD/M-80.01. Available from the Methods
Standardization Branch, Quality Assurance Division, Environmental
Monitoring Systems Laboratory (MD-77), U.S. Environmental Protection
Agency, Research Triangle Park, NC 27711, 1980.
12. Smith, F., P. S. Wohlschlegel, R. S. C. Rogers, and D. J.
Mulligan. Investigation of Flow Rate Calibration Procedures Associated
with the High-Volume Method for Determination of Suspended Particulates.
EPA-600/4-78-047, U.S. Environmental Protection Agency, Research
Triangle Park, NC, June 1978.
[[Page 34]]
[[Page 35]]
[[Page 36]]
[[Page 37]]
[47 FR 54912, Dec. 6, 1982; 48 FR 17355, Apr. 22, 1983]
Appendix C to Part 50--Measurement Principle and Calibration Procedure
for the Measurement of Carbon Monoxide in the Atmosphere (Non-Dispersive
Infrared Photometry)
Measurement Principle
1. Measurements are based on the absorption of infrared radiation by
carbon monoxide (CO) in a non-dispersive photometer. Infrared energy
from a source is passed through a cell containing the gas sample to be
analyzed, and the quantitative absorption of energy by CO in the sample
cell is measured by a suitable detector. The photometer is sensitized to
CO by employing CO gas in either the detector or in a filter cell in the
optical path, thereby limiting the measured absorption to one or more of
the characteristic wavelengths at which CO strongly absorbs. Optical
filters or other means may
[[Page 38]]
also be used to limit sensitivity of the photometer to a narrow band of
interest. Various schemes may be used to provide a suitable zero
reference for the photometer. The measured absorption is converted to an
electrical output signal, which is related to the concentration of CO in
the measurement cell.
2. An analyzer based on this principle will be considered a
reference method only if it has been designated as a reference method in
accordance with part 53 of this chapter.
3. Sampling considerations.
The use of a particle filter on the sample inlet line of an NDIR CO
analyzer is optional and left to the discretion of the user or the
manufacturer. Use of filter should depend on the analyzer's
susceptibility to interference, malfunction, or damage due to particles.
Calibration Procedure
1. Principle. Either of two methods may be used for dynamic
multipoint calibration of CO analyzers:
(1) One method uses a single certified standard cylinder of CO,
diluted as necessary with zero air, to obtain the various calibration
concentrations needed.
(2) The other method uses individual certified standard cylinders of
CO for each concentration needed. Additional information on calibration
may be found in Section 2.0.9 of Reference 1.
2. Apparatus. The major components and typical configurations of the
calibration systems for the two calibration methods are shown in Figures
1 and 2.
2.1 Flow controller(s). Device capable of adjusting and regulating
flow rates. Flow rates for the dilution method (Figure 1) must be
regulated to 1%.
2.2 Flow meter(s). Calibrated flow meter capable of measuring and
monitoring flow rates. Flow rates for the dilution method (Figure 1)
must be measured with an accuracy of 2% of the measured
value.
2.3 Pressure regulator(s) for standard CO cylinder(s). Regulator
must have nonreactive diaphragm and internal parts and a suitable
delivery pressure.
2.4 Mixing chamber. A chamber designed to provide thorough mixing of
CO and diluent air for the dilution method.
2.5 Output manifold. The output manifold should be of sufficient
diameter to insure an insignificant pressure drop at the analyzer
connection. The system must have a vent designed to insure atmospheric
pressure at the manifold and to prevent ambient air from entering the
manifold.
3. Reagents.
3.1 CO concentration standard(s). Cylinder(s) of CO in air
containing appropriate concentrations(s) of CO suitable for the selected
operating range of the analyzer under calibration; CO standards for the
dilution method may be contained in a nitrogen matrix if the zero air
dilution ratio is not less than 100:1. The assay of the cylinder(s) must
be traceable either to a National Bureau of Standards (NBS) CO in air
Standard Reference Material (SRM) or to an NBS/EPA-approved commercially
available Certified Reference Material (CRM). CRM's are described in
Reference 2, and a list of CRM sources is available from the address
shown for Reference 2. A recommended protocol for certifying CO gas
cylinders against either a CO SRM or a CRM is given in Reference 1. CO
gas cylinders should be recertified on a regular basis as determined by
the local quality control program.
3.2 Dilution gas (zero air). Air, free of contaminants which will
cause a detectable response on the CO analyzer. The zero air should
contain <0.1 ppm CO. A procedure for generating zero air is given in
Reference 1.
4. Procedure Using Dynamic Dilution Method.
4.1 Assemble a dynamic calibration system such as the one shown in
Figure 1. All calibration gases including zero air must be introduced
into the sample inlet of the analyzer system. For specific operating
instructions refer to the manufacturer's manual.
4.2 Insure that all flowmeters are properly calibrated, under the
conditions of use, if appropriate, against an authoritative standard
such as a soap-bubble meter or wet-test meter. All volumetric flowrates
should be corrected to 25 deg.C and 760 mm Hg (101 kPa). A discussion
on calibration of flowmeters is given in Reference 1.
4.3 Select the operating range of the CO analyzer to be calibrated.
4.4 Connect the signal output of the CO analyzer to the input of the
strip chart recorder or other data collection device. All adjustments to
the analyzer should be based on the appropriate strip chart or data
device readings. References to analyzer responses in the procedure given
below refer to recorder or data device responses.
4.5 Adjust the calibration system to deliver zero air to the output
manifold. The total air flow must exceed the total demand of the
analyzer(s) connected to the output manifold to insure that no ambient
air is pulled into the manifold vent. Allow the analyzer to sample zero
air until a stable respose is obtained. After the response has
stabilized, adjust the analyzer zero control. Offsetting the analyzer
zero adjustments to +5 percent of scale is recommended to facilitate
observing negative zero drift. Record the stable zero air response as
ZCO.
4.6 Adjust the zero air flow and the CO flow from the standard CO
cylinder to provide a diluted CO concentration of approximately 80
percent of the upper range limit (URL) of the operating range of the
analyzer. The total air flow must exceed the total demand of the
analyzer(s) connected to the output manifold to insure that no ambient
air is
[[Page 39]]
pulled into the manifold vent. The exact CO concentration is calculated
from:
[GRAPHIC] [TIFF OMITTED] TR31AU93.026
where:
[CO]OUT = diluted CO concentration at the output manifold,
ppm;
[CO]STD = concentration of the undiluted CO standard, ppm;
FCO = flow rate of the CO standard corrected to 25 deg.C and
760 mm Hg, (101 kPa), L/min; and
FD = flow rate of the dilution air corrected to 25 deg.C and
760 mm Hg, (101 kPa), L/min.
Sample this CO concentration until a stable response is obtained.
Adjust the analyzer span control to obtain a recorder response as
indicated below:
Recorder response (percent scale) =
[GRAPHIC] [TIFF OMITTED] TR31AU93.027
where:
URL = nominal upper range limit of the analyzer's operating range, and
ZCO = analyzer response to zero air, % scale.
If substantial adjustment of the analyzer span control is required,
it may be necessary to recheck the zero and span adjustments by
repeating Steps 4.5 and 4.6. Record the CO concentration and the
analyzer's response. 4.7 Generate several additional concentrations (at
least three evenly spaced points across the remaining scale are
suggested to verify linearity) by decreasing FCO or
increasing FD. Be sure the total flow exceeds the analyzer's
total flow demand. For each concentration generated, calculate the exact
CO concentration using Equation (1). Record the concentration and the
analyzer's response for each concentration. Plot the analyzer responses
versus the corresponding CO concentrations and draw or calculate the
calibration curve.
5. Procedure Using Multiple Cylinder Method. Use the procedure for
the dynamic dilution method with the following changes:
5.1 Use a multi-cylinder system such as the typical one shown in
Figure 2.
5.2 The flowmeter need not be accurately calibrated, provided the
flow in the output manifold exceeds the analyzer's flow demand.
5.3 The various CO calibration concentrations required in Steps 4.6
and 4.7 are obtained without dilution by selecting the appropriate
certified standard cylinder.
References
1. Quality Assurance Handbook for Air Pollution Measurement Systems,
Volume II--Ambient Air Specific Methods, EPA-600/4-77-027a, U.S.
Environmental Protection Agency, Environmental Monitoring Systems
Laboratory, Research Triangle Park, NC 27711, 1977.
2. A procedure for Establishing Traceability of Gas Mixtures to
Certain National Bureau of Standards Standard Reference Materials. EPA-
600/7-81-010, U.S. Environmental Protection Agency, Environmental
Monitoring Systems Laboratory (MD-77), Research Triangle Park, NC 27711,
January 1981.
[[Page 40]]
[[Page 41]]
[47 FR 54922, Dec. 6, 1982; 48 FR 17355, Apr. 22, 1983]
[[Page 42]]
Appendix D to Part 50--Measurement Principle and Calibration Procedure
for the Measurement of Ozone in the Atmosphere
measurement principle
1. Ambient air and ethylene are delivered simultaneously to a mixing
zone where the ozone in the air reacts with the ethylene to emit light,
which is detected by a photomultiplier tube. The resulting photocurrent
is amplified and is either read directly or displayed on a recorder.
2. An analyzer based on this principle will be considered a
reference method only if it has been designated as a reference method in
accordance with part 53 of this chapter and calibrated as follows:
calibration procedure
1. Principle. The calibration procedure is based on the photometric
assay of ozone (O3) concentrations in a dynamic flow system.
The concentration of O3 in an absorption cell is determined
from a measurement of the amount of 254 nm light absorbed by the sample.
This determination requires knowledge of (1) the absorption coefficient
([alpha]) of O3 at 254 nm, (2) the optical path length (l)
through the sample, (3) the transmittance of the sample at a wavelength
of 254 nm, and (4) the temperature (T) and pressure (P) of the sample.
The transmittance is defined as the ratio I/I0, where I is
the intensity of light which passes through the cell and is sensed by
the detector when the cell contains an O3 sample, and
I0 is the intensity of light which passes through the cell
and is sensed by the detector when the cell contains zero air. It is
assumed that all conditions of the system, except for the contents of
the absorption cell, are identical during measurement of I and
I0. The quantities defined above are related by the Beer-
Lambert absorption law,
[GRAPHIC] [TIFF OMITTED] TR31AU93.028
where:
[alpha] = absorption coefficient of O3 at 254 nm=308
4 atm-1 cm-1 at 0 deg.C and 760 torr.
(1, 2, 3, 4, 5, 6, 7)
c = O3 concentration in atmospheres
l = optical path length in cm
In practice, a stable O3 generator is used to produce
O3 concentrations over the required range. Each O3
concentration is determined from the measurement of the transmittance
(I/I0) of the sample at 254 nm with a photometer of path
length l and calculated from the equation,
[GRAPHIC] [TIFF OMITTED] TR31AU93.029
The calculated O3 concentrations must be corrected for
O3 losses which may occur in the photometer and for the
temperature and pressure of the sample.
2. Applicability. This procedure is applicable to the calibration of
ambient air O3 analyzers, either directly or by means of a
transfer standard certified by this procedure. Transfer standards must
meet the requirements and specifications set forth in Reference 8.
3. Apparatus. A complete UV calibration system consists of an ozone
generator, an output port or manifold, a photometer, an appropriate
source of zero air, and other components as necessary. The configuration
must provide a stable ozone concentration at the system output and allow
the photometer to accurately assay the output concentration to the
precision specified for the photometer (3.1). Figure 1 shows a commonly
used configuration and serves to illustrate the calibration procedure
which follows. Other configurations may require appropriate variations
in the procedural steps. All connections between components in the
calibration system downstream of the O3 generator should be
of glass, Teflon, or other relatively inert materials. Additional
information regarding the assembly of a UV photometric calibration
apparatus is given in Reference 9. For certification of transfer
standards which provide their own source of O3, the transfer
standard may replace the O3 generator and possibly other
components shown in Figure 1; see Reference 8 for guidance.
3.1 UV photometer. The photometer consists of a low-pressure mercury
discharge lamp, (optional) collimation optics, an absorption cell, a
detector, and signal-processing electronics, as illustrated in Figure 1.
It must be capable of measuring the transmittance, I/I0, at a
wavelength of 254 nm with sufficient precision such that the standard
deviation of the concentration measurements does not exceed the greater
of 0.005 ppm or 3% of the concentration. Because the low-pressure
mercury lamp radiates at several wavelengths, the photometer must
incorporate suitable means to assure that no O3 is generated
in the cell by the lamp, and that at least 99.5% of the radiation sensed
by the detector is 254 nm radiation. (This can be readily achieved by
prudent selection of optical filter and detector response
characteristics.) The length of the light path through the absorption
cell must be known with an accuracy of at least 99.5%. In addition, the
cell and associated plumbing must be designed to
[[Page 43]]
minimize loss of O3 from contact with cell walls and gas
handling components. See Reference 9 for additional information.
3.2 Air flow controllers. Devices capable of regulating air flows as
necessary to meet the output stability and photometer precision
requirements.
3.3 Ozone generator. Device capable of generating stable levels of
O3 over the required concentration range.
3.4 Output manifold. The output manifold should be constructed of
glass, Teflon, or other relatively inert material, and should be of
sufficient diameter to insure a negligible pressure drop at the
photometer connection and other output ports. The system must have a
vent designed to insure atmospheric pressure in the manifold and to
prevent ambient air from entering the manifold.
3.5 Two-way valve. Manual or automatic valve, or other means to
switch the photometer flow between zero air and the O3
concentration.
3.6 Temperature indicator. Accurate to 1 deg.C.
3.7 Barometer or pressure indicator. Accurate to 2 torr.
4. Reagents.
4.1 Zero air. The zero air must be free of contaminants which would
cause a detectable response from the O3 analyzer, and it
should be free of NO, C2 H4, and other species
which react with O3. A procedure for generating suitable zero
air is given in Reference 9. As shown in Figure 1, the zero air supplied
to the photometer cell for the I0 reference measurement must
be derived from the same source as the zero air used for generation of
the ozone concentration to be assayed (I measurement). When using the
photometer to certify a transfer standard having its own source of
ozone, see Reference 8 for guidance on meeting this requirement.
5. Procedure.
5.1 General operation. The calibration photometer must be dedicated
exclusively to use as a calibration standard. It should always be used
with clean, filtered calibration gases, and never used for ambient air
sampling. Consideration should be given to locating the calibration
photometer in a clean laboratory where it can be stationary, protected
from physical shock, operated by a responsible analyst, and used as a
common standard for all field calibrations via transfer standards.
5.2 Preparation. Proper operation of the photometer is of critical
importance to the accuracy of this procedure. The following steps will
help to verify proper operation. The steps are not necessarily required
prior to each use of the photometer. Upon initial operation of the
photometer, these steps should be carried out frequently, with all
quantitative results or indications recorded in a chronological record
either in tabular form or plotted on a graphical chart. As the
performance and stability record of the photometer is established, the
frequency of these steps may be reduced consistent with the documented
stability of the photometer.
5.2.1 Instruction manual: Carry out all set up and adjustment
procedures or checks as described in the operation or instruction manual
associated with the photometer.
5.2.2 System check: Check the photometer system for integrity,
leaks, cleanliness, proper flowrates, etc. Service or replace filters
and zero air scrubbers or other consumable materials, as necessary.
5.2.3 Linearity: Verify that the photometer manufacturer has
adequately established that the linearity error of the photometer is
less than 3%, or test the linearity by dilution as follows: Generate and
assay an O3 concentration near the upper range limit of the
system (0.5 or 1.0 ppm), then accurately dilute that concentration with
zero air and reassay it. Repeat at several different dilution ratios.
Compare the assay of the original concentration with the assay of the
diluted concentration divided by the dilution ratio, as follows
[GRAPHIC] [TIFF OMITTED] TR31AU93.030
where:
E = linearity error, percent
A1 = assay of the original concentration
A2 = assay of the diluted concentration
R = dilution ratio = flow of original concentration divided by the total
flow
The linearity error must be less than 5%. Since the accuracy of the
measured flow-rates will affect the linearity error as measured this
way, the test is not necessarily conclusive. Additional information on
verifying linearity is contained in Reference 9.
5.2.4 Intercomparison: When possible, the photometer should be
occasionally intercompared, either directly or via transfer standards,
with calibration photometers used by other agencies or laboratories.
5.2.5 Ozone losses: Some portion of the O3 may be lost
upon contact with the photometer cell walls and gas handling components.
The magnitude of this loss must be determined and used to correct the
calculated O3 concentration. This loss must not exceed 5%.
Some guidelines for quantitatively determining this loss are discussed
in Reference 9.
5.3 Assay of O3 concentrations.
5.3.1 Allow the photometer system to warm up and stabilizer.
5.3.2 Verify that the flowrate through the photometer absorption
cell, F allows the cell to be flushed in a reasonably short period of
time (2 liter/min is a typical flow). The precision of the measurements
is inversely related to the time required for flushing, since the
photometer drift error increases with time.
[[Page 44]]
5.3.3 Insure that the flowrate into the output manifold is at least
1 liter/min greater than the total flowrate required by the photometer
and any other flow demand connected to the manifold.
5.3.4 Insure that the flowrate of zero air, Fz, is at
least 1 liter/min greater than the flowrate required by the photometer.
5.3.5 With zero air flowing in the output manifold, actuate the two-
way valve to allow the photometer to sample first the manifold zero air,
then Fz. The two photometer readings must be equal
(I=Io).
Note: In some commercially available photometers, the operation of
the two-way valve and various other operations in section 5.3 may be
carried out automatically by the photometer.
5.3.6 Adjust the O3 generator to produce an O3
concentration as needed.
5.3.7 Actuate the two-way valve to allow the photometer to sample
zero air until the absorption cell is thoroughly flushed and record the
stable measured value of Io.
5.3.8 Actuate the two-way valve to allow the photometer to sample
the ozone concentration until the absorption cell is thoroughly flushed
and record the stable measured value of I.
5.3.9 Record the temperature and pressure of the sample in the
photometer absorption cell. (See Reference 9 for guidance.)
5.3.10 Calculate the O3 concentration from equation 4. An
average of several determinations will provide better precision.
[GRAPHIC] [TIFF OMITTED] TR31AU93.032
where:
[O3]OUT = O3 concentration, ppm
[alpha] = absorption coefficient of O3 at 254 nm=308
atm-1 cm-1 at 0 deg.C and 760 torr
l = optical path length, cm
T = sample temperature, K
P = sample pressure, torr
L = correction factor for O3 losses from 5.2.5=(1-fraction
O3 lost).
Note: Some commercial photometers may automatically evaluate all or
part of equation 4. It is the operator's responsibility to verify that
all of the information required for equation 4 is obtained, either
automatically by the photometer or manually. For ``automatic''
photometers which evaluate the first term of equation 4 based on a
linear approximation, a manual correction may be required, particularly
at higher O3 levels. See the photometer instruction manual
and Reference 9 for guidance.
5.3.11 Obtain additional O3 concentration standards as
necessary by repeating steps 5.3.6 to 5.3.10 or by Option 1.
5.4 Certification of transfer standards. A transfer standard is
certified by relating the output of the transfer standard to one or more
ozone standards as determined according to section 5.3. The exact
procedure varies depending on the nature and design of the transfer
standard. Consult Reference 8 for guidance.
5.5 Calibration of ozone analyzers. Ozone analyzers are calibrated
as follows, using ozone standards obtained directly according to section
5.3 or by means of a certified transfer standard.
5.5.1 Allow sufficient time for the O3 analyzer and the
photometer or transfer standard to warmup and stabilize.
5.5.2 Allow the O3 analyzer to sample zero air until a
stable response is obtained and adjust the O3 analyzer's zero
control. Offsetting the analyzer's zero adjustment to +5% of scale is
recommended to facilitate observing negative zero drift. Record the
stable zero air response as ``Z''.
5.5.3 Generate an O3 concentration standard of
approximately 80% of the desired upper range limit (URL) of the
O3 analyzer. Allow the O3 analyzer to sample this
O3 concentration standard until a stable response is
obtained.
5.5.4 Adjust the O3 analyzer's span control to obtain a
convenient recorder response as indicated below:
recorder response (%scale) =
[GRAPHIC] [TIFF OMITTED] TR31AU93.033
where:
URL = upper range limit of the O3 analyzer, ppm
Z = recorder response with zero air, % scale
Record the O3 concentration and the corresponding
analyzer response. If substantial adjustment of the span control is
necessary, recheck the zero and span adjustments by repeating steps
5.5.2 to 5.5.4.
5.5.5 Generate several other O3 concentration standards
(at least 5 others are recommended) over the scale range of the
O3 analyzer by adjusting the O3 source or by
Option 1. For each O3 concentration standard, record the
O3 and the corresponding analyzer response.
5.5.6 Plot the O3 analyzer responses versus the
corresponding O3 concentrations and draw the O3
analyzer's calibration curve or calculate the appropriate response
factor.
5.5.7 Option 1: The various O3 concentrations required in
steps 5.3.11 and 5.5.5 may be obtained by dilution of the O3
concentration generated in steps 5.3.6 and 5.5.3. With this option,
accurate flow measurements are required. The dynamic calibration system
may be modified as shown in Figure 2 to allow for dilution air to be
metered in downstream of the O3 generator. A mixing chamber
between the O3 generator and the output manifold is also
required. The flowrate through the O3 generator
(Fo) and the dilution air flowrate
[[Page 45]]
(FD) are measured with a reliable flow or volume standard
traceable to NBS. Each O3 concentration generated by dilution
is calculated from:
[GRAPHIC] [TIFF OMITTED] TR31AU93.031
where:
[O3]'OUT = diluted O3 concentration,
ppm
F0 = flowrate through the O3 generator, liter/min
FD = diluent air flowrate, liter/min
References
1. E.C.Y. Inn and Y. Tanaka, ``Absorption coefficient of Ozone in
the Ultraviolet and Visible Regions'', J. Opt. Soc. Am., 43, 870 (1953).
2. A. G. Hearn, ``Absorption of Ozone in the Ultraviolet and Visible
Regions of the Spectrum'', Proc. Phys. Soc. (London), 78, 932 (1961).
3. W. B. DeMore and O. Raper, ``Hartley Band Extinction Coefficients
of Ozone in the Gas Phase and in Liquid Nitrogen, Carbon Monoxide, and
Argon'', J. Phys. Chem., 68, 412 (1964).
4. M. Griggs, ``Absorption Coefficients of Ozone in the Ultraviolet
and Visible Regions'', J. Chem. Phys., 49, 857 (1968).
5. K. H. Becker, U. Schurath, and H. Seitz, ``Ozone Olefin Reactions
in the Gas Phase. 1. Rate Constants and Activation Energies'', Int'l
Jour. of Chem. Kinetics, VI, 725 (1974).
6. M. A. A. Clyne and J. A. Coxom, ``Kinetic Studies of Oxy-halogen
Radical Systems'', Proc. Roy. Soc., A303, 207 (1968).
7. J. W. Simons, R. J. Paur, H. A. Webster, and E. J. Bair, ``Ozone
Ultraviolet Photolysis. VI. The Ultraviolet Spectrum'', J. Chem. Phys.,
59, 1203 (1973).
8. Transfer Standards for Calibration of Ambient Air Monitoring
Analyzers for Ozone, EPA publication number EPA-600/4-79-056, EPA,
National Exposure Research Laboratory, Department E, (MD-77B), Research
Triangle Park, NC 27711.
9. Technical Assistance Document for the Calibration of Ambient
Ozone Monitors, EPA publication number EPA-600/4-79-057, EPA, National
Exposure Research Laboratory, Department E, (MD-77B), Research Triangle
Park, NC 27711.
[[Page 46]]
[[Page 47]]
[44 FR 8224, Feb. 8, 1979, as amended at 62 FR 38895, July 18, 1997]
Appendix E to Part 50 [Reserved]
Appendix F to Part 50--Measurement Principle and Calibration Procedure
for the Measurement of Nitrogen Dioxide in the Atmosphere (Gas Phase
Chemiluminescence)
Principle and Applicability
1. Atmospheric concentrations of nitrogen dioxide (NO2)
are measured indirectly by photometrically measuring the light
intensity, at wavelengths greater than 600 nanometers, resulting from
the chemiluminescent reaction of nitric oxide (NO) with ozone
(O3). (1,2,3) NO2 is first quantitatively reduced
to NO(4,5,6) by means of a converter. NO, which commonly exists in
ambient air together with NO2, passes through the converter
unchanged causing a resultant total NOX concentration equal
to NO+NO2. A sample of the input air is also measured without
having passed through the converted. This latter NO measurement is
subtracted from the former measurement (NO+NO2) to yield the
final NO2 measurement. The NO and NO+NO2
measurements may be made concurrently with dual systems, or cyclically
with the same system provided the cycle time does not exceed 1 minute.
2. Sampling considerations.
2.1 Chemiluminescence NO/NOX/NO2 analyzers
will respond to other nitrogen containing compounds, such as
peroxyacetyl nitrate (PAN), which might be reduced to NO in the thermal
converter. (7) Atmospheric concentrations of these potential
interferences are generally low relative to NO2 and valid
NO2 measurements may be obtained. In certain geographical
areas, where the concentration of these potential interferences is known
or suspected to be high relative to NO2, the use of an
equivalent method for the measurement of NO2 is recommended.
2.2 The use of integrating flasks on the sample inlet line of
chemiluminescence NO/NOX/NO2 analyzers is optional
and left to couraged. The sample residence time between the sampling
point and the analyzer should be kept to a minimum to avoid erroneous
NO2 measurements resulting from the reaction of ambient
levels of NO and O3 in the sampling system.
2.3 The use of particulate filters on the sample inlet line of
chemiluminescence NO/NOX/NO2 analyzers is optional
and left to the discretion of the user or the manufacturer.
Use of the filter should depend on the analyzer's susceptibility to
interference, malfunction, or damage due to particulates. Users are
cautioned that particulate matter concentrated on a filter may cause
erroneous NO2 measurements and therefore filters should be
changed frequently.
3. An analyzer based on this principle will be considered a
reference method only if it has been designated as a reference method in
accordance with part 53 of this chapter.
Calibration
1. Alternative A--Gas phase titration (GPT) of an NO standard with
O3.
Major equipment required: Stable O3 generator.
Chemiluminescence NO/NOX/NO2 analyzer with strip
chart recorder(s). NO concentration standard.
1.1 Principle. This calibration technique is based upon the rapid
gas phase reaction between NO and O3 to produce
stoichiometric quantities of NO2 in accordance with the
following equation: (8)
[GRAPHIC] [TIFF OMITTED] TC08NO91.075
The quantitative nature of this reaction is such that when the NO
concentration is known, the concentration of NO2 can be
determined. Ozone is added to excess NO in a dynamic calibration system,
and the NO channel of the chemiluminescence NO/NOX/
NO2 analyzer is used as an indicator of changes in NO
concentration. Upon the addition of O3, the decrease in NO
concentration observed on the calibrated NO channel is equivalent to the
concentration of NO2 produced. The amount of NO2
generated may be varied by adding variable amounts of O3 from
a stable uncalibrated O3 generator. (9)
1.2 Apparatus. Figure 1, a schematic of a typical GPT apparatus,
shows the suggested configuration of the components listed below. All
connections between components in the calibration system downstream from
the O3 generator should be of glass, Teflon[reg],
or other non-reactive material.
1.2.1 Air flow controllers. Devices capable of maintaining constant
air flows within 2% of the required flowrate.
1.2.2 NO flow controller. A device capable of maintaining constant
NO flows within 2% of the required flowrate. Component parts
in contact with the NO should be of a non-reactive material.
1.2.3 Air flowmeters. Calibrated flowmeters capable of measuring and
monitoring air flowrates with an accuracy of 2% of the
measured flowrate.
1.2.4 NO flowmeter. A calibrated flowmeter capable of measuring and
monitoring NO flowrates with an accuracy of 2% of the
measured flowrate. (Rotameters have been reported to operate unreliably
when measuring low NO flows and are not recommended.)
1.2.5 Pressure regulator for standard NO cylinder. This regulator
must have a nonreactive diaphragm and internal parts and a suitable
delivery pressure.
[[Page 48]]
1.2.6 Ozone generator. The generator must be capable of generating
sufficient and stable levels of O3 for reaction with NO to
generate NO2 concentrations in the range required. Ozone
generators of the electric discharge type may produce NO and
NO2 and are not recommended.
1.2.7 Valve. A valve may be used as shown in Figure 1 to divert the
NO flow when zero air is required at the manifold. The valve should be
constructed of glass, Teflon[reg], or other nonreactive
material.
1.2.8 Reaction chamber. A chamber, constructed of glass,
Teflon[reg], or other nonreactive material, for the
quantitative reaction of O3 with excess NO. The chamber
should be of sufficient volume (VRC) such that the residence
time (tR) meets the requirements specified in 1.4. For
practical reasons, tR should be less than 2 minutes.
1.2.9 Mixing chamber. A chamber constructed of glass,
Teflon[reg], or other nonreactive material and designed to
provide thorough mixing of reaction products and diluent air. The
residence time is not critical when the dynamic parameter specification
given in 1.4 is met.
1.2.10 Output manifold. The output manifold should be constructed of
glass, Teflon[reg], or other non-reactive material and should
be of sufficient diameter to insure an insignificant pressure drop at
the analyzer connection. The system must have a vent designed to insure
atmospheric pressure at the manifold and to prevent ambient air from
entering the manifold.
1.3 Reagents.
1.3.1 NO concentration standard. Gas cylinder standard containing 50
to 100 ppm NO in N2 with less than 1 ppm NO2. This
standard must be traceable to a National Bureau of Standards (NBS) NO in
N2 Standard Reference Material (SRM 1683 or SRM 1684), an NBS
NO2 Standard Reference Material (SRM 1629), or an NBS/EPA-
approved commercially available Certified Reference Material (CRM).
CRM's are described in Reference 14, and a list of CRM sources is
available from the address shown for Reference 14. A recommended
protocol for certifying NO gas cylinders against either an NO SRM or CRM
is given in section 2.0.7 of Reference 15. Reference 13 gives procedures
for certifying an NO gas cylinder against an NBS NO2 SRM and
for determining the amount of NO2 impurity in an NO cylinder.
1.3.2 Zero air. Air, free of contaminants which will cause a
detectable response on the NO/NOX/NO2 analyzer or
which might react with either NO, O3, or NO2 in
the gas phase titration. A procedure for generating zero air is given in
reference 13.
1.4 Dynamic parameter specification.
1.4.1 The O3 generator air flowrate (F0) and
NO flowrate (FNO) (see Figure 1) must be adjusted such that
the following relationship holds:
[GRAPHIC] [TIFF OMITTED] TC08NO91.076
[GRAPHIC] [TIFF OMITTED] TC08NO91.077
[GRAPHIC] [TIFF OMITTED] TC08NO91.078
where:
PR = dynamic parameter specification, determined empirically,
to insure complete reaction of the available O3, ppm-minute
[NO]RC = NO concentration in the reaction chamber, ppm
R = residence time of the reactant gases in the reaction
chamber, minute
[NO]STD = concentration of the undiluted NO standard, ppm
FNO = NO flowrate, scm 3/min
FO = O3 generator air flowrate, scm 3/
min
VRC = volume of the reaction chamber, scm 3
1.4.2 The flow conditions to be used in the GPT system are
determined by the following procedure:
(a) Determine FT, the total flow required at the output
manifold (FT=analyzer demand plus 10 to 50% excess).
(b) Establish [NO]OUT as the highest NO concentration
(ppm) which will be required at the output manifold. [NO]OUT
should be approximately equivalent to 90% of the upper range limit (URL)
of the NO2 concentration range to be covered.
(c) Determine FNO as
[GRAPHIC] [TIFF OMITTED] TC08NO91.079
(d) Select a convenient or available reaction chamber volume.
Initially, a trial VRC may be selected to be in the range of
approximately 200 to 500 scm\3\.
(e) Compute FO as
(f) Compute tR as
[GRAPHIC] [TIFF OMITTED] TC08NO91.080
Verify that tR < 2 minutes. If not, select a reaction chamber
with a smaller VRC.
(g) Compute the diluent air flowrate as
[GRAPHIC] [TIFF OMITTED] TC08NO91.081
where:
FD = diluent air flowrate, scm 3/min
[[Page 49]]
(h) If FO turns out to be impractical for the desired
system, select a reaction chamber having a different VRC and
recompute FO and FD.
Note: A dynamic parameter lower than 2.75 ppm-minutes may be used if
it can be determined empirically that quantitative reaction of
O3 with NO occurs. A procedure for making this determination
as well as a more detailed discussion of the above requirements and
other related considerations is given in reference 13.
1.5 Procedure.
1.5.1 Assemble a dynamic calibration system such as the one shown in
Figure 1.
1.5.2 Insure that all flowmeters are calibrated under the conditions
of use against a reliable standard such as a soap-bubble meter or wet-
test meter. All volumetric flowrates should be corrected to 25 deg.C
and 760 mm Hg. A discussion on the calibration of flowmeters is given in
reference 13.
1.5.3 Precautions must be taken to remove O2 and other
contaminants from the NO pressure regulator and delivery system prior to
the start of calibration to avoid any conversion of the standard NO to
NO2. Failure to do so can cause significant errors in
calibration. This problem may be minimized by (1) carefully evacuating
the regulator, when possible, after the regulator has been connected to
the cylinder and before opening the cylinder valve; (2) thoroughly
flushing the regulator and delivery system with NO after opening the
cylinder valve; (3) not removing the regulator from the cylinder between
calibrations unless absolutely necessary. Further discussion of these
procedures is given in reference 13.
1.5.4 Select the operating range of the NO/NOX/
NO2 analyzer to be calibrated. In order to obtain maximum
precision and accuracy for NO2 calibration, all three
channels of the analyzer should be set to the same range. If operation
of the NO and NOX channels on higher ranges is desired,
subsequent recalibration of the NO and NOX channels on the
higher ranges is recommended.
Note: Some analyzer designs may require identical ranges for NO,
NOX, and NO2 during operation of the analyzer.
1.5.5 Connect the recorder output cable(s) of the NO/NOX/
NO2 analyzer to the input terminals of the strip chart
recorder(s). All adjustments to the analyzer should be performed based
on the appropriate strip chart readings. References to analyzer
responses in the procedures given below refer to recorder responses.
1.5.6 Determine the GPT flow conditions required to meet the dynamic
parameter specification as indicated in 1.4.
1.5.7 Adjust the diluent air and O3 generator air flows
to obtain the flows determined in section 1.4.2. The total air flow must
exceed the total demand of the analyzer(s) connected to the output
manifold to insure that no ambient air is pulled into the manifold vent.
Allow the analyzer to sample zero air until stable NO, NOX,
and NO2 responses are obtained. After the responses have
stabilized, adjust the analyzer zero control(s).
Note: Some analyzers may have separate zero controls for NO,
NOX, and NO2. Other analyzers may have separate
zero controls only for NO and NOX, while still others may
have only one zero control common to all three channels.
Offsetting the analyzer zero adjustments to +5 percent of scale is
recommended to facilitate observing negative zero drift. Record the
stable zero air responses as ZNO, Znox, and Zno2.
1.5.8 Preparation of NO and NOX calibration curves.
1.5.8.1 Adjustment of NO span control. Adjust the NO flow from the
standard NO cylinder to generate an NO concentration of approximately 80
percent of the upper range limit (URL) of the NO range. This exact NO
concentration is calculated from:
[GRAPHIC] [TIFF OMITTED] TR31AU93.044
where:
[NO]OUT = diluted NO concentration at the output manifold,
ppm
Sample this NO concentration until the NO and NOX responses
have stabilized. Adjust the NO span control to obtain a recorder
response as indicated below:
recorder response (percent scale) =
[GRAPHIC] [TIFF OMITTED] TR31AU93.045
where:
URL = nominal upper range limit of the NO channel, ppm
Note: Some analyzers may have separate span controls for NO,
NOX, and NO2. Other analyzers may have separate
span controls only for NO and NOX, while still others may
have only one span control common to all three channels. When only one
span control is available, the span adjustment is made on the NO channel
of the analyzer.
If substantial adjustment of the NO span control is necessary, it may be
necessary to recheck the zero and span adjustments by repeating steps
1.5.7 and 1.5.8.1. Record the NO concentration and the analyzer's NO
response.
1.5.8.2 Adjustment of NOX span control. When adjusting
the analyzer's NOX span control, the presence of any
NO2 impurity in the standard NO cylinder must be taken into
account. Procedures for determining the amount of NO2
impurity in the standard NO
[[Page 50]]
cylinder are given in reference 13. The exact NOX
concentration is calculated from:
[GRAPHIC] [TIFF OMITTED] TR31AU93.046
where:
[NOX]OUT = diluted NOX concentration at
the output manifold, ppm
[NO2]IMP = concentration of NO2
impurity in the standard NO cylinder, ppm
Adjust the NOX span control to obtain a recorder response as
indicated below:
recorder response (% scale) =
[GRAPHIC] [TIFF OMITTED] TR31AU93.047
Note: If the analyzer has only one span control, the span adjustment
is made on the NO channel and no further adjustment is made here for
NOx.
If substantial adjustment of the NOX span control is
necessary, it may be necessary to recheck the zero and span adjustments
by repeating steps 1.5.7 and 1.5.8.2. Record the NOX
concentration and the analyzer's NOX response.
1.5.8.3 Generate several additional concentrations (at least five
evenly spaced points across the remaining scale are suggested to verify
linearity) by decreasing FNO or increasing FD. For
each concentration generated, calculate the exact NO and NOX
concentrations using equations (9) and (11) respectively. Record the
analyzer's NO and NOX responses for each concentration. Plot
the analyzer responses versus the respective calculated NO and
NOX concentrations and draw or calculate the NO and
NOX calibration curves. For subsequent calibrations where
linearity can be assumed, these curves may be checked with a two-point
calibration consisting of a zero air point and NO and NOX
concentrations of approximately 80% of the URL.
1.5.9 Preparation of NO2 calibration curve.
1.5.9.1 Assuming the NO2 zero has been properly adjusted
while sampling zero air in step 1.5.7, adjust FO and
FD as determined in section 1.4.2. Adjust FNO to
generate an NO concentration near 90% of the URL of the NO range. Sample
this NO concentration until the NO and NOX responses have
stabilized. Using the NO calibration curve obtained in section 1.5.8,
measure and record the NO concentration as [NO]orig. Using
the NOX calibration curve obtained in section 1.5.8, measure
and record the NOX concentration as
[NOX]orig.
1.5.9.2 Adjust the O3 generator to generate sufficient
O3 to produce a decrease in the NO concentration equivalent
to approximately 80% of the URL of the NO2 range. The
decrease must not exceed 90% of the NO concentration determined in step
1.5.9.1. After the analyzer responses have stabilized, record the
resultant NO and NOX concentrations as [NO]rem and
[NOX]rem.
1.5.9.3 Calculate the resulting NO2 concentration from:
[GRAPHIC] [TIFF OMITTED] TC08NO91.082
where:
[NO2]OUT = diluted NO2 concentration at
the output manifold, ppm
[NO]orig = original NO concentration, prior to addition of
O3, ppm
[NO]rem = NO concentration remaining after addition of
O3, ppm
Adjust the NO2 span control to obtain a recorder response as
indicated below:
recorder response (% scale) =
[GRAPHIC] [TIFF OMITTED] TR31AU93.048
Note: If the analyzer has only one or two span controls, the span
adjustments are made on the NO channel or NO and NOX channels
and no further adjustment is made here for NO2.
If substantial adjustment of the NO2 span control is
necessary, it may be necessary to recheck the zero and span adjustments
by repeating steps 1.5.7 and 1.5.9.3. Record the NO2
concentration and the corresponding analyzer NO2 and
NOX responses.
1.5.9.4 Maintaining the same FNO, FO, and
FD as in section 1.5.9.1, adjust the ozone generator to
obtain several other concentrations of NO2 over the
NO2 range (at least five evenly spaced points across the
remaining scale are suggested). Calculate each NO2
concentration using equation (13) and record the corresponding analyzer
NO2 and NOX responses. Plot the analyzer's
NO2 responses versus the corresponding calculated
NO2 concentrations and draw or calculate the NO2
calibration curve.
1.5.10 Determination of converter efficiency.
[[Page 51]]
1.5.10.1 For each NO2 concentration generated during the
preparation of the NO2 calibration curve (see section 1.5.9)
calculate the concentration of NO2 converted from:
[GRAPHIC] [TIFF OMITTED] TC08NO91.083
where:
[NO2]CONV = concentration of NO2
converted, ppm
[NOX]orig = original NOX concentration
prior to addition of O3, ppm
[NOX]rem = NOX concentration remaining
after addition of O3, ppm
Note: Supplemental information on calibration and other procedures
in this method are given in reference 13.
Plot [NO2]CONV (y-axis) versus
[NO2]OUT (x-axis) and draw or calculate the
converter efficiency curve. The slope of the curve times 100 is the
average converter efficiency, EC. The average converter
efficiency must be greater than 96%; if it is less than 96%, replace or
service the converter.
2. Alternative B--NO2 permeation device.
Major equipment required:
Stable O3 generator.
Chemiluminescence NO/NOX/NO2 analyzer with
strip chart recorder(s).
NO concentration standard.
NO2 concentration standard.
2.1 Principle. Atmospheres containing accurately known
concentrations of nitrogen dioxide are generated by means of a
permeation device. (10) The permeation device emits NO2 at a
known constant rate provided the temperature of the device is held
constant (0.1 deg.C) and the device has been accurately
calibrated at the temperature of use. The NO2 emitted from
the device is diluted with zero air to produce NO2
concentrations suitable for calibration of the NO2 channel of
the NO/NOX/NO2 analyzer. An NO concentration
standard is used for calibration of the NO and NOX channels
of the analyzer.
2.2 Apparatus. A typical system suitable for generating the required
NO and NO2 concentrations is shown in Figure 2. All
connections between components downstream from the permeation device
should be of glass, Teflon[reg], or other non-reactive
material.
2.2.1 Air flow controllers. Devices capable of maintaining constant
air flows within 2% of the required flowrate.
2.2.2 NO flow controller. A device capable of maintaining constant
NO flows within 2% of the required flowrate. Component parts
in contact with the NO must be of a non-reactive material.
2.2.3 Air flowmeters. Calibrated flowmeters capable of measuring and
monitoring air flowrates with an accuracy of 2% of the
measured flowrate.
2.2.4 NO flowmeter. A calibrated flowmeter capable of measuring and
monitoring NO flowrates with an accuracy of 2% of the
measured flowrate. (Rotameters have been reported to operate unreliably
when measuring low NO flows and are not recommended.)
2.2.5 Pressure regulator for standard NO cylinder. This regulator
must have a non-reactive diaphragm and internal parts and a suitable
delivery pressure.
2.2.6 Drier. Scrubber to remove moisture from the permeation device
air system. The use of the drier is optional with NO2
permeation devices not sensitive to moisture. (Refer to the supplier's
instructions for use of the permeation device.)
2.2.7 Constant temperature chamber. Chamber capable of housing the
NO2 permeation device and maintaining its temperature to
within 0.1 deg.C.
2.2.8 Temperature measuring device. Device capable of measuring and
monitoring the temperature of the NO2 permeation device with
an accuracy of 0.05 deg.C.
2.2.9 Valves. A valve may be used as shown in Figure 2 to divert the
NO2 from the permeation device when zero air or NO is
required at the manifold. A second valve may be used to divert the NO
flow when zero air or NO2 is required at the manifold.
The valves should be constructed of glass, Teflon[reg],
or other nonreactive material.
2.2.10 Mixing chamber. A chamber constructed of glass,
Teflon[reg], or other nonreactive material and designed to
provide thorough mixing of pollutant gas streams and diluent air.
2.2.11 Output manifold. The output manifold should be constructed of
glass, Teflon[reg], or other non-reactive material and should
be of sufficient diameter to insure an insignificant pressure drop at
the analyzer connection. The system must have a vent designed to insure
atmospheric pressure at the manifold and to prevent ambient air from
entering the manifold.
2.3 Reagents.
2.3.1 Calibration standards. Calibration standards are required for
both NO and NO2. The reference standard for the calibration
may be either an NO or NO2 standard, and must be traceable to
a National Bureau of Standards (NBS) NO in N2 Standard
Reference Material (SRM 1683 or SRM 1684), and NBS NO2
Standard Reference Material (SRM 1629), or an NBS/EPA-approved
commercially
[[Page 52]]
available Certified Reference Material (CRM). CRM's are described in
Reference 14, and a list of CRM sources is available from the address
shown for Reference 14. Reference 15 gives recommended procedures for
certifying an NO gas cylinder against an NO SRM or CRM and for
certifying an NO2 permeation device against an NO2
SRM. Reference 13 contains procedures for certifying an NO gas cylinder
against an NO2 SRM and for certifying an NO2
permeation device against an NO SRM or CRM. A procedure for determining
the amount of NO2 impurity in an NO cylinder is also
contained in Reference 13. The NO or NO2 standard selected as
the reference standard must be used to certify the other standard to
ensure consistency between the two standards.
2.3.1.1 NO2 Concentration standard. A permeation device
suitable for generating NO2 concentrations at the required
flow-rates over the required concentration range. If the permeation
device is used as the reference standard, it must be traceable to an SRM
or CRM as specified in 2.3.1. If an NO cylinder is used as the reference
standard, the NO2 permeation device must be certified against
the NO standard according to the procedure given in Reference 13. The
use of the permeation device should be in strict accordance with the
instructions supplied with the device. Additional information regarding
the use of permeation devices is given by Scaringelli et al. (11) and
Rook et al. (12).
2.3.1.2 NO Concentration standard. Gas cylinder containing 50 to 100
ppm NO in N2 with less than 1 ppm NO2. If this
cylinder is used as the reference standard, the cylinder must be
traceable to an SRM or CRM as specified in 2.3.1. If an NO2
permeation device is used as the reference standard, the NO cylinder
must be certified against the NO2 standard according to the
procedure given in Reference 13. The cylinder should be recertified on a
regular basis as determined by the local quality control program.
2.3.3 Zero air. Air, free of contaminants which might react with NO
or NO2 or cause a detectable response on the NO/
NOX/NO2 analyzer. When using permeation devices
that are sensitive to moisture, the zero air passing across the
permeation device must be dry to avoid surface reactions on the device.
(Refer to the supplier's instructions for use of the permeation device.)
A procedure for generating zero air is given in reference 13.
2.4 Procedure.
2.4.1 Assemble the calibration apparatus such as the typical one
shown in Figure 2.
2.4.2 Insure that all flowmeters are calibrated under the conditions
of use against a reliable standard such as a soap bubble meter or wet-
test meter. All volumetric flowrates should be corrected to 25 deg.C
and 760 mm Hg. A discussion on the calibration of flowmeters is given in
reference 13.
2.4.3 Install the permeation device in the constant temperature
chamber. Provide a small fixed air flow (200-400 scm 3/min)
across the device. The permeation device should always have a continuous
air flow across it to prevent large buildup of NO2 in the
system and a consequent restabilization period. Record the flowrate as
FP. Allow the device to stabilize at the calibration temperature for at
least 24 hours. The temperature must be adjusted and controlled to
within 0.1 deg.C or less of the calibration temperature as
monitored with the temperature measuring device.
2.4.4 Precautions must be taken to remove O2 and other
contaminants from the NO pressure regulator and delivery system prior to
the start of calibration to avoid any conversion of the standard NO to
NO2. Failure to do so can cause significant errors in
calibration. This problem may be minimized by
(1) Carefully evacuating the regulator, when possible, after the
regulator has been connected to the cylinder and before opening the
cylinder valve;
(2) Thoroughly flushing the regulator and delivery system with NO
after opening the cylinder valve;
(3) Not removing the regulator from the cylinder between
calibrations unless absolutely necessary. Further discussion of these
procedures is given in reference 13.
2.4.5 Select the operating range of the NO/NOX
NO2 analyzer to be calibrated. In order to obtain maximum
precision and accuracy for NO2 calibration, all three
channels of the analyzer should be set to the same range. If operation
of the NO and NOX channels on higher ranges is desired,
subsequent recalibration of the NO and NOX channels on the
higher ranges is recommended.
Note: Some analyzer designs may require identical ranges for NO,
NOX, and NO2 during operation of the analyzer.
2.4.6 Connect the recorder output cable(s) of the NO/NOX/
NO2 analyzer to the input terminals of the strip chart
recorder(s). All adjustments to the analyzer should be performed based
on the appropriate strip chart readings. References to analyzer
responses in the procedures given below refer to recorder responses.
2.4.7 Switch the valve to vent the flow from the permeation device
and adjust the diluent air flowrate, FD, to provide zero air
at the output manifold. The total air flow must exceed the total demand
of the analyzer(s) connected to the output manifold to insure that no
ambient air is pulled into the manifold vent. Allow the analyzer to
sample zero air until stable NO, NOX, and NO2
responses are obtained. After the responses have stabilized, adjust the
analyzer zero control(s).
Note: Some analyzers may have separate zero controls for NO,
NOX, and NO2. Other analyzers may have separate
zero controls only for NO and NOX, while still others may
[[Page 53]]
have only one zero common control to all three channels.
Offsetting the analyzer zero adjustments to +5% of scale is recommended
to facilitate observing negative zero drift. Record the stable zero air
responses as ZNO, ZNOX, and
ZNO2.
2.4.8 Preparation of NO and NOX calibration curves.
2.4.8.1 Adjustment of NO span control. Adjust the NO flow from the
standard NO cylinder to generate an NO concentration of approximately
80% of the upper range limit (URL) of the NO range. The exact NO
concentration is calculated from:
[GRAPHIC] [TIFF OMITTED] TR31AU93.049
where:
[NO]OUT = diluted NO concentration at the output manifold,
ppm
FNO = NO flowrate, scm\3\/min
[NO]STD=concentration of the undiluted NO standard, ppm
FD = diluent air flowrate, scm 3/min
Sample this NO concentration until the NO and NOX responses
have stabilized. Adjust the NO span control to obtain a recorder
response as indicated below:
recorder response (% scale) =
[GRAPHIC] [TIFF OMITTED] TR31AU93.050
[GRAPHIC] [TIFF OMITTED] TR31AU93.051
where:
URL = nominal upper range limit of the NO channel, ppm
Note: Some analyzers may have separate span controls for NO,
NOX, and NO2. Other analyzers may have separate
span controls only for NO and NOX, while still others may
have only one span control common to all three channels. When only one
span control is available, the span adjustment is made on the NO channel
of the analyzer.
If substantial adjustment of the NO span control is necessary, it may be
necessary to recheck the zero and span adjustments by repeating steps
2.4.7 and 2.4.8.1. Record the NO concentration and the analyzer's NO
response.
2.4.8.2 Adjustment of NOX span control. When adjusting
the analyzer's NOX span control, the presence of any
NO2 impurity in the standard NO cylinder must be taken into
account. Procedures for determining the amount of NO2
impurity in the standard NO cylinder are given in reference 13. The
exact NOX concentration is calculated from:
[GRAPHIC] [TIFF OMITTED] TR31AU93.052
where:
[NOX]OUT = diluted NOX cencentration at
the output manifold, ppm
[NO2]IMP = concentration of NO2
impurity in the standard NO cylinder, ppm
Adjust the NOX span control to obtain a convenient recorder
response as indicated below:
recorder response (% scale)
[GRAPHIC] [TIFF OMITTED] TR31AU93.053
Note: If the analyzer has only one span control, the span adjustment
is made on the NO channel and no further adjustment is made here for
NOX.
If substantial adjustment of the NOX span control is
necessary, it may be necessary to recheck the zero and span adjustments
by repeating steps 2.4.7 and 2.4.8.2. Record the NOX
concentration and the analyzer's NOX response.
2.4.8.3 Generate several additional concentrations (at least five
evenly spaced points across the remaining scale are suggested to verify
linearity) by decreasing FNO or increasing FD. For
each concentration generated, calculate the exact NO and NOX
concentrations using equations (16) and (18) respectively. Record the
analyzer's NO and NOX responses for each concentration. Plot
the analyzer responses versus the respective calculated NO and
NOX concentrations and draw or calculate the NO and
NOX calibration curves. For subsequent calibrations where
linearity can be assumed, these curves may be checked with a two-point
calibration consisting of a zero point and NO and NOX
concentrations of approximately 80 percent of the URL.
2.4.9 Preparation of NO2 calibration curve.
2.4.9.1 Remove the NO flow. Assuming the NO2 zero has
been properly adjusted while sampling zero air in step 2.4.7, switch the
valve to provide NO2 at the output manifold.
2.4.9.2 Adjust FD to generate an NO2
concentration of approximately 80 percent of the URL of the
NO2 range. The total air flow must exceed the demand of the
analyzer(s) under calibration. The actual concentration of
NO2 is calculated from:
[GRAPHIC] [TIFF OMITTED] TR31AU93.054
where:
[NO2]OUT = diluted NO2 concentration at
the output manifold, ppm
R = permeation rate, [mu]g/min
[[Page 54]]
K = 0.532[mu]l NO2/[mu]g NO2 (at 25 deg.C and 760
mm Hg)
Fp = air flowrate across permeation device, scm\3\/min
FD = diluent air flowrate, scm\3\/min
Sample this NO2 concentration until the NOX and
NO2 responses have stabilized. Adjust the NO2 span
control to obtain a recorder response as indicated below:
recorder response (% scale)
[GRAPHIC] [TIFF OMITTED] TR31AU93.055
Note: If the analyzer has only one or two span controls, the span
adjustments are made on the NO channel or NO and NOX channels
and no further adjustment is made here for NO2.
If substantial adjustment of the NO2 span control is
necessary it may be necessary to recheck the zero and span adjustments
by repeating steps 2.4.7 and 2.4.9.2. Record the NO2
concentration and the analyzer's NO2 response. Using the
NOX calibration curve obtained in step 2.4.8, measure and
record the NOX concentration as [NOX]M.
2.4.9.3 Adjust FD to obtain several other concentrations
of NO2 over the NO2 range (at least five evenly
spaced points across the remaining scale are suggested). Calculate each
NO2 concentration using equation (20) and record the
corresponding analyzer NO2 and NOX responses. Plot
the analyzer's NO2 responses versus the corresponding
calculated NO2 concentrations and draw or calculate the
NO2 calibration curve.
2.4.10 Determination of converter efficiency.
2.4.10.1 Plot [NOX]M (y-axis) versus
[NO2]OUT (x-axis) and draw or calculate the
converter efficiency curve. The slope of the curve times 100 is the
average converter efficiency, EC. The average converter
efficiency must be greater than 96 percent; if it is less than 96
percent, replace or service the converter.
Note: Supplemental information on calibration and other procedures
in this method are given in reference 13.
3. Frequency of calibration. The frequency of calibration, as well
as the number of points necessary to establish the calibration curve and
the frequency of other performance checks, will vary from one analyzer
to another. The user's quality control program should provide guidelines
for initial establishment of these variables and for subsequent
alteration as operational experience is accumulated. Manufacturers of
analyzers should include in their instruction/operation manuals
information and guidance as to these variables and on other matters of
operation, calibration, and quality control.
References
1. A. Fontijn, A. J. Sabadell, and R. J. Ronco, ``Homogeneous
Chemiluminescent Measurement of Nitric Oxide with Ozone,'' Anal. Chem.,
42, 575 (1970).
2. D. H. Stedman, E. E. Daby, F. Stuhl, and H. Niki, ``Analysis of
Ozone and Nitric Oxide by a Chemiluminiscent Method in Laboratory and
Atmospheric Studies of Photochemical Smog,'' J. Air Poll. Control
Assoc., 22, 260 (1972).
3. B. E. Martin, J. A. Hodgeson, and R. K. Stevens, ``Detection of
Nitric Oxide Chemiluminescence at Atmospheric Pressure,'' Presented at
164th National ACS Meeting, New York City, August 1972.
4. J. A. Hodgeson, K. A. Rehme, B. E. Martin, and R. K. Stevens,
``Measurements for Atmospheric Oxides of Nitrogen and Ammonia by
Chemiluminescence,'' Presented at 1972 APCA Meeting, Miami, FL, June
1972.
5. R. K. Stevens and J. A. Hodgeson, ``Applications of
Chemiluminescence Reactions to the Measurement of Air Pollutants,''
Anal. Chem., 45, 443A (1973).
6. L. P. Breitenbach and M. Shelef, ``Development of a Method for
the Analysis of NO2 and NH3 by NO-Measuring
Instruments,'' J. Air Poll. Control Assoc., 23, 128 (1973).
7. A. M. Winer, J. W. Peters, J. P. Smith, and J. N. Pitts, Jr.,
``Response of Commercial Chemiluminescent NO-NO2 Analyzers to
Other Nitrogen-Containing Compounds,'' Environ. Sci. Technol., 8, 1118
(1974).
8. K. A. Rehme, B. E. Martin, and J. A. Hodgeson, Tentative Method
for the Calibration of Nitric Oxide, Nitrogen Dioxide, and Ozone
Analyzers by Gas Phase Titration,'' EPA-R2-73-246, March 1974.
9. J. A. Hodgeson, R. K. Stevens, and B. E. Martin, ``A Stable Ozone
Source Applicable as a Secondary Standard for Calibration of Atmospheric
Monitors,'' ISA Transactions, 11, 161 (1972).
10. A. E. O'Keeffe and G. C. Ortman, ``Primary Standards for Trace
Gas Analysis,'' Anal. Chem., 38, 760 (1966).
11. F. P. Scaringelli, A. E. O'Keeffe, E. Rosenberg, and J. P. Bell,
``Preparation of Known Concentrations of Gases and Vapors with
Permeation Devices Calibrated Gravimetrically,'' Anal. Chem., 42, 871
(1970).
12. H. L. Rook, E. E. Hughes, R. S. Fuerst, and J. H. Margeson,
``Operation Characteristics of NO2 Permeation Devices,''
Presented at 167th National ACS Meeting, Los Angeles, CA, April 1974.
13. E. C. Ellis, ``Technical Assistance Document for the
Chemiluminescence Measurement of Nitrogen Dioxide,'' EPA-E600/4-75-003
(Available in draft form from the United States Environmental Protection
Agency, Department E (MD-76), Environmental Monitoring and Support
Laboratory, Research Triangle Park, NC 27711).
[[Page 55]]
14. A Procedure for Establishing Traceability of Gas Mixtures to
Certain National Bureau of Standards Standard Reference Materials. EPA-
600/7-81-010, Joint publication by NBS and EPA. Available from the U.S.
Environmental Protection Agency, Environmental Monitoring Systems
Laboratory (MD-77), Research Triangle Park, NC 27711, May 1981.
15. Quality Assurance Handbook for Air Pollution Measurement
Systems, Volume II, Ambient Air Specific Methods. The U.S. Environmental
Protection Agency, Environmental Monitoring Systems Laboratory, Research
Triangle Park, NC 27711. Publication No. EAP-600/4-77-027a.
[[Page 56]]
[41 FR 52688, Dec. 1, 1976, as amended at 48 FR 2529, Jan 20, 1983]
Appendix G to Part 50--Reference Method for the Determination of Lead in
Suspended Particulate Matter Collected From Ambient Air
1. Principle and applicability.
1.1 Ambient air suspended particulate matter is collected on a
glass-fiber filter for 24 hours using a high volume air sampler. The
analysis of the 24-hour samples may be performed for either individual
samples or composites of the samples collected over a calendar month or
quarter, provided that the compositing procedure has been approved in
accordance with section 2.8 of appendix C to part 58 of this chapter--
Modifications of methods by users. (Guidance or assistance in requesting
approval under Section 2.8 can be obtained from the address given in
section 2.7 of appendix C to part 58 of this chapter.)
1.2 Lead in the particulate matter is solubilized by extraction with
nitric acid (HNO3), facilitated by heat or by a mixture of
HNO3 and hydrochloric acid (HCl) facilitated by
ultrasonication.
1.3 The lead content of the sample is analyzed by atomic absorption
spectrometry using an air-acetylene flame, the 283.3 or 217.0 nm lead
absorption line, and the optimum instrumental conditions recommended by
the manufacturer.
1.4 The ultrasonication extraction with HNO3/HCl will
extract metals other than lead from ambient particulate matter.
2. Range, sensitivity, and lower detectable limit. The values given
below are typical of the methods capabilities. Absolute values will vary
for individual situations depending on the type of instrument used, the
lead line, and operating conditions.
2.1 Range. The typical range of the method is 0.07 to 7.5 [mu]g Pb/
m\3\ assuming an upper linear range of analysis of 15 [mu]g/ml and an
air volume of 2,400 m\3\.
2.2 Sensitivity. Typical sensitivities for a 1 percent change in
absorption (0.0044 absorbance units) are 0.2 and 0.5 [mu]g Pb/ml for the
217.0 and 283.3 nm lines, respectively.
2.3 Lower detectable limit (LDL). A typical LDL is 0.07 [mu]g Pb/
m\3\. The above value was calculated by doubling the between-laboratory
standard deviation obtained for the lowest measurable lead concentration
in a collaborative test of the method.(15) An air volume of 2,400 m\3\
was assumed.
3. Interferences. Two types of interferences are possible: chemical
and light scattering.
3.1 Chemical. Reports on the absence (1, 2, 3, 4, 5) of chemical
interferences far outweigh those reporting their presence, (6)
therefore, no correction for chemical interferences is given here. If
the analyst suspects that the sample matrix is causing a chemical
interference, the interference can be verified and corrected for by
carrying out the analysis
[[Page 57]]
with and without the method of standard additions.(7)
3.2 Light scattering. Nonatomic absorption or light scattering,
produced by high concentrations of dissolved solids in the sample, can
produce a significant interference, especially at low lead
concentrations. (2) The interference is greater at the 217.0 nm line
than at the 283.3 nm line. No interference was observed using the 283.3
nm line with a similar method.(1)
Light scattering interferences can, however, be corrected for
instrumentally. Since the dissolved solids can vary depending on the
origin of the sample, the correction may be necessary, especially when
using the 217.0 nm line. Dual beam instruments with a continuum source
give the most accurate correction. A less accurate correction can be
obtained by using a nonabsorbing lead line that is near the lead
analytical line. Information on use of these correction techniques can
be obtained from instrument manufacturers' manuals.
If instrumental correction is not feasible, the interference can be
eliminated by use of the ammonium pyrrolidinecarbodithioate-
methylisobutyl ketone, chelation-solvent extraction technique of sample
preparation.(8)
4. Precision and bias.
4.1 The high-volume sampling procedure used to collect ambient air
particulate matter has a between-laboratory relative standard deviation
of 3.7 percent over the range 80 to 125 [mu]g/m\3\.(9) The combined
extraction-analysis procedure has an average within-laboratory relative
standard deviation of 5 to 6 percent over the range 1.5 to 15 [mu]g Pb/
ml, and an average between laboratory relative standard deviation of 7
to 9 percent over the same range. These values include use of either
extraction procedure.
4.2 Single laboratory experiments and collaborative testing indicate
that there is no significant difference in lead recovery between the hot
and ultrasonic extraction procedures.(15)
5. Apparatus.
5.1 Sampling.
5.1.1 High-Volume Sampler. Use and calibrate the sampler as
described in appendix B to this part.
5.2 Analysis.
5.2.1 Atomic absorption spectrophotometer. Equipped with lead hollow
cathode or electrodeless discharge lamp.
5.2.1.1 Acetylene. The grade recommended by the instrument
manufacturer should be used. Change cylinder when pressure drops below
50-100 psig.
5.2.1.2 Air. Filtered to remove particulate, oil, and water.
5.2.2 Glassware. Class A borosilicate glassware should be used
throughout the analysis.
5.2.2.1 Beakers. 30 and 150 ml. graduated, Pyrex.
5.2.2.2 Volumetric flasks. 100-ml.
5.2.2.3 Pipettes. To deliver 50, 30, 15, 8, 4, 2, 1 ml.
5.2.2.4 Cleaning. All glassware should be scrupulously cleaned. The
following procedure is suggested. Wash with laboratory detergent, rinse,
soak for 4 hours in 20 percent (w/w) HNO3, rinse 3 times with
distilled-deionized water, and dry in a dust free manner.
5.2.3 Hot plate.
5.2.4. Ultrasonication water bath, unheated. Commercially available
laboratory ultrasonic cleaning baths of 450 watts or higher ``cleaning
power,'' i.e., actual ultrasonic power output to the bath have been
found satisfactory.
5.2.5 Template. To aid in sectioning the glass-fiber filter. See
figure 1 for dimensions.
5.2.6 Pizza cutter. Thin wheel. Thickness 1mm.
5.2.7 Watch glass.
5.2.8 Polyethylene bottles. For storage of samples. Linear
polyethylene gives better storage stability than other polyethylenes and
is preferred.
5.2.9 Parafilm ``M''.\1\ American Can Co., Marathon Products,
Neenah, Wis., or equivalent.
---------------------------------------------------------------------------
\1\ Mention of commercial products does not imply endorsement by the
U.S. Environmental Protection Agency.
---------------------------------------------------------------------------
6. Reagents.
6.1 Sampling.
6.1.1 Glass fiber filters. The specifications given below are
intended to aid the user in obtaining high quality filters with
reproducible properties. These specifications have been met by EPA
contractors.
6.1.1.1 Lead content. The absolute lead content of filters is not
critical, but low values are, of course, desirable. EPA typically
obtains filters with a lead content of 75 [mu]g/filter.
It is important that the variation in lead content from filter to
filter, within a given batch, be small.
6.1.1.2 Testing.
6.1.1.2.1 For large batches of filters (500 filters)
select at random 20 to 30 filters from a given batch. For small batches
(500 filters) a lesser number of filters may be taken. Cut
one \3/4\[dprime]x8[dprime] strip from each filter anywhere in the
filter. Analyze all strips, separately, according to the directions in
sections 7 and 8.
6.1.1.2.2 Calculate the total lead in each filter as
[GRAPHIC] [TIFF OMITTED] TC08NO91.084
where:
Fb = Amount of lead per 72 square inches of filter, [mu]g.
6.1.1.2.3 Calculate the mean, Fb, of the values and the
relative standard deviation
[[Page 58]]
(standard deviation/mean x 100). If the relative standard deviation is
high enough so that, in the analysts opinion, subtraction of
Fb, (section 10.3) may result in a significant error in the
[mu]g Pb/m\3,\ the batch should be rejected.
6.1.1.2.4 For acceptable batches, use the value of Fb to
correct all lead analyses (section 10.3) of particulate matter collected
using that batch of filters. If the analyses are below the LDL (section
2.3) no correction is necessary.
6.2 Analysis.
6.2.1 Concentrated (15.6 M) HNO3. ACS reagent grade
HNO3 and commercially available redistilled HNO3
has found to have sufficiently low lead concentrations.
6.2.2 Concentrated (11.7 M) HCl. ACS reagent grade.
6.2.3 Distilled-deionized water. (D.I. water).
6.2.4 3 M HNO3. This solution is used in the hot
extraction procedure. To prepare, add 192 ml of concentrated
HNO3 to D.I. water in a 1 l volumetric flask. Shake well,
cool, and dilute to volume with D.I. water. Caution: Nitric acid fumes
are toxic. Prepare in a well ventilated fume hood.
6.2.5 0.45 M HNO3. This solution is used as the matrix
for calibration standards when using the hot extraction procedure. To
prepare, add 29 ml of concentrated HNO3 to D.I. water in a 1
l volumetric flask. Shake well, cool, and dilute to volume with D.I.
water.
6.2.6 2.6 M HNO3+0 to 0.9 M HCl. This solution is used in
the ultrasonic extraction procedure. The concentration of HCl can be
varied from 0 to 0.9 M. Directions are given for preparation of a 2.6 M
HNO3+0.9 M HCl solution. Place 167 ml of concentrated
HNO3 into a 1 l volumetric flask and add 77 ml of
concentrated HCl. Stir 4 to 6 hours, dilute to nearly 1 l with D.I.
water, cool to room temperature, and dilute to 1 l.
6.2.7 0.40 M HNO3 + X M HCl. This solution is used as the
matrix for calibration standards when using the ultrasonic extraction
procedure. To prepare, add 26 ml of concentrated HNO3, plus
the ml of HCl required, to a 1 l volumetric flask. Dilute to nearly 1 l
with D.I. water, cool to room temperature, and dilute to 1 l. The amount
of HCl required can be determined from the following equation:
[GRAPHIC] [TIFF OMITTED] TC08NO91.085
where:
y = ml of concentrated HCl required.
x = molarity of HCl in 6.2.6.
0.15 = dilution factor in 7.2.2.
6.2.8 Lead nitrate, Pb(NO3)2. ACS reagent
grade, purity 99.0 percent. Heat for 4 hours at 120 deg.C and cool in a
desiccator.
6.3 Calibration standards.
6.3.1 Master standard, 1000 [mu]g Pb/ml in HNO3. Dissolve
1.598 g of Pb(NO3)2 in 0.45 M HNO3
contained in a 1 l volumetric flask and dilute to volume with 0.45 M
HNO3.
6.3.2 Master standard, 1000 [mu]g Pb/ml in HNO3/HCl.
Prepare as in section 6.3.1 except use the HNO3/HCl solution
in section 6.2.7.
Store standards in a polyethylene bottle. Commercially available
certified lead standard solutions may also be used.
7. Procedure.
7.1 Sampling. Collect samples for 24 hours using the procedure
described in reference 10 with glass-fiber filters meeting the
specifications in section 6.1.1. Transport collected samples to the
laboratory taking care to minimize contamination and loss of sample.
(16).
7.2 Sample preparation.
7.2.1 Hot extraction procedure.
7.2.1.1 Cut a \3/4\[dprime]x8[dprime] strip from the exposed filter
using a template and a pizza cutter as described in Figures 1 and 2.
Other cutting procedures may be used.
Lead in ambient particulate matter collected on glass fiber filters
has been shown to be uniformly distributed across the
filter.1, 3, 11 Another study \12\ has shown that when
sampling near a roadway, strip position contributes significantly to the
overall variability associated with lead analyses. Therefore, when
sampling near a roadway, additional strips should be analyzed to
minimize this variability.
7.2.1.2 Fold the strip in half twice and place in a 150-ml beaker.
Add 15 ml of 3 M HNO3 to cover the sample. The acid should
completely cover the sample. Cover the beaker with a watch glass.
7.2.1.3 Place beaker on the hot-plate, contained in a fume hood, and
boil gently for 30 min. Do not let the sample evaporate to dryness.
Caution: Nitric acid fumes are toxic.
7.2.1.4 Remove beaker from hot plate and cool to near room
temperature.
7.2.1.5 Quantitatively transfer the sample as follows:
7.2.1.5.1 Rinse watch glass and sides of beaker with D.I. water.
7.2.1.5.2 Decant extract and rinsings into a 100-ml volumetric
flask.
7.2.1.5.3 Add D.I. water to 40 ml mark on beaker, cover with watch
glass, and set aside for a minimum of 30 minutes. This is a critical
step and cannot be omitted since it allows the HNO3 trapped
in the filter to diffuse into the rinse water.
7.2.1.5.4 Decant the water from the filter into the volumetric
flask.
7.2.1.5.5 Rinse filter and beaker twice with D.I. water and add
rinsings to volumetric flask until total volume is 80 to 85 ml.
7.2.1.5.6 Stopper flask and shake vigorously. Set aside for
approximately 5 minutes or until foam has dissipated.
7.2.1.5.7 Bring solution to volume with D.I. water. Mix thoroughly.
[[Page 59]]
7.2.1.5.8 Allow solution to settle for one hour before proceeding
with analysis.
7.2.1.5.9 If sample is to be stored for subsequent analysis,
transfer to a linear polyethylene bottle.
7.2.2 Ultrasonic extraction procedure.
7.2.2.1 Cut a \3/4\[dprime]x8[dprime] strip from the exposed filter
as described in section 7.2.1.1.
7.2.2.2 Fold the strip in half twice and place in a 30 ml beaker.
Add 15 ml of the HNO3/HCl solution in section 6.2.6. The acid
should completely cover the sample. Cover the beaker with parafilm.
The parafilm should be placed over the beaker such that none of the
parafilm is in contact with water in the ultrasonic bath. Otherwise,
rinsing of the parafilm (section 7.2.2.4.1) may contaminate the sample.
7.2.2.3 Place the beaker in the ultrasonication bath and operate for
30 minutes.
7.2.2.4 Quantitatively transfer the sample as follows:
7.2.2.4.1 Rinse parafilm and sides of beaker with D.I. water.
7.2.2.4.2 Decant extract and rinsings into a 100 ml volumetric
flask.
7.2.2.4.3 Add 20 ml D.I. water to cover the filter strip, cover with
parafilm, and set aside for a minimum of 30 minutes. This is a critical
step and cannot be omitted. The sample is then processed as in sections
7.2.1.5.4 through 7.2.1.5.9.
Note: Samples prepared by the hot extraction procedure are now in
0.45 M HNO3. Samples prepared by the ultrasonication
procedure are in 0.40 M HNO3 + X M HCl.
8. Analysis.
8.1 Set the wavelength of the monochromator at 283.3 or 217.0 nm.
Set or align other instrumental operating conditions as recommended by
the manufacturer.
8.2 The sample can be analyzed directly from the volumetric flask,
or an appropriate amount of sample decanted into a sample analysis tube.
In either case, care should be taken not to disturb the settled solids.
8.3 Aspirate samples, calibration standards and blanks (section 9.2)
into the flame and record the equilibrium absorbance.
8.4 Determine the lead concentration in [mu]g Pb/ml, from the
calibration curve, section 9.3.
8.5 Samples that exceed the linear calibration range should be
diluted with acid of the same concentration as the calibration standards
and reanalyzed.
9. Calibration.
9.1 Working standard, 20 [mu]g Pb/ml. Prepared by diluting 2.0 ml of
the master standard (section 6.3.1 if the hot acid extraction was used
or section 6.3.2 if the ultrasonic extraction procedure was used) to 100
ml with acid of the same concentration as used in preparing the master
standard.
9.2 Calibration standards. Prepare daily by diluting the working
standard, with the same acid matrix, as indicated below. Other lead
concentrations may be used.
------------------------------------------------------------------------
Final Concentration
Volume of 20 [mu]g/ml working standard, ml volume, ml [mu]g Pb/ml
------------------------------------------------------------------------
0............................................ 100 0
1.0.......................................... 200 0.1
2.0.......................................... 200 0.2
2.0.......................................... 100 0.4
4.0.......................................... 100 0.8
8.0.......................................... 100 1.6
15.0......................................... 100 3.0
30.0......................................... 100 6.0
50.0......................................... 100 10.0
100.0........................................ 100 20.0
------------------------------------------------------------------------
9.3 Preparation of calibration curve. Since the working range of
analysis will vary depending on which lead line is used and the type of
instrument, no one set of instructions for preparation of a calibration
curve can be given. Select standards (plus the reagent blank), in the
same acid concentration as the samples, to cover the linear absorption
range indicated by the instrument manufacturer. Measure the absorbance
of the blank and standards as in section 8.0. Repeat until good
agreement is obtained between replicates. Plot absorbance (y-axis)
versus concentration in [mu]g Pb/ml (x-axis). Draw (or compute) a
straight line through the linear portion of the curve. Do not force the
calibration curve through zero. Other calibration procedures may be
used.
To determine stability of the calibration curve, remeasure--
alternately--one of the following calibration standards for every 10th
sample analyzed: Concentration [le] 1[mu]g Pb/ml;
concentration [le] 10 [mu]g Pb/ml. If either standard
deviates by more than 5 percent from the value predicted by the
calibration curve, recalibrate and repeat the previous 10 analyses.
10. Calculation.
10.1 Measured air volume. Calculate the measured air volume at
Standard Temperature and Pressure as described in Reference 10.
10.2 Lead concentration. Calculate lead concentration in the air
sample.
[[Page 60]]
where:
C = Concentration, [mu]g Pb/sm\3\.
[mu]g Pb/ml = Lead concentration determined from section 8.
100 ml/strip = Total sample volume.
12 strips = Total useable filter area, 8[dprime]x9[dprime]. Exposed area
of one strip, \3/4\[dprime]x7[dprime].
Filter = Total area of one strip, \3/4\[dprime]x8[dprime].
Fb = Lead concentration of blank filter, [mu]g, from section
6.1.1.2.3.
VSTP = Air volume from section 10.2.
11. Quality control.
\3/4\[dprime]x8[dprime] glass fiber filter strips containing 80 to
2000 [mu]g Pb/strip (as lead salts) and blank strips with zero Pb
content should be used to determine if the method--as being used--has
any bias. Quality control charts should be established to monitor
differences between measured and true values. The frequency of such
checks will depend on the local quality control program.
To minimize the possibility of generating unreliable data, the user
should follow practices established for assuring the quality of air
pollution data, (13) and take part in EPA's semiannual audit program for
lead analyses.
12. Trouble shooting.
1. During extraction of lead by the hot extraction procedure, it is
important to keep the sample covered so that corrosion products--formed
on fume hood surfaces which may contain lead--are not deposited in the
extract.
2. The sample acid concentration should minimize corrosion of the
nebulizer. However, different nebulizers may require lower acid
concentrations. Lower concentrations can be used provided samples and
standards have the same acid concentration.
3. Ashing of particulate samples has been found, by EPA and
contractor laboratories, to be unnecessary in lead analyses by atomic
absorption. Therefore, this step was omitted from the method.
4. Filtration of extracted samples, to remove particulate matter,
was specifically excluded from sample preparation, because some analysts
have observed losses of lead due to filtration.
5. If suspended solids should clog the nebulizer during analysis of
samples, centrifuge the sample to remove the solids.
13. Authority.
(Secs. 109 and 301(a), Clean Air Act, as amended (42 U.S.C. 7409,
7601(a)))
14. References.
1. Scott, D. R. et al. ``Atomic Absorption and Optical Emission
Analysis of NASN Atmospheric Particulate Samples for Lead.'' Envir. Sci.
and Tech., 10, 877-880 (1976).
2. Skogerboe, R. K. et al. ``Monitoring for Lead in the
Environment.'' pp. 57-66, Department of Chemistry, Colorado State
University, Fort Collins, CO 80523. Submitted to National Science
Foundation for publications, 1976.
3. Zdrojewski, A. et al. ``The Accurate Measurement of Lead in
Airborne Particulates.'' Inter. J. Environ. Anal. Chem., 2, 63-77
(1972).
4. Slavin, W., ``Atomic Absorption Spectroscopy.'' Published by
Interscience Company, New York, NY (1968).
5. Kirkbright, G. F., and Sargent, M., ``Atomic Absorption and
Fluorescence Spectroscopy.'' Published by Academic Press, New York, NY
1974.
6. Burnham, C. D. et al., ``Determination of Lead in Airborne
Particulates in Chicago and Cook County, IL, by Atomic Absorption
Spectroscopy.'' Envir. Sci. and Tech., 3, 472-475 (1969).
7. ``Proposed Recommended Practices for Atomic Absorption
Spectrometry.'' ASTM Book of Standards, part 30, pp. 1596-1608 (July
1973).
8. Koirttyohann, S. R. and Wen, J. W., ``Critical Study of the APCD-
MIBK Extraction System for Atomic Absorption.'' Anal. Chem., 45, 1986-
1989 (1973).
9. Collaborative Study of Reference Method for the Determination of
Suspended Particulates in the Atmosphere (High Volume Method).
Obtainable from National Technical Information Service, Department of
Commerce, Port Royal Road, Springfield, VA 22151, as PB-205-891.
10. [Reserved]
11. Dubois, L., et al., ``The Metal Content of Urban Air.'' JAPCA,
16, 77-78 (1966).
12. EPA Report No. 600/4-77-034, June 1977, ``Los Angeles Catalyst
Study Symposium.'' Page 223.
13. Quality Assurance Handbook for Air Pollution Measurement System.
Volume 1--Principles. EPA-600/9-76-005, March 1976.
14. Thompson, R. J. et al., ``Analysis of Selected Elements in
Atmospheric Particulate Matter by Atomic Absorption.'' Atomic Absorption
Newsletter, 9, No. 3, May-June 1970.
15. To be published. EPA, QAB, EMSL, RTP, N.C. 27711
[[Page 61]]
16. Quality Assurance Handbook for Air Pollution Measurement
Systems. Volume II--Ambient Air Specific Methods. EPA-600/4-77/027a, May
1977.
[[Page 62]]
(Secs. 109, 301(a) of the Clean Air Act, as amended (42 U.S.C. 7409,
7601(a)); secs. 110, 301(a) and 319 of the Clean Air Act (42 U.S.C.
7410, 7601(a), 7619))
[43 FR 46258, Oct. 5, 1978; 44 FR 37915, June 29, 1979, as amended at 46
FR 44163, Sept. 3, 1981; 52 FR 24664, July 1, 1987]
Appendix H to Part 50--Interpretation of the 1-Hour Primary and
Secondary National Ambient Air Quality Standards for Ozone
1. General
This appendix explains how to determine when the expected number of
days per calendar year with maximum hourly average concentrations above
0.12 ppm (235 [mu]g/m\3\) is equal to or less than 1. An expanded
discussion of these procedures and associated examples are contained in
the ``Guideline for Interpretation of Ozone Air Quality Standards.'' For
purposes of clarity in the following discussion, it is convenient to use
the term ``exceedance'' to describe a daily maximum hourly average ozone
measurement that is greater than the level of the standard. Therefore,
the phrase ``expected number of days with maximum hourly average ozone
concentrations above the level of the standard'' may be simply stated as
the ``expected number of exceedances.''
[[Page 63]]
The basic principle in making this determination is relatively
straightforward. Most of the complications that arise in determining the
expected number of annual exceedances relate to accounting for
incomplete sampling. In general, the average number of exceedances per
calendar year must be less than or equal to 1. In its simplest form, the
number of exceedances at a monitoring site would be recorded for each
calendar year and then averaged over the past 3 calendar years to
determine if this average is less than or equal to 1.
2. Interpretation of Expected Exceedances
The ozone standard states that the expected number of exceedances
per year must be less than or equal to 1. The statistical term
``expected number'' is basically an arithmetic average. The following
example explains what it would mean for an area to be in compliance with
this type of standard. Suppose a monitoring station records a valid
daily maximum hourly average ozone value for every day of the year
during the past 3 years. At the end of each year, the number of days
with maximum hourly concentrations above 0.12 ppm is determined and this
number is averaged with the results of previous years. As long as this
average remains ``less than or equal to 1,'' the area is in compliance.
3. Estimating the Number of Exceedances for a Year
In general, a valid daily maximum hourly average value may not be
available for each day of the year, and it will be necessary to account
for these missing values when estimating the number of exceedances for a
particular calendar year. The purpose of these computations is to
determine if the expected number of exceedances per year is less than or
equal to 1. Thus, if a site has two or more observed exceedances each
year, the standard is not met and it is not necessary to use the
procedures of this section to account for incomplete sampling.
The term ``missing value'' is used here in the general sense to
describe all days that do not have an associated ozone measurement. In
some cases, a measurement might actually have been missed but in other
cases no measurement may have been scheduled for that day. A daily
maximum ozone value is defined to be the highest hourly ozone value
recorded for the day. This daily maximum value is considered to be valid
if 75 percent of the hours from 9:01 a.m. to 9:00 p.m. (LST) were
measured or if the highest hour is greater than the level of the
standard.
In some areas, the seasonal pattern of ozone is so pronounced that
entire months need not be sampled because it is extremely unlikely that
the standard would be exceeded. Any such waiver of the ozone monitoring
requirement would be handled under provisions of 40 CFR, part 58. Some
allowance should also be made for days for which valid daily maximum
hourly values were not obtained but which would quite likely have been
below the standard. Such an allowance introduces a complication in that
it becomes necessary to define under what conditions a missing value may
be assumed to have been less than the level of the standard. The
following criterion may be used for ozone:
A missing daily maximum ozone value may be assumed to be less than
the level of the standard if the valid daily maxima on both the
preceding day and the following day do not exceed 75 percent of the
level of the standard.
Let z denote the number of missing daily maximum values that may be
assumed to be less than the standard. Then the following formula shall
be used to estimate the expected number of exceedances for the year:
[GRAPHIC] [TIFF OMITTED] TC08NO91.086
(*Indicates multiplication.)
where:
e = the estimated number of exceedances for the year,
N = the number of required monitoring days in the year,
n = the number of valid daily maxima,
v = the number of daily values above the level of the standard, and
z = the number of days assumed to be less than the standard level.
This estimated number of exceedances shall be rounded to one decimal
place (fractional parts equal to 0.05 round up).
It should be noted that N will be the total number of days in the
year unless the appropriate Regional Administrator has granted a waiver
under the provisions of 40 CFR part 58.
The above equation may be interpreted intuitively in the following
manner. The estimated number of exceedances is equal to the observed
number of exceedances (v) plus an increment that accounts for incomplete
sampling. There were (N-n) missing values for the year but a certain
number of these, namely z, were assumed to be less than the standard.
Therefore, (N-n-z) missing values are considered to include possible
exceedances. The fraction of measured values that are above the level of
the standard is v/n. It is assumed that this same fraction applies to
the (N-n-z) missing values and that (v/n)*(N-n-z) of these values would
also have exceeded the level of the standard.
[44 FR 8220, Feb. 8, 1979, as amended at 62 FR 38895, July 18, 1997]
[[Page 64]]
Appendix I to Part 50--Interpretation of the 8-Hour Primary and
Secondary National Ambient Air Quality Standards for Ozone
1. General.
This appendix explains the data handling conventions and
computations necessary for determining whether the national 8-hour
primary and secondary ambient air quality standards for ozone specified
in Sec. 50.10 are met at an ambient ozone air quality monitoring site.
Ozone is measured in the ambient air by a reference method based on
appendix D of this part. Data reporting, data handling, and computation
procedures to be used in making comparisons between reported ozone
concentrations and the level of the ozone standard are specified in the
following sections. Whether to exclude, retain, or make adjustments to
the data affected by stratospheric ozone intrusion or other natural
events is subject to the approval of the appropriate Regional
Administrator.
2. Primary and Secondary Ambient Air Quality Standards for Ozone.
2.1 Data Reporting and Handling Conventions.
2.1.1 Computing 8-hour averages. Hourly average concentrations shall
be reported in parts per million (ppm) to the third decimal place, with
additional digits to the right being truncated. Running 8-hour averages
shall be computed from the hourly ozone concentration data for each hour
of the year and the result shall be stored in the first, or start, hour
of the 8-hour period. An 8-hour average shall be considered valid if at
least 75% of the hourly averages for the 8-hour period are available. In
the event that only 6 (or 7) hourly averages are available, the 8-hour
average shall be computed on the basis of the hours available using 6
(or 7) as the divisor. (8-hour periods with three or more missing hours
shall not be ignored if, after substituting one-half the minimum
detectable limit for the missing hourly concentrations, the 8-hour
average concentration is greater than the level of the standard.) The
computed 8-hour average ozone concentrations shall be reported to three
decimal places (the insignificant digits to the right of the third
decimal place are truncated, consistent with the data handling
procedures for the reported data.)
2.1.2 Daily maximum 8-hour average concentrations. (a) There are 24
possible running 8-hour average ozone concentrations for each calendar
day during the ozone monitoring season. (Ozone monitoring seasons vary
by geographic location as designated in part 58, appendix D to this
chapter.) The daily maximum 8-hour concentration for a given calendar
day is the highest of the 24 possible 8-hour average concentrations
computed for that day. This process is repeated, yielding a daily
maximum 8-hour average ozone concentration for each calendar day with
ambient ozone monitoring data. Because the 8-hour averages are recorded
in the start hour, the daily maximum 8-hour concentrations from two
consecutive days may have some hourly concentrations in common.
Generally, overlapping daily maximum 8-hour averages are not likely,
except in those non-urban monitoring locations with less pronounced
diurnal variation in hourly concentrations.
(b) An ozone monitoring day shall be counted as a valid day if valid
8-hour averages are available for at least 75% of possible hours in the
day (i.e., at least 18 of the 24 averages). In the event that less than
75% of the 8-hour averages are available, a day shall also be counted as
a valid day if the daily maximum 8-hour average concentration for that
day is greater than the level of the ambient standard.
2.2 Primary and Secondary Standard-related Summary Statistic. The
standard-related summary statistic is the annual fourth-highest daily
maximum 8-hour ozone concentration, expressed in parts per million,
averaged over three years. The 3-year average shall be computed using
the three most recent, consecutive calendar years of monitoring data
meeting the data completeness requirements described in this appendix.
The computed 3-year average of the annual fourth-highest daily maximum
8-hour average ozone concentrations shall be expressed to three decimal
places (the remaining digits to the right are truncated.)
2.3 Comparisons with the Primary and Secondary Ozone Standards. (a)
The primary and secondary ozone ambient air quality standards are met at
an ambient air quality monitoring site when the 3-year average of the
annual fourth-highest daily maximum 8-hour average ozone concentration
is less than or equal to 0.08 ppm. The number of significant figures in
the level of the standard dictates the rounding convention for comparing
the computed 3-year average annual fourth-highest daily maximum 8-hour
average ozone concentration with the level of the standard. The third
decimal place of the computed value is rounded, with values equal to or
greater than 5 rounding up. Thus, a computed 3-year average ozone
concentration of 0.085 ppm is the smallest value that is greater than
0.08 ppm.
(b) This comparison shall be based on three consecutive, complete
calendar years of air quality monitoring data. This requirement is met
for the three year period at a monitoring site if daily maximum 8-hour
average concentrations are available for at least 90%, on average, of
the days during the designated ozone monitoring season, with a minimum
data completeness in any one year of at least 75% of the designated
sampling days. When
[[Page 65]]
computing whether the minimum data completeness requirements have been
met, meteorological or ambient data may be sufficient to demonstrate
that meteorological conditions on missing days were not conducive to
concentrations above the level of the standard. Missing days assumed
less than the level of the standard are counted for the purpose of
meeting the data completeness requirement, subject to the approval of
the appropriate Regional Administrator.
(c) Years with concentrations greater than the level of the standard
shall not be ignored on the ground that they have less than complete
data. Thus, in computing the 3-year average fourth maximum
concentration, calendar years with less than 75% data completeness shall
be included in the computation if the average annual fourth maximum 8-
hour concentration is greater than the level of the standard.
(d) Comparisons with the primary and secondary ozone standards are
demonstrated by examples 1 and 2 in paragraphs (d)(1) and (d) (2)
respectively as follows:
(1) As shown in example 1, the primary and secondary standards are
met at this monitoring site because the 3-year average of the annual
fourth-highest daily maximum 8-hour average ozone concentrations (i.e.,
0.084 ppm) is less than or equal to 0.08 ppm. The data completeness
requirement is also met because the average percent of days with valid
ambient monitoring data is greater than 90%, and no single year has less
than 75% data completeness.
Example 1. Ambient monitoring site attaining the primary and secondary ozone standards
----------------------------------------------------------------------------------------------------------------
1st Highest 2nd Highest 3rd Highest 4th Highest 5th Highest
Percent Daily Max 8- Daily Max 8- Daily Max 8- Daily Max 8- Daily Max 8-
Year Valid Days hour Conc. hour Conc. hour Conc. hour Conc. hour Conc.
(ppm) (ppm) (ppm) (ppm) (ppm)
----------------------------------------------------------------------------------------------------------------
1993.............................. 100% 0.092 0.091 0.090 0.088 0.085
----------------------------------------------------------------------------------------------------------------
1994.............................. 96% 0.090 0.089 0.086 0.084 0.080
----------------------------------------------------------------------------------------------------------------
1995.............................. 98% 0.087 0.085 0.083 0.080 0.075
================================================================================================================
Average....................... 98%
----------------------------------------------------------------------------------------------------------------
(2) As shown in example 2, the primary and secondary standards are
not met at this monitoring site because the 3-year average of the
fourth-highest daily maximum 8-hour average ozone concentrations (i.e.,
0.093 ppm) is greater than 0.08 ppm. Note that the ozone concentration
data for 1994 is used in these computations, even though the data
capture is less than 75%, because the average fourth-highest daily
maximum 8-hour average concentration is greater than 0.08 ppm.
Example 2. Ambient Monitoring Site Failing to Meet the Primary and Secondary Ozone Standards
----------------------------------------------------------------------------------------------------------------
1st Highest 2nd Highest 3rd Highest 4th Highest 5th Highest
Percent Daily Max 8- Daily Max 8- Daily Max 8- Daily Max 8- Daily Max 8-
Year Valid Days hour Conc. hour Conc. hour Conc. hour Conc. hour Conc.
(ppm) (ppm) (ppm) (ppm) (ppm)
----------------------------------------------------------------------------------------------------------------
1993.............................. 96% 0.105 0.103 0.103 0.102 0.102
----------------------------------------------------------------------------------------------------------------
1994.............................. 74% 0.090 0.085 0.082 0.080 0.078
----------------------------------------------------------------------------------------------------------------
1995.............................. 98% 0.103 0.101 0.101 0.097 0.095
================================================================================================================
Average....................... 89%
----------------------------------------------------------------------------------------------------------------
3. Design Values for Primary and Secondary Ambient Air Quality
Standards for Ozone. The air quality design value at a monitoring site
is defined as that concentration that when reduced to the level of the
standard ensures that the site meets the standard. For a concentration-
based standard, the air quality design value is simply the standard-
related test statistic. Thus, for the primary and secondary ozone
standards, the 3-year average annual fourth-highest daily maximum 8-hour
average ozone concentration is also the air quality design value for the
site.
[62 FR 38895, July 18, 1997]
Appendix J to Part 50--Reference Method for the Determination of
Particulate Matter as PM10 in the Atmosphere
1.0 Applicability.
[[Page 66]]
1.1 This method provides for the measurement of the mass
concentration of particulate matter with an aerodynamic diameter less
than or equal to a nominal 10 micrometers (PM1O) in ambient
air over a 24-hour period for purposes of determining attainment and
maintenance of the primary and secondary national ambient air quality
standards for particulate matter specified in Sec. 50.6 of this chapter.
The measurement process is nondestructive, and the PM10
sample can be subjected to subsequent physical or chemical analyses.
Quality assurance procedures and guidance are provided in part 58,
appendices A and B, of this chapter and in References 1 and 2.
2.0 Principle.
2.1 An air sampler draws ambient air at a constant flow rate into a
specially shaped inlet where the suspended particulate matter is
inertially separated into one or more size fractions within the
PM10 size range. Each size fraction in the PM1O
size range is then collected on a separate filter over the specified
sampling period. The particle size discrimination characteristics
(sampling effectiveness and 50 percent cutpoint) of the sampler inlet
are prescribed as performance specifications in part 53 of this chapter.
2.2 Each filter is weighed (after moisture equilibration) before and
after use to determine the net weight (mass) gain due to collected
PM10. The total volume of air sampled, corrected to EPA
reference conditions (25 C, 101.3 kPa), is determined from the measured
flow rate and the sampling time. The mass concentration of
PM10 in the ambient air is computed as the total mass of
collected particles in the PM10 size range divided by the
volume of air sampled, and is expressed in micrograms per standard cubic
meter ([mu]g/std m\3\). For PM10 samples collected at
temperatures and pressures significantly different from EPA reference
conditions, these corrected concentrations sometimes differ
substantially from actual concentrations (in micrograms per actual cubic
meter), particularly at high elevations. Although not required, the
actual PM10 concentration can be calculated from the
corrected concentration, using the average ambient temperature and
barometric pressure during the sampling period.
2.3 A method based on this principle will be considered a reference
method only if (a) the associated sampler meets the requirements
specified in this appendix and the requirements in part 53 of this
chapter, and (b) the method has been designated as a reference method in
accordance with part 53 of this chapter.
3.0 Range.
3.1 The lower limit of the mass concentration range is determined by
the repeatability of filter tare weights, assuming the nominal air
sample volume for the sampler. For samplers having an automatic filter-
changing mechanism, there may be no upper limit. For samplers that do
not have an automatic filter-changing mechanism, the upper limit is
determined by the filter mass loading beyond which the sampler no longer
maintains the operating flow rate within specified limits due to
increased pressure drop across the loaded filter. This upper limit
cannot be specified precisely because it is a complex function of the
ambient particle size distribution and type, humidity, filter type, and
perhaps other factors. Nevertheless, all samplers should be capable of
measuring 24-hour PM10 mass concentrations of at least 300
[mu]g/std m\3\ while maintaining the operating flow rate within the
specified limits.
4.0 Precision.
4.1 The precision of PM10 samplers must be 5 [mu]g/m\3\
for PM10 concentrations below 80 [mu]g/m\3\ and 7 percent for
PM10 concentrations above 80 [mu]g/m\3\, as required by part
53 of this chapter, which prescribes a test procedure that determines
the variation in the PM10 concentration measurements of
identical samplers under typical sampling conditions. Continual
assessment of precision via collocated samplers is required by part 58
of this chapter for PM10 samplers used in certain monitoring
networks.
5.0 Accuracy.
5.1 Because the size of the particles making up ambient particulate
matter varies over a wide range and the concentration of particles
varies with particle size, it is difficult to define the absolute
accuracy of PM10 samplers. Part 53 of this chapter provides a
specification for the sampling effectiveness of PM10
samplers. This specification requires that the expected mass
concentration calculated for a candidate PM10 sampler, when
sampling a specified particle size distribution, be within
10 percent of that calculated for an ideal sampler whose
sampling effectiveness is explicitly specified. Also, the particle size
for 50 percent sampling effectivensss is required to be
100.5 micrometers. Other specifications related to accuracy
apply to flow measurement and calibration, filter media, analytical
(weighing) procedures, and artifact. The flow rate accuracy of
PM10 samplers used in certain monitoring networks is required
by part 58 of this chapter to be assessed periodically via flow rate
audits.
6.0 Potential Sources of Error.
6.1 Volatile Particles. Volatile particles collected on filters are
often lost during shipment and/or storage of the filters prior to the
post-sampling weighing \3\. Although shipment or storage of loaded
filters is sometimes unavoidable, filters should be reweighed as soon as
practical to minimize these losses.
6.2 Artifacts. Positive errors in PM10 concentration
measurements may result from retention of gaseous species on filters
4, 5. Such errors include the retention of sulfur
[[Page 67]]
dioxide and nitric acid. Retention of sulfur dioxide on filters,
followed by oxidation to sulfate, is referred to as artifact sulfate
formation, a phenomenon which increases with increasing filter
alkalinity \6\. Little or no artifact sulfate formation should occur
using filters that meet the alkalinity specification in section 7.2.4.
Artifact nitrate formation, resulting primarily from retention of nitric
acid, occurs to varying degrees on many filter types, including glass
fiber, cellulose ester, and many quartz fiber filters
5, 7, 8, 9, 10. Loss of true atmospheric particulate nitrate
during or following sampling may also occur due to dissociation or
chemical reaction. This phenomenon has been observed on
Teflon[reg] filters \8\ and inferred for quartz fiber filters
11, 12. The magnitude of nitrate artifact errors in
PM10 mass concentration measurements will vary with location
and ambient temperature; however, for most sampling locations, these
errors are expected to be small.
6.3 Humidity. The effects of ambient humidity on the sample are
unavoidable. The filter equilibration procedure in section 9.0 is
designed to minimize the effects of moisture on the filter medium.
6.4 Filter Handling. Careful handling of filters between presampling
and postsampling weighings is necessary to avoid errors due to damaged
filters or loss of collected particles from the filters. Use of a filter
cartridge or cassette may reduce the magnitude of these errors. Filters
must also meet the integrity specification in section 7.2.3.
6.5 Flow Rate Variation. Variations in the sampler's operating flow
rate may alter the particle size discrimination characteristics of the
sampler inlet. The magnitude of this error will depend on the
sensitivity of the inlet to variations in flow rate and on the particle
distribution in the atmosphere during the sampling period. The use of a
flow control device (section 7.1.3) is required to minimize this error.
6.6 Air Volume Determination. Errors in the air volume determination
may result from errors in the flow rate and/or sampling time
measurements. The flow control device serves to minimize errors in the
flow rate determination, and an elapsed time meter (section 7.1.5) is
required to minimize the error in the sampling time measurement.
7.0 Apparatus.
7.1 PM10 Sampler.
7.1.1 The sampler shall be designed to:
a. Draw the air sample into the sampler inlet and through the
particle collection filter at a uniform face velocity.
b. Hold and seal the filter in a horizontal position so that sample
air is drawn downward through the filter.
c. Allow the filter to be installed and removed conveniently.
d. Protect the filter and sampler from precipitation and prevent
insects and other debris from being sampled.
e. Minimize air leaks that would cause error in the measurement of
the air volume passing through the filter.
f. Discharge exhaust air at a sufficient distance from the sampler
inlet to minimize the sampling of exhaust air.
g. Minimize the collection of dust from the supporting surface.
7.1.2 The sampler shall have a sample air inlet system that, when
operated within a specified flow rate range, provides particle size
discrimination characteristics meeting all of the applicable performance
specifications prescribed in part 53 of this chapter. The sampler inlet
shall show no significant wind direction dependence. The latter
requirement can generally be satisfied by an inlet shape that is
circularly symmetrical about a vertical axis.
7.1.3 The sampler shall have a flow control device capable of
maintaining the sampler's operating flow rate within the flow rate
limits specified for the sampler inlet over normal variations in line
voltage and filter pressure drop.
7.1.4 The sampler shall provide a means to measure the total flow
rate during the sampling period. A continuous flow recorder is
recommended but not required. The flow measurement device shall be
accurate to 2 percent.
7.1.5 A timing/control device capable of starting and stopping the
sampler shall be used to obtain a sample collection period of 24
1 hr (1,440 60 min). An elapsed time meter,
accurate to within 15 minutes, shall be used to measure
sampling time. This meter is optional for samplers with continuous flow
recorders if the sampling time measurement obtained by means of the
recorder meets the 15 minute accuracy specification.
7.1.6 The sampler shall have an associated operation or instruction
manual as required by part 53 of this chapter which includes detailed
instructions on the calibration, operation, and maintenance of the
sampler.
7.2 Filters.
7.2.1 Filter Medium. No commercially available filter medium is
ideal in all respects for all samplers. The user's goals in sampling
determine the relative importance of various filter characteristics
(e.g., cost, ease of handling, physical and chemical characteristics,
etc.) and, consequently, determine the choice among acceptable filters.
Furthermore, certain types of filters may not be suitable for use with
some samplers, particularly under heavy loading conditions (high mass
concentrations), because of high or rapid increase in the filter flow
resistance that would exceed the capability of the sampler's flow
control device. However, samplers equipped with automatic filter-
changing
[[Page 68]]
mechanisms may allow use of these types of filters. The specifications
given below are minimum requirements to ensure acceptability of the
filter medium for measurement of PM10 mass concentrations.
Other filter evaluation criteria should be considered to meet individual
sampling and analysis objectives.
7.2.2 Collection Efficiency. [gE]99 percent, as measured by the DOP
test (ASTM-2986) with 0.3 [mu]m particles at the sampler's operating
face velocity.
7.2.3 Integrity. 5 [mu]g/m\3\ (assuming sampler's
nominal 24-hour air sample volume). Integrity is measured as the
PM10 concentration equivalent corresponding to the average
difference between the initial and the final weights of a random sample
of test filters that are weighed and handled under actual or simulated
sampling conditions, but have no air sample passed through them (i.e.,
filter blanks). As a minimum, the test procedure must include initial
equilibration and weighing, installation on an inoperative sampler,
removal from the sampler, and final equilibration and weighing.
7.2.4 Alkalinity. <25 microequivalents/gram of filter, as measured
by the procedure given in Reference 13 following at least two months
storage in a clean environment (free from contamination by acidic gases)
at room temperature and humidity.
7.3 Flow Rate Transfer Standard. The flow rate transfer standard
must be suitable for the sampler's operating flow rate and must be
calibrated against a primary flow or volume standard that is traceable
to the National Bureau of Standards (NBS). The flow rate transfer
standard must be capable of measuring the sampler's operating flow rate
with an accuracy of 2 percent.
7.4 Filter Conditioning Environment.
7.4.1 Temperature range: 15 to 30 C.
7.4.2 Temperature control: 3 C.
7.4.3 Humidity range: 20% to 45% RH.
7.4.4 Humidity control: 5% RH.
7.5 Analytical Balance. The analytical balance must be suitable for
weighing the type and size of filters required by the sampler. The range
and sensitivity required will depend on the filter tare weights and mass
loadings. Typically, an analytical balance with a sensitivity of 0.1 mg
is required for high volume samplers (flow rates 0.5 m\3\/
min). Lower volume samplers (flow rates <0.5 m\3\/min) will require a
more sensitive balance.
8.0 Calibration.
8.1 General Requirements.
8.1.1 Calibration of the sampler's flow measurement device is
required to establish traceability of subsequent flow measurements to a
primary standard. A flow rate transfer standard calibrated against a
primary flow or volume standard shall be used to calibrate or verify the
accuracy of the sampler's flow measurement device.
8.1.2 Particle size discrimination by inertial separation requires
that specific air velocities be maintained in the sampler's air inlet
system. Therefore, the flow rate through the sampler's inlet must be
maintained throughout the sampling period within the design flow rate
range specified by the manufacturer. Design flow rates are specified as
actual volumetric flow rates, measured at existing conditions of
temperature and pressure (Qa). In contrast, mass
concentrations of PM10 are computed using flow rates
corrected to EPA reference conditions of temperature and pressure
(Qstd).
8.2 Flow Rate Calibration Procedure.
8.2.1 PM10 samplers employ various types of flow control
and flow measurement devices. The specific procedure used for flow rate
calibration or verification will vary depending on the type of flow
controller and flow indicator employed. Calibration in terms of actual
volumetric flow rates (Qa) is generally recommended, but
other measures of flow rate (e.g., Qstd) may be used provided
the requirements of section 8.1 are met. The general procedure given
here is based on actual volumetric flow units (Qa) and serves
to illustrate the steps involved in the calibration of a PM10
sampler. Consult the sampler manufacturer's instruction manual and
Reference 2 for specific guidance on calibration. Reference 14 provides
additional information on the use of the commonly used measures of flow
rate and their interrelationships.
8.2.2 Calibrate the flow rate transfer standard against a primary
flow or volume standard traceable to NBS. Establish a calibration
relationship (e.g., an equation or family of curves) such that
traceability to the primary standard is accurate to within 2 percent
over the expected range of ambient conditions (i.e., temperatures and
pressures) under which the transfer standard will be used. Recalibrate
the transfer standard periodically.
8.2.3 Following the sampler manufacturer's instruction manual,
remove the sampler inlet and connect the flow rate transfer standard to
the sampler such that the transfer standard accurately measures the
sampler's flow rate. Make sure there are no leaks between the transfer
standard and the sampler.
8.2.4 Choose a minimum of three flow rates (actual m\3\/min), spaced
over the acceptable flow rate range specified for the inlet (see 7.1.2)
that can be obtained by suitable adjustment of the sampler flow rate. In
accordance with the sampler manufacturer's instruction manual, obtain or
verify the calibration relationship between the flow rate (actual m\3\/
min) as indicated by the transfer standard and the sampler's flow
indicator response. Record the ambient temperature and barometric
pressure. Temperature and pressure corrections to subsequent flow
indicator readings may be required for certain types of
[[Page 69]]
flow measurement devices. When such corrections are necessary,
correction on an individual or daily basis is preferable. However,
seasonal average temperature and average barometric pressure for the
sampling site may be incorporated into the sampler calibration to avoid
daily corrections. Consult the sampler manufacturer's instruction manual
and Reference 2 for additional guidance.
8.2.5 Following calibration, verify that the sampler is operating at
its design flow rate (actual m\3\/min) with a clean filter in place.
8.2.6 Replace the sampler inlet.
9.0 Procedure.
9.1 The sampler shall be operated in accordance with the specific
guidance provided in the sampler manufacturer's instruction manual and
in Reference 2. The general procedure given here assumes that the
sampler's flow rate calibration is based on flow rates at ambient
conditions (Qa) and serves to illustrate the steps involved
in the operation of a PM10 sampler.
9.2 Inspect each filter for pinholes, particles, and other
imperfections. Establish a filter information record and assign an
identification number to each filter.
9.3 Equilibrate each filter in the conditioning environment (see
7.4) for at least 24 hours.
9.4 Following equilibration, weigh each filter and record the
presampling weight with the filter identification number.
9.5 Install a preweighed filter in the sampler following the
instructions provided in the sampler manufacturer's instruction manual.
9.6 Turn on the sampler and allow it to establish run-temperature
conditions. Record the flow indicator reading and, if needed, the
ambient temperature and barometric pressure. Determine the sampler flow
rate (actual m\3\/min) in accordance with the instructions provided in
the sampler manufacturer's instruction manual. NOTE.--No onsite
temperature or pressure measurements are necessary if the sampler's flow
indicator does not require temperature or pressure corrections or if
seasonal average temperature and average barometric pressure for the
sampling site are incorporated into the sampler calibration (see step
8.2.4). If individual or daily temperature and pressure corrections are
required, ambient temperature and barometric pressure can be obtained by
on-site measurements or from a nearby weather station. Barometric
pressure readings obtained from airports must be station pressure, not
corrected to sea level, and may need to be corrected for differences in
elevation between the sampling site and the airport.
9.7 If the flow rate is outside the acceptable range specified by
the manufacturer, check for leaks, and if necessary, adjust the flow
rate to the specified setpoint. Stop the sampler.
9.8 Set the timer to start and stop the sampler at appropriate
times. Set the elapsed time meter to zero or record the initial meter
reading.
9.9 Record the sample information (site location or identification
number, sample date, filter identification number, and sampler model and
serial number).
9.10 Sample for 241 hours.
9.11 Determine and record the average flow rate (Qa) in
actual m\3\/min for the sampling period in accordance with the
instructions provided in the sampler manufacturer's instruction manual.
Record the elapsed time meter final reading and, if needed, the average
ambient temperature and barometric pressure for the sampling period (see
note following step 9.6).
9.12 Carefully remove the filter from the sampler, following the
sampler manufacturer's instruction manual. Touch only the outer edges of
the filter.
9.13 Place the filter in a protective holder or container (e.g.,
petri dish, glassine envelope, or manila folder).
9.14 Record any factors such as meteorological conditions,
construction activity, fires or dust storms, etc., that might be
pertinent to the measurement on the filter information record.
9.15 Transport the exposed sample filter to the filter conditioning
environment as soon as possible for equilibration and subsequent
weighing.
9.16 Equilibrate the exposed filter in the conditioning environment
for at least 24 hours under the same temperature and humidity conditions
used for presampling filter equilibration (see 9.3).
9.17 Immediately after equilibration, reweigh the filter and record
the postsampling weight with the filter identification number.
10.0 Sampler Maintenance.
10.1 The PM10 sampler shall be maintained in strict
accordance with the maintenance procedures specified in the sampler
manufacturer's instruction manual.
11.0 Calculations.
11.1 Calculate the average flow rate over the sampling period
corrected to EPA reference conditions as Qstd. When the
sampler's flow indicator is calibrated in actual volumetric units
(Qa), Qstd is calculated as:
Qstd=Qax(Pav/
Tav)(Tstd/Pstd)
where
Qstd = average flow rate at EPA reference conditions, std
m\3\/min;
Qa = average flow rate at ambient conditions, m\3\/min;
Pav = average barometric pressure during the sampling period
or average barometric pressure for the sampling site, kPa (or mm Hg);
Tav = average ambient temperature during the sampling period
or seasonal average
[[Page 70]]
ambient temperature for the sampling site, K;
Tstd = standard temperature, defined as 298 K;
Pstd = standard pressure, defined as 101.3 kPa (or 760 mm
Hg).
11.2 Calculate the total volume of air sampled as:
Vstd = Qstdxt
where
Vstd = total air sampled in standard volume units, std m\3\;
t = sampling time, min.
11.3 Calculate the PM10 concentration as:
PM10 = (Wf-Wi)x10\6\/Vstd
where
PM10 = mass concentration of PM10, [mu]g/std m\3\;
Wf, Wi = final and initial weights of filter
collecting PM1O particles, g;
10\6\ = conversion of g to [mu]g.
Note: If more than one size fraction in the PM10 size
range is collected by the sampler, the sum of the net weight gain by
each collection filter [[Sigma](Wf-Wi)] is used to
calculate the PM10 mass concentration.
12.0 References.
1. Quality Assurance Handbook for Air Pollution Measurement Systems,
Volume I, Principles. EPA-600/9-76-005, March 1976. Available from CERI,
ORD Publications, U.S. Environmental Protection Agency, 26 West St.
Clair Street, Cincinnati, OH 45268.
2. Quality Assurance Handbook for Air Pollution Measurement Systems,
Volume II, Ambient Air Specific Methods. EPA-600/4-77-027a, May 1977.
Available from CERI, ORD Publications, U.S. Environmental Protection
Agency, 26 West St. Clair Street, Cincinnati, OH 45268.
3. Clement, R.E., and F.W. Karasek. Sample Composition Changes in
Sampling and Analysis of Organic Compounds in Aerosols. Int. J. Environ.
Analyt. Chem., 7:109, 1979.
4. Lee, R.E., Jr., and J. Wagman. A Sampling Anomaly in the
Determination of Atmospheric Sulfate Concentration. Amer. Ind. Hyg.
Assoc. J., 27:266, 1966.
5. Appel, B.R., S.M. Wall, Y. Tokiwa, and M. Haik. Interference
Effects in Sampling Particulate Nitrate in Ambient Air. Atmos. Environ.,
13:319, 1979.
6. Coutant, R.W. Effect of Environmental Variables on Collection of
Atmospheric Sulfate. Environ. Sci. Technol., 11:873, 1977.
7. Spicer, C.W., and P. Schumacher. Interference in Sampling
Atmospheric Particulate Nitrate. Atmos. Environ., 11:873, 1977.
8. Appel, B.R., Y. Tokiwa, and M. Haik. Sampling of Nitrates in
Ambient Air. Atmos. Environ., 15:283, 1981.
9. Spicer, C.W., and P.M. Schumacher. Particulate Nitrate:
Laboratory and Field Studies of Major Sampling Interferences. Atmos.
Environ., 13:543, 1979.
10. Appel, B.R. Letter to Larry Purdue, U.S. EPA, Environmental
Monitoring and Support Laboratory. March 18, 1982, Docket No. A-82-37,
II-I-1.
11. Pierson, W.R., W.W. Brachaczek, T.J. Korniski, T.J. Truex, and
J.W. Butler. Artifact Formation of Sulfate, Nitrate, and Hydrogen Ion on
Backup Filters: Allegheny Mountain Experiment. J. Air Pollut. Control
Assoc., 30:30, 1980.
12. Dunwoody, C.L. Rapid Nitrate Loss From PM10 Filters.
J. Air Pollut. Control Assoc., 36:817, 1986.
13. Harrell, R.M. Measuring the Alkalinity of Hi-Vol Air Filters.
EMSL/RTP-SOP-QAD-534, October 1985. Available from the U.S.
Environmental Protection Agency, EMSL/QAD, Research Triangle Park, NC
27711.
14. Smith, F., P.S. Wohlschlegel, R.S.C. Rogers, and D.J. Mulligan.
Investigation of Flow Rate Calibration Procedures Associated With the
High Volume Method for Determination of Suspended Particulates. EPA-600/
4-78-047, U.S. Environmental Protection Agency, Research Triangle Park,
NC 27711, 1978.
[52 FR 24664, July 1, 1987; 52 FR 29467, Aug. 7, 1987]
Appendix K to Part 50--Interpretation of the National Ambient Air
Quality Standards for Particulate Matter
1.0 General.
(a) This appendix explains the computations necessary for analyzing
particulate matter data to determine attainment of the 24-hour and
annual standards specified in 40 CFR 50.6. For the primary and secondary
standards, particulate matter is measured in the ambient air as
PM10 (particles with an aerodynamic diameter less than or
equal to a nominal 10 micrometers) by a reference method based on
appendix J of this part and designated in accordance with part 53 of
this chapter, or by an equivalent method designated in accordance with
part 53 of this chapter. The required frequency of measurements is
specified in part 58 of this chapter.
(b) The terms used in this appendix are defined as follows:
Average refers to an arithmetic mean. All particulate matter
standards are expressed in terms of expected annual values: Expected
number of exceedances per year for the 24-hour standards and expected
annual arithmetic mean for the annual standards.
Daily value for PM10 refers to the 24-hour average
concentration of PM10 calculated or measured from midnight to
midnight (local time).
Exceedance means a daily value that is above the level of the 24-
hour standard after
[[Page 71]]
rounding to the nearest 10 [mu]g/m\3\ (i.e., values ending in 5 or
greater are to be rounded up).
Expected annual value is the number approached when the annual
values from an increasing number of years are averaged, in the absence
of long-term trends in emissions or meteorological conditions.
Year refers to a calendar year.
(c) Although the discussion in this appendix focuses on monitored
data, the same principles apply to modeling data, subject to EPA
modeling guidelines.
2.0 Attainment Determinations.
2.1 24-Hour Primary and Secondary Standards.
(a) Under 40 CFR 50.6(a) the 24-hour primary and secondary standards
are attained when the expected number of exceedances per year at each
monitoring site is less than or equal to one. In the simplest case, the
number of expected exceedances at a site is determined by recording the
number of exceedances in each calendar year and then averaging them over
the past 3 calendar years. Situations in which 3 years of data are not
available and possible adjustments for unusual events or trends are
discussed in sections 2.3 and 2.4 of this appendix. Further, when data
for a year are incomplete, it is necessary to compute an estimated
number of exceedances for that year by adjusting the observed number of
exceedances. This procedure, performed by calendar quarter, is described
in section 3.0 of this appendix. The expected number of exceedances is
then estimated by averaging the individual annual estimates for the past
3 years.
(b) The comparison with the allowable expected exceedance rate of
one per year is made in terms of a number rounded to the nearest tenth
(fractional values equal to or greater than 0.05 are to be rounded up;
e.g., an exceedance rate of 1.05 would be rounded to 1.1, which is the
lowest rate for nonattainment).
2.2 Annual Primary and Secondary Standards. Under 40 CFR 50.6(b),
the annual primary and secondary standards are attained when the
expected annual arithmetic mean PM10 concentration is less
than or equal to the level of the standard. In the simplest case, the
expected annual arithmetic mean is determined by averaging the annual
arithmetic mean PM10 concentrations for the past 3 calendar
years. Because of the potential for incomplete data and the possible
seasonality in PM10 concentrations, the annual mean shall be
calculated by averaging the four quarterly means of PM10
concentrations within the calendar year. The equations for calculating
the annual arithmetic mean are given in section 4.0 of this appendix.
Situations in which 3 years of data are not available and possible
adjustments for unusual events or trends are discussed in sections 2.3
and 2.4 of this appendix. The expected annual arithmetic mean is rounded
to the nearest 1 [mu]g/m\3\ before comparison with the annual standards
(fractional values equal to or greater than 0.5 are to be rounded up).
2.3 Data Requirements.
(a) 40 CFR 58.13 specifies the required minimum frequency of
sampling for PM10. For the purposes of making comparisons
with the particulate matter standards, all data produced by National Air
Monitoring Stations (NAMS), State and Local Air Monitoring Stations
(SLAMS) and other sites submitted to EPA in accordance with the part 58
requirements must be used, and a minimum of 75 percent of the scheduled
PM10 samples per quarter are required.
(b) To demonstrate attainment of either the annual or 24-hour
standards at a monitoring site, the monitor must provide sufficient data
to perform the required calculations of sections 3.0 and 4.0 of this
appendix. The amount of data required varies with the sampling
frequency, data capture rate and the number of years of record. In all
cases, 3 years of representative monitoring data that meet the 75
percent criterion of the previous paragraph should be utilized, if
available, and would suffice. More than 3 years may be considered, if
all additional representative years of data meeting the 75 percent
criterion are utilized. Data not meeting these criteria may also suffice
to show attainment; however, such exceptions will have to be approved by
the appropriate Regional Administrator in accordance with EPA guidance.
(c) There are less stringent data requirements for showing that a
monitor has failed an attainment test and thus has recorded a violation
of the particulate matter standards. Although it is generally necessary
to meet the minimum 75 percent data capture requirement per quarter to
use the computational equations described in sections 3.0 and 4.0 of
this appendix, this criterion does not apply when less data is
sufficient to unambiguously establish nonattainment. The following
examples illustrate how nonattainment can be demonstrated when a site
fails to meet the completeness criteria. Nonattainment of the 24-hour
primary standards can be established by the observed annual number of
exceedances (e.g., four observed exceedances in a single year), or by
the estimated number of exceedances derived from the observed number of
exceedances and the required number of scheduled samples (e.g., two
observed exceedances with every other day sampling). Nonattainment of
the annual standards can be demonstrated on the basis of quarterly mean
concentrations developed from observed data combined with one-half the
minimum detectable concentration substituted for missing values. In both
cases, expected annual values must exceed the levels allowed by the
standards.
2.4 Adjustment for Exceptional Events and Trends.
[[Page 72]]
(a) An exceptional event is an uncontrollable event caused by
natural sources of particulate matter or an event that is not expected
to recur at a given location. Inclusion of such a value in the
computation of exceedances or averages could result in inappropriate
estimates of their respective expected annual values. To reduce the
effect of unusual events, more than 3 years of representative data may
be used. Alternatively, other techniques, such as the use of statistical
models or the use of historical data could be considered so that the
event may be discounted or weighted according to the likelihood that it
will recur. The use of such techniques is subject to the approval of the
appropriate Regional Administrator in accordance with EPA guidance.
(b) In cases where long-term trends in emissions and air quality are
evident, mathematical techniques should be applied to account for the
trends to ensure that the expected annual values are not inappropriately
biased by unrepresentative data. In the simplest case, if 3 years of
data are available under stable emission conditions, this data should be
used. In the event of a trend or shift in emission patterns, either the
most recent representative year(s) could be used or statistical
techniques or models could be used in conjunction with previous years of
data to adjust for trends. The use of less than 3 years of data, and any
adjustments are subject to the approval of the appropriate Regional
Administrator in accordance with EPA guidance.
3.0 Computational Equations for the 24-hour Standards.
3.1 Estimating Exceedances for a Year.
(a) If PM10 sampling is scheduled less frequently than
every day, or if some scheduled samples are missed, a PM10
value will not be available for each day of the year. To account for the
possible effect of incomplete data, an adjustment must be made to the
data collected at each monitoring location to estimate the number of
exceedances in a calendar year. In this adjustment, the assumption is
made that the fraction of missing values that would have exceeded the
standard level is identical to the fraction of measured values above
this level. This computation is to be made for all sites that are
scheduled to monitor throughout the entire year and meet the minimum
data requirements of section 2.3 of this appendix. Because of possible
seasonal imbalance, this adjustment shall be applied on a quarterly
basis. The estimate of the expected number of exceedances for the
quarter is equal to the observed number of exceedances plus an increment
associated with the missing data. The following equation must be used
for these computations:
Equation 1
[GRAPHIC] [TIFF OMITTED] TR18JY97.180
where:
eq = the estimated number of exceedances for calendar quarter
q;
vq = the observed number of exceedances for calendar quarter
q;
Nq = the number of days in calendar quarter q;
nq = the number of days in calendar quarter q with
PM10 data; and
q = the index for calendar quarter, q=1, 2, 3 or 4.
(b) The estimated number of exceedances for a calendar quarter must
be rounded to the nearest hundredth (fractional values equal to or
greater than 0.005 must be rounded up).
(c) The estimated number of exceedances for the year, e, is the sum
of the estimates for each calendar quarter.
Equation 2
[GRAPHIC] [TIFF OMITTED] TR18JY97.181
(d) The estimated number of exceedances for a single year must be
rounded to one decimal place (fractional values equal to or greater than
0.05 are to be rounded up). The expected number of exceedances is then
estimated by averaging the individual annual estimates for the most
recent 3 or more representative years of data. The expected number of
exceedances must be rounded to one decimal place (fractional values
equal to or greater than 0.05 are to be rounded up).
(e) The adjustment for incomplete data will not be necessary for
monitoring or modeling data which constitutes a complete record, i.e.,
365 days per year.
(f) To reduce the potential for overestimating the number of
expected exceedances, the correction for missing data will not be
required for a calendar quarter in which the first observed exceedance
has occurred if:
(1) There was only one exceedance in the calendar quarter;
(2) Everyday sampling is subsequently initiated and maintained for 4
calendar quarters in accordance with 40 CFR 58.13; and
(3) Data capture of 75 percent is achieved during the required
period of everyday sampling. In addition, if the first exceedance is
observed in a calendar quarter in which the monitor is already sampling
every day, no adjustment for missing data will be made to the first
exceedance if a 75 percent data capture rate was achieved in the quarter
in which it was observed.
[[Page 73]]
Example 1
a. During a particular calendar quarter, 39 out of a possible 92
samples were recorded, with one observed exceedance of the 24-hour
standard. Using Equation 1, the estimated number of exceedances for the
quarter is:
eq=1x92/39=2.359 or 2.36.
b. If the estimated exceedances for the other 3 calendar quarters in
the year were 2.30, 0.0 and 0.0, then, using Equation 2, the estimated
number of exceedances for the year is 2.36=2.30=0.0=0.0 which equals
4.66 or 4.7. If no exceedances were observed for the 2 previous years,
then the expected number of exceedances is estimated by: (1/
3)x(4.7=0=0)=1.57 or 1.6. Since 1.6 exceeds the allowable number of
expected exceedances, this monitoring site would fail the attainment
test.
Example 2
In this example, everyday sampling was initiated following the first
observed exceedance as required by 40 CFR 58.13. Accordingly, the first
observed exceedance would not be adjusted for incomplete sampling.
During the next three quarters, 1.2 exceedances were estimated. In this
case, the estimated exceedances for the year would be 1.0=1.2=0.0=0.0
which equals 2.2. If, as before, no exceedances were observed for the
two previous years, then the estimated exceedances for the 3-year period
would then be (1/3)x(2.2=0.0=0.0)=0.7, and the monitoring site would not
fail the attainment test.
3.2 Adjustments for Non-Scheduled Sampling Days.
(a) If a systematic sampling schedule is used and sampling is
performed on days in addition to the days specified by the systematic
sampling schedule, e.g., during episodes of high pollution, then an
adjustment must be made in the eqution for the estimation of
exceedances. Such an adjustment is needed to eliminate the bias in the
estimate of the quarterly and annual number of exceedances that would
occur if the chance of an exceedance is different for scheduled than for
non-scheduled days, as would be the case with episode sampling.
(b) The required adjustment treats the systematic sampling schedule
as a stratified sampling plan. If the period from one scheduled sample
until the day preceding the next scheduled sample is defined as a
sampling stratum, then there is one stratum for each scheduled sampling
day. An average number of observed exceedances is computed for each of
these sampling strata. With nonscheduled sampling days, the estimated
number of exceedances is defined as:
Equation 3
[GRAPHIC] [TIFF OMITTED] TR18JY97.182
where:
eq = the estimated number of exceedances for the quarter;
Nq = the number of days in the quarter;
mq = the number of strata with samples during the quarter;
vj = the number of observed exceedances in stratum j; and
kj = the number of actual samples in stratum j.
(c) Note that if only one sample value is recorded in each stratum,
then Equation 3 reduces to Equation 1.
Example 3
A monitoring site samples according to a systematic sampling
schedule of one sample every 6 days, for a total of 15 scheduled samples
in a quarter out of a total of 92 possible samples. During one 6-day
period, potential episode levels of PM10 were suspected, so 5
additional samples were taken. One of the regular scheduled samples was
missed, so a total of 19 samples in 14 sampling strata were measured.
The one 6-day sampling stratum with 6 samples recorded 2 exceedances.
The remainder of the quarter with one sample per stratum recorded zero
exceedances. Using Equation 3, the estimated number of exceedances for
the quarter is:
eq=(92/14)x(2/6=0=. . .=0)=2.19.
4.0 Computational Equations for Annual Standards.
4.1 Calculation of the Annual Arithmetic Mean. (a) An annual
arithmetic mean value for PM10 is determined by averaging the
quarterly means for the 4 calendar quarters of the year. The following
equation is to be used for calculation of the mean for a calendar
quarter:
Equation 4
[GRAPHIC] [TIFF OMITTED] TR18JY97.183
where:
xq = the quarterly mean concentration for quarter q, q=1, 2,
3, or 4,
nq = the number of samples in the quarter, and
xi = the ith concentration value recorded in the quarter.
(b) The quarterly mean, expressed in [mu]g/m\3\, must be rounded to
the nearest tenth (fractional values of 0.05 should be rounded up).
[[Page 74]]
(c) The annual mean is calculated by using the following equation:
Equation 5
[GRAPHIC] [TIFF OMITTED] TR18JY97.184
where:
x = the annual mean; and
xq = the mean for calendar quarter q.
(d) The average of quarterly means must be rounded to the nearest
tenth (fractional values of 0.05 should be rounded up).
(e) The use of quarterly averages to compute the annual average will
not be necessary for monitoring or modeling data which results in a
complete record, i.e., 365 days per year.
(f) The expected annual mean is estimated as the average of three or
more annual means. This multi-year estimate, expressed in [mu]g/m\3\,
shall be rounded to the nearest integer for comparison with the annual
standard (fractional values of 0.5 should be rounded up).
Example 4
Using Equation 4, the quarterly means are calculated for each
calendar quarter. If the quarterly means are 52.4, 75.3, 82.1, and 63.2
[mu]g/m \3\, then the annual mean is:
x = (1/4)x(52.4=75.3=82.1=63.2) = 68.25 or 68.3.
4.2 Adjustments for Non-scheduled Sampling Days. (a) An adjustment
in the calculation of the annual mean is needed if sampling is performed
on days in addition to the days specified by the systematic sampling
schedule. For the same reasons given in the discussion of estimated
exceedances, under section 3.2 of this appendix, the quarterly averages
would be calculated by using the following equation:
Equation 6
[GRAPHIC] [TIFF OMITTED] TR18JY97.185
where:
xq = the quarterly mean concentration for quarter q, q=1, 2,
3, or 4;
xij = the ith concentration value recorded in stratum j;
kj = the number of actual samples in stratum j; and
mq = the number of strata with data in the quarter.
(b) If one sample value is recorded in each stratum, Equation 6
reduces to a simple arithmetic average of the observed values as
described by Equation 4.
Example 5
a. During one calendar quarter, 9 observations were recorded. These
samples were distributed among 7 sampling strata, with 3 observations in
one stratum. The concentrations of the 3 observations in the single
stratum were 202, 242, and 180 [mu]g/m\3\. The remaining 6 observed
concentrations were 55, 68, 73, 92, 120, and 155 [mu]g/m\3\. Applying
the weighting factors specified in Equation 6, the quarterly mean is:
xq = (1/7) x [(1/3) x (202 = 242 = 180) = 155 = 68 = 73 = 92
= 120 = 155] = 110.1
b. Although 24-hour measurements are rounded to the nearest 10
[mu]g/m\3\ for determinations of exceedances of the 24-hour standard,
note that these values are rounded to the nearest 1 [mu]g/m\3\ for the
calculation of means.
[62 FR 38712, July 18, 1997]
Appendix L to Part 50--Reference Method for the Determination of Fine
Particulate Matter as PM2.5 in the Atmosphere
1.0 Applicability.
1.1 This method provides for the measurement of the mass
concentration of fine particulate matter having an aerodynamic diameter
less than or equal to a nominal 2.5 micrometers (PM2.5) in
ambient air over a 24-hour period for purposes of determining whether
the primary and secondary national ambient air quality standards for
fine particulate matter specified in Sec. 50.7 of this part are met. The
measurement process is considered to be nondestructive, and the
PM2.5 sample obtained can be subjected to subsequent physical
or chemical analyses. Quality assessment procedures are provided in part
58, appendix A of this chapter, and quality assurance guidance are
provided in references 1, 2, and 3 in section 13.0 of this appendix.
1.2 This method will be considered a reference method for purposes
of part 58 of this chapter only if:
(a) The associated sampler meets the requirements specified in this
appendix and the applicable requirements in part 53 of this chapter, and
(b) The method and associated sampler have been designated as a
reference method in accordance with part 53 of this chapter.
1.3 PM2.5 samplers that meet nearly all specifications
set forth in this method but have minor deviations and/or modifications
of the reference method sampler will be designated as ``Class I''
equivalent methods for PM2.5 in accordance with part 53 of
this chapter.
2.0 Principle.
2.1 An electrically powered air sampler draws ambient air at a
constant volumetric flow rate into a specially shaped inlet and
[[Page 75]]
through an inertial particle size separator (impactor) where the
suspended particulate matter in the PM2.5 size range is
separated for collection on a polytetrafluoroethylene (PTFE) filter over
the specified sampling period. The air sampler and other aspects of this
reference method are specified either explicitly in this appendix or
generally with reference to other applicable regulations or quality
assurance guidance.
2.2 Each filter is weighed (after moisture and temperature
conditioning) before and after sample collection to determine the net
gain due to collected PM2.5. The total volume of air sampled
is determined by the sampler from the measured flow rate at actual
ambient temperature and pressure and the sampling time. The mass
concentration of PM2.5 in the ambient air is computed as the
total mass of collected particles in the PM2.5 size range
divided by the actual volume of air sampled, and is expressed in
micrograms per cubic meter of air ([mu]g/m\3\).
3.0 PM2.5 Measurement Range.
3.1 Lower concentration limit. The lower detection limit of the mass
concentration measurement range is estimated to be approximately 2
[mu]g/m\3\, based on noted mass changes in field blanks in conjunction
with the 24 m\3\ nominal total air sample volume specified for the 24-
hour sample.
3.2 Upper concentration limit. The upper limit of the mass
concentration range is determined by the filter mass loading beyond
which the sampler can no longer maintain the operating flow rate within
specified limits due to increased pressure drop across the loaded
filter. This upper limit cannot be specified precisely because it is a
complex function of the ambient particle size distribution and type,
humidity, the individual filter used, the capacity of the sampler flow
rate control system, and perhaps other factors. Nevertheless, all
samplers are estimated to be capable of measuring 24-hour
PM2.5 mass concentrations of at least 200 [mu]g/m\3\ while
maintaining the operating flow rate within the specified limits.
3.3 Sample period. The required sample period for PM2.5
concentration measurements by this method shall be 1,380 to 1500 minutes
(23 to 25 hours). However, when a sample period is less than 1,380
minutes, the measured concentration (as determined by the collected
PM2.5 mass divided by the actual sampled air volume),
multiplied by the actual number of minutes in the sample period and
divided by 1,440, may be used as if it were a valid concentration
measurement for the specific purpose of determining a violation of the
NAAQS. This value assumes that the PM2.5 concentration is
zero for the remaining portion of the sample period and therefore
represents the minimum concentration that could have been measured for
the full 24-hour sample period. Accordingly, if the value thus
calculated is high enough to be an exceedance, such an exceedance would
be a valid exceedance for the sample period. When reported to AIRS, this
data value should receive a special code to identify it as not to be
commingled with normal concentration measurements or used for other
purposes.
4.0 Accuracy.
4.1 Because the size and volatility of the particles making up
ambient particulate matter vary over a wide range and the mass
concentration of particles varies with particle size, it is difficult to
define the accuracy of PM2.5 measurements in an absolute
sense. The accuracy of PM2.5 measurements is therefore
defined in a relative sense, referenced to measurements provided by this
reference method. Accordingly, accuracy shall be defined as the degree
of agreement between a subject field PM2.5 sampler and a
collocated PM2.5 reference method audit sampler operating
simultaneously at the monitoring site location of the subject sampler
and includes both random (precision) and systematic (bias) errors. The
requirements for this field sampler audit procedure are set forth in
part 58, appendix A of this chapter.
4.2 Measurement system bias. Results of collocated measurements
where the duplicate sampler is a reference method sampler are used to
assess a portion of the measurement system bias according to the
schedule and procedure specified in part 58, appendix A of this chapter.
4.3 Audits with reference method samplers to determine system
accuracy and bias. According to the schedule and procedure specified in
part 58, appendix A of this chapter, a reference method sampler is
required to be located at each of selected PM2.5 SLAMS sites
as a duplicate sampler. The results from the primary sampler and the
duplicate reference method sampler are used to calculate accuracy of the
primary sampler on a quarterly basis, bias of the primary sampler on an
annual basis, and bias of a single reporting organization on an annual
basis. Reference 2 in section 13.0 of this appendix provides additional
information and guidance on these reference method audits.
4.4 Flow rate accuracy and bias. Part 58, appendix A of this chapter
requires that the flow rate accuracy and bias of individual
PM2.5 samplers used in SLAMS monitoring networks be assessed
periodically via audits of each sampler's operational flow rate. In
addition, part 58, appendix A of this chapter requires that flow rate
bias for each reference and equivalent method operated by each reporting
organization be assessed quarterly and annually. Reference 2 in section
13.0 of this appendix provides additional information and guidance on
flow rate accuracy audits and calculations for accuracy and bias.
5.0 Precision. A data quality objective of 10 percent coefficient of
variation or better has
[[Page 76]]
been established for the operational precision of PM2.5
monitoring data.
5.1 Tests to establish initial operational precision for each
reference method sampler are specified as a part of the requirements for
designation as a reference method under Sec. 53.58 of this chapter.
5.2 Measurement System Precision. Collocated sampler results, where
the duplicate sampler is not a reference method sampler but is a sampler
of the same designated method as the primary sampler, are used to assess
measurement system precision according to the schedule and procedure
specified in part 58, appendix A of this chapter. Part 58, appendix A of
this chapter requires that these collocated sampler measurements be used
to calculate quarterly and annual precision estimates for each primary
sampler and for each designated method employed by each reporting
organization. Reference 2 in section 13.0 of this appendix provides
additional information and guidance on this requirement.
6.0 Filter for PM2.5 Sample Collection. Any filter
manufacturer or vendor who sells or offers to sell filters specifically
identified for use with this PM2.5 reference method shall
certify that the required number of filters from each lot of filters
offered for sale as such have been tested as specified in this section
6.0 and meet all of the following design and performance specifications.
6.1 Size. Circular, 46.2 mm diameter 0.25 mm.
6.2 Medium. Polytetrafluoroethylene (PTFE Teflon), with integral
support ring.
6.3 Support ring. Polymethylpentene (PMP) or equivalent inert
material, 0.38 0.04 mm thick, outer diameter 46.2 mm
0.25 mm, and width of 3.68 mm ( 0.00, -0.51 mm).
6.4 Pore size. 2 [mu]m as measured by ASTM F 316-94.
6.5 Filter thickness. 30 to 50 [mu]m.
6.6 Maximum pressure drop (clean filter). 30 cm H2O
column @ 16.67 L/min clean air flow.
6.7 Maximum moisture pickup. Not more than 10 [mu]g weight increase
after 24-hour exposure to air of 40 percent relative humidity, relative
to weight after 24-hour exposure to air of 35 percent relative humidity.
6.8 Collection efficiency. Greater than 99.7 percent, as measured by
the DOP test (ASTM D 2986-91) with 0.3 [mu]m particles at the sampler's
operating face velocity.
6.9 Filter weight stability. Filter weight loss shall be less than
20 [mu]g, as measured in each of the following two tests specified in
sections 6.9.1 and 6.9.2 of this appendix. The following conditions
apply to both of these tests: Filter weight loss shall be the average
difference between the initial and the final filter weights of a random
sample of test filters selected from each lot prior to sale. The number
of filters tested shall be not less than 0.1 percent of the filters of
each manufacturing lot, or 10 filters, whichever is greater. The filters
shall be weighed under laboratory conditions and shall have had no air
sample passed through them, i.e., filter blanks. Each test procedure
must include initial conditioning and weighing, the test, and final
conditioning and weighing. Conditioning and weighing shall be in
accordance with sections 8.0 through 8.2 of this appendix and general
guidance provided in reference 2 of section 13.0 of this appendix.
6.9.1 Test for loose, surface particle contamination. After the
initial weighing, install each test filter, in turn, in a filter
cassette (Figures L-27, L-28, and L-29 of this appendix) and drop the
cassette from a height of 25 cm to a flat hard surface, such as a
particle-free wood bench. Repeat two times, for a total of three drop
tests for each test filter. Remove the test filter from the cassette and
weigh the filter. The average change in weight must be less than 20
[mu]g.
6.9.2 Test for temperature stability. After weighing each filter,
place the test filters in a drying oven set at 40 deg.C 2
deg.C for not less than 48 hours. Remove, condition, and reweigh each
test filter. The average change in weight must be less than 20 [mu]g.
6.10 Alkalinity. Less than 25 microequivalents/gram of filter, as
measured by the guidance given in reference 2 in section 13.0 of this
appendix.
6.11 Supplemental requirements. Although not required for
determination of PM2.5 mass concentration under this
reference method, additional specifications for the filter must be
developed by users who intend to subject PM2.5 filter samples
to subsequent chemical analysis. These supplemental specifications
include background chemical contamination of the filter and any other
filter parameters that may be required by the method of chemical
analysis. All such supplemental filter specifications must be compatible
with and secondary to the primary filter specifications given in this
section 6.0 of this appendix.
7.0 PM2.5 Sampler.
7.1 Configuration. The sampler shall consist of a sample air inlet,
downtube, particle size separator (impactor), filter holder assembly,
air pump and flow rate control system, flow rate measurement device,
ambient and filter temperature monitoring system, barometric pressure
measurement system, timer, outdoor environmental enclosure, and suitable
mechanical, electrical, or electronic control capability to meet or
exceed the design and functional performance as specified in this
section 7.0 of this appendix. The performance specifications require
that the sampler:
(a) Provide automatic control of sample volumetric flow rate and
other operational parameters.
(b) Monitor these operational parameters as well as ambient
temperature and pressure.
(c) Provide this information to the sampler operator at the end of
each sample period in
[[Page 77]]
digital form, as specified in table L-1 of section 7.4.19 of this
appendix.
7.2 Nature of specifications. The PM2.5 sampler is
specified by a combination of design and performance requirements. The
sample inlet, downtube, particle size discriminator, filter cassette,
and the internal configuration of the filter holder assembly are
specified explicitly by design figures and associated mechanical
dimensions, tolerances, materials, surface finishes, assembly
instructions, and other necessary specifications. All other aspects of
the sampler are specified by required operational function and
performance, and the design of these other aspects (including the design
of the lower portion of the filter holder assembly) is optional, subject
to acceptable operational performance. Test procedures to demonstrate
compliance with both the design and performance requirements are set
forth in subpart E of part 53 of this chapter.
7.3 Design specifications. Except as indicated in this section 7.3
of this appendix, these components must be manufactured or reproduced
exactly as specified, in an ISO 9001-registered facility, with
registration initially approved and subsequently maintained during the
period of manufacture. See Sec. 53.1(t) of this chapter for the
definition of an ISO-registered facility. Minor modifications or
variances to one or more components that clearly would not affect the
aerodynamic performance of the inlet, downtube, impactor, or filter
cassette will be considered for specific approval. Any such proposed
modifications shall be described and submitted to the EPA for specific
individual acceptability either as part of a reference or equivalent
method application under part 53 of this chapter or in writing in
advance of such an intended application under part 53 of this chapter.
7.3.1 Sample inlet assembly. The sample inlet assembly, consisting
of the inlet, downtube, and impactor shall be configured and assembled
as indicated in Figure L-1 of this appendix and shall meet all
associated requirements. A portion of this assembly shall also be
subject to the maximum overall sampler leak rate specification under
section 7.4.6 of this appendix.
7.3.2 Inlet. The sample inlet shall be fabricated as indicated in
Figures L-2 through L-18 of this appendix and shall meet all associated
requirements.
7.3.3 Downtube. The downtube shall be fabricated as indicated in
Figure L-19 of this appendix and shall meet all associated requirements.
7.3.4 Impactor.
7.3.4.1 The impactor (particle size separator) shall be fabricated
as indicated in Figures L-20 through L-24 of this appendix and shall
meet all associated requirements. Following the manufacture and
finishing of each upper impactor housing (Figure L-21 of this appendix),
the dimension of the impaction jet must be verified by the manufacturer
using Class ZZ go/no-go plug gauges that are traceable to NIST.
7.3.4.2 Impactor filter specifications:
(a) Size. Circular, 35 to 37 mm diameter.
(b) Medium. Borosilicate glass fiber, without binder.
(c) Pore size. 1 to 1.5 micrometer, as measured by ASTM F 316-80.
(d) Thickness. 300 to 500 micrometers.
7.3.4.3 Impactor oil specifications:
(a) Composition. Tetramethyltetraphenyltrisiloxane, single-compound
diffusion oil.
(b) Vapor pressure. Maximum 2x10-8 mm Hg at 25 deg.C.
(c) Viscosity. 36 to 40 centistokes at 25 deg.C.
(d) Density. 1.06 to 1.07 g/cm\3\ at 25 deg.C.
(e) Quantity. 1 mL 0.1 mL.
7.3.5 Filter holder assembly. The sampler shall have a sample filter
holder assembly to adapt and seal to the down tube and to hold and seal
the specified filter, under section 6.0 of this appendix, in the sample
air stream in a horizontal position below the downtube such that the
sample air passes downward through the filter at a uniform face
velocity. The upper portion of this assembly shall be fabricated as
indicated in Figures L-25 and L-26 of this appendix and shall accept and
seal with the filter cassette, which shall be fabricated as indicated in
Figures L-27 through L-29 of this appendix.
(a) The lower portion of the filter holder assembly shall be of a
design and construction that:
(1) Mates with the upper portion of the assembly to complete the
filter holder assembly,
(2) Completes both the external air seal and the internal filter
cassette seal such that all seals are reliable over repeated filter
changings, and
(3) Facilitates repeated changing of the filter cassette by the
sampler operator.
(b) Leak-test performance requirements for the filter holder
assembly are included in section 7.4.6 of this appendix.
(c) If additional or multiple filters are stored in the sampler as
part of an automatic sequential sample capability, all such filters,
unless they are currently and directly installed in a sampling channel
or sampling configuration (either active or inactive), shall be covered
or (preferably) sealed in such a way as to:
(1) Preclude significant exposure of the filter to possible
contamination or accumulation of dust, insects, or other material that
may be present in the ambient air, sampler, or sampler ventilation air
during storage periods either before or after sampling; and
(2) To minimize loss of volatile or semi-volatile PM sample
components during storage of the filter following the sample period.
7.3.6 Flow rate measurement adapter. A flow rate measurement adapter
as specified in
[[Page 78]]
Figure L-30 of this appendix shall be furnished with each sampler.
7.3.7 Surface finish. All internal surfaces exposed to sample air
prior to the filter shall be treated electrolytically in a sulfuric acid
bath to produce a clear, uniform anodized surface finish of not less
than 1000 mg/ft2 (1.08 mg/cm2) in accordance with
military standard specification (mil. spec.) 8625F, Type II, Class 1 in
reference 4 of section 13.0 of this appendix. This anodic surface
coating shall not be dyed or pigmented. Following anodization, the
surfaces shall be sealed by immersion in boiling deionized water for not
less than 15 minutes. Section 53.51(d)(2) of this chapter should also be
consulted.
7.3.8 Sampling height. The sampler shall be equipped with legs, a
stand, or other means to maintain the sampler in a stable, upright
position and such that the center of the sample air entrance to the
inlet, during sample collection, is maintained in a horizontal plane and
is 2.0 0.2 meters above the floor or other horizontal
supporting surface. Suitable bolt holes, brackets, tie-downs, or other
means should be provided to facilitate mechanically securing the sample
to the supporting surface to prevent toppling of the sampler due to
wind.
7.4 Performance specifications.
7.4.1 Sample flow rate. Proper operation of the impactor requires
that specific air velocities be maintained through the device.
Therefore, the design sample air flow rate through the inlet shall be
16.67 L/min (1.000 m\3\/hour) measured as actual volumetric flow rate at
the temperature and pressure of the sample air entering the inlet.
7.4.2 Sample air flow rate control system. The sampler shall have a
sample air flow rate control system which shall be capable of providing
a sample air volumetric flow rate within the specified range, under
section 7.4.1 of this appendix, for the specified filter, under section
6.0 of this appendix, at any atmospheric conditions specified, under
section 7.4.7 of this appendix, at a filter pressure drop equal to that
of a clean filter plus up to 75 cm water column (55 mm Hg), and over the
specified range of supply line voltage, under section 7.4.15.1 of this
appendix. This flow control system shall allow for operator adjustment
of the operational flow rate of the sampler over a range of at least
15 percent of the flow rate specified in section 7.4.1 of
this appendix.
7.4.3 Sample flow rate regulation. The sample flow rate shall be
regulated such that for the specified filter, under section 6.0 of this
appendix, at any atmospheric conditions specified, under section 7.4.7
of this appendix, at a filter pressure drop equal to that of a clean
filter plus up to 75 cm water column (55 mm Hg), and over the specified
range of supply line voltage, under section 7.4.15.1 of this appendix,
the flow rate is regulated as follows:
7.4.3.1 The volumetric flow rate, measured or averaged over
intervals of not more than 5 minutes over a 24-hour period, shall not
vary more than 5 percent from the specified 16.67 L/min flow
rate over the entire sample period.
7.4.3.2 The coefficient of variation (sample standard deviation
divided by the mean) of the flow rate, measured over a 24-hour period,
shall not be greater than 2 percent.
7.4.3.3 The amplitude of short-term flow rate pulsations, such as
may originate from some types of vacuum pumps, shall be attenuated such
that they do not cause significant flow measurement error or affect the
collection of particles on the particle collection filter.
7.4.4 Flow rate cut off. The sampler's sample air flow rate control
system shall terminate sample collection and stop all sample flow for
the remainder of the sample period in the event that the sample flow
rate deviates by more than 10 percent from the sampler design flow rate
specified in section 7.4.1 of this appendix for more than 60 seconds.
However, this sampler cut-off provision shall not apply during periods
when the sampler is inoperative due to a temporary power interruption,
and the elapsed time of the inoperative period shall not be included in
the total sample time measured and reported by the sampler, under
section 7.4.13 of this appendix.
7.4.5 Flow rate measurement.
7.4.5.1 The sampler shall provide a means to measure and indicate
the instantaneous sample air flow rate, which shall be measured as
volumetric flow rate at the temperature and pressure of the sample air
entering the inlet, with an accuracy of 2 percent. The
measured flow rate shall be available for display to the sampler
operator at any time in either sampling or standby modes, and the
measurement shall be updated at least every 30 seconds. The sampler
shall also provide a simple means by which the sampler operator can
manually start the sample flow temporarily during non-sampling modes of
operation, for the purpose of checking the sample flow rate or the flow
rate measurement system.
7.4.5.2 During each sample period, the sampler's flow rate
measurement system shall automatically monitor the sample volumetric
flow rate, obtaining flow rate measurements at intervals of not greater
than 30 seconds.
(a) Using these interval flow rate measurements, the sampler shall
determine or calculate the following flow-related parameters, scaled in
the specified engineering units:
(1) The instantaneous or interval-average flow rate, in L/min.
(2) The value of the average sample flow rate for the sample period,
in L/min.
(3) The value of the coefficient of variation (sample standard
deviation divided by the
[[Page 79]]
average) of the sample flow rate for the sample period, in percent.
(4) The occurrence of any time interval during the sample period in
which the measured sample flow rate exceeds a range of 5
percent of the average flow rate for the sample period for more than 5
minutes, in which case a warning flag indicator shall be set.
(5) The value of the integrated total sample volume for the sample
period, in m\3\.
(b) Determination or calculation of these values shall properly
exclude periods when the sampler is inoperative due to temporary
interruption of electrical power, under section 7.4.13 of this appendix,
or flow rate cut off, under section 7.4.4 of this appendix.
(c) These parameters shall be accessible to the sampler operator as
specified in table L-1 of section 7.4.19 of this appendix. In addition,
it is strongly encouraged that the flow rate for each 5-minute interval
during the sample period be available to the operator following the end
of the sample period.
7.4.6 Leak test capability.
7.4.6.1 External leakage. The sampler shall include an external air
leak-test capability consisting of components, accessory hardware,
operator interface controls, a written procedure in the associated
Operation/Instruction Manual, under section 7.4.18 of this appendix, and
all other necessary functional capability to permit and facilitate the
sampler operator to conveniently carry out a leak test of the sampler at
a field monitoring site without additional equipment. The sampler
components to be subjected to this leak test include all components and
their interconnections in which external air leakage would or could
cause an error in the sampler's measurement of the total volume of
sample air that passes through the sample filter.
(a) The suggested technique for the operator to use for this leak
test is as follows:
(1) Remove the sampler inlet and installs the flow rate measurement
adapter supplied with the sampler, under section 7.3.6 of this appendix.
(2) Close the valve on the flow rate measurement adapter and use the
sampler air pump to draw a partial vacuum in the sampler, including (at
least) the impactor, filter holder assembly (filter in place), flow
measurement device, and interconnections between these devices, of at
least 55 mm Hg (75 cm water column), measured at a location downstream
of the filter holder assembly.
(3) Plug the flow system downstream of these components to isolate
the components under vacuum from the pump, such as with a built-in
valve.
(4) Stop the pump.
(5) Measure the trapped vacuum in the sampler with a built-in
pressure measuring device.
(6) (i) Measure the vacuum in the sampler with the built-in pressure
measuring device again at a later time at least 10 minutes after the
first pressure measurement.
(ii) Caution: Following completion of the test, the adaptor valve
should be opened slowly to limit the flow rate of air into the sampler.
Excessive air flow rate may blow oil out of the impactor.
(7) Upon completion of the test, open the adaptor valve, remove the
adaptor and plugs, and restore the sampler to the normal operating
configuration.
(b) The associated leak test procedure shall require that for
successful passage of this test, the difference between the two pressure
measurements shall not be greater than the number of mm of Hg specified
for the sampler by the manufacturer, based on the actual internal volume
of the sampler, that indicates a leak of less than 80 mL/min.
(c) Variations of the suggested technique or an alternative external
leak test technique may be required for samplers whose design or
configuration would make the suggested technique impossible or
impractical. The specific proposed external leak test procedure, or
particularly an alternative leak test technique, proposed for a
particular candidate sampler may be described and submitted to the EPA
for specific individual acceptability either as part of a reference or
equivalent method application under part 53 of this chapter or in
writing in advance of such an intended application under part 53 of this
chapter.
7.4.6.2 Internal, filter bypass leakage. The sampler shall include
an internal, filter bypass leak-check capability consisting of
components, accessory hardware, operator interface controls, a written
procedure in the Operation/Instruction Manual, and all other necessary
functional capability to permit and facilitate the sampler operator to
conveniently carry out a test for internal filter bypass leakage in the
sampler at a field monitoring site without additional equipment. The
purpose of the test is to determine that any portion of the sample flow
rate that leaks past the sample filter without passing through the
filter is insignificant relative to the design flow rate for the
sampler.
(a) The suggested technique for the operator to use for this leak
test is as follows:
(1) Carry out an external leak test as provided under section
7.4.6.1 of this appendix which indicates successful passage of the
prescribed external leak test.
(2) Install a flow-impervious membrane material in the filter
cassette, either with or without a filter, as appropriate, which
effectively prevents air flow through the filter.
(3) Use the sampler air pump to draw a partial vacuum in the
sampler, downstream of the filter holder assembly, of at least 55 mm Hg
(75 cm water column).
(4) Plug the flow system downstream of the filter holder to isolate
the components under
[[Page 80]]
vacuum from the pump, such as with a built-in valve.
(5) Stop the pump.
(6) Measure the trapped vacuum in the sampler with a built-in
pressure measuring device.
(7) Measure the vacuum in the sampler with the built-in pressure
measuring device again at a later time at least 10 minutes after the
first pressure measurement.
(8) Remove the flow plug and membrane and restore the sampler to the
normal operating configuration.
(b) The associated leak test procedure shall require that for
successful passage of this test, the difference between the two pressure
measurements shall not be greater than the number of mm of Hg specified
for the sampler by the manufacturer, based on the actual internal volume
of the portion of the sampler under vacuum, that indicates a leak of
less than 80 mL/min.
(c) Variations of the suggested technique or an alternative
internal, filter bypass leak test technique may be required for samplers
whose design or configuration would make the suggested technique
impossible or impractical. The specific proposed internal leak test
procedure, or particularly an alternative internal leak test technique
proposed for a particular candidate sampler may be described and
submitted to the EPA for specific individual acceptability either as
part of a reference or equivalent method application under part 53 of
this chapter or in writing in advance of such intended application under
part 53 of this chapter.
7.4.7 Range of operational conditions. The sampler is required to
operate properly and meet all requirements specified in this appendix
over the following operational ranges.
7.4.7.1 Ambient temperature. -30 to =45 deg.C (Note: Although for
practical reasons, the temperature range over which samplers are
required to be tested under part 53 of this chapter is -20 to =40
deg.C, the sampler shall be designed to operate properly over this wider
temperature range.).
7.4.7.2 Ambient relative humidity. 0 to 100 percent.
7.4.7.3 Barometric pressure range. 600 to 800 mm Hg.
7.4.8 Ambient temperature sensor. The sampler shall have capability
to measure the temperature of the ambient air surrounding the sampler
over the range of -30 to =45 deg.C, with a resolution of 0.1 deg.C and
accuracy of 2.0 deg.C, referenced as described in reference
3 in section 13.0 of this appendix, with and without maximum solar
insolation.
7.4.8.1 The ambient temperature sensor shall be mounted external to
the sampler enclosure and shall have a passive, naturally ventilated sun
shield. The sensor shall be located such that the entire sun shield is
at least 5 cm above the horizontal plane of the sampler case or
enclosure (disregarding the inlet and downtube) and external to the
vertical plane of the nearest side or protuberance of the sampler case
or enclosure. The maximum temperature measurement error of the ambient
temperature measurement system shall be less than 1.6 deg.C at 1 m/s
wind speed and 1000 W/m2 solar radiation intensity.
7.4.8.2 The ambient temperature sensor shall be of such a design and
mounted in such a way as to facilitate its convenient dismounting and
immersion in a liquid for calibration and comparison to the filter
temperature sensor, under section 7.4.11 of this appendix.
7.4.8.3 This ambient temperature measurement shall be updated at
least every 30 seconds during both sampling and standby (non-sampling)
modes of operation. A visual indication of the current (most recent)
value of the ambient temperature measurement, updated at least every 30
seconds, shall be available to the sampler operator during both sampling
and standby (non-sampling) modes of operation, as specified in table L-1
of section 7.4.19 of this appendix.
7.4.8.4 This ambient temperature measurement shall be used for the
purpose of monitoring filter temperature deviation from ambient
temperature, as required by section 7.4.11 of this appendix, and may be
used for purposes of effecting filter temperature control, under section
7.4.10 of this appendix, or computation of volumetric flow rate, under
sections 7.4.1 to 7.4.5 of this appendix, if appropriate.
7.4.8.5 Following the end of each sample period, the sampler shall
report the maximum, minimum, and average temperature for the sample
period, as specified in table L-1 of section 7.4.19 of this appendix.
7.4.9 Ambient barometric sensor. The sampler shall have capability
to measure the barometric pressure of the air surrounding the sampler
over a range of 600 to 800 mm Hg referenced as described in reference 3
in section 13.0 of this appendix; also see part 53, subpart E of this
chapter. This barometric pressure measurement shall have a resolution of
5 mm Hg and an accuracy of 10 mm Hg and shall be updated at
least every 30 seconds. A visual indication of the value of the current
(most recent) barometric pressure measurement, updated at least every 30
seconds, shall be available to the sampler operator during both sampling
and standby (non-sampling) modes of operation, as specified in table L-1
of section 7.4.19 of this appendix. This barometric pressure measurement
may be used for purposes of computation of volumetric flow rate, under
sections 7.4.1 to 7.4.5 of this appendix, if appropriate. Following the
end of a sample period, the sampler shall report the maximum, minimum,
and mean barometric pressures for the sample period, as specified in
table L-1 of section 7.4.19 of this appendix.
[[Page 81]]
7.4.10 Filter temperature control (sampling and post-sampling). The
sampler shall provide a means to limit the temperature rise of the
sample filter (all sample filters for sequential samplers), from
insolation and other sources, to no more 5 deg.C above the temperature
of the ambient air surrounding the sampler, during both sampling and
post-sampling periods of operation. The post-sampling period is the non-
sampling period between the end of the active sampling period and the
time of retrieval of the sample filter by the sampler operator.
7.4.11 Filter temperature sensor(s).
7.4.11.1 The sampler shall have the capability to monitor the
temperature of the sample filter (all sample filters for sequential
samplers) over the range of -30 to =45 deg.C during both sampling and
non-sampling periods. While the exact location of this temperature
sensor is not explicitly specified, the filter temperature measurement
system must demonstrate agreement, within 1 deg.C, with a test
temperature sensor located within 1 cm of the center of the filter
downstream of the filter during both sampling and non-sampling modes, as
specified in the filter temperature measurement test described in part
53, subpart E of this chapter. This filter temperature measurement shall
have a resolution of 0.1 deg.C and accuracy of 1.0 deg.C,
referenced as described in reference 3 in section 13.0 of this appendix.
This temperature sensor shall be of such a design and mounted in such a
way as to facilitate its reasonably convenient dismounting and immersion
in a liquid for calibration and comparison to the ambient temperature
sensor under section 7.4.8 of this appendix.
7.4.11.2 The filter temperature measurement shall be updated at
least every 30 seconds during both sampling and standby (non-sampling)
modes of operation. A visual indication of the current (most recent)
value of the filter temperature measurement, updated at least every 30
seconds, shall be available to the sampler operator during both sampling
and standby (non-sampling) modes of operation, as specified in table L-1
of section 7.4.19 of this appendix.
7.4.11.3 For sequential samplers, the temperature of each filter
shall be measured individually unless it can be shown, as specified in
the filter temperature measurement test described in Sec. 53.57 of this
chapter, that the temperature of each filter can be represented by fewer
temperature sensors.
7.4.11.4 The sampler shall also provide a warning flag indicator
following any occurrence in which the filter temperature (any filter
temperature for sequential samplers) exceeds the ambient temperature by
more than 5 deg.C for more than 30 consecutive minutes during either
the sampling or post-sampling periods of operation, as specified in
table L-1 of section 7.4.19 of this appendix, under section 10.12 of
this appendix, regarding sample validity when a warning flag occurs. It
is further recommended (not required) that the sampler be capable of
recording the maximum differential between the measured filter
temperature and the ambient temperature and its time and date of
occurrence during both sampling and post-sampling (non-sampling) modes
of operation and providing for those data to be accessible to the
sampler operator following the end of the sample period, as suggested in
table L-1 of section 7.4.19 of this appendix.
7.4.12 Clock/timer system.
(a) The sampler shall have a programmable real-time clock timing/
control system that:
(1) Is capable of maintaining local time and date, including year,
month, day-of-month, hour, minute, and second to an accuracy of
1.0 minute per month.
(2) Provides a visual indication of the current system time,
including year, month, day-of-month, hour, and minute, updated at least
each minute, for operator verification.
(3) Provides appropriate operator controls for setting the correct
local time and date.
(4) Is capable of starting the sample collection period and sample
air flow at a specific, operator-settable time and date, and stopping
the sample air flow and terminating the sampler collection period 24
hours (1440 minutes) later, or at a specific, operator-settable time and
date.
(b) These start and stop times shall be readily settable by the
sampler operator to within 1.0 minute. The system shall
provide a visual indication of the current start and stop time settings,
readable to 1.0 minute, for verification by the operator,
and the start and stop times shall also be available via the data output
port, as specified in table L-1 of section 7.4.19 of this appendix. Upon
execution of a programmed sample period start, the sampler shall
automatically reset all sample period information and warning flag
indications pertaining to a previous sample period. Refer also to
section 7.4.15.4 of this appendix regarding retention of current date
and time and programmed start and stop times during a temporary
electrical power interruption.
7.4.13 Sample time determination. The sampler shall be capable of
determining the elapsed sample collection time for each PM2.5
sample, accurate to within 1.0 minute, measured as the time
between the start of the sampling period, under section 7.4.12 of this
appendix and the termination of the sample period, under section 7.4.12
of this appendix or section 7.4.4 of this appendix. This elapsed sample
time shall not include periods when the sampler is inoperative due to a
temporary interruption of electrical power, under section 7.4.15.4 of
this appendix. In the event that the elapsed sample time determined for
the sample period is not within the
[[Page 82]]
range specified for the required sample period in section 3.3 of this
appendix, the sampler shall set a warning flag indicator. The date and
time of the start of the sample period, the value of the elapsed sample
time for the sample period, and the flag indicator status shall be
available to the sampler operator following the end of the sample
period, as specified in table L-1 of section 7.4.19 of this appendix.
7.4.14 Outdoor environmental enclosure. The sampler shall have an
outdoor enclosure (or enclosures) suitable to protect the filter and
other non-weatherproof components of the sampler from precipitation,
wind, dust, extremes of temperature and humidity; to help maintain
temperature control of the filter (or filters, for sequential samplers);
and to provide reasonable security for sampler components and settings.
7.4.15 Electrical power supply.
7.4.15.1 The sampler shall be operable and function as specified
herein when operated on an electrical power supply voltage of 105 to 125
volts AC (RMS) at a frequency of 59 to 61 Hz. Optional operation as
specified at additional power supply voltages and/or frequencies shall
not be precluded by this requirement.
7.4.15.2 The design and construction of the sampler shall comply
with all applicable National Electrical Code and Underwriters
Laboratories electrical safety requirements.
7.4.15.3 The design of all electrical and electronic controls shall
be such as to provide reasonable resistance to interference or
malfunction from ordinary or typical levels of stray electromagnetic
fields (EMF) as may be found at various monitoring sites and from
typical levels of electrical transients or electronic noise as may often
or occasionally be present on various electrical power lines.
7.4.15.4 In the event of temporary loss of electrical supply power
to the sampler, the sampler shall not be required to sample or provide
other specified functions during such loss of power, except that the
internal clock/timer system shall maintain its local time and date
setting within 1 minute per week, and the sampler shall
retain all other time and programmable settings and all data required to
be available to the sampler operator following each sample period for at
least 7 days without electrical supply power. When electrical power is
absent at the operator-set time for starting a sample period or is
interrupted during a sample period, the sampler shall automatically
start or resume sampling when electrical power is restored, if such
restoration of power occurs before the operator-set stop time for the
sample period.
7.4.15.5 The sampler shall have the capability to record and retain
a record of the year, month, day-of-month, hour, and minute of the start
of each power interruption of more than 1 minute duration, up to 10 such
power interruptions per sample period. (More than 10 such power
interruptions shall invalidate the sample, except where an exceedance is
measured, under section 3.3 of this appendix.) The sampler shall provide
for these power interruption data to be available to the sampler
operator following the end of the sample period, as specified in table
L-1 of section 7.4.19 of this appendix.
7.4.16 Control devices and operator interface. The sampler shall
have mechanical, electrical, or electronic controls, control devices,
electrical or electronic circuits as necessary to provide the timing,
flow rate measurement and control, temperature control, data storage and
computation, operator interface, and other functions specified.
Operator-accessible controls, data displays, and interface devices shall
be designed to be simple, straightforward, reliable, and easy to learn,
read, and operate under field conditions. The sampler shall have
provision for operator input and storage of up to 64 characters of
numeric (or alphanumeric) data for purposes of site, sampler, and sample
identification. This information shall be available to the sampler
operator for verification and change and for output via the data output
port along with other data following the end of a sample period, as
specified in table L-1 of section 7.4.19 of this appendix. All data
required to be available to the operator following a sample collection
period or obtained during standby mode in a post-sampling period shall
be retained by the sampler until reset, either manually by the operator
or automatically by the sampler upon initiation of a new sample
collection period.
7.4.17 Data output port requirement. The sampler shall have a
standard RS-232C data output connection through which digital data may
be exported to an external data storage or transmission device. All
information which is required to be available at the end of each sample
period shall be accessible through this data output connection. The
information that shall be accessible though this output port is
summarized in table L-1 of section 7.4.19 of this appendix. Since no
specific format for the output data is provided, the sampler
manufacturer or vendor shall make available to sampler purchasers
appropriate computer software capable of receiving exported sampler data
and correctly translating the data into a standard spreadsheet format
and optionally any other formats as may be useful to sampler users. This
requirement shall not preclude the sampler from offering other types of
output connections in addition to the required RS-232C port.
7.4.18 Operation/instruction manual. The sampler shall include an
associated comprehensive operation or instruction manual, as required by
part 53 of this chapter, which includes detailed operating instructions
on
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the setup, operation, calibration, and maintenance of the sampler. This
manual shall provide complete and detailed descriptions of the
operational and calibration procedures prescribed for field use of the
sampler and all instruments utilized as part of this reference method.
The manual shall include adequate warning of potential safety hazards
that may result from normal use or malfunction of the method and a
description of necessary safety precautions. The manual shall also
include a clear description of all procedures pertaining to
installation, operation, periodic and corrective maintenance, and
troubleshooting, and shall include parts identification diagrams.
7.4.19 Data reporting requirements. The various information that the
sampler is required to provide and how it is to be provided is
summarized in the following table L-1.
Table L-1--Summary of Information To Be Provided By the Sampler
--------------------------------------------------------------------------------------------------------------------------------------------------------
Availability Format
Appendix L section -------------------------------------------------------------------------------------------------
Information to be provided reference End of Visual
Anytime1 period2 display\3\ Data output4 Digital reading5 Units
--------------------------------------------------------------------------------------------------------------------------------------------------------
Flow rate, 30-second maximum 7.4.5.1............ [bcheck] ............ [bcheck] * XX.X............... L/min
interval.
Flow rate, average for the sample 7.4.5.2............ * [bcheck] * [bcheck] XX.X............... L/min
period.
Flow rate, CV, for sample period. 7.4.5.2............ * [bcheck] * [bcheck][msh XX.X............... %
box]
Flow rate, 5-min. average out of 7.4.5.2............ [bcheck] [bcheck] [bcheck] [bcheck][msh On/Off............. ...................
spec. (FLAG6). box]
Sample volume, total............. 7.4.5.2............ * [bcheck] [bcheck] [bcheck][msh XX.X............... m\3\
box]
Temperature, ambient, 30-second 7.4.8.............. [bcheck] ............ [bcheck] ............ XX.X............... deg.C
interval.
Temperature, ambient, min., max., 7.4.8.............. * [bcheck] [bcheck] [bcheck][msh XX.X............... deg.C
average for the sample period. box]
Baro pressure, ambient, 30-second 7.4.9.............. [bcheck] ............ [bcheck] ............ XXX................ mm Hg
interval.
Baro pressure, ambient, min., 7.4.9.............. * [bcheck] [bcheck] [bcheck][msh XXX................ mm Hg
max., average for the sample box]
period.
Filter temperature, 30-second 7.4.11............. [bcheck] ............ [bcheck] ............ XX.X............... deg.C
interval.
Filter temperature differential, 7.4.11............. * [bcheck] [bcheck] [bcheck][msh On/Off............. ...................
30-second interval, out of spec. box]
(FLAG6).
Filter temperature, maximum 7.4.11............. * * * * X.X, YY/MM/DD HH:mm deg.C, Yr./Mon./
differential from ambient, date, Day Hrs. min
time of occurrence.
Date and time.................... 7.4.12............. [bcheck] ............ [bcheck] ............ YY/MM/DD HH:mm..... Yr./Mon./Day Hrs.
min
Sample start and stop time 7.4.12............. [bcheck] [bcheck] [bcheck] [bcheck] YY/MM/DD HH:mm..... Yr./Mon./Day Hrs.
settings. min
Sample period start time......... 7.4.12............. ............ [bcheck] [bcheck] [bcheck][msh YYYY/MM/DD HH:mm... Yr./Mon./Day Hrs.
box] min
Elapsed sample time.............. 7.4.13............. * [bcheck] [bcheck] [bcheck][msh HH:mm.............. Hrs. min
box]
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Elapsed sample time, out of spec. 7.4.13............. ............ [bcheck] [bcheck] [bcheck][msh On/Off............. ...................
(FLAG6). box]
Power interruptions [lE]1 min., 7.4.15.5........... * [bcheck] * [bcheck] 1HH:mm, 2HH:mm, etc Hrs. min
start time of first 10. ....
User-entered information, such as 7.4.16............. [bcheck] [bcheck] [bcheck] [bcheck][msh As entered......... ...................
sampler and site identification. box]
--------------------------------------------------------------------------------------------------------------------------------------------------------
[bcheck] Provision of this information is required.
*Provision of this information is optional. If information related to the entire sample period is optionally provided prior to the end of the sample
period, the value provided should be the value calculated for the portion of the sampler period completed up to the time the information is provided.
[mshbox] Indicates that this information is also required to be provided to the AIRS data bank; see Sec. Sec. 58.26 and 58.35 of this chapter.
1 Information is required to be available to the operator at any time the sampler is operating, whether sampling or not.
2 Information relates to the entire sampler period and must be provided following the end of the sample period until reset manually by the operator or
automatically by the sampler upon the start of a new sample period.
\3\ Information shall be available to the operator visually.
4 Information is to be available as digital data at the sampler's data output port specified in section 7.4.16 of this appendix following the end of the
sample period until reset manually by the operator or automatically by the sampler upon the start of a new sample period.
5 Digital readings, both visual and data output, shall have not less than the number of significant digits and resolution specified.
6 Flag warnings may be displayed to the operator by a single-flag indicator or each flag may be displayed individually. Only a set (on) flag warning
must be indicated; an off (unset) flag may be indicated by the absence of a flag warning. Sampler users should refer to section 10.12 of this appendix
regarding the validity of samples for which the sampler provided an associated flag warning.
8.0 Filter Weighing. See reference 2 in section 13.0 of this
appendix, for additional, more detailed guidance.
8.1 Analytical balance. The analytical balance used to weigh filters
must be suitable for weighing the type and size of filters specified,
under section 6.0 of this appendix, and have a readability of
1 [mu]g. The balance shall be calibrated as specified by the
manufacturer at installation and recalibrated immediately prior to each
weighing session. See reference 2 in section 13.0 of this appendix for
additional guidance.
8.2 Filter conditioning. All sample filters used shall be
conditioned immediately before both the pre- and post-sampling weighings
as specified below. See reference 2 in section 13.0 of this appendix for
additional guidance.
8.2.1 Mean temperature. 20 - 23 deg.C.
8.2.2 Temperature control. 2 deg.C over 24 hours.
8.2.3 Mean humidity. Generally, 30-40 percent relative humidity;
however, where it can be shown that the mean ambient relative humidity
during sampling is less than 30 percent, conditioning is permissible at
a mean relative humidity within 5 relative humidity percent
of the mean ambient relative humidity during sampling, but not less than
20 percent.
8.2.4 Humidity control. 5 relative humidity percent over
24 hours.
8.2.5 Conditioning time. Not less than 24 hours.
8.3 Weighing procedure.
8.3.1 New filters should be placed in the conditioning environment
immediately upon arrival and stored there until the pre-sampling
weighing. See reference 2 in section 13.0 of this appendix for
additional guidance.
8.3.2 The analytical balance shall be located in the same controlled
environment in which the filters are conditioned. The filters shall be
weighed immediately following the conditioning period without
intermediate or transient exposure to other conditions or environments.
8.3.3 Filters must be conditioned at the same conditions (humidity
within 5 relative humidity percent) before both the pre- and
post-sampling weighings.
8.3.4 Both the pre- and post-sampling weighings should be carried
out on the same analytical balance, using an effective technique to
neutralize static charges on the filter, under reference 2 in section
13.0 of this appendix. If possible, both weighings should be carried out
by the same analyst.
8.3.5 The pre-sampling (tare) weighing shall be within 30 days of
the sampling period.
8.3.6 The post-sampling conditioning and weighing shall be completed
within 240 hours (10 days) after the end of the sample period, unless
the filter sample is maintained at 4 deg.C
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or less during the entire time between retrieval from the sampler and
the start of the conditioning, in which case the period shall not exceed
30 days. Reference 2 in section 13.0 of this appendix has additional
guidance on transport of cooled filters.
8.3.7 Filter blanks.
8.3.7.1 New field blank filters shall be weighed along with the pre-
sampling (tare) weighing of each lot of PM2.5 filters. These
blank filters shall be transported to the sampling site, installed in
the sampler, retrieved from the sampler without sampling, and reweighed
as a quality control check.
8.3.7.2 New laboratory blank filters shall be weighed along with the
pre-sampling (tare) weighing of each set of PM2.5 filters.
These laboratory blank filters should remain in the laboratory in
protective containers during the field sampling and should be reweighed
as a quality control check.
8.3.8 Additional guidance for proper filter weighing and related
quality assurance activities is provided in reference 2 in section 13.0
of this appendix.
9.0 Calibration. Reference 2 in section 13.0 of this appendix
contains additional guidance.
9.1 General requirements.
9.1.1 Multipoint calibration and single-point verification of the
sampler's flow rate measurement device must be performed periodically to
establish and maintain traceability of subsequent flow measurements to a
flow rate standard.
9.1.2 An authoritative flow rate standard shall be used for
calibrating or verifying the sampler's flow rate measurement device with
an accuracy of 2 percent. The flow rate standard shall be a
separate, stand-alone device designed to connect to the flow rate
measurement adapter, Figure L-30 of this appendix. This flow rate
standard must have its own certification and be traceable to a National
Institute of Standards and Technology (NIST) primary standard for volume
or flow rate. If adjustments to the sampler's flow rate measurement
system calibration are to be made in conjunction with an audit of the
sampler's flow measurement system, such adjustments shall be made
following the audit. Reference 2 in section 13.0 of this appendix
contains additional guidance.
9.1.3 The sampler's flow rate measurement device shall be re-
calibrated after electromechanical maintenance or transport of the
sampler.
9.2 Flow rate calibration/verification procedure.
9.2.1 PM2.5 samplers may employ various types of flow
control and flow measurement devices. The specific procedure used for
calibration or verification of the flow rate measurement device will
vary depending on the type of flow rate controller and flow rate
measurement employed. Calibration shall be in terms of actual ambient
volumetric flow rates (Qa), measured at the sampler's inlet
downtube. The generic procedure given here serves to illustrate the
general steps involved in the calibration of a PM2.5 sampler.
The sampler operation/instruction manual required under section 7.4.18
of this appendix and the Quality Assurance Handbook in reference 2 in
section 13.0 of this appendix provide more specific and detailed
guidance for calibration.
9.2.2 The flow rate standard used for flow rate calibration shall
have its own certification and be traceable to a NIST primary standard
for volume or flow rate. A calibration relationship for the flow rate
standard, e.g., an equation, curve, or family of curves relating actual
flow rate (Qa) to the flow rate indicator reading, shall be
established that is accurate to within 2 percent over the expected range
of ambient temperatures and pressures at which the flow rate standard
may be used. The flow rate standard must be re-calibrated or re-verified
at least annually.
9.2.3 The sampler flow rate measurement device shall be calibrated
or verified by removing the sampler inlet and connecting the flow rate
standard to the sampler's downtube in accordance with the operation/
instruction manual, such that the flow rate standard accurately measures
the sampler's flow rate. The sampler operator shall first carry out a
sampler leak check and confirm that the sampler passes the leak test and
then verify that no leaks exist between the flow rate standard and the
sampler.
9.2.4 The calibration relationship between the flow rate (in actual
L/min) indicated by the flow rate standard and by the sampler's flow
rate measurement device shall be established or verified in accordance
with the sampler operation/instruction manual. Temperature and pressure
corrections to the flow rate indicated by the flow rate standard may be
required for certain types of flow rate standards. Calibration of the
sampler's flow rate measurement device shall consist of at least three
separate flow rate measurements (multipoint calibration) evenly spaced
within the range of -10 percent to =10 percent of the sampler's
operational flow rate, section 7.4.1 of this appendix. Verification of
the sampler's flow rate shall consist of one flow rate measurement at
the sampler's operational flow rate. The sampler operation/instruction
manual and reference 2 in section 13.0 of this appendix provide
additional guidance.
9.2.5 If during a flow rate verification the reading of the
sampler's flow rate indicator or measurement device differs by
4 percent or more from the flow rate measured by the flow
rate standard, a new multipoint calibration shall be performed and the
flow rate verification must then be repeated.
9.2.6 Following the calibration or verification, the flow rate
standard shall be removed from the sampler and the sampler inlet shall
be reinstalled. Then the sampler's
[[Page 86]]
normal operating flow rate (in L/min) shall be determined with a clean
filter in place. If the flow rate indicated by the sampler differs by
2 percent or more from the required sampler flow rate, the
sampler flow rate must be adjusted to the required flow rate, under
section 7.4.1 of this appendix.
9.3 Periodic calibration or verification of the calibration of the
sampler's ambient temperature, filter temperature, and barometric
pressure measurement systems is also required. Reference 3 of section
13.0 of this appendix contains additional guidance.
10.0 PM2.5 Measurement Procedure. The detailed procedure
for obtaining valid PM2.5 measurements with each specific
sampler designated as part of a reference method for PM2.5
under part 53 of this chapter shall be provided in the sampler-specific
operation or instruction manual required by section 7.4.18 of this
appendix. Supplemental guidance is provided in section 2.12 of the
Quality Assurance Handbook listed in reference 2 in section 13.0 of this
appendix. The generic procedure given here serves to illustrate the
general steps involved in the PM2.5 sample collection and
measurement, using a PM2.5 reference method sampler.
10.1 The sampler shall be set up, calibrated, and operated in
accordance with the specific, detailed guidance provided in the specific
sampler's operation or instruction manual and in accordance with a
specific quality assurance program developed and established by the
user, based on applicable supplementary guidance provided in reference 2
in section 13.0 of this appendix.
10.2 Each new sample filter shall be inspected for correct type and
size and for pinholes, particles, and other imperfections. Unacceptable
filters should be discarded. A unique identification number shall be
assigned to each filter, and an information record shall be established
for each filter. If the filter identification number is not or cannot be
marked directly on the filter, alternative means, such as a number-
identified storage container, must be established to maintain positive
filter identification.
10.3 Each filter shall be conditioned in the conditioning
environment in accordance with the requirements specified in section 8.2
of this appendix.
10.4 Following conditioning, each filter shall be weighed in
accordance with the requirements specified in section 8.0 of this
appendix and the presampling weight recorded with the filter
identification number.
10.5 A numbered and preweighed filter shall be installed in the
sampler following the instructions provided in the sampler operation or
instruction manual.
10.6 The sampler shall be checked and prepared for sample collection
in accordance with instructions provided in the sampler operation or
instruction manual and with the specific quality assurance program
established for the sampler by the user.
10.7 The sampler's timer shall be set to start the sample collection
at the beginning of the desired sample period and stop the sample
collection 24 hours later.
10.8 Information related to the sample collection (site location or
identification number, sample date, filter identification number, and
sampler model and serial number) shall be recorded and, if appropriate,
entered into the sampler.
10.9 The sampler shall be allowed to collect the PM2.5
sample during the set 24-hour time period.
10.10 Within 96 hours of the end of the sample collection period,
the filter, while still contained in the filter cassette, shall be
carefully removed from the sampler, following the procedure provided in
the sampler operation or instruction manual and the quality assurance
program, and placed in a protective container. The protective container
shall contain no loose material that could be transferred to the filter.
The protective container shall hold the filter cassette securely such
that the cover shall not come in contact with the filter's surfaces.
Reference 2 in section 13.0 of this appendix contains additional
information.
10.11 The total sample volume in actual m\3\ for the sampling period
and the elapsed sample time shall be obtained from the sampler and
recorded in accordance with the instructions provided in the sampler
operation or instruction manual. All sampler warning flag indications
and other information required by the local quality assurance program
shall also be recorded.
10.12 All factors related to the validity or representativeness of
the sample, such as sampler tampering or malfunctions, unusual
meteorological conditions, construction activity, fires or dust storms,
etc. shall be recorded as required by the local quality assurance
program. The occurrence of a flag warning during a sample period shall
not necessarily indicate an invalid sample but rather shall indicate the
need for specific review of the QC data by a quality assurance officer
to determine sample validity.
10.13 After retrieval from the sampler, the exposed filter
containing the PM2.5 sample should be transported to the
filter conditioning environment as soon as possible ideally to arrive at
the conditioning environment within 24 hours for conditioning and
subsequent weighing. During the period between filter retrieval from the
sampler and the start of the conditioning, the filter shall be
maintained as cool as practical and continuously protected from exposure
to temperatures over 25 deg.C. See section 8.3.6 of this appendix
regarding time limits for completing the post-sampling weighing. See
reference 2 in section 13.0 of this appendix for additional guidance on
transporting filter
[[Page 87]]
samplers to the conditioning and weighing laboratory.
10.14. The exposed filter containing the PM2.5 sample
shall be re-conditioned in the conditioning environment in accordance
with the requirements specified in section 8.2 of this appendix.
10.15. The filter shall be reweighed immediately after conditioning
in accordance with the requirements specified in section 8.0 of this
appendix, and the postsampling weight shall be recorded with the filter
identification number.
10.16 The PM2.5 concentration shall be calculated as
specified in section 12.0 of this appendix.
11.0 Sampler Maintenance. The sampler shall be maintained as
described by the sampler's manufacturer in the sampler-specific
operation or instruction manual required under section 7.4.18 of this
appendix and in accordance with the specific quality assurance program
developed and established by the user based on applicable supplementary
guidance provided in reference 2 in section 13.0 of this appendix.
12.0 Calculations
12.1 (a) The PM2.5 concentration is calculated as:
PM2.5 = (Wf - Wi)/Va
where:
PM2.5 = mass concentration of PM2.5, [mu]g/m\3\;
Wf, Wi = final and initial weights, respectively,
of the filter used to collect the PM2.5 particle sample,
[mu]g;
Va = total air volume sampled in actual volume units, as
provided by the sampler, m\3\.
Note: Total sample time must be between 1,380 and 1,500 minutes (23
and 25 hrs) for a fully valid PM2.5 sample; however, see also
section 3.3 of this appendix.
13.0 References.
1. Quality Assurance Handbook for Air Pollution Measurement Systems,
Volume I, Principles. EPA/600/R-94/038a, April 1994. Available from
CERI, ORD Publications, U.S. Environmental Protection Agency, 26 West
Martin Luther King Drive, Cincinnati, Ohio 45268.
2. Copies of section 2.12 of the Quality Assurance Handbook for Air
Pollution Measurement Systems, Volume II, Ambient Air Specific Methods,
EPA/600/R-94/038b, are available from Department E (MD-77B), U.S. EPA,
Research Triangle Park, NC 27711.
3. Quality Assurance Handbook for Air Pollution Measurement Systems,
Volume IV: Meteorological Measurements, (Revised Edition) EPA/600/R-94/
038d, March, 1995. Available from CERI, ORD Publications, U.S.
Environmental Protection Agency, 26 West Martin Luther King Drive,
Cincinnati, Ohio 45268.
4. Military standard specification (mil. spec.) 8625F, Type II,
Class 1 as listed in Department of Defense Index of Specifications and
Standards (DODISS), available from DODSSP-Customer Service,
Standardization Documents Order Desk, 700 Robbins Avenue, Building 4D,
Philadelphia, PA 1911-5094.
14.0 Figures L-1 through L-30 to Appendix L.
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[62 FR 38714, July 18, 1997, as amended at 64 FR 19719, Apr. 22, 1999]
Appendix M to Part 50--Reference Method for the Determination of
Particulate Matter as PM10 in the Atmosphere
1.0 Applicability.
1.1 This method provides for the measurement of the mass
concentration of particulate matter with an aerodynamic diameter less
than or equal to a nominal 10 micrometers (PM1O) in ambient
air over a 24-hour period for purposes of determining attainment and
maintenance of the primary and secondary national ambient air quality
standards for particulate matter specified in Sec. 50.6 of this chapter.
The measurement process is nondestructive, and the PM10
sample can be subjected to subsequent physical or chemical analyses.
Quality assurance procedures and guidance are provided in part 58,
Appendices A and B of this chapter and in references 1 and 2 of section
12.0 of this appendix.
2.0 Principle.
2.1 An air sampler draws ambient air at a constant flow rate into a
specially shaped inlet where the suspended particulate matter is
inertially separated into one or more size fractions within the
PM10 size range. Each size fraction in the PM1O
size range is then collected on a separate filter over the specified
sampling period. The particle size discrimination characteristics
(sampling effectiveness and 50 percent cutpoint) of the sampler inlet
are prescribed as performance specifications in part 53 of this chapter.
2.2 Each filter is weighed (after moisture equilibration) before and
after use to determine the net weight (mass) gain due to collected
PM10. The total volume of air sampled, measured at the actual
ambient temperature and pressure, is determined from the measured flow
rate and the sampling time. The mass concentration of PM10 in
the ambient air is computed as the total mass of collected particles in
the PM10 size range divided by the volume of air sampled, and
is expressed in micrograms per actual cubic meter ([mu]g/m\3\).
2.3 A method based on this principle will be considered a reference
method only if the associated sampler meets the requirements specified
in this appendix and the requirements in part 53 of this chapter, and
the method has been designated as a reference method in accordance with
part 53 of this chapter.
3.0 Range.
3.1 The lower limit of the mass concentration range is determined by
the repeatability of filter tare weights, assuming the nominal air
sample volume for the sampler. For samplers having an automatic filter-
changing mechanism, there may be no upper limit. For samplers that do
not have an automatic filter-changing mechanism, the upper limit is
determined by the filter mass loading beyond which the sampler no longer
maintains the operating flow rate within specified limits due to
increased pressure drop across the loaded filter. This upper limit
cannot be specified precisely because it is a complex function of the
ambient particle size distribution and type, humidity, filter type, and
perhaps other factors. Nevertheless, all samplers should be capable of
measuring 24-hour PM10 mass concentrations of at least 300
[mu]g/m\3\ while maintaining the operating flow rate within the
specified limits.
4.0 Precision.
4.1 The precision of PM10 samplers must be 5 [mu]g/m\3\
for PM10 concentrations below 80 [mu]g/m\3\ and 7 percent for
PM10 concentrations above 80 [mu]g/m\3\, as required by part
53 of this chapter, which prescribes a test procedure that determines
the variation in the PM10 concentration measurements of
identical samplers under typical sampling conditions. Continual
assessment of precision via collocated samplers is required by part 58
of this chapter for PM10 samplers used in certain monitoring
networks.
5.0 Accuracy.
5.1 Because the size of the particles making up ambient particulate
matter varies over a wide range and the concentration of particles
varies with particle size, it is difficult to define the absolute
accuracy of PM10 samplers. Part 53 of this chapter provides a
specification for the sampling effectiveness of PM10
samplers. This specification requires that the expected mass
concentration calculated for a candidate PM10 sampler, when
sampling a specified particle size distribution, be within
10 percent of that calculated for an ideal sampler whose
sampling effectiveness is explicitly specified. Also, the particle size
for 50 percent sampling effectiveness is required to be
100.5 micrometers. Other specifications related to accuracy
apply to flow measurement and calibration, filter media, analytical
(weighing) procedures, and artifact. The flow rate accuracy of
PM10 samplers used in certain monitoring networks is required
by part 58 of this chapter to be assessed periodically via flow rate
audits.
6.0 Potential Sources of Error.
6.1 Volatile Particles. Volatile particles collected on filters are
often lost during shipment and/or storage of the filters prior to the
post-sampling weighing \3\. Although shipment or storage of loaded
filters is sometimes unavoidable, filters should be reweighed as soon as
practical to minimize these losses.
6.2 Artifacts. Positive errors in PM10 concentration
measurements may result from retention of gaseous species on filters
4, 5. Such errors include the retention of sulfur dioxide and
nitric acid. Retention of sulfur
[[Page 119]]
dioxide on filters, followed by oxidation to sulfate, is referred to as
artifact sulfate formation, a phenomenon which increases with increasing
filter alkalinity \6\. Little or no artifact sulfate formation should
occur using filters that meet the alkalinity specification in section
7.2.4 of this appendix, Artifact nitrate formation, resulting primarily
from retention of nitric acid, occurs to varying degrees on many filter
types, including glass fiber, cellulose ester, and many quartz fiber
filters 5, 7, 8, 9, 10. Loss of true atmospheric particulate
nitrate during or following sampling may also occur due to dissociation
or chemical reaction. This phenomenon has been observed on
Teflon[reg]filters \8\ and inferred for quartz fiber filters
11, 12. The magnitude of nitrate artifact errors in
PM10 mass concentration measurements will vary with location
and ambient temperature; however, for most sampling locations, these
errors are expected to be small.
6.3 Humidity. The effects of ambient humidity on the sample are
unavoidable. The filter equilibration procedure in section 9.0 of this
appendix is designed to minimize the effects of moisture on the filter
medium.
6.4 Filter Handling. Careful handling of filters between presampling
and postsampling weighings is necessary to avoid errors due to damaged
filters or loss of collected particles from the filters. Use of a filter
cartridge or cassette may reduce the magnitude of these errors. Filters
must also meet the integrity specification in section 7.2.3 of this
appendix.
6.5 Flow Rate Variation. Variations in the sampler's operating flow
rate may alter the particle size discrimination characteristics of the
sampler inlet. The magnitude of this error will depend on the
sensitivity of the inlet to variations in flow rate and on the particle
distribution in the atmosphere during the sampling period. The use of a
flow control device, under section 7.1.3 of this appendix, is required
to minimize this error.
6.6 Air Volume Determination. Errors in the air volume determination
may result from errors in the flow rate and/or sampling time
measurements. The flow control device serves to minimize errors in the
flow rate determination, and an elapsed time meter, under section 7.1.5
of this appendix, is required to minimize the error in the sampling time
measurement.
7.0 Apparatus.
7.1 PM10 Sampler.
7.1.1 The sampler shall be designed to:
(a) Draw the air sample into the sampler inlet and through the
particle collection filter at a uniform face velocity.
(b) Hold and seal the filter in a horizontal position so that sample
air is drawn downward through the filter.
(c) Allow the filter to be installed and removed conveniently.
(d) Protect the filter and sampler from precipitation and prevent
insects and other debris from being sampled.
(e) Minimize air leaks that would cause error in the measurement of
the air volume passing through the filter.
(f) Discharge exhaust air at a sufficient distance from the sampler
inlet to minimize the sampling of exhaust air.
(g) Minimize the collection of dust from the supporting surface.
7.1.2 The sampler shall have a sample air inlet system that, when
operated within a specified flow rate range, provides particle size
discrimination characteristics meeting all of the applicable performance
specifications prescribed in part 53 of this chapter. The sampler inlet
shall show no significant wind direction dependence. The latter
requirement can generally be satisfied by an inlet shape that is
circularly symmetrical about a vertical axis.
7.1.3 The sampler shall have a flow control device capable of
maintaining the sampler's operating flow rate within the flow rate
limits specified for the sampler inlet over normal variations in line
voltage and filter pressure drop.
7.1.4 The sampler shall provide a means to measure the total flow
rate during the sampling period. A continuous flow recorder is
recommended but not required. The flow measurement device shall be
accurate to 2 percent.
7.1.5 A timing/control device capable of starting and stopping the
sampler shall be used to obtain a sample collection period of 24
1 hr (1,440 60 min). An elapsed time meter,
accurate to within 15 minutes, shall be used to measure
sampling time. This meter is optional for samplers with continuous flow
recorders if the sampling time measurement obtained by means of the
recorder meets the 15 minute accuracy specification.
7.1.6 The sampler shall have an associated operation or instruction
manual as required by part 53 of this chapter which includes detailed
instructions on the calibration, operation, and maintenance of the
sampler.
7.2 Filters.
7.2.1 Filter Medium. No commercially available filter medium is
ideal in all respects for all samplers. The user's goals in sampling
determine the relative importance of various filter characteristics,
e.g., cost, ease of handling, physical and chemical characteristics,
etc., and, consequently, determine the choice among acceptable filters.
Furthermore, certain types of filters may not be suitable for use with
some samplers, particularly under heavy loading conditions (high mass
concentrations), because of high or rapid increase in the filter flow
resistance that would exceed the capability of the sampler's flow
control device. However, samplers equipped with automatic filter-
changing
[[Page 120]]
mechanisms may allow use of these types of filters. The specifications
given below are minimum requirements to ensure acceptability of the
filter medium for measurement of PM10 mass concentrations.
Other filter evaluation criteria should be considered to meet individual
sampling and analysis objectives.
7.2.2 Collection Efficiency. [lE]99 percent, as measured by the DOP
test (ASTM-2986) with 0.3 [mu]m particles at the sampler's operating
face velocity.
7.2.3 Integrity. 5 [mu]g/m\3\ (assuming sampler's
nominal 24-hour air sample volume). Integrity is measured as the
PM10 concentration equivalent corresponding to the average
difference between the initial and the final weights of a random sample
of test filters that are weighed and handled under actual or simulated
sampling conditions, but have no air sample passed through them, i.e.,
filter blanks. As a minimum, the test procedure must include initial
equilibration and weighing, installation on an inoperative sampler,
removal from the sampler, and final equilibration and weighing.
7.2.4 Alkalinity. <25 microequivalents/gram of filter, as measured
by the procedure given in reference 13 of section 12.0 of this appendix
following at least two months storage in a clean environment (free from
contamination by acidic gases) at room temperature and humidity.
7.3 Flow Rate Transfer Standard. The flow rate transfer standard
must be suitable for the sampler's operating flow rate and must be
calibrated against a primary flow or volume standard that is traceable
to the National Institute of Standard and Technology (NIST). The flow
rate transfer standard must be capable of measuring the sampler's
operating flow rate with an accuracy of 2 percent.
7.4 Filter Conditioning Environment.
7.4.1 Temperature range. 15 to 30 C.
7.4.2 Temperature control. 3 C.
7.4.3 Humidity range. 20% to 45% RH.
7.4.4 Humidity control. 5% RH.
7.5 Analytical Balance. The analytical balance must be suitable for
weighing the type and size of filters required by the sampler. The range
and sensitivity required will depend on the filter tare weights and mass
loadings. Typically, an analytical balance with a sensitivity of 0.1 mg
is required for high volume samplers (flow rates 0.5 m\3\/
min). Lower volume samplers (flow rates <0.5 m\3\/min) will require a
more sensitive balance.
8.0 Calibration.
8.1 General Requirements.
8.1.1 Calibration of the sampler's flow measurement device is
required to establish traceability of subsequent flow measurements to a
primary standard. A flow rate transfer standard calibrated against a
primary flow or volume standard shall be used to calibrate or verify the
accuracy of the sampler's flow measurement device.
8.1.2 Particle size discrimination by inertial separation requires
that specific air velocities be maintained in the sampler's air inlet
system. Therefore, the flow rate through the sampler's inlet must be
maintained throughout the sampling period within the design flow rate
range specified by the manufacturer. Design flow rates are specified as
actual volumetric flow rates, measured at existing conditions of
temperature and pressure (Qa).
8.2 Flow Rate Calibration Procedure.
8.2.1 PM10 samplers employ various types of flow control
and flow measurement devices. The specific procedure used for flow rate
calibration or verification will vary depending on the type of flow
controller and flow rate indicator employed. Calibration is in terms of
actual volumetric flow rates (Qa) to meet the requirements of
section 8.1 of this appendix. The general procedure given here serves to
illustrate the steps involved in the calibration. Consult the sampler
manufacturer's instruction manual and reference 2 of section 12.0 of
this appendix for specific guidance on calibration. Reference 14 of
section 12.0 of this appendix provides additional information on various
other measures of flow rate and their interrelationships.
8.2.2 Calibrate the flow rate transfer standard against a primary
flow or volume standard traceable to NIST. Establish a calibration
relationship, e.g., an equation or family of curves, such that
traceability to the primary standard is accurate to within 2 percent
over the expected range of ambient conditions, i.e., temperatures and
pressures, under which the transfer standard will be used. Recalibrate
the transfer standard periodically.
8.2.3 Following the sampler manufacturer's instruction manual,
remove the sampler inlet and connect the flow rate transfer standard to
the sampler such that the transfer standard accurately measures the
sampler's flow rate. Make sure there are no leaks between the transfer
standard and the sampler.
8.2.4 Choose a minimum of three flow rates (actual m\3\/min), spaced
over the acceptable flow rate range specified for the inlet, under
section 7.1.2 of the appendix, that can be obtained by suitable
adjustment of the sampler flow rate. In accordance with the sampler
manufacturer's instruction manual, obtain or verify the calibration
relationship between the flow rate (actual m\3\/min) as indicated by the
transfer standard and the sampler's flow indicator response. Record the
ambient temperature and barometric pressure. Temperature and pressure
corrections to subsequent flow indicator readings may be required for
certain types of flow measurement devices. When such corrections are
necessary, correction on an individual or
[[Page 121]]
daily basis is preferable. However, seasonal average temperature and
average barometric pressure for the sampling site may be incorporated
into the sampler calibration to avoid daily corrections. Consult the
sampler manufacturer's instruction manual and reference 2 in section
12.0 of this appendix for additional guidance.
8.2.5 Following calibration, verify that the sampler is operating at
its design flow rate (actual m\3\/min) with a clean filter in place.
8.2.6 Replace the sampler inlet.
9.0 Procedure.
9.1 The sampler shall be operated in accordance with the specific
guidance provided in the sampler manufacturer's instruction manual and
in reference 2 in section 12.0 of this appendix. The general procedure
given here assumes that the sampler's flow rate calibration is based on
flow rates at ambient conditions (Qa) and serves to
illustrate the steps involved in the operation of a PM10
sampler.
9.2 Inspect each filter for pinholes, particles, and other
imperfections. Establish a filter information record and assign an
identification number to each filter.
9.3 Equilibrate each filter in the conditioning environment (see
7.4) for at least 24 hours.
9.4 Following equilibration, weigh each filter and record the
presampling weight with the filter identification number.
9.5 Install a preweighed filter in the sampler following the
instructions provided in the sampler manufacturer's instruction manual.
9.6 (a) Turn on the sampler and allow it to establish run-
temperature conditions. Record the flow indicator reading and, if
needed, the ambient temperature and barometric pressure. Determine the
sampler flow rate (actual m\3\/min) in accordance with the instructions
provided in the sampler manufacturer's instruction manual.
(b) Note: No onsite temperature or pressure measurements are
necessary if the sampler's flow indicator does not require temperature
or pressure corrections or if seasonal average temperature and average
barometric pressure for the sampling site are incorporated into the
sampler calibration, under section 8.2.4 of this appendix. If individual
or daily temperature and pressure corrections are required, ambient
temperature and barometric pressure can be obtained by on-site
measurements or from a nearby weather station. Barometric pressure
readings obtained from airports must be station pressure, not corrected
to sea level, and may need to be corrected for differences in elevation
between the sampling site and the airport.
9.7 If the flow rate is outside the acceptable range specified by
the manufacturer, check for leaks, and if necessary, adjust the flow
rate to the specified setpoint. Stop the sampler.
9.8 Set the timer to start and stop the sampler at appropriate
times. Set the elapsed time meter to zero or record the initial meter
reading.
9.9 Record the sample information (site location or identification
number, sample date, filter identification number, and sampler model and
serial number).
9.10 Sample for 241 hours.
9.11 Determine and record the average flow rate (Qa) in
actual m\3\/min for the sampling period in accordance with the
instructions provided in the sampler manufacturer's instruction manual.
Record the elapsed time meter final reading and, if needed, the average
ambient temperature and barometric pressure for the sampling period, in
note following section 9.6 of this appendix.
9.12 Carefully remove the filter from the sampler, following the
sampler manufacturer's instruction manual. Touch only the outer edges of
the filter.
9.13 Place the filter in a protective holder or container, e.g.,
petri dish, glassine envelope, or manila folder.
9.14 Record any factors such as meteorological conditions,
construction activity, fires or dust storms, etc., that might be
pertinent to the measurement on the filter information record.
9.15 Transport the exposed sample filter to the filter conditioning
environment as soon as possible for equilibration and subsequent
weighing.
9.16 Equilibrate the exposed filter in the conditioning environment
for at least 24 hours under the same temperature and humidity conditions
used for presampling filter equilibration (see section 9.3 of this
appendix).
9.17 Immediately after equilibration, reweigh the filter and record
the postsampling weight with the filter identification number.
10.0 Sampler Maintenance.
10.1 The PM10 sampler shall be maintained in strict
accordance with the maintenance procedures specified in the sampler
manufacturer's instruction manual.
11.0 Calculations.
11.1 Calculate the total volume of air sampled as:
V = Qat
where:
V = total air sampled, at ambient temperature and pressure,m\3\;
Qa = average sample flow rate at ambient temperature and
pressure, m\3\/min; and
t = sampling time, min.
11.2 (a) Calculate the PM10 concentration as:
PM10 = (Wf-Wi)x10\6\/V
where:
[[Page 122]]
PM10 = mass concentration of PM10, [mu]g/m\3\;
Wf, Wi = final and initial weights of filter
collecting PM1O particles, g; and
10\6\ = conversion of g to [mu]g.
(b) Note: If more than one size fraction in the PM10 size
range is collected by the sampler, the sum of the net weight gain by
each collection filter [[Sigma](Wf-Wi)] is used to
calculate the PM10 mass concentration.
12.0 References.
1. Quality Assurance Handbook for Air Pollution Measurement Systems,
Volume I, Principles. EPA-600/9-76-005, March 1976. Available from CERI,
ORD Publications, U.S. Environmental Protection Agency, 26 West St.
Clair Street, Cincinnati, OH 45268.
2. Quality Assurance Handbook for Air Pollution Measurement Systems,
Volume II, Ambient Air Specific Methods. EPA-600/4-77-027a, May 1977.
Available from CERI, ORD Publications, U.S. Environmental Protection
Agency, 26 West St. Clair Street, Cincinnati, OH 45268.
3. Clement, R.E., and F.W. Karasek. Sample Composition Changes in
Sampling and Analysis of Organic Compounds in Aerosols. Int. J. Environ.
Analyt. Chem., 7:109, 1979.
4. Lee, R.E., Jr., and J. Wagman. A Sampling Anomaly in the
Determination of Atmospheric Sulfate Concentration. Amer. Ind. Hyg.
Assoc. J., 27:266, 1966.
5. Appel, B.R., S.M. Wall, Y. Tokiwa, and M. Haik. Interference
Effects in Sampling Particulate Nitrate in Ambient Air. Atmos. Environ.,
13:319, 1979.
6. Coutant, R.W. Effect of Environmental Variables on Collection of
Atmospheric Sulfate. Environ. Sci. Technol., 11:873, 1977.Spicer, C.W.,
and P. Schumacher. Interference in Sampling Atmospheric Particulate
Nitrate. Atmos. Environ., 11:873, 1977.
8. Appel, B.R., Y. Tokiwa, and M. Haik. Sampling of Nitrates in
Ambient Air. Atmos. Environ., 15:283, 1981.
9. Spicer, C.W., and P.M. Schumacher. Particulate Nitrate:
Laboratory and Field Studies of Major Sampling Interferences. Atmos.
Environ., 13:543, 1979.
10. Appel, B.R. Letter to Larry Purdue, U.S. EPA, Environmental
Monitoring and Support Laboratory. March 18, 1982, Docket No. A-82-37,
II-I-1.
11. Pierson, W.R., W.W. Brachaczek, T.J. Korniski, T.J. Truex, and
J.W. Butler. Artifact Formation of Sulfate, Nitrate, and Hydrogen Ion on
Backup Filters: Allegheny Mountain Experiment. J. Air Pollut. Control
Assoc., 30:30, 1980.
12. Dunwoody, C.L. Rapid Nitrate Loss From PM10 Filters.
J. Air Pollut. Control Assoc., 36:817, 1986.
13. Harrell, R.M. Measuring the Alkalinity of Hi-Vol Air Filters.
EMSL/RTP-SOP-QAD-534, October 1985. Available from the U.S.
Environmental Protection Agency, EMSL/QAD, Research Triangle Park, NC
27711.
14. Smith, F., P.S. Wohlschlegel, R.S.C. Rogers, and D.J. Mulligan.
Investigation of Flow Rate Calibration Procedures Associated With the
High Volume Method for Determination of Suspended Particulates. EPA-600/
4-78-047, U.S. Environmental Protection Agency, Research Triangle Park,
NC 27711, 1978.
[62 FR 38753, July 18, 1997]
Appendix N to Part 50--Interpretation of the National Ambient Air
Quality Standards for Particulate Matter
1.0 General.
(a) This appendix explains the data handling conventions and
computations necessary for determining when the annual and 24-hour
primary and secondary national ambient air quality standards for PM
specified in Sec. 50.7 of this chapter are met. Particulate matter is
measured in the ambient air as PM10 and PM2.5
(particles with an aerodynamic diameter less than or equal to a nominal
10 and 2.5 micrometers, respectively) by a reference method based on
appendix M of this part for PM10 and on appendix L of this
part for PM2.5, as applicable, and designated in accordance
with part 53 of this chapter, or by an equivalent method designated in
accordance with part 53 of this chapter. Data handling and computation
procedures to be used in making comparisons between reported
PM10 and PM2.5 concentrations and the levels of
the PM standards are specified in the following sections.
(b) Data resulting from uncontrollable or natural events, for
example structural fires or high winds, may require special
consideration. In some cases, it may be appropriate to exclude these
data because they could result in inappropriate values to compare with
the levels of the PM standards. In other cases, it may be more
appropriate to retain the data for comparison with the level of the PM
standards and then allow the EPA to formulate the appropriate regulatory
response. Whether to exclude, retain, or make adjustments to the data
affected by uncontrollable or natural events is subject to the approval
of the appropriate Regional Administrator.
(c) The terms used in this appendix are defined as follows:
Average and mean refer to an arithmetic mean.
Daily value for PM refers to the 24-hour average concentration of PM
calculated or measured from midnight to midnight (local time) for
PM10 or PM2.5.
Designated monitors are those monitoring sites designated in a State
PM Monitoring Network Description for spatial averaging in areas opting
for spatial averaging in accordance with part 58 of this chapter.
[[Page 123]]
98th percentile (used for PM2.5) means the
daily value out of a year of monitoring data below which 98 percent of
all values in the group fall.
99th percentile (used for PM10) means the
daily value out of a year of monitoring data below which 99 percent of
all values in the group fall.
Year refers to a calendar year.
(d) Sections 2.1 and 2.5 of this appendix contain data handling
instructions for the option of using a spatially averaged network of
monitors for the annual standard. If spatial averaging is not considered
for an area, then the spatial average is equivalent to the annual
average of a single site and is treated accordingly in subsequent
calculations. For example, paragraph (a)(3) of section 2.1 of this
appendix could be eliminated since the spatial average would be
equivalent to the annual average.
2.0 Comparisons with the PM2.5 Standards.
2.1 Annual PM2.5 Standard.
(a) The annual PM2.5 standard is met when the 3-year
average of the spatially averaged annual means is less than or equal to
15.0 [mu]g/m\3\. The 3-year average of the spatially averaged annual
means is determined by averaging quarterly means at each monitor to
obtain the annual mean PM2.5 concentrations at each monitor,
then averaging across all designated monitors, and finally averaging for
3 consecutive years. The steps can be summarized as follows:
(1) Average 24-hour measurements to obtain quarterly means at each
monitor.
(2) Average quarterly means to obtain annual means at each monitor.
(3) Average across designated monitoring sites to obtain an annual
spatial mean for an area (this can be one site in which case the spatial
mean is equal to the annual mean).
(4) Average 3 years of annual spatial means to obtain a 3-year
average of spatially averaged annual means.
(b) In the case of spatial averaging, 3 years of spatial averages
are required to demonstrate that the standard has been met. Designated
sites with less than 3 years of data shall be included in spatial
averages for those years that data completeness requirements are met.
For the annual PM2.5 standard, a year meets data completeness
requirements when at least 75 percent of the scheduled sampling days for
each quarter have valid data. However, years with high concentrations
and more than a minimal amount of data (at least 11 samples in each
quarter) shall not be ignored just because they are comprised of
quarters with less than complete data. Thus, in computing annual
spatially averaged means, years containing quarters with at least 11
samples but less than 75 percent data completeness shall be included in
the computation if the resulting spatially averaged annual mean
concentration (rounded according to the conventions of section 2.3 of
this appendix) is greater than the level of the standard.
(c) Situations may arise in which there are compelling reasons to
retain years containing quarters which do not meet the data completeness
requirement of 75 percent or the minimum number of 11 samples. The use
of less than complete data is subject to the approval of the appropriate
Regional Administrator.
(d) The equations for calculating the 3-year average annual mean of
the PM2.5 standard are given in section 2.5 of this appendix.
2.2 24-Hour PM2.5 Standard.
(a) The 24-hour PM2.5 standard is met when the 3-year
average of the 98th percentile values at each monitoring site
is less than or equal to 65 [mu]g/m\3\. This comparison shall be based
on 3 consecutive, complete years of air quality data. A year meets data
completeness requirements when at least 75 percent of the scheduled
sampling days for each quarter have valid data. However, years with high
concentrations shall not be ignored just because they are comprised of
quarters with less than complete data. Thus, in computing the 3-year
average 98th percentile value, years containing quarters with
less than 75 percent data completeness shall be included in the
computation if the annual 98th percentile value (rounded
according to the conventions of section 2.3 of this appendix) is greater
than the level of the standard.
(b) Situations may arise in which there are compelling reasons to
retain years containing quarters which do not meet the data completeness
requirement. The use of less than complete data is subject to the
approval of the appropriate Regional Administrator.
(c) The equations for calculating the 3-year average of the annual
98th percentile values is given in section 2.6 of this
appendix.
2.3 Rounding Conventions. For the purposes of comparing calculated
values to the applicable level of the standard, it is necessary to round
the final results of the calculations described in sections 2.5 and 2.6
of this appendix. For the annual PM2.5 standard, the 3-year
average of the spatially averaged annual means shall be rounded to the
nearest 0.1 [mu]g/m\3\ (decimals 0.05 and greater are rounded up to the
next 0.1, and any decimal lower than 0.05 is rounded down to the nearest
0.1). For the 24-hour PM2.5 standard, the 3-year average of
the annual 98th percentile values shall be rounded to the
nearest 1 [mu]g/m\3\ (decimals 0.5 and greater are rounded up to nearest
whole number, and any decimal lower than 0.5 is rounded down to the
nearest whole number).
2.4 Monitoring Considerations.
(a) Section 58.13 of this chapter specifies the required minimum
frequency of sampling
[[Page 124]]
for PM2.5. Exceptions to the specified sampling frequencies,
such as a reduced frequency during a season of expected low
concentrations, are subject to the approval of the appropriate Regional
Administrator. Section 58.14 of 40 CFR part 58 and section 2.8 of
appendix D of 40 CFR part 58, specify which monitors are eligible for
making comparisons with the PM standards. In determining a spatial mean
using two or more monitoring sites operating in a given year, the annual
mean for an individual site may be included in the spatial mean if and
only if the mean for that site meets the criterion specified in Sec. 2.8
of appendix D of 40 CFR part 58. In the event data from an otherwise
eligible site is excluded from being averaged with data from other sites
on the basis of this criterion, then the 3-year mean from that site
shall be compared directly to the annual standard.
(b) For the annual PM2.5 standard, when designated
monitors are located at the same site and are reporting PM2.5
values for the same time periods, and when spatial averaging has been
chosen, their concentrations shall be averaged before an area-wide
spatial average is calculated. Such monitors will then be considered as
one monitor.
2.5 Equations for the Annual PM2.5 Standard.
(a) An annual mean value for PM2.5 is determined by first
averaging the daily values of a calendar quarter:
Equation 1
[GRAPHIC] [TIFF OMITTED] TR18JY97.000
where:
xq,y,s = the mean for quarter q of year y for site s;
nq = the number of monitored values in the quarter; and
xi,q,y,s = the ith value in quarter q for year y
for site s.
(b) The following equation is then to be used for calculation of the
annual mean:
Equation 2
[GRAPHIC] [TIFF OMITTED] TR18JY97.001
where:
xy,s = the annual mean concentration for year y (y = 1, 2, or
3) and for site s; and
xq,y,s = the mean for quarter q of year y for site s.
(c)(1) The spatially averaged annual mean for year y is computed by
first calculating the annual mean for each site designated to be
included in a spatial average, xy,s, and then computing the
average of these values across sites:
Equation 3
[GRAPHIC] [TIFF OMITTED] TR18JY97.002
where:
xy = the spatially averaged mean for year y;
xy,s = the annual mean for year y and site s; and
ns = the number of sites designated to be averaged.
(2) In the event that an area designated for spatial averaging has
two or more sites at the same location producing data for the same time
periods, the sites are averaged together before using Equation 3 by:
Equation 4
[GRAPHIC] [TIFF OMITTED] TR18JY97.003
where:
xy,s* = the annual mean for year y for the sites at the same
location (which will now be considered one site);
nc = the number of sites at the same location designated to
be included in the spatial average; and
xy,s = the annual mean for year y and site s.
(d) The 3-year average of the spatially averaged annual means is
calculated by using the following equation:
Equation 5
[GRAPHIC] [TIFF OMITTED] TR18JY97.004
where:
x = the 3-year average of the spatially averaged annual means; and
xy = the spatially averaged annual mean for year y.
Example 1--Area Designated for Spatial Averaging That Meets the Primary
Annual PM2.5 Standard.
a. In an area designated for spatial averaging, four designated
monitors recorded data in at least 1 year of a particular 3-year period.
Using Equations 1 and 2, the annual means for PM2.5 at each
site are calculated for each year. The following table can be created
from the results. Data completeness percentages for the quarter with the
fewest number of samples are also shown.
[[Page 125]]
Table 1--Results from Equations 1 and 2
--------------------------------------------------------------------------------------------------------------------------------------------------------
Site Site Site Site
[bottom]1 [bottom]2 [bottom]3 [bottom]4 Spatial mean
--------------------------------------------------------------------------------------------------------------------------------------------------------
Year 1......................................... Annual mean ([mu]g/m\3\)......... 12.7 ............ ............ ............ 12.7
% data completeness.............. 80 0 0 0 ............
Year 2......................................... Annual mean ([mu]g/m\3\)......... 12.6 17.5 15.2 ............ 15.05
% data completeness.............. 90 63 38 0 ............
Year 3......................................... Annual mean ([mu]g/m\3\)......... 12.5 18.5 14.1 16.9 15.50
% data completeness.............. 90 80 85 50 ............
3-year mean.................................... ................................. ............ ............ ............ ............ 14.42
--------------------------------------------------------------------------------------------------------------------------------------------------------
b. The data from these sites are averaged in the order described in
section 2.1 of this appendix. Note that the annual mean from site
3 in year 2 and the annual mean from site 4 in year 3
do not meet the 75 percent data completeness criteria. Assuming the 38
percent data completeness represents a quarter with fewer than 11
samples, site 3 in year 2 does not meet the minimum data
completeness requirement of 11 samples in each quarter. The site is
therefore excluded from the calculation of the spatial mean for year 2.
However, since the spatial mean for year 3 is above the level of the
standard and the minimum data requirement of 11 samples in each quarter
has been met, the annual mean from site 4 in year 3 is included
in the calculation of the spatial mean for year 3 and in the calculation
of the 3-year average. The 3-year average is rounded to 14.4 [mu]g/m\3\,
indicating that this area meets the annual PM2.5 standard.
Example 2--Area With Two Monitors at the Same Location That Meets the
Primary Annual PM2.5 Standard.
a. In an area designated for spatial averaging, six designated
monitors, with two monitors at the same location (5 and
6), recorded data in a particular 3-year period. Using
Equations 1 and 2, the annual means for PM2.5 are calculated
for each year. The following table can be created from the results.
Table 2--Results From Equations 1 and 2
--------------------------------------------------------------------------------------------------------------------------------------------------------
Average of
Site Site Site Site Site Site [bottom]5 Spatial
Annual mean ([mu]g/m\3\) [bottom]1 [bottom]2 [bottom]3 [bottom]4 [bottom]5 [bottom]6 and mean
[bottom]6
--------------------------------------------------------------------------------------------------------------------------------------------------------
Year 1............................................ 12.9 9.9 12.6 11.1 14.5 14.6 14.55 12.21
Year 2............................................ 14.5 13.3 12.2 10.9 16.1 16.0 16.05 13.39
Year 3............................................ 14.4 12.4 11.5 9.7 12.3 12.1 12.20 12.04
3-Year mean....................................... ........... ........... ........... ........... ........... ........... .......... 12.55
--------------------------------------------------------------------------------------------------------------------------------------------------------
b. The annual means for sites 5 and 6 are averaged
together using Equation 4 before the spatial average is calculated using
Equation 3 since they are in the same location. The 3-year mean is
rounded to 12.6 [mu]g/m\3\, indicating that this area meets the annual
PM2.5 standard.
Example 3--Area With a Single Monitor That Meets the Primary Annual
PM2.5 Standard.
a. Given data from a single monitor in an area, the calculations are
as follows. Using Equations 1 and 2, the annual means for
PM2.5 are calculated for each year. If the annual means are
10.28, 17.38, and 12.25 [mu]g/m\3\, then the 3-year mean is:
[GRAPHIC] [TIFF OMITTED] TR18JY97.005
b. This value is rounded to 13.3, indicating that this area meets
the annual PM2.5 standard.
2.6 Equations for the 24-Hour PM2.5 Standard.
(a) When the data for a particular site and year meet the data
completeness requirements in section 2.2 of this appendix, calculation
of the 98th percentile is accomplished by the following
steps. All the daily values from a particular site and year comprise a
series of values (x1, x2, x3, ...,
xn), that can be sorted into a series where each number is
equal to or larger than the preceding number (x[1],
x[2], x[3], ..., x[n]). In this case,
x[1] is the smallest number and x[n] is the
largest value. The 98th percentile is found from the
[[Page 126]]
sorted series of daily values which is ordered from the lowest to the
highest number. Compute (0.98) x (n) as the number ``i.d'', where ``i''
is the integer part of the result and ``d'' is the decimal part of the
result. The 98th percentile value for year y,
P0.98, y, is given by Equation 6:
Equation 6
[GRAPHIC] [TIFF OMITTED] TR18JY97.006
where:
P0.98,y = 98th percentile for year y;
x[i=1] = the (i=1)th number in the ordered series
of numbers; and
i = the integer part of the product of 0.98 and n.
(b) The 3-year average 98th percentile is then calculated
by averaging the annual 98th percentiles:
Equation 7
[GRAPHIC] [TIFF OMITTED] TR18JY97.007
(c) The 3-year average 98th percentile is rounded
according to the conventions in section 2.3 of this appendix before a
comparison with the standard is made.
Example 4--Ambient Monitoring Site With Every-Day Sampling That Meets
the Primary 24-Hour PM2.5 Standard.
a. In each year of a particular 3 year period, varying numbers of
daily PM2.5 values (e.g., 281, 304, and 296) out of a
possible 365 values were recorded at a particular site with the
following ranked values (in [mu]g/m\3\):
Table 3--Ordered Monitoring Data For 3 Years
----------------------------------------------------------------------------------------------------------------
Year 1 Year 2 Year 3
----------------------------------------------------------------------------------------------------------------
j rank Xj value j rank Xj value j rank Xj value
----------------------------------------------------------------------------------------------------------------
275 57.9 296 54.3 290 66.0
276 59.0 297 57.1 291 68.4
277 62.2 298 63.0 292 69.8
----------------------------------------------------------------------------------------------------------------
b. Using Equation 6, the 98th percentile values for each
year are calculated as follows:
[GRAPHIC] [TIFF OMITTED] TR18JY97.008
[GRAPHIC] [TIFF OMITTED] TR18JY97.009
[GRAPHIC] [TIFF OMITTED] TR18JY97.010
c.1. Using Equation 7, the 3-year average 98th percentile
is calculated as follows:
[GRAPHIC] [TIFF OMITTED] TR18JY97.011
2. Therefore, this site meets the 24-hour PM2.5 standard.
3.0 Comparisons with the PM10 Standards.
3.1 Annual PM10 Standard.
(a) The annual PM10 standard is met when the 3-year
average of the annual mean PM10 concentrations at each
monitoring site is less than or equal to 50 [mu]g/m\3\. The 3-year
average of the annual means is determined by averaging quarterly means
to obtain annual mean PM10 concentrations for 3 consecutive,
complete years at each monitoring site. The steps can be summarized as
follows:
(1) Average 24-hour measurements to obtain a quarterly mean.
[[Page 127]]
(2) Average quarterly means to obtain an annual mean.
(3) Average annual means to obtain a 3-year mean.
(b) For the annual PM10 standard, a year meets data
completeness requirements when at least 75 percent of the scheduled
sampling days for each quarter have valid data. However, years with high
concentrations and more than a minimal amount of data (at least 11
samples in each quarter) shall not be ignored just because they are
comprised of quarters with less than complete data. Thus, in computing
the 3-year average annual mean concentration, years containing quarters
with at least 11 samples but less than 75 percent data completeness
shall be included in the computation if the annual mean concentration
(rounded according to the conventions of section 2.3 of this appendix)
is greater than the level of the standard.
(c) Situations may arise in which there are compelling reasons to
retain years containing quarters which do not meet the data completeness
requirement of 75 percent or the minimum number of 11 samples. The use
of less than complete data is subject to the approval of the appropriate
Regional Administrator.
(d) The equations for calculating the 3-year average annual mean of
the PM10 standard are given in section 3.5 of this appendix.
3.2 24-Hour PM10 Standard.
(a) The 24-hour PM10 standard is met when the 3-year
average of the annual 99th percentile values at each
monitoring site is less than or equal to 150 [mu]g/m\3\. This comparison
shall be based on 3 consecutive, complete years of air quality data. A
year meets data completeness requirements when at least 75 percent of
the scheduled sampling days for each quarter have valid data. However,
years with high concentrations shall not be ignored just because they
are comprised of quarters with less than complete data. Thus, in
computing the 3-year average of the annual 99th percentile
values, years containing quarters with less than 75 percent data
completeness shall be included in the computation if the annual
99th percentile value (rounded according to the conventions
of section 2.3 of this appendix) is greater than the level of the
standard.
(b) Situations may arise in which there are compelling reasons to
retain years containing quarters which do not meet the data completeness
requirement. The use of less than complete data is subject to the
approval of the appropriate Regional Administrator.
(c) The equation for calculating the 3-year average of the annual
99th percentile values is given in section 2.6 of this
appendix.
3.3 Rounding Conventions. For the annual PM10 standard,
the 3-year average of the annual PM10 means shall be rounded
to the nearest 1 [mu]g/m\3\ (decimals 0.5 and greater are rounded up to
the next whole number, and any decimal less than 0.5 is rounded down to
the nearest whole number). For the 24-hour PM10 standard, the
3-year average of the annual 99th percentile values of
PM10 shall be rounded to the nearest 10 [mu]g/m\3\ (155
[mu]g/m\3\ and greater would be rounded to 160 [mu]g/m\3\ and 154 [mu]g/
m\3\ and less would be rounded to 150 [mu]g/m\3\).
3.4 Monitoring Considerations. Section 58.13 of this chapter
specifies the required minimum frequency of sampling for
PM10. Exceptions to the specified sampling frequencies, such
as a reduced frequency during a season of expected low concentrations,
are subject to the approval of the appropriate Regional Administrator.
For making comparisons with the PM10 NAAQS, all sites meeting
applicable requirements in part 58 of this chapter would be used.
3.5 Equations for the Annual PM10 Standard.
(a) An annual arithmetic mean value for PM10 is
determined by first averaging the 24-hour values of a calendar quarter
using the following equation:
Equation 8
[GRAPHIC] [TIFF OMITTED] TR18JY97.012
where:
xq,y = the mean for quarter q of year y;
nq = the number of monitored values in the quarter; and
xi,q,y = the ith value in quarter q for year y.
(b) The following equation is then to be used for calculation of the
annual mean:
Equation 9
[GRAPHIC] [TIFF OMITTED] TR18JY97.013
where:
xy = the annual mean concentration for year y, (y=1, 2, or
3); and
xq,y = the mean for a quarter q of year y.
(c) The 3-year average of the annual means is calculated by using
the following equation:
Equation 10
[GRAPHIC] [TIFF OMITTED] TR18JY97.014
where:
x = the 3-year average of the annual means; and
xy = the annual mean for calendar year y.
[[Page 128]]
Example 5--Ambient Monitoring Site That Does Not Meet the Annual
PM10 Standard.
a. Given data from a PM10 monitor and using Equations 8
and 9, the annual means for PM10 are calculated for each
year. If the annual means are 52.42, 82.17, and 63.23 [mu]g/m\3\, then
the 3-year average annual mean is:
[GRAPHIC] [TIFF OMITTED] TR18JY97.015
b. Therefore, this site does not meet the annual PM10
standard.
3.6 Equation for the 24-Hour PM10 Standard.
(a) When the data for a particular site and year meet the data
completeness requirements in section 3.2 of this appendix, calculation
of the 99th percentile is accomplished by the following
steps. All the daily values from a particular site and year comprise a
series of values (x1, x2, x3, ...,
xn) that can be sorted into a series where each number is
equal to or larger than the preceding number (x[1],
x[2], x[3], ..., x[n]). In this case,
x[1] is the smallest number and x[n] is the largest value.
The 99th percentile is found from the sorted series of daily
values which is ordered from the lowest to the highest number. Compute
(0.99) x (n) as the number ``i.d'', where ``i'' is the integer part of
the result and ``d'' is the decimal part of the result. The
99th percentile value for year y, P0.99,y, is
given by Equation 11:
Equation 11
[GRAPHIC] [TIFF OMITTED] TR18JY97.016
where:
P0.99,y = the 99th percentile for year y;
x[i=1] = the (i=1)th number in the ordered series
of numbers; and
i = the integer part of the product of 0.99 and n.
(b) The 3-year average 99th percentile value is then
calculated by averaging the annual 99th percentiles:
Equation 12
[GRAPHIC] [TIFF OMITTED] TR18JY97.017
(c) The 3-year average 99th percentile is rounded
according to the conventions in section 3.3 of this appendix before a
comparison with the standard is made.
Example 6--Ambient Monitoring Site With Sampling Every Sixth Day That
Meets the Primary 24-Hour PM10 Standard.
a. In each year of a particular 3 year period, varying numbers of
PM10 daily values (e.g., 110, 98, and 100) out of a possible
121 daily values were recorded at a particular site with the following
ranked values (in [mu]g/m\3\):
Table 4--Ordered Monitoring Data For 3 Years
----------------------------------------------------------------------------------------------------------------
Year 1 Year 2 Year 3
----------------------------------------------------------------------------------------------------------------
j rank Xj value j rank Xj value j rank Xj value
----------------------------------------------------------------------------------------------------------------
108 120 96 143 98 140
109 128 97 148 99 144
110 130 98 150 100 147
----------------------------------------------------------------------------------------------------------------
b. Using Equation 11, the 99th percentile values for each
year are calculated as follows:
[GRAPHIC] [TIFF OMITTED] TR18JY97.018
[GRAPHIC] [TIFF OMITTED] TR18JY97.019
[[Page 129]]
[GRAPHIC] [TIFF OMITTED] TR18JY97.020
c. 1. Using Equation 12, the 3-year average 99th
percentile is calculated as follows:
[GRAPHIC] [TIFF OMITTED] TR18JY97.021
2. Therefore, this site meets the 24-hour PM10 standard.
[62 FR 38755, July 18, 1997]
PART 51--REQUIREMENTS FOR PREPARATION, ADOPTION, AND SUBMITTAL OF
IMPLEMENTATION PLANS--Table of Contents
Sec.
Subpart A--Emission Inventory Reporting Requirements
General Information for Inventory Preparers
51.1 Who is responsible for actions described in this subpart?
51.5 What tools are available to help prepare and report emissions
data?
51.10 How does my State report emissions that are required by the
NOX SIP Call?
Specific Reporting Requirements
51.15 What data does my State need to report to EPA?
51.20 What are the emission thresholds that separate point and area
sources?
51.25 What geographic area must my State's inventory cover?
51.30 When does my State report the data to EPA?
51.35 How can my State equalize the effort for annual reporting?
51.40 In what form should my State report the data to EPA?
51.45 Where should my State report the data?
Appendix A to Subpart A of Part 51--Tables and Glossary
Appendix B to Subpart A of Part 51 [Reserved]
Subparts B--E [Reserved]
Subpart F--Procedural Requirements
51.100 Definitions.
51.101 Stipulations.
51.102 Public hearings.
51.103 Submission of plans, preliminary review of plans.
51.104 Revisions.
51.105 Approval of plans.
Subpart G--Control Strategy
51.110 Attainment and maintenance of national standards.
51.111 Description of control measures.
51.112 Demonstration of adequacy.
51.113 [Reserved]
51.114 Emissions data and projections.
51.115 Air quality data and projections.
51.116 Data availability.
51.117 Additional provisions for lead.
51.118 Stack height provisions.
51.119 Intermittent control systems.
51.120 Requirements for State Implementation Plan revisions relating to
new motor vehicles.
51.121 Findings and requirements for submission of State implementation
plan revisions relating to emissions of oxides of nitrogen.
51.122 Emissions reporting requirements for SIP revisions relating to
budgets for NOX emissions.
Subpart H--Prevention of Air Pollution Emergency Episodes
51.150 Classification of regions for episode plans.
51.151 Significant harm levels.
51.152 Contingency plans.
51.153 Reevaluation of episode plans.
Subpart I--Review of New Sources and Modifications
51.160 Legally enforceable procedures.
51.161 Public availability of information.
51.162 Identification of responsible agency.
51.163 Administrative procedures.
51.164 Stack height procedures.
51.165 Permit requirements.
51.166 Prevention of significant deterioration of air quality.
[[Page 130]]
Subpart J--Ambient Air Quality Surveillance
51.190 Ambient air quality monitoring requirements.
Subpart K--Source Survelliance
51.210 General.
51.211 Emission reports and recordkeeping.
51.212 Testing, inspection, enforcement, and complaints.
51.213 Transportation control measures.
51.214 Continuous emission monitoring.
Subpart L--Legal Authority
51.230 Requirements for all plans.
51.231 Identification of legal authority.
51.232 Assignment of legal authority to local agencies.
Subpart M--Intergovernmental Consultation
Agency Designation
51.240 General plan requirements.
51.241 Nonattainment areas for carbon monoxide and ozone.
51.242 [Reserved]
Subpart N--Compliance Schedules
51.260 Legally enforceable compliance schedules.
51.261 Final compliance schedules.
51.262 Extension beyond one year.
Subpart O--Miscellaneous Plan Content Requirements
51.280 Resources.
51.281 Copies of rules and regulations.
51.285 Public notification.
Subpart P--Protection of Visibility
51.300 Purpose and applicability.
51.301 Definitions.
51.302 Implementation control strategies for reasonably attributable
visibility impairment.
51.303 Exemptions from control.
51.304 Identification of integral vistas.
51.305 Monitoring for reasonably attributable visibility impairment.
51.306 Long-term strategy requirements for reasonably attributable
visibility impairment.
51.307 New source review.
51.308 Regional haze program requirements.
51.309 Requirements related to the Grand Canyon Visibility Transport
Commission.
Subpart Q--Reports
Air Quality Data Reporting
51.320 Annual air quality data report.
Source Emissions and State Action Reporting
51.321 Annual source emissions and State action report.
51.322 Sources subject to emissions reporting.
51.323 Reportable emissions data and information.
51.324 Progress in plan enforcement.
51.326 Reportable revisions.
51.327 Enforcement orders and other State actions.
51.328 [Reserved]
Subpart R--Extensions
51.341 Request for 18-month extension.
Subpart S--Inspection/Maintenance Program Requirements
51.350 Applicability.
51.351 Enhanced I/M performance standard.
51.352 Basic I/M performance standard.
51.353 Network type and program evaluation.
51.354 Adequate tools and resources.
51.355 Test frequency and convenience.
51.356 Vehicle coverage.
51.357 Test procedures and standards.
51.358 Test equipment.
51.359 Quality control.
51.360 Waivers and compliance via diagnostic inspection.
51.361 Motorist compliance enforcement.
51.362 Motorist compliance enforcement program oversight.
51.363 Quality assurance.
51.364 Enforcement against contractors, stations and inspectors.
51.365 Data collection.
51.366 Data analysis and reporting.
51.367 Inspector training and licensing or certification.
51.368 Public information and consumer protection.
51.369 Improving repair effectiveness.
51.370 Compliance with recall notices.
51.371 On-road testing.
51.372 State Implementation Plan submissions.
51.373 Implementation deadlines.
Appendix A to Subpart S--Calibrations, Adjustments and Quality Control
Appendix B to Subpart S--Test Procedures
Appendix C to Subpart S--Steady-State Short Test Standards
Appendix D to Subpart S--Steady-State Short Test Equipment
[[Page 131]]
Appendix E to Subpart S--Transient Test Driving Cycle
Subpart T--Conformity to State or Federal Implementation Plans of
Transportation Plans, Programs, and Projects Developed, Funded or
Approved Under Title 23 U.S.C. or the Federal Transit Laws
51.390 Implementation plan revision.
Subpart U--Economic Incentive Programs
51.490 Applicability.
51.491 Definitions.
51.492 State program election and submittal.
51.493 State program requirements.
51.494 Use of program revenues.
Subpart W--Determining Conformity of General Federal Actions to State or
Federal Implementation Plans
51.850 Prohibition.
51.851 State Implementation Plan (SIP) revision.
51.852 Definitions.
51.853 Applicability.
51.854 Conformity analysis.
51.855 Reporting requirements.
51.856 Public participation.
51.857 Frequency of conformity determinations.
51.858 Criteria for determining conformity of general Federal actions.
51.859 Procedures for conformity determinations of general Federal
actions.
51.860 Mitigation of air quality impacts.
Appendixes A-K [Reserved]
Appendix L to Part 51--Example Regulations for Prevention of Air
Pollution Emergency Episodes
Appendix M to Part 51--Recommended Test Methods for State Implementation
Plans
Appendixes N-O [Reserved]
Appendix P to Part 51--Minimum Emission Monitoring Requirements
Appendixes Q-R [Reserved]
Appendix S to Part 51--Emission Offset Interpretative Ruling
Appendixes T-U [Reserved]
Appendix V to Part 51--Criteria for Determining the Completeness of Plan
Submissions
Appendix W to Part 51--Guideline on Air Quality Models
Appendix X to Part 51--Examples of Economic Incentive Programs
Authority: 23 U.S.C. 101; 42 U.S.C. 7401-7671q.
Source: 36 FR 22398, Nov. 25, 1971, unless otherwise noted.
Subpart A--Emission Inventory Reporting Requirements
Source: 67 FR 39611, June 10, 2002, unless otherwise noted.
General Information for Inventory Preparers
Sec. 51.1 Who is responsible for actions described in this subpart?
State agencies whose geographic coverage include any point, area,
mobile, or biogenic sources must inventory these sources and report this
information to EPA.
Sec. 51.5 What tools are available to help prepare and report emissions data?
We urge your State to use estimation procedures described in
documents from the Emission Inventory Improvement Program (EIIP). These
procedures are standardized and ranked according to relative uncertainty
for each emission estimating technique. Using this guidance will enable
others to use your State's data and evaluate its quality and consistency
with other data.
Sec. 51.10 How does my State report emissions that are required by the
NOX SIP Call?
The States and the District of Columbia that are subject to the
NOX SIP Call (Sec. 51.121) should report their emissions
under the provisions of Sec. 51.122. To avoid confusion, these
requirements are not repeated here.
Specific Reporting Requirements
Sec. 51.15 What data does my State need to report to EPA?
(a) Pollutants. Report actual emissions of the following (see
Glossary to Appendix A to this subpart for precise definitions as
required):
(1) Required Pollutants:
(i) Sulfur oxides.
(ii) VOC.
(iii) Nitrogen oxides.
(iv) Carbon monoxide.
(v) Lead and lead compounds.
(vi) Primary PM2.5.
(vii) Primary PM10.
(viii) NH3.
(2) Optional Pollutant:
[[Page 132]]
(i) Primary PM.
(ii) [Reserved]
(b) Sources. Emissions should be reported from the following
sources:
(1) Point.
(2) Area.
(3) Onroad mobile.
(4) Nonroad mobile.
(5) Biogenic.
(c) Supporting information. Report the data elements in Tables 2a
through 2d of Appendix A to this subpart. Depending on the format you
choose to report your State data, additional information not listed in
Tables 2a through 2d will be required. We may ask you for other data on
a voluntary basis to meet special purposes.
(d) Confidential data. We don't consider the data in Tables 2a
through 2d of Appendix A to this subpart confidential, but some States
limit release of this type of data. Any data that you submit to EPA
under this rule will be considered in the public domain and cannot be
treated as confidential. If Federal and State requirements are
inconsistent, consult your EPA Regional Office for a final
reconciliation.
Sec. 51.20 What are the emission thresholds that separate point and area
sources?
(a) All anthropogenic stationary sources must be included in your
inventory as either point or area sources.
(b) See Table 1 of Appendix A to this subpart for minimum reporting
thresholds on point sources.
(c) Your State has two alternatives to the point source reporting
thresholds in paragraph (b) of this section:
(1) You may choose to define point sources by the definition of a
major source used under CAA Title V, see 40 CFR 70.2.
(2) If your State has lower emission reporting thresholds for point
sources than paragraph (b) of this section, then you may use these in
reporting your emissions to EPA.
(d) All stationary sources that have actual emissions lower than the
thresholds specified in paragraphs (b) and (c) of this section, should
be reported as area sources.
Sec. 51.25 What geographic area must my State's inventory cover?
Because of the regional nature of these pollutants, your State's
inventory must be statewide, regardless of an area's attainment status.
Sec. 51.30 When does my State report the data to EPA?
Your State is required to report two basic types of emission
inventories to us: Annual Cycle Inventory; and Three-year Cycle
Inventory.
(a) Annual cycle. You are required to report annually data from Type
A (large) point sources. Except as provided in paragraph (e) of this
section, the first annual cycle inventory will be for the year 2001 and
must be submitted to us within 17 months, i.e., by June 1, 2003.
Subsequent annual cycle inventories will be due 17 months following the
end of the reporting year. See Table 2a of Appendix A to this subpart
for the specific data elements to report annually.
(b) Three-year cycle. You are required to report triennially, data
for Type B (all) point sources, area sources and mobile sources. Except
as provided in paragraph (e) of this section, the first three-year cycle
inventory will be for the year 2002 and must be submitted to us within
17 months, i.e., by June 1, 2004. Subsequent three-year cycle
inventories will be due 17 months following the end of the reporting
year. See Tables 2a, 2b and 2c of Appendix A to this subpart for the
specific data elements that must be reported triennially.
(c) NOX SIP call. There are specific annual and three-
year reporting requirements for States subject to the NOX SIP
call. See Sec. 51.122 for these requirements.
(d) Biogenic emissions. Biogenic emissions are part of your 3-year
cycle inventory. Your State must establish an initial baseline for
biogenic emissions that is due as specified under paragraph (b) of this
section. Your State need not submit more biogenic data unless land use
characteristics or the methods for estimating emissions change
substantially. If either of these changes, your State must report the
biogenic emission data elements shown
[[Page 133]]
in Table 2d of Appendix A to this subpart. Report these data elements 17
months after the end of the reporting year.
(e) Point Sources. States must commence reporting point source
emissions of PM2.5 and NH3 on June 1, 2004 unless
that date is less than 60 days after EPA publishes an approved
Information Collection Request (ICR) addressing this section of the
rule. If EPA fails to publish an approved ICR 60 days in advance of June
1, 2004, States must commence reporting point source emissions of
PM2.5 and NH3 on the next annual or triennial
reporting date (as appropriate) that is at least 60 days after EPA
publishes an approved ICR addressing this section.
Sec. 51.35 How can my State equalize the effort for annual reporting?
(a) Compiling a 3-year cycle inventory means much more effort every
three years. As an option, your State may ease this workload spike by
using the following approach:
(1) Annually collect and report data for all Type A (large) point
sources (This is required for all Type A point sources).
(2) Annually collect data for one-third of your smaller point
sources (Type B point sources minus Type A (large) point sources).
Collect data for a different third of these sources each year so that
data has been collected for all of the smaller point sources by the end
of each three-year cycle. You may report these data to EPA annually, or
as an option you may save three years of data and then report all of the
smaller point sources on the three-year cycle due date.
(3) Annually collect data for one-third of the area, nonroad mobile,
onroad mobile and, if required, biogenic sources. You may report these
data to EPA annually, or as an option you may save three years of data
and then report all of these data on the three-year cycle due date.
(b) For the sources described in paragraph (a) of this section, your
State will therefore have data from three successive years at any given
time, rather than from the single year in which it is compiled.
(c) If your State chooses the method of inventorying one-third of
your smaller point sources and 3-year cycle area, nonroad mobile, onroad
mobile sources each year, your State must compile each year of the
three-year period identically. For example, if a process hasn't changed
for a source category or individual plant, your State must use the same
emission factors to calculate emissions for each year of the three-year
period. If your State has revised emission factors during the three
years for a process that hasn't changed, resubmit previous year's data
using the revised factor. If your State uses models to estimate
emissions, you must make sure that the model is the same for all three
years.
(d) If your State chooses the method of inventorying one-third of
your smaller point sources and 3-year cycle area, nonroad mobile, onroad
mobile sources each year and reporting them on the 3-year cycle due
date, the first required date for you to report on all such sources will
be June 1, 2004 as specified in Sec. 51.25. You can satisfy the 2004
reporting requirement by either: Starting to inventory one third of your
sources in 2000; or doing a one-time complete 3-year cycle inventory for
2002, then changing to the option of inventorying one third of your
sources for subsequent years.
(e) If your State needs a new reference year emission inventory for
a selected pollutant, your State can't use these optional reporting
frequencies for the new reference year.
(f) If your State is a NOX SIP call State, you can't use
these optional reporting frequencies for NOX SIP call
reporting.
Sec. 51.40 In what form should my State report the data to EPA?
You must report your emission inventory data to us in electronic
form. We support specific electronic data reporting formats and you are
required to report your data in a format consistent with these. Because
electronic reporting technology continually changes, contact the
Emission Factor and Inventory Group (EFIG) for the latest specific
formats. You can find information on the current formats at the
following Internet address: http://
[[Page 134]]
www.epa.gov/ttn/chief. You may also call our Info CHIEF help desk at
(919) 541-1000 or email to [email protected].
Sec. 51.45 Where should my State report the data?
(a) Your State submits or reports data by providing it directly to
EPA.
(b) The latest information on data reporting procedures is available
at the following Internet address: http://www.epa.gov/ttn/chief.
You may also call our Info CHIEF help desk at (919)541-1000 or email
to [email protected].
Appendix A to Subpart A of Part 51--Tables and Glossary
Table 1--Minimum Point Source Reporting Thresholds by Pollutant(tpy \1\)
----------------------------------------------------------------------------------------------------------------
Three-year cycle
Pollutant Annual cycle --------------------------------------------------------
(type A sources) Type B sources \2\ NAA \3\
----------------------------------------------------------------------------------------------------------------
1. SOx............................. [ge]2500 [ge]100 [ge]100
2. VOC............................. [ge]250 [ge]100 03 (moderate)[ge]100
3. VOC............................. .................. .................. O3 (serious)[ge]50
4. VOC............................. .................. .................. O3 (severe)[ge]25
5. VOC............................. .................. .................. O3 (extreme)[ge]10
6. NOX............................. [ge]2500 [ge]100 [ge]100
7. CO.............................. [ge]2500 [ge]1000 O3 (all areas)[ge]100
8. CO.............................. .................. .................. CO (all areas)[ge]100
9. Pb.............................. .................. [ge]5 [ge]5
10. PM10........................... [ge]250 [ge]100 PM1010 (moderate)[ge]100
11. PM10........................... .................. .................. PM10 (serious)[ge]70
12. PM2.5.......................... [ge]250 [ge]100 [ge]100
13. NH3............................ [ge]250 [ge]100 [ge]100
----------------------------------------------------------------------------------------------------------------
\1\ tpy = tons per year of actual emissions.
\2\ Type A sources are a subset of the Type B sources and are the larger emitting sources by pollutant.
\3\ NAA = Nonattainment Area. Special point source reporting thresholds apply for certain pollutants by type of
nonattainment area. The pollutants by nonattainment area are: Ozone: VOC, NOX, CO; CO: CO; PM10: PM10.
Table 2a--Data Elements That States Must Report for Point Sources
------------------------------------------------------------------------
Every 3 years
Data elements Annual (Type A (Type B sources
sources) and NAAs)
------------------------------------------------------------------------
1. Inventory year............... [bcheck] [bcheck]
2. Inventory start date......... [bcheck] [bcheck]
3. Inventory end date........... [bcheck] [bcheck]
4. Inventory type............... [bcheck] [bcheck]
5. State FIPS code.............. [bcheck] [bcheck]
6. County FIPS code............. [bcheck] [bcheck]
7. Facility ID code............. [bcheck] [bcheck]
8. Point ID code................ [bcheck] [bcheck]
9. Process ID code.............. [bcheck] [bcheck]
10. Stack ID code............... [bcheck] [bcheck]
11. Site name................... [bcheck] [bcheck]
12. Physical address............ [bcheck] [bcheck]
13. SCC or PCC.................. [bcheck] [bcheck]
14. Heat content (fuel) (annual [bcheck] [bcheck]
average).......................
15. Ash content (fuel) (annual [bcheck] [bcheck]
average).......................
16. Sulfur content (fuel) [bcheck] [bcheck]
(annual average)...............
17. Pollutant code.............. [bcheck] [bcheck]
18. Activity/throughput (annual) [bcheck] [bcheck]
19. Activity/throughput (daily). [bcheck] [bcheck]
20. Work weekday emissions...... [bcheck] [bcheck]
21. Annual emissions............ [bcheck] [bcheck]
22. Emission factor............. [bcheck] [bcheck]
23. Winter throughput (%)....... [bcheck] [bcheck]
24. Spring throughput (%)....... [bcheck] [bcheck]
25. Summer throughput (%)....... [bcheck] [bcheck]
26. Fall throughput (%)......... [bcheck] [bcheck]
27. Hr/day in operation......... [bcheck] [bcheck]
28. Start time (hour)........... [bcheck] [bcheck]
29. Day/wk in operation......... [bcheck] [bcheck]
30. Wk/yr in operation.......... [bcheck] [bcheck]
31. X stack coordinate .................. [bcheck]
(latitude).....................
32. Y stack coordinate .................. [bcheck]
(longitude)....................
33. Stack Height................ .................. [bcheck]
[[Page 135]]
34. Stack diameter.............. .................. [bcheck]
35. Exit gas temperature........ .................. [bcheck]
36. Exit gas velocity........... .................. [bcheck]
37. Exit gas flow rate.......... .................. [bcheck]
38. SIC/NAICS................... .................. [bcheck]
39. Design capacity............. .................. [bcheck]
40. Maximum namemplate capacity. .................. [bcheck]
41. Primary control eff (%)..... .................. [bcheck]
42. Secondary control eff (%)... .................. [bcheck]
43. Control device type......... .................. [bcheck]
44. Rule effectiveness (%)...... .................. [bcheck]
------------------------------------------------------------------------
Table 2b--Data Elements that States Must Report for Area and Nonroad
Mobile Sources
------------------------------------------------------------------------
Every 3
Data elements years
------------------------------------------------------------------------
1. Inventory year......................................... [bcheck]
2. Inventory start date................................... [bcheck]
3. Inventory end date..................................... [bcheck]
4. Inventory type......................................... [bcheck]
5. State FIPS code........................................ [bcheck]
6. County FIPS code....................................... [bcheck]
7. SCC or PCC............................................. [bcheck]
8. Emission factor........................................ [bcheck]
9. Activity/throughput level (annual)..................... [bcheck]
10. Total capture/control efficiency (%).................. [bcheck]
11. Rule effectiveness (%)................................ [bcheck]
12. Rule penetration (%).................................. [bcheck]
13. Pollutant code........................................ [bcheck]
14. Summer/winter work weekday emissions.................. [bcheck]
15. Annual emissions...................................... [bcheck]
16. Winter throughput (%)................................. [bcheck]
17. Spring throughput (%)................................. [bcheck]
18. Summer throughput (%)................................. [bcheck]
19. Fall throughput (%)................................... [bcheck]
20. Hrs/day in operation.................................. [bcheck]
21. Days/wk in operation.................................. [bcheck]
22. Wks/yr in operation................................... [bcheck]
------------------------------------------------------------------------
Table 2c--Data Elements that States Must Report for Onroad Mobile
Sources
------------------------------------------------------------------------
Every 3
Data elements years
------------------------------------------------------------------------
1. Inventory year......................................... [bcheck]
2. Inventory start date................................... [bcheck]
3. Inventory end date..................................... [bcheck]
4. Inventory type......................................... [bcheck]
5. State FIPS code........................................ [bcheck]
6. County FIPS code....................................... [bcheck]
7. SCC or PCC............................................. [bcheck]
8. Emission factor........................................ [bcheck]
9. Activity (VMT by Roadway Class)........................ [bcheck]
10. Pollutant code........................................ [bcheck]
11. Summer/winter work weekday emissions.................. [bcheck]
12. Annual emissions...................................... [bcheck]
------------------------------------------------------------------------
Table 2d--Data Elements that States Must Report for Biogenic Sources
------------------------------------------------------------------------
Every 3
Data elements years
------------------------------------------------------------------------
1. Inventory year......................................... [bcheck]
2. Inventory start date................................... [bcheck]
3. Inventory end date..................................... [bcheck]
4. Inventory type......................................... [bcheck]
5. State FIPS code........................................ [bcheck]
6. County FIPS code....................................... [bcheck]
7. SCC or PCC............................................. [bcheck]
8. Pollutant code......................................... [bcheck]
9. Summer/winter work weekday emissions................... [bcheck]
10. Annual emissions...................................... [bcheck]
------------------------------------------------------------------------
Glossary
Activity rate/throughput (annual)--A measurable factor or parameter
that relates directly or indirectly to the emissions of an air pollution
source. Depending on the type of source category, activity information
may refer to the amount of fuel combusted, raw material processed,
product manufactured, or material handled or processed. It may also
refer to population, employment, number of units, or miles traveled.
Activity information is typically the value that is multiplied against
an emission factor to generate an emissions estimate.
Activity rate/throughput (daily)--The beginning and ending dates and
times that define the emissions period used to estimate the daily
activity rate/throughput.
Annual emissions--Actual emissions for a plant, point, or process--
measured or calculated that represent a calendar year.
Area sources--Area sources collectively represent individual sources
that have not been inventoried as specific point, mobile, or biogenic
sources. These individual sources treated collectively as area sources
are typically too small, numerous, or difficult to inventory using the
methods for the other classes of sources.
Ash content--Inert residual portion of a fuel.
Biogenic sources--Biogenic emissions are all pollutants emitted from
non-anthropogenic sources. Example sources include trees
[[Page 136]]
and vegetation, oil and gas seeps, and microbial activity.
Control device type--The name of the type of control device (e.g.,
wet scrubber, flaring, or process change).
County FIPS Code--Federal Information Placement System (FIPS) is the
system of unique numeric codes the government developed to identify
States, counties and parishes for the entire United States, Puerto Rico,
and Guam.
Day/wk in operations--Days per week that the emitting process
operates--average over the inventory period.
Design capacity--A measure of the size of a point source, based on
the reported maximum continuous capacity of the unit.
Emission factor--Ratio relating emissions of a specific pollutant to
an activity or material throughput level.
Exit gas flow rate--Numeric value of stack gas's flow rate.
Exit gas temperature--Numeric value of an exit gas stream's
temperature.
Exit gas velocity--Numeric value of an exit gas stream's velocity.
Facility ID code--Unique code for a plant or facility, containing
one or more pollutant-emitting sources. This is the data element in
Appendix A, Table 2a, that is defined elsewhere in this glossary as a
``point source''.
Fall throughput(%)--Part of the throughput for the three Fall months
(September, October, November). This expresses part of the annual
activity information based on four seasons--typically spring, summer,
fall, and winter. It can be a percentage of the annual activity (e.g.,
production in summer is 40% of the year's production) or units of the
activity (e.g., out of 600 units produced, spring = 150 units, summer =
250 units, fall = 150 units, and winter = 50 units).
Heat content--The amount of thermal heat energy in a solid, liquid,
or gaseous fuel. Fuel heat content is typically expressed in units of
Btu/lb of fuel, Btu/gal of fuel, joules/kg of fuel, etc.
Hr/day in operations--Hours per day that the emitting process
operates--average over the inventory period.
Inventory end date--Last day of the inventory period.
Inventory start date--First day of the inventory period.
Inventory type--Type of inventory represented by data (i.e., point,
3-year cycle, daily).
Inventory year--The calendar year for which you calculated emissions
estimates.
Lead (Pb)--As defined in 40 CFR 50.12, lead should be reported as
elemental lead and its compounds.
Maximum nameplate capacity--A measure of a unit's size that the
manufacturer puts on the unit's nameplate.
Mobile source--A motor vehicle, nonroad engine or nonroad vehicle.
A ``motor vehicle'' is any self-propelled vehicle used to
carry people or property on a street or highway.
A ``nonroad engine'' is an internal combustion engine
(including fuel system) that is not used in a motor vehicle or vehicle
only used for competition, or that is not affected by sections 111 or
202 of the CAA.
A ``nonroad vehicle'' is a vehicle that is run by a nonroad
engine and that is not a motor vehicle or a vehicle only used for
competition.
PM (Particulate Matter)--Particulate matter is a criteria air
pollutant. For the purpose of this subpart, the following definitions
apply:
(1) Primary PM: Particles that enter the atmosphere as a direct
emission from a stack or an open source. It is comprised of two
components: Filterable PM and Condensible PM. (As specified in
Sec. 51.15 (a)(2), these two PM components are the components measured
by a stack sampling train such as EPA Method 5 and have no upper
particle size limit.)
(2) Filterable PM: Particles that are directly emitted by a source
as a solid or liquid at stack or release conditions and captured on the
filter of a stack test train.
(3) Condensible PM: Material that is vapor phase at stack
conditions, but which condenses and/or reacts upon cooling and dilution
in the ambient air to form solid or liquid PM immediately after
discharge from the stack.
(4) Secondary PM: Particles that form through chemical reactions in
the ambient air well after dilution and condensation have occurred.
Secondary PM is usually formed at some distance downwind from the
source. Secondary PM should NOT be reported in the emission inventory
and is NOT covered by this subpart.
(5) Primary PM2.5: Also PM2.5 (or Filterable
PM2.5 and Condensible PM individually. Note that all
Condensible PM is assumed to be in the PM2.5 size fraction)--
Particulate matter with an aerodynamic diameter equal to or less than
2.5 micrometers.
(6) Primary PM10: Also PM10 (or Filterable
PM10 and Condensible PM individually)--Particulate matter
with an aerodynamic diameter equal to or less than 10 micrometers.
PCC--Process classification code. A process-level code that
describes the equipment or operation which is emitting pollutants. This
code is being considered as a replacement for the SCC.
Physical address--Street address of a facility. This is the address
of the location where the emissions occur; not, for example, the
corporate headquarters.
Point ID code--Unique code for the point of generation of emissions,
typically a physical piece of equipment.
[[Page 137]]
Point source--Point sources are large, stationary (non-mobile),
identifiable sources of emissions that release pollutants into the
atmosphere. As used in this rule, a point source is defined as a
facility that annually emits more than a ``threshold'' value as defined
under Sec. 51.20.
Pollutant code--A unique code for each reported pollutant assigned
in the Emission Inventory Improvement Program (EIIP) Data Model. The
EIIP model was developed to promote consistency in organizations sharing
emissions data. The model uses character names for criteria pollutants
and Chemical Abstracts Service (CAS) numbers for all other pollutants.
You may be using SAROAD codes for pollutants, but you should be able to
map them to the pollutant codes in the EIIP Data Model.
Process ID code--Unique code for the process generating the
emissions, typically a description of a process.
Roadway class--A classification system developed by the Federal
Highway Administration that defines all public roadways as to type.
Currently there are four roadway types: (1) Freeway, (2) freeway ramp,
(3) arterial/collector and (4) local.
Rule effectiveness (RE)--How well a regulatory program achieves all
possible emission reductions. This rating reflects the assumption that
controls typically aren't 100 percent effective because of equipment
downtime, upsets, decreases in control efficiencies, and other
deficiencies in emission estimates. RE adjusts the control efficiency.
Rule penetration--The percentage of an area source category covered
by an applicable regulation.
SCC--Source classification code. A process-level code that describes
the equipment and/or operation which is emitting pollutants.
Seasonal activity rate/throughput--A measurable factor or parameter
that relates directly or indirectly to the pollutant season emissions of
an air pollution source. Depending on the type of source category,
activity information may refer to the amount of fuel combusted, raw
material processed, product manufactured, or material handled or
processed. It may also refer to population, employment, number of units,
or miles traveled. Activity information is typically the value that is
multiplied against an emission factor to generate an emissions estimate.
Seasonal fuel heat content--The amount of thermal heat energy in a
solid, liquid, or gaseous fuel used during the pollutant season. Fuel
heat content is typically expressed in units of Btu/lb of fuel, Btu/gal
of fuel, joules/kg of fuel, etc.
Secondary control eff (%)--The emission reduction efficiency of a
secondary control device. Control efficiency is usually expressed as a
percentage or in tenths.
SIC/NAICS--Standard Industrial Classification code. NAICS (North
American Industry Classification System) codes will replace SIC codes.
U.S. Department of Commerce's code for businesses by products or
services.
Site name--The name of the facility.
Spring throughput (%)--Part of throughput or activity for the three
spring months (March, April, May). See the definition of Fall
Throughput.
Stack diameter--A stack's inner physical diameter.
Stack height--A stack's physical height above the surrounding
terrain.
Stack ID code--Unique code for the point where emissions from one or
more processes release into the atmosphere.
Start time (hour)--Start time (if available) that you used to
calculate the emissions estimates.
State FIPS Code--Federal Information Placement System (FIPS) is the
system of unique numeric codes the government developed to identify
States, counties and parishes for the entire United States, Puerto Rico,
and Guam.
Sulfur content--Sulfur content of a fuel, usually expressed as
percent by weight.
Summer throughput(%)--Part of throughput or activity for the three
summer months (June, July, August). See the definition of Fall
Throughput.
Summer/winter work weekday emissions--Average day's emissions for a
typical day. Ozone daily emissions = summer work weekday; CO and PM
daily emissions = winter work weekday.
Total capture/control efficiency--The emission reduction efficiency
of a primary control device, which shows the amount controls or material
changes reduce a particular pollutant from a process' emissions. Control
efficiency is usually expressed as a percentage or in tenths.
Type A source--Large point sources with actual annual emissions
greater than or equal to any of the emission thresholds listed in Table
1 for Type A sources.
Type B source--Point sources with actual annual emissions during any
year of the three year cycle greater than or equal to any of the
emission thresholds listed in Table 1 for Type B sources. Type B sources
include all Type A sources.
VMT by Roadway Class--Vehicle miles traveled (VMT) expresses vehicle
activity and is used with emission factors. The emission factors are
usually expressed in terms of grams per mile of travel. Because VMT
doesn't correlate directly to emissions that occur while the vehicle
isn't moving, these nonmoving emissions are incorporated into the
emission factors in EPA's MOBILE Model.
VOC--Volatile Organic Compounds. The EPA's regulatory definition of
VOC is in 40 CFR 51.100.
[[Page 138]]
Winter throughput (%)--Part of throughput or activity for the three
winter months (December, January, February, all from the same year,
e.g., Winter 2000 = January 2000 + February, 2000 + December 2000). See
the definition of Fall Throughput.
Wk/yr in operation--Weeks per year that the emitting process
operates.
Work Weekday--Any day of the week except Saturday or Sunday.
X stack coordinate (latitude)--An object's north-south geographical
coordinate. Y stack coordinate (longitude)--An object's east-west
geographical coordinate.
Subparts B--E [Reserved]
Subpart F--Procedural Requirements
Authority: 42 U.S.C. 7401, 7411, 7412, 7413, 7414, 7470-7479, 7501-
7508, 7601, and 7602.
Sec. 51.100 Definitions.
As used in this part, all terms not defined herein will have the
meaning given them in the Act:
(a) Act means the Clean Air Act (42 U.S.C. 7401 et seq., as amended
by Pub. L. 91-604, 84 Stat. 1676 Pub. L. 95-95, 91 Stat., 685 and Pub.
L. 95-190, 91 Stat., 1399.)
(b) Administrator means the Administrator of the Environmental
Protection Agency (EPA) or an authorized representative.
(c) Primary standard means a national primary ambient air quality
standard promulgated pursuant to section 109 of the Act.
(d) Secondary standard means a national secondary ambient air
quality standard promulgated pursuant to section 109 of the Act.
(e) National standard means either a primary or secondary standard.
(f) Owner or operator means any person who owns, leases, operates,
controls, or supervises a facility, building, structure, or installation
which directly or indirectly result or may result in emissions of any
air pollutant for which a national standard is in effect.
(g) Local agency means any local government agency other than the
State agency, which is charged with responsibility for carrying out a
portion of the plan.
(h) Regional Office means one of the ten (10) EPA Regional Offices.
(i) State agency means the air pollution control agency primarily
responsible for development and implementation of a plan under the Act.
(j) Plan means an implementation plan approved or promulgated under
section 110 of 172 of the Act.
(k) Point source means the following:
(1) For particulate matter, sulfur oxides, carbon monoxide, volatile
organic compounds (VOC) and nitrogen dioxide--
(i) Any stationary source the actual emissions of which are in
excess of 90.7 metric tons (100 tons) per year of the pollutant in a
region containing an area whose 1980 urban place population, as defined
by the U.S. Bureau of the Census, was equal to or greater than 1
million.
(ii) Any stationary source the actual emissions of which are in
excess of 22.7 metric tons (25 tons) per year of the pollutant in a
region containing an area whose 1980 urban place population, as defined
by the U.S. Bureau of the Census, was less than 1 million; or
(2) For lead or lead compounds measured as elemental lead, any
stationary source that actually emits a total of 4.5 metric tons (5
tons) per year or more.
(l) Area source means any small residential, governmental,
institutional, commercial, or industrial fuel combustion operations;
onsite solid waste disposal facility; motor vehicles, aircraft vessels,
or other transportation facilities or other miscellaneous sources
identified through inventory techniques similar to those described in
the ``AEROS Manual series, Vol. II AEROS User's Manual,'' EPA-450/2-76-
029 December 1976.
(m) Region means an area designated as an air quality control region
(AQCR) under section 107(c) of the Act.
(n) Control strategy means a combination of measures designated to
achieve the aggregate reduction of emissions necessary for attainment
and maintenance of national standards including, but not limited to,
measures such as:
(1) Emission limitations.
[[Page 139]]
(2) Federal or State emission charges or taxes or other economic
incentives or disincentives.
(3) Closing or relocation of residential, commercial, or industrial
facilities.
(4) Changes in schedules or methods of operation of commercial or
industrial facilities or transportation systems, including, but not
limited to, short-term changes made in accordance with standby plans.
(5) Periodic inspection and testing of motor vehicle emission
control systems, at such time as the Administrator determines that such
programs are feasible and practicable.
(6) Emission control measures applicable to in-use motor vehicles,
including, but not limited to, measures such as mandatory maintenance,
installation of emission control devices, and conversion to gaseous
fuels.
(7) Any transportation control measure including those
transportation measures listed in section 108(f) of the Clean Air Act as
amended.
(8) Any variation of, or alternative to any measure delineated
herein.
(9) Control or prohibition of a fuel or fuel additive used in motor
vehicles, if such control or prohibition is necessary to achieve a
national primary or secondary air quality standard and is approved by
the Administrator under section 211(c)(4)(C) of the Act.
(o) Reasonably available control technology (RACT) means devices,
systems, process modifications, or other apparatus or techniques that
are reasonably available taking into account:
(1) The necessity of imposing such controls in order to attain and
maintain a national ambient air quality standard;
(2) The social, environmental, and economic impact of such controls;
and
(3) Alternative means of providing for attainment and maintenance of
such standard. (This provision defines RACT for the purposes of
Sec. 51.341(b) only.)
(p) Compliance schedule means the date or dates by which a source or
category of sources is required to comply with specific emission
limitations contained in an implementation plan and with any increments
of progress toward such compliance.
(q) Increments of progress means steps toward compliance which will
be taken by a specific source, including:
(1) Date of submittal of the source's final control plan to the
appropriate air pollution control agency;
(2) Date by which contracts for emission control systems or process
modifications will be awarded; or date by which orders will be issued
for the purchase of component parts to accomplish emission control or
process modification;
(3) Date of initiation of on-site construction or installation of
emission control equipment or process change;
(4) Date by which on-site construction or installation of emission
control equipment or process modification is to be completed; and
(5) Date by which final compliance is to be achieved.
(r) Transportation control measure means any measure that is
directed toward reducing emissions of air pollutants from transportation
sources. Such measures include, but are not limited to, those listed in
section 108(f) of the Clean Air Act.
(s) Volatile organic compounds (VOC) means any compound of carbon,
excluding carbon monoxide, carbon dioxide, carbonic acid, metallic
carbides or carbonates, and ammonium carbonate, which participates in
atmospheric photochemical reactions.
(1) This includes any such organic compound other than the
following, which have been determined to have negligible photochemical
reactivity: methane; ethane; methylene chloride (dichloromethane);
1,1,1-trichloroethane (methyl chloroform); 1,1,2-trichloro-1,2,2-
trifluoroethane (CFC-113); trichlorofluoromethane (CFC-11);
dichlorodifluoromethane (CFC-12); chlorodifluoromethane (HCFC-22);
trifluoromethane (HFC-23); 1,2-dichloro 1,1,2,2-tetrafluoroethane (CFC-
114); chloropentafluoroethane (CFC-115); 1,1,1-trifluoro 2,2-
dichloroethane (HCFC-123); 1,1,1,2-tetrafluoroethane (HFC-134a); 1,1-
dichloro 1-fluoroethane (HCFC-141b); 1-chloro 1,1-difluoroethane (HCFC-
142b); 2-chloro-1,1,1,2-tetrafluoroethane (HCFC-124); pentafluoroethane
(HFC-125); 1,1,2,2-tetrafluoroethane (HFC-134); 1,1,1-trifluoroethane
(HFC-143a); 1,1-
[[Page 140]]
difluoroethane (HFC-152a); parachlorobenzotrifluoride (PCBTF); cyclic,
branched, or linear completely methylated siloxanes; acetone;
perchloroethylene (tetrachloroethylene); 3,3-dichloro-1,1,1,2,2-
pentafluoropropane (HCFC-225ca); 1,3-dichloro-1,1,2,2,3-
pentafluoropropane (HCFC-225cb); 1,1,1,2,3,4,4,5,5,5-decafluoropentane
(HFC 43-10mee); difluoromethane (HFC-32); ethylfluoride (HFC-161);
1,1,1,3,3,3-hexafluoropropane (HFC-236fa); 1,1,2,2,3-pentafluoropropane
(HFC-245ca); 1,1,2,3,3-pentafluoropropane (HFC-245ea); 1,1,1,2,3-
pentafluoropropane (HFC-245eb); 1,1,1,3,3-pentafluoropropane (HFC-
245fa); 1,1,1,2,3,3-hexafluoropropane (HFC-236ea); 1,1,1,3,3-
pentafluorobutane (HFC-365mfc); chlorofluoromethane (HCFC-31); 1 chloro-
1-fluoroethane (HCFC-151a); 1,2-dichloro-1,1,2-trifluoroethane (HCFC-
123a); 1,1,1,2,2,3,3,4,4-nonafluoro-4-methoxy-butane
(C4F9OCH3); 2-(difluoromethoxymethyl)-
1,1,1,2,3,3,3-heptafluoropropane
((CF3)2CFCF2OCH3); 1-ethoxy-
1,1,2,2,3,3,4,4,4-nonafluorobutane
(C4F9OC2H5); 2-
(ethoxydifluoromethyl)-1,1,1,2,3,3,3-heptafluoropropane
((CF3)2CFCF2OC2H5)
; methyl acetate and perfluorocarbon compounds which fall into these
classes:
(i) Cyclic, branched, or linear, completely fluorinated alkanes;
(ii) Cyclic, branched, or linear, completely fluorinated ethers with
no unsaturations;
(iii) Cyclic, branched, or linear, completely fluorinated tertiary
amines with no unsaturations; and
(iv) Sulfur containing perfluorocarbons with no unsaturations and
with sulfur bonds only to carbon and fluorine.
(2) For purposes of determining compliance with emissions limits,
VOC will be measured by the test methods in the approved State
implementation plan (SIP) or 40 CFR part 60, appendix A, as applicable.
Where such a method also measures compounds with negligible
photochemical reactivity, these negligibility-reactive compounds may be
excluded as VOC if the amount of such compounds is accurately
quantified, and such exclusion is approved by the enforcement authority.
(3) As a precondition to excluding these compounds as VOC or at any
time thereafter, the enforcement authority may require an owner or
operator to provide monitoring or testing methods and results
demonstrating, to the satisfaction of the enforcement authority, the
amount of negligibly-reactive compounds in the source's emissions.
(4) For purposes of Federal enforcement for a specific source, the
EPA shall use the test methods specified in the applicable EPA-approved
SIP, in a permit issued pursuant to a program approved or promulgated
under title V of the Act, or under 40 CFR part 51, subpart I or appendix
S, or under 40 CFR parts 52 or 60. The EPA shall not be bound by any
State determination as to appropriate methods for testing or monitoring
negligibly-reactive compounds if such determination is not reflected in
any of the above provisions.
(t)-(w) [Reserved]
(x) Time period means any period of time designated by hour, month,
season, calendar year, averaging time, or other suitable
characteristics, for which ambient air quality is estimated.
(y) Variance means the temporary deferral of a final compliance date
for an individual source subject to an approved regulation, or a
temporary change to an approved regulation as it applies to an
individual source.
(z) Emission limitation and emission standard mean a requirement
established by a State, local government, or the Administrator which
limits the quantity, rate, or concentration of emissions of air
pollutants on a continuous basis, including any requirements which limit
the level of opacity, prescribe equipment, set fuel specifications, or
prescribe operation or maintenance procedures for a source to assure
continuous emission reduction.
(aa) Capacity factor means the ratio of the average load on a
machine or equipment for the period of time considered to the capacity
rating of the machine or equipment.
(bb) Excess emissions means emissions of an air pollutant in excess
of an emission standard.
[[Page 141]]
(cc) Nitric acid plant means any facility producing nitric acid 30
to 70 percent in strength by either the pressure or atmospheric pressure
process.
(dd) Sulfuric acid plant means any facility producing sulfuric acid
by the contact process by burning elemental sulfur, alkylation acid,
hydrogen sulfide, or acid sludge, but does not include facilities where
conversion to sulfuric acid is utilized primarily as a means of
preventing emissions to the atmosphere of sulfur dioxide or other sulfur
compounds.
(ee) Fossil fuel-fired steam generator means a furnance or bioler
used in the process of burning fossil fuel for the primary purpose of
producing steam by heat transfer.
(ff) Stack means any point in a source designed to emit solids,
liquids, or gases into the air, including a pipe or duct but not
including flares.
(gg) A stack in existence means that the owner or operator had (1)
begun, or caused to begin, a continuous program of physical on-site
construction of the stack or (2) entered into binding agreements or
contractual obligations, which could not be cancelled or modified
without substantial loss to the owner or operator, to undertake a
program of construction of the stack to be completed within a reasonable
time.
(hh)(1) Dispersion technique means any technique which attempts to
affect the concentration of a pollutant in the ambient air by:
(i) Using that portion of a stack which exceeds good engineering
practice stack height:
(ii) Varying the rate of emission of a pollutant according to
atmospheric conditions or ambient concentrations of that pollutant; or
(iii) Increasing final exhaust gas plume rise by manipulating source
process parameters, exhaust gas parameters, stack parameters, or
combining exhaust gases from several existing stacks into one stack; or
other selective handling of exhaust gas streams so as to increase the
exhaust gas plume rise.
(2) The preceding sentence does not include:
(i) The reheating of a gas stream, following use of a pollution
control system, for the purpose of returning the gas to the temperature
at which it was originally discharged from the facility generating the
gas stream;
(ii) The merging of exhaust gas streams where:
(A) The source owner or operator demonstrates that the facility was
originally designed and constructed with such merged gas streams;
(B) After July 8, 1985 such merging is part of a change in operation
at the facility that includes the installation of pollution controls and
is accompanied by a net reduction in the allowable emissions of a
pollutant. This exclusion from the definition of dispersion techniques
shall apply only to the emission limitation for the pollutant affected
by such change in operation; or
(C) Before July 8, 1985, such merging was part of a change in
operation at the facility that included the installation of emissions
control equipment or was carried out for sound economic or engineering
reasons. Where there was an increase in the emission limitation or, in
the event that no emission limitation was in existence prior to the
merging, an increase in the quantity of pollutants actually emitted
prior to the merging, the reviewing agency shall presume that merging
was significantly motivated by an intent to gain emissions credit for
greater dispersion. Absent a demonstration by the source owner or
operator that merging was not significantly motivated by such intent,
the reviewing agency shall deny credit for the effects of such merging
in calculating the allowable emissions for the source;
(iii) Smoke management in agricultural or silvicultural prescribed
burning programs;
(iv) Episodic restrictions on residential woodburning and open
burning; or
(v) Techniques under Sec. 51.100(hh)(1)(iii) which increase final
exhaust gas plume rise where the resulting allowable emissions of sulfur
dioxide from the facility do not exceed 5,000 tons per year.
(ii) Good engineering practice (GEP) stack height means the greater
of:
(1) 65 meters, measured from the ground-level elevation at the base
of the stack:
(2)(i) For stacks in existence on January 12, 1979, and for which
the owner
[[Page 142]]
or operator had obtained all applicable permits or approvals required
under 40 CFR parts 51 and 52.
Hg = 2.5H,
provided the owner or operator produces evidence that this equation was
actually relied on in establishing an emission limitation:
(ii) For all other stacks,
Hg = H + 1.5L
where:
Hg = good engineering practice stack height, measured from
the ground-level elevation at the base of the stack,
H = height of nearby structure(s) measured from the ground-level
elevation at the base of the stack.
L = lesser dimension, height or projected width, of nearby structure(s)
provided that the EPA, State or local control agency may require the use
of a field study or fluid model to verify GEP stack height for the
source; or
(3) The height demonstrated by a fluid model or a field study
approved by the EPA State or local control agency, which ensures that
the emissions from a stack do not result in excessive concentrations of
any air pollutant as a result of atmospheric downwash, wakes, or eddy
effects created by the source itself, nearby structures or nearby
terrain features.
(jj) Nearby as used in Sec. 51.100(ii) of this part is defined for a
specific structure or terrain feature and
(1) For purposes of applying the formulae provided in
Sec. 51.100(ii)(2) means that distance up to five times the lesser of
the height or the width dimension of a structure, but not greater than
0.8 km (\1/2\ mile), and
(2) For conducting demonstrations under Sec. 51.100(ii)(3) means not
greater than 0.8 km (\1/2\ mile), except that the portion of a terrain
feature may be considered to be nearby which falls within a distance of
up to 10 times the maximum height (Ht) of the feature, not to
exceed 2 miles if such feature achieves a height (Ht) 0.8 km
from the stack that is at least 40 percent of the GEP stack height
determined by the formulae provided in Sec. 51.100(ii)(2)(ii) of this
part or 26 meters, whichever is greater, as measured from the ground-
level elevation at the base of the stack. The height of the structure or
terrain feature is measured from the ground-level elevation at the base
of the stack.
(kk) Excessive concentration is defined for the purpose of
determining good engineering practice stack height under
Sec. 51.100(ii)(3) and means:
(1) For sources seeking credit for stack height exceeding that
established under Sec. 51.100(ii)(2) a maximum ground-level
concentration due to emissions from a stack due in whole or part to
downwash, wakes, and eddy effects produced by nearby structures or
nearby terrain features which individually is at least 40 percent in
excess of the maximum concentration experienced in the absence of such
downwash, wakes, or eddy effects and which contributes to a total
concentration due to emissions from all sources that is greater than an
ambient air quality standard. For sources subject to the prevention of
significant deterioration program (40 CFR 51.166 and 52.21), an
excessive concentration alternatively means a maximum ground-level
concentration due to emissions from a stack due in whole or part to
downwash, wakes, or eddy effects produced by nearby structures or nearby
terrain features which individually is at least 40 percent in excess of
the maximum concentration experienced in the absence of such downwash,
wakes, or eddy effects and greater than a prevention of significant
deterioration increment. The allowable emission rate to be used in
making demonstrations under this part shall be prescribed by the new
source performance standard that is applicable to the source category
unless the owner or operator demonstrates that this emission rate is
infeasible. Where such demonstrations are approved by the authority
administering the State implementation plan, an alternative emission
rate shall be established in consultation with the source owner or
operator.
(2) For sources seeking credit after October 11, 1983, for increases
in existing stack heights up to the heights established under
Sec. 51.100(ii)(2), either (i) a maximum ground-level concentration due
in whole or part to downwash, wakes or eddy effects as provided in
[[Page 143]]
paragraph (kk)(1) of this section, except that the emission rate
specified by any applicable State implementation plan (or, in the
absence of such a limit, the actual emission rate) shall be used, or
(ii) the actual presence of a local nuisance caused by the existing
stack, as determined by the authority administering the State
implementation plan; and
(3) For sources seeking credit after January 12, 1979 for a stack
height determined under Sec. 51.100(ii)(2) where the authority
administering the State implementation plan requires the use of a field
study or fluid model to verify GEP stack height, for sources seeking
stack height credit after November 9, 1984 based on the aerodynamic
influence of cooling towers, and for sources seeking stack height credit
after December 31, 1970 based on the aerodynamic influence of structures
not adequately represented by the equations in Sec. 51.100(ii)(2), a
maximum ground-level concentration due in whole or part to downwash,
wakes or eddy effects that is at least 40 percent in excess of the
maximum concentration experienced in the absence of such downwash,
wakes, or eddy effects.
(ll)-(mm) [Reserved]
(nn) Intermittent control system (ICS) means a dispersion technique
which varies the rate at which pollutants are emitted to the atmosphere
according to meteorological conditions and/or ambient concentrations of
the pollutant, in order to prevent ground-level concentrations in excess
of applicable ambient air quality standards. Such a dispersion technique
is an ICS whether used alone, used with other dispersion techniques, or
used as a supplement to continuous emission controls (i.e., used as a
supplemental control system).
(oo) Particulate matter means any airborne finely divided solid or
liquid material with an aerodynamic diameter smaller than 100
micrometers.
(pp) Particulate matter emissions means all finely divided solid or
liquid material, other than uncombined water, emitted to the ambient air
as measured by applicable reference methods, or an equivalent or
alternative method, specified in this chapter, or by a test method
specified in an approved State implementation plan.
(qq) PM10 means particulate matter with an aerodynamic
diameter less than or equal to a nominal 10 micrometers as measured by a
reference method based on appendix J of part 50 of this chapter and
designated in accordance with part 53 of this chapter or by an
equivalent method designated in accordance with part 53 of this chapter.
(rr) PM10 emissions means finely divided solid or liquid
material, with an aerodynamic diameter less than or equal to a nominal
10 micrometers emitted to the ambient air as measured by an applicable
reference method, or an equivalent or alternative method, specified in
this chapter or by a test method specified in an approved State
implementation plan.
(ss) Total suspended particulate means particulate matter as
measured by the method described in appendix B of part 50 of this
chapter.
[51 FR 40661, Nov. 7, 1986, as amended at 52 FR 24712, July 1, 1987; 57
FR 3945, Feb. 3, 1992; 61 FR 4590, Feb. 7, 1996; 61 FR 16060, Apr. 11,
1996; 61 FR 30162, June 14, 1996; 61 FR 52850, Oct. 8, 1996; 62 FR
44903, Aug. 25, 1997; 63 FR 9151, Feb. 24, 1998; 63 FR 17333, Apr. 9,
1998]
Sec. 51.101 Stipulations.
Nothing in this part will be construed in any manner:
(a) To encourage a State to prepare, adopt, or submit a plan which
does not provide for the protection and enhancement of air quality so as
to promote the public health and welfare and productive capacity.
(b) To encourage a State to adopt any particular control strategy
without taking into consideration the cost-effectiveness of such control
strategy in relation to that of alternative control strategies.
(c) To preclude a State from employing techniques other than those
specified in this part for purposes of estimating air quality or
demonstrating the adequacy of a control strategy, provided that such
other techniques are shown to be adequate and appropriate for such
purposes.
(d) To encourage a State to prepare, adopt, or submit a plan without
taking into consideration the social and economic impact of the control
strategy
[[Page 144]]
set forth in such plan, including, but not limited to, impact on
availability of fuels, energy, transportation, and employment.
(e) To preclude a State from preparing, adopting, or submitting a
plan which provides for attainment and maintenance of a national
standard through the application of a control strategy not specifically
identified or described in this part.
(f) To preclude a State or political subdivision thereof from
adopting or enforcing any emission limitations or other measures or
combinations thereof to attain and maintain air quality better than that
required by a national standard.
(g) To encourage a State to adopt a control strategy uniformly
applicable throughout a region unless there is no satisfactory
alternative way of providing for attainment and maintenance of a
national standard throughout such region.
[61 FR 30163, June 14, 1996]
Sec. 51.102 Public hearings.
(a) Except as otherwise provided in paragraph (c) of this section,
States must conduct one or more public hearings on the following prior
to adoption and submission to EPA of:
(1) Any plan or revision of it required by Sec. 51.104(a).
(2) Any individual compliance schedule under (Sec. 51.260).
(3) Any revision under Sec. 51.104(d).
(b) Separate hearings may be held for plans to implement primary and
secondary standards.
(c) No hearing will be required for any change to an increment of
progress in an approved individual compliance schedule unless such
change is likely to cause the source to be unable to comply with the
final compliance date in the schedule. The requirements of Secs. 51.104
and 51.105 will be applicable to such schedules, however.
(d) Any hearing required by paragraph (a) of this section will be
held only after reasonable notice, which will be considered to include,
at least 30 days prior to the date of such hearing(s):
(1) Notice given to the public by prominent advertisement in the
area affected announcing the date(s), time(s), and place(s) of such
hearing(s);
(2) Availability of each proposed plan or revision for public
inspection in at least one location in each region to which it will
apply, and the availability of each compliance schedule for public
inspection in at least one location in the region in which the affected
source is located;
(3) Notification to the Administrator (through the appropriate
Regional Office);
(4) Notification to each local air pollution control agency which
will be significantly impacted by such plan, schedule or revision;
(5) In the case of an interstate region, notification to any other
States included, in whole or in part, in the regions which are
significantly impacted by such plan or schedule or revision.
(e) The State must prepare and retain, for inspection by the
Administrator upon request, a record of each hearing. The record must
contain, as a minimum, a list of witnesses together with the text of
each presentation.
(f) The State must submit with the plan, revision, or schedule a
certification that the hearing required by paragraph (a) of this section
was held in accordance with the notice required by paragraph (d) of this
section.
(g) Upon written application by a State agency (through the
appropriate Regional Office), the Administrator may approve State
procedures for public hearings. The following criteria apply:
(1) Procedures approved under this section shall be deemed to
satisfy the requirement of this part regarding public hearings.
(2) Procedures different from this part may be approved if they--
(i) Ensure public participation in matters for which hearings are
required; and
(ii) Provide adequate public notification of the opportunity to
participate.
(3) The Administrator may impose any conditions on approval he or
she deems necessary.
[36 FR 22938, Nov. 25, 1971, as amended at 65 FR 8657, Feb. 22, 2000]
[[Page 145]]
Sec. 51.103 Submission of plans, preliminary review of plans.
(a) The State makes an official plan submission to EPA only when the
submission conforms to the requirements of appendix V to this part, and
the State delivers five copies of the plan to the appropriate Regional
Office, with a letter giving notice of such action.
(b) Upon request of a State, the Administrator will provide
preliminary review of a plan or portion thereof submitted in advance of
the date such plan is due. Such requests must be made in writing to the
appropriate Regional Office and must be accompanied by five copies of
the materials to be reviewed. Requests for preliminary review do not
relieve a State of the responsibility of adopting and submitting plans
in accordance with prescribed due dates.
[51 FR 40661, Nov. 7, 1986, as amended at 55 FR 5830, Feb. 16, 1990; 63
FR 9151, Feb. 24, 1998]
Sec. 51.104 Revisions.
(a) States may revise the plan from time to time consistent with the
requirements applicable to implementation plans under this part.
(b) The States must submit any revision of any regulation or any
compliance schedule under paragraph (c) of this section to the
Administrator no later than 60 days after its adoption.
(c) EPA will approve revisions only after applicable hearing
requirements of Sec. 51.102 have been satisfied.
(d) In order for a variance to be considered for approval as a
revision to the State implementation plan, the State must submit it in
accordance with the requirements of this section.
[51 FR 40661, Nov. 7, 1986, as amended at 61 FR 16060, Apr. 11, 1996]
Sec. 51.105 Approval of plans.
Revisions of a plan, or any portion thereof, will not be considered
part of an applicable plan until such revisions have been approved by
the Administrator in accordance with this part.
[51 FR 40661, Nov. 7, 1986, as amended at 60 FR 33922, June 29, 1995]
Subpart G--Control Strategy
Source: 51 FR 40665, Nov. 7, 1986, unless otherwise noted.
Sec. 51.110 Attainment and maintenance of national standards.
(a) Each plan providing for the attainment of a primary or secondary
standard must specify the projected attainment date.
(b)-(f) [Reserved]
(g) During developing of the plan, EPA encourages States to identify
alternative control strategies, as well as the costs and benefits of
each such alternative for attainment or maintenance of the national
standard.
[51 FR 40661 Nov. 7, 1986 as amended at 61 FR 16060, Apr. 11, 1996; 61
FR 30163, June 14, 1996]
Sec. 51.111 Description of control measures.
Each plan must set forth a control strategy which includes the
following:
(a) A description of enforcement methods including, but not limited
to:
(1) Procedures for monitoring compliance with each of the selected
control measures,
(2) Procedures for handling violations, and
(3) A designation of agency responsibility for enforcement of
implementation.
(b) [Reserved]
[51 FR 40665, Nov. 7, 1986, as amended at 60 FR 33922, June 29, 1995]
Sec. 51.112 Demonstration of adequacy.
(a) Each plan must demonstrate that the measures, rules, and
regulations contained in it are adequate to provide for the timely
attainment and maintenance of the national standard that it implements.
(1) The adequacy of a control strategy shall be demonstrated by
means of applicable air quality models, data bases, and other
requirements specified in appendix W of this part (Guideline on Air
Quality Models).
(2) Where an air quality model specified in appendix W of this part
(Guideline on Air Quality Models) is inappropriate, the model may be
modified or another model substituted. Such a modification or
substitution of a model
[[Page 146]]
may be made on a case-by-case basis or, where appropriate, on a generic
basis for a specific State program. Written approval of the
Administrator must be obtained for any modification or substitution. In
addition, use of a modified or substituted model must be subject to
notice and opportunity for public comment under procedures set forth in
Sec. 51.102.
(b) The demonstration must include the following:
(1) A summary of the computations, assumptions, and judgments used
to determine the degree of reduction of emissions (or reductions in the
growth of emissions) that will result from the implementation of the
control strategy.
(2) A presentation of emission levels expected to result from
implementation of each measure of the control strategy.
(3) A presentation of the air quality levels expected to result from
implementation of the overall control strategy presented either in
tabular form or as an isopleth map showing expected maximum pollutant
concentrations.
(4) A description of the dispersion models used to project air
quality and to evaluate control strategies.
(5) For interstate regions, the analysis from each constituent State
must, where practicable, be based upon the same regional emission
inventory and air quality baseline.
[51 FR 40665, Nov. 7, 1986, as amended at 58 FR 38821, July 20, 1993; 60
FR 40468, Aug. 9, 1995; 61 FR 41840, Aug. 12, 1996]
Sec. 51.113 [Reserved]
Sec. 51.114 Emissions data and projections.
(a) Except for lead, each plan must contain a detailed inventory of
emissions from point and area sources. Lead requirements are specified
in Sec. 51.117. The inventory must be based upon measured emissions or,
where measured emissions are not available, documented emission factors.
(b) Each plan must contain a summary of emission levels projected to
result from application of the new control strategy.
(c) Each plan must identify the sources of the data used in the
projection of emissions.
Sec. 51.115 Air quality data and projections.
(a) Each plan must contain a summary of data showing existing air
quality.
(b) Each plan must:
(1) Contain a summary of air quality concentrations expected to
result from application of the control strategy, and
(2) Identify and describe the dispersion model, other air quality
model, or receptor model used.
(c) Actual measurements of air quality must be used where available
if made by methods specified in appendix C to part 58 of this chapter.
Estimated air quality using appropriate modeling techniques may be used
to supplement measurements.
(d) For purposes of developing a control strategy, background
concentration shall be taken into consideration with respect to
particulate matter. As used in this subpart, background concentration is
that portion of the measured ambient levels that cannot be reduced by
controlling emissions from man-made sources.
(e) In developing an ozone control strategy for a particular area,
background ozone concentrations and ozone transported into an area must
be considered. States may assume that the ozone standard will be
attained in upwind areas.
Sec. 51.116 Data availability.
(a) The State must retain all detailed data and calculations used in
the preparation of each plan or each plan revision, and make them
available for public inspection and submit them to the Administrator at
his request.
(b) The detailed data and calculations used in the preparation of
plan revisions are not considered a part of the plan.
(c) Each plan must provide for public availability of emission data
reported by source owners or operators or otherwise obtained by a State
or local agency. Such emission data must be correlated with applicable
emission limitations or other measures. As used in
[[Page 147]]
this paragraph, correlated means presented in such a manner as to show
the relationship between measured or estimated amounts of emissions and
the amounts of such emissions allowable under the applicable emission
limitations or other measures.
Sec. 51.117 Additional provisions for lead.
In addition to other requirements in Secs. 51.100 through 51.116 the
following requirements apply to lead. To the extent they conflict, there
requirements are controlling over those of the proceeding sections.
(a) Control strategy demonstration. Each plan must contain a
demonstration showing that the plan will attain and maintain the
standard in the following areas:
(1) Areas in the vicinity of the following point sources of lead:
Primary lead smelters, Secondary lead smelters, Primary copper smelters,
Lead gasoline additive plants, Lead-acid storage battery manufacturing
plants that produce 2,000 or more batteries per day. Any other
stationary source that actually emits 25 or more tons per year of lead
or lead compounds measured as elemental lead.
(2) Any other area that has lead air concentrations in excess of the
national ambient air quality standard concentration for lead, measured
since January 1, 1974.
(b) Time period for demonstration of adequacy. The demonstration of
adequacy of the control strategy required under Sec. 51.112 may cover a
longer period if allowed by the appropriate EPA Regional Administrator.
(c) Special modeling provisions. (1) For urbanized areas with
measured lead concentrations in excess of 4.0 [mu]g/m\3\, quarterly mean
measured since January 1, 1974, the plan must employ the modified
rollback model for the demonstration of attainment as a minimum, but may
use an atmospheric dispersion model if desired, consistent with
requirements contained in Sec. 51.112(a). If a proportional model is
used, the air quality data should be the same year as the emissions
inventory required under the paragraph e.
(2) For each point source listed in Sec. 51.117(a), that plan must
employ an atmospheric dispersion model for demonstration of attainment,
consistent with requirements contained in Sec. 51.112(a).
(3) For each area in the vicinity of an air quality monitor that has
recorded lead concentrations in excess of the lead national standard
concentration, the plan must employ the modified rollback model as a
minimum, but may use an atmospheric dispersion model if desired for the
demonstration of attainment, consistent with requirements contained in
Sec. 51.112(a).
(d) Air quality data and projections. (1) Each State must submit to
the appropriate EPA Regional Office with the plan, but not part of the
plan, all lead air quality data measured since January 1, 1974. This
requirement does not apply if the data has already been submitted.
(2) The data must be submitted in accordance with the procedures and
data forms specified in Chapter 3.4.0 of the ``AEROS User's Manual''
concerning storage and retrieval of aerometric data (SAROAD) except
where the Regional Administrator waives this requirement.
(3) If additional lead air quality data are desired to determine
lead air concentrations in areas suspected of exceeding the lead
national ambient air quality standard, the plan may include data from
any previously collected filters from particulate matter high volume
samplers. In determining the lead content of the filters for control
strategy demonstration purposes, a State may use, in addition to the
reference method, X-ray fluorescence or any other method approved by the
Regional Administrator.
(e) Emissions data. (1) The point source inventory on which the
summary of the baseline lead emissions inventory is based must contain
all sources that emit five or more tons of lead per year.
(2) Each State must submit lead emissions data to the appropriate
EPA Regional Office with the original plan. The submission must be made
with the plan, but not as part of the plan, and must include emissions
data and information related to point and area source emissions. The
emission data and information should include the
[[Page 148]]
information identified in the Hazardous and Trace Emissions System
(HATREMS) point source coding forms for all point sources and the area
source coding forms for all sources that are not point sources, but need
not necessarily be in the format of those forms.
[41 FR 18388, May 3, 1976, as amended at 58 FR 38822, July 20, 1993]
Sec. 51.118 Stack height provisions.
(a) The plan must provide that the degree of emission limitation
required of any source for control of any air pollutant must not be
affected by so much of any source's stack height that exceeds good
engineering practice or by any other dispersion technique, except as
provided in Sec. 51.118(b). The plan must provide that before a State
submits to EPA a new or revised emission limitation that is based on a
good engineering practice stack height that exceeds the height allowed
by Sec. 51.100(ii) (1) or (2), the State must notify the public of the
availabilty of the demonstration study and must provide opportunity for
a public hearing on it. This section does not require the plan to
restrict, in any manner, the actual stack height of any source.
(b) The provisions of Sec. 51.118(a) shall not apply to (1) stack
heights in existence, or dispersion techniques implemented on or before
December 31, 1970, except where pollutants are being emitted from such
stacks or using such dispersion techniques by sources, as defined in
section 111(a)(3) of the Clean Air Act, which were constructed, or
reconstructed, or for which major modifications, as defined in
Secs. 51.165(a)(1)(v)(A), 51.166(b)(2)(i) and 52.21(b)(2)(i), were
carried out after December 31, 1970; or (2) coal-fired steam electric
generating units subject to the provisions of section 118 of the Clean
Air Act, which commenced operation before July 1, 1957, and whose stacks
were construced under a construction contract awarded before February 8,
1974.
Sec. 51.119 Intermittent control systems.
(a) The use of an intermittent control system (ICS) may be taken
into account in establishing an emission limitation for a pollutant
under a State implementation plan, provided:
(1) The ICS was implemented before December 31, 1970, according to
the criteria specified in Sec. 51.119(b).
(2) The extent to which the ICS is taken into account is limited to
reflect emission levels and associated ambient pollutant concentrations
that would result if the ICS was the same as it was before December 31,
1970, and was operated as specified by the operating system of the ICS
before December 31, 1970.
(3) The plan allows the ICS to compensate only for emissions from a
source for which the ICS was implemented before December 31, 1970, and,
in the event the source has been modified, only to the extent the
emissions correspond to the maximum capacity of the source before
December 31, 1970. For purposes of this paragraph, a source for which
the ICS was implemented is any particular structure or equipment the
emissions from which were subject to the ICS operating procedures.
(4) The plan requires the continued operation of any constant
pollution control system which was in use before December 31, 1970, or
the equivalent of that system.
(5) The plan clearly defines the emission limits affected by the ICS
and the manner in which the ICS is taken into account in establishing
those limits.
(6) The plan contains requirements for the operation and maintenance
of the qualifying ICS which, together with the emission limitations and
any other necessary requirements, will assure that the national ambient
air quality standards and any applicable prevention of significant
deterioration increments will be attained and maintained. These
requirements shall include, but not necessarily be limited to, the
following:
(i) Requirements that a source owner or operator continuously
operate and maintain the components of the ICS specified at
Sec. 51.119(b)(3) (ii)-(iv) in a manner which assures that the ICS is
[[Page 149]]
at least as effective as it was before December 31, 1970. The air
quality monitors and meteorological instrumentation specified at
Sec. 51.119(b) may be operated by a local authority or other entity
provided the source has ready access to the data from the monitors and
instrumentation.
(ii) Requirements which specify the circumstances under which, the
extent to which, and the procedures through which, emissions shall be
curtailed through the activation of ICS.
(iii) Requirements for recordkeeping which require the owner or
operator of the source to keep, for periods of at least 3 years, records
of measured ambient air quality data, meteorological information
acquired, and production data relating to those processes affected by
the ICS.
(iv) Requirements for reporting which require the owner or operator
of the source to notify the State and EPA within 30 days of a NAAQS
violation pertaining to the pollutant affected by the ICS.
(7) Nothing in this paragraph affects the applicability of any new
source review requirements or new source performance standards contained
in the Clean Air Act or 40 CFR subchapter C. Nothing in this paragraph
precludes a State from taking an ICS into account in establishing
emission limitations to any extent less than permitted by this
paragraph.
(b) An intermittent control system (ICS) may be considered
implemented for a pollutant before December 31, 1970, if the following
criteria are met:
(1) The ICS must have been established and operational with respect
to that pollutant prior to December 31, 1970, and reductions in
emissions of that pollutant must have occurred when warranted by
meteorological and ambient monitoring data.
(2) The ICS must have been designed and operated to meet an air
quality objective for that pollutant such as an air quality level or
standard.
(3) The ICS must, at a minimum, have included the following
components prior to December 31, 1970:
(i) Air quality monitors. An array of sampling stations whose
location and type were consistent with the air quality objective and
operation of the system.
(ii) Meteorological instrumentation. A meteorological data
acquisition network (may be limited to a single station) which provided
meteorological prediction capabilities sufficient to determine the need
for, and degree of, emission curtailments necessary to achieve the air
quality design objective.
(iii) Operating system. A system of established procedures for
determining the need for curtailments and for accomplishing such
curtailments. Documentation of this system, as required by paragraph
(n)(4), may consist of a compendium of memoranda or comparable material
which define the criteria and procedures for curtailments and which
identify the type and number of personnel authorized to initiate
curtailments.
(iv) Meteorologist. A person, schooled in meteorology, capable of
interpreting data obtained from the meteorological network and qualified
to forecast meteorological incidents and their effect on ambient air
quality. Sources may have obtained meteorological services through a
consultant. Services of such a consultant could include sufficient
training of source personnel for certain operational procedures, but not
for design, of the ICS.
(4) Documentation sufficient to support the claim that the ICS met
the criteria listed in this paragraph must be provided. Such
documentation may include affidavits or other documentation.
Sec. 51.120 Requirements for State Implementation Plan revisions relating
to new motor vehicles.
(a) The EPA Administrator finds that the State Implementation Plans
(SIPs) for the States of Connecticut, Delaware, Maine, Maryland,
Massachusetts, New Hampshire, New Jersey, New York, Pennsylvania, Rhode
Island, and Vermont, the portion of Virginia included (as of November
15, 1990) within the Consolidated Metropolitan Statistical Area that
includes the District of Columbia, are substantially inadequate to
comply with the requirements of section 110(a)(2)(D) of the Clean Air
[[Page 150]]
Act, 42 U.S.C. 7410(a)(2)(D), and to mitigate adequately the interstate
pollutant transport described in section 184 of the Clean Air Act, 42
U.S.C. 7511C, to the extent that they do not provide for emission
reductions from new motor vehicles in the amount that would be achieved
by the Ozone Transport Commission low emission vehicle (OTC LEV) program
described in paragraph (c) of this section. This inadequacy will be
deemed cured for each of the aforementioned States (including the
District of Columbia) in the event that EPA determines through
rulemaking that a national LEV-equivalent new motor vehicle emission
control program is an acceptable alternative for OTC LEV and finds that
such program is in effect. In the event no such finding is made, each of
those States must adopt and submit to EPA by February 15, 1996 a SIP
revision meeting the requirements of paragraph (b) of this section in
order to cure the SIP inadequacy.
(b) If a SIP revision is required under paragraph (a) of this
section, it must contain the OTC LEV program described in paragraph (c)
of this section unless the State adopts and submits to EPA, as a SIP
revision, other emission-reduction measures sufficient to meet the
requirements of paragraph (d) of this section. If a State adopts and
submits to EPA, as a SIP revision, other emission-reduction measures
pursuant to paragraph (d) of this section, then for purposes of
determining whether such a SIP revision is complete within the meaning
of section 110(k)(1) (and hence is eligible at least for consideration
to be approved as satisfying paragraph (d) of this section), such a SIP
revision must contain other adopted emission-reduction measures that,
together with the identified potentially broadly practicable measures,
achieve at least the minimum level of emission reductions that could
potentially satisfy the requirements of paragraph (d) of this section.
All such measures must be fully adopted and enforceable.
(c) The OTC LEV program is a program adopted pursuant to section 177
of the Clean Air Act.
(1) The OTC LEV program shall contain the following elements:
(i) It shall apply to all new 1999 and later model year passenger
cars and light-duty trucks (0-5750 pounds loaded vehicle weight), as
defined in Title 13, California Code of Regulations, section 1900(b)(11)
and (b)(8), respectively, that are sold, imported, delivered, purchased,
leased, rented, acquired, received, or registered in any area of the
State that is in the Northeast Ozone Transport Region as of December 19,
1994.
(ii) All vehicles to which the OTC LEV program is applicable shall
be required to have a certificate from the California Air Resources
Board (CARB) affirming compliance with California standards.
(iii) All vehicles to which this LEV program is applicable shall be
required to meet the mass emission standards for Non-Methane Organic
Gases (NMOG), Carbon Monoxide (CO), Oxides of Nitrogen (NOX),
Formaldehyde (HCHO), and particulate matter (PM) as specified in Title
13, California Code of Regulations, section 1960.1(f)(2) (and
formaldehyde standards under section 1960.1(e)(2), as applicable) or as
specified by California for certification as a TLEV (Transitional Low-
Emission Vehicle), LEV (Low-Emission Vehicle), ULEV (Ultra-Low-Emission
Vehicle), or ZEV (Zero-Emission Vehicle) under section 1960.1(g)(1) (and
section 1960.1(e)(3), for formaldehyde standards, as applicable).
(iv) All manufacturers of vehicles subject to the OTC LEV program
shall be required to meet the fleet average NMOG exhaust emission values
for production and delivery for sale of their passenger cars, light-duty
trucks 0-3750 pounds loaded vehicle weight, and light-duty trucks 3751-
5750 pounds loaded vehicle weight specified in Title 13, California Code
of Regulations, section 1960.1(g)(2) for each model year beginning in
1999. A State may determine not to implement the NMOG fleet average in
the first model year of the program if the State begins implementation
of the program late in a calendar year. However, all States must
implement the NMOG fleet average in any full model years of the LEV
program.
(v) All manufacturers shall be allowed to average, bank and trade
credits in the same manner as allowed
[[Page 151]]
under the program specified in Title 13, California Code of Regulations,
section 1960.1(g)(2) footnote 7 for each model year beginning in 1999.
States may account for credits banked by manufacturers in California or
New York in years immediately preceding model year 1999, in a manner
consistent with California banking and discounting procedures.
(vi) The provisions for small volume manufacturers and intermediate
volume manufacturers, as applied by Title 13, California Code of
Regulations to California's LEV program, shall apply. Those
manufacturers defined as small volume manufacturers and intermediate
volume manufacturers in California under California's regulations shall
be considered small volume manufacturers and intermediate volume
manufacturers under this program.
(vii) The provisions for hybrid electric vehicles (HEVs), as defined
in Title 13 California Code of Regulations, section 1960.1, shall apply
for purposes of calculating fleet average NMOG values.
(viii) The provisions for fuel-flexible vehicles and dual-fuel
vehicles specified in Title 13, California Code of Regulations, section
1960.1(g)(1) footnote 4 shall apply.
(ix) The provisions for reactivity adjustment factors, as defined by
Title 13, California Code of Regulations, shall apply.
(x) The aforementioned State OTC LEV standards shall be identical to
the aforementioned California standards as such standards exist on
December 19, 1994.
(xi) All States' OTC LEV programs must contain any other provisions
of California's LEV program specified in Title 13, California Code of
Regulations necessary to comply with section 177 of the Clean Air Act.
(2) States are not required to include the mandate for production of
ZEVs specified in Title 13, California Code of Regulations, section
1960.1(g)(2) footnote 9.
(3) Except as specified elsewhere in this section, States may
implement the OTC LEV program in any manner consistent with the Act that
does not decrease the emissions reductions or jeopardize the
effectiveness of the program.
(d) The SIP revision that paragraph (b) of this section describes as
an alternative to the OTC LEV program described in paragraph (c) of this
section must contain a set of State-adopted measures that provides at
least the following amount of emission reductions in time to bring
serious ozone nonattainment areas into attainment by their 1999
attainment date:
(1) Reductions at least equal to the difference between:
(i) The nitrogen oxides (NOX) emission reductions from
the 1990 statewide emissions inventory achievable through implementation
of all of the Clean Air Act-mandated and potentially broadly practicable
control measures throughout all portions of the State that are within
the Northeast Ozone Transport Region created under section 184(a) of the
Clean Air Act as of December 19, 1994; and
(ii) A reduction in NOX emissions from the 1990 statewide
inventory in such portions of the State of 50% or whatever greater
reduction is necessary to prevent significant contribution to
nonattainment in, or interference with maintenance by, any downwind
State.
(2) Reductions at least equal to the difference between:
(i) The VOC emission reductions from the 1990 statewide emissions
inventory achievable through implementation of all of the Clean Air Act-
mandated and potentially broadly practicable control measures in all
portions of the State in, or near and upwind of, any of the serious or
severe ozone nonattainment areas lying in the series of such areas
running northeast from the Washington, DC, ozone nonattainment area to
and including the Portsmouth, New Hampshire ozone nonattainment area;
and
(ii) A reduction in VOC emissions from the 1990 emissions inventory
in all such areas of 50% or whatever greater reduction is necessary to
prevent significant contribution to nonattainment in, or interference
with maintenance by, any downwind State.
[60 FR 4736, Jan. 24, 1995]
[[Page 152]]
Sec. 51.121 Findings and requirements for submission of State implementation
plan revisions relating to emissions of oxides of nitrogen.
(a)(1) The Administrator finds that the State implementation plan
(SIP) for each jurisdiction listed in paragraph (c) of this section is
substantially inadequate to comply with the requirements of section
110(a)(2)(D)(i)(I) of the Clean Air Act (CAA), 42 U.S.C.
7410(a)(2)(D)(i)(I), because the SIP does not include adequate
provisions to prohibit sources and other activities from emitting
nitrogen oxides (``NOX'') in amounts that will contribute
significantly to nonattainment in one or more other States with respect
to the 1-hour ozone national ambient air quality standards (NAAQS). Each
of the jurisdictions listed in paragraph (c) of this section must submit
to EPA a SIP revision that cures the inadequacy.
(2) Under section 110(a)(1) of the CAA, 42 U.S.C. 7410(a)(1), the
Administrator determines that each jurisdiction listed in paragraph (c)
of this section must submit a SIP revision to comply with the
requirements of section 110(a)(2)(D)(i)(I), 42 U.S.C.
7410(a)(2)(D)(i)(I), through the adoption of adequate provisions
prohibiting sources and other activities from emitting NOX in
amounts that will contribute significantly to nonattainment in, or
interfere with maintenance by, one or more other States with respect to
the 8-hour ozone NAAQS.
(b)(1) For each jurisdiction listed in paragraph (c) of this
section, the SIP revision required under paragraph (a) of this section
will contain adequate provisions, for purposes of complying with section
110(a)(2)(D)(i)(I) of the CAA, 42 U.S.C. 7410(a)(2)(D)(i)(I), only if
the SIP revision:
(i) Contains control measures adequate to prohibit emissions of
NOX that would otherwise be projected, in accordance with
paragraph (g) of this section, to cause the jurisdiction's overall
NOX emissions to be in excess of the budget for that
jurisdiction described in paragraph (e) of this section (except as
provided in paragraph (b)(2) of this section),
(ii) Requires full implementation of all such control measures by no
later than May 1, 2003, and
(iii) Meets the other requirements of this section. The SIP
revision's compliance with the requirement of paragraph (b)(1)(i) of
this section shall be considered compliance with the jurisdiction's
budget for purposes of this section.
(2) The requirements of paragraph (b)(1)(i) of this section shall be
deemed satisfied, for the portion of the budget covered by an interstate
trading program, if the SIP revision:
(i) Contains provisions for an interstate trading program that EPA
determines will, in conjunction with interstate trading programs for one
or more other jurisdictions, prohibit NOX emissions in excess
of the sum of the portion of the budgets covered by the trading programs
for those jurisdictions; and
(ii) Conforms to the following criteria:
(A) Emissions reductions used to demonstrate compliance with the
revision must occur during the ozone season.
(B) Emissions reductions occurring prior to the year 2003 may be
used by a source to demonstrate compliance with the SIP revision for the
2003 and 2004 ozone seasons, provided the SIP's provisions regarding
such use comply with the requirements of paragraph (e)(3) of this
section.
(C) Emissions reduction credits or emissions allowances held by a
source or other person following the 2003 ozone season or any ozone
season thereafter that are not required to demonstrate compliance with
the SIP for the relevant ozone season may be banked and used to
demonstrate compliance with the SIP in a subsequent ozone season.
(D) Early reductions created according to the provisions in
paragraph (b)(2)(ii)(B) of this section and used in the 2003 ozone
season are not subject to the flow control provisions set forth in
paragraph (b)(2)(ii)(E) of this section.
(E) Starting with the 2004 ozone season, the SIP shall include
provisions to limit the use of banked emissions reduction credits or
emissions allowances
[[Page 153]]
beyond a predetermined amount as calculated by one of the following
approaches:
(1) Following the determination of compliance after each ozone
season, if the total number of emissions reduction credits or banked
allowances held by sources or other persons subject to the trading
program exceeds 10 percent of the sum of the allowable ozone season
NOX emissions for all sources subject to the trading program,
then all banked allowances used for compliance for the following ozone
season shall be subject to the following:
(i) A ratio will be established according to the following formula:
(0.10) x (the sum of the allowable ozone season NOX emissions
for all sources subject to the trading program) / (the total number of
banked emissions reduction credits or emissions allowances held by all
sources or other persons subject to the trading program).
(ii) The ratio, determined using the formula specified in paragraph
(b)(2)(ii)(E)(1)(i) of this section, will be multiplied by the number of
banked emissions reduction credits or emissions allowances held in each
account at the time of compliance determination. The resulting product
is the number of banked emissions reduction credits or emissions
allowances in the account which can be used in the current year's ozone
season at a rate of 1 credit or allowance for every 1 ton of emissions.
The SIP shall specify that banked emissions reduction credits or
emissions allowances in excess of the resulting product either may not
be used for compliance, or may only be used for compliance at a rate no
less than 2 credits or allowances for every 1 ton of emissions.
(2) At the time of compliance determination for each ozone season,
if the total number of banked emissions reduction credits or emissions
allowances held by a source subject to the trading program exceeds 10
percent of the source's allowable ozone season NOX emissions,
all banked emissions reduction credits or emissions allowances used for
compliance in such ozone season by the source shall be subject to the
following:
(i) The source may use an amount of banked emissions reduction
credits or emissions allowances not greater than 10 percent of the
source's allowable ozone season NOX emissions for compliance
at a rate of 1 credit or allowance for every 1 ton of emissions.
(ii) The SIP shall specify that banked emissions reduction credits
or emissions allowances in excess of 10 percent of the source's
allowable ozone season NOX emissions may not be used for
compliance, or may only be used for compliance at a rate no less than 2
credits or allowances for every 1 ton of emissions.
(c) The following jurisdictions (hereinafter referred to as
``States'') are subject to the requirements of this section: Alabama,
Connecticut, Delaware, Georgia, Illinois, Indiana, Kentucky, Maryland,
Massachusetts, Michigan, Missouri, New Jersey, New York, North Carolina,
Ohio, Pennsylvania, Rhode Island, South Carolina, Tennessee, Virginia,
West Virginia, Wisconsin, and the District of Columbia.
(d)(1) The SIP submissions required under paragraph (a) of this
section must be submitted to EPA by no later than September 30, 1999.
(2) The State makes an official submission of its SIP revision to
EPA only when:
(i) The submission conforms to the requirements of appendix V to
this part; and
(ii) The State delivers five copies of the plan to the appropriate
Regional Office, with a letter giving notice of such action.
(e)(1) The NOX budget for a State listed in paragraph (c)
of this section is defined as the total amount of NOX
emissions from all sources in that State, as indicated in paragraph
(e)(2) of this section with respect to that State, which the State must
demonstrate that it will not exceed in the 2007 ozone season pursuant to
paragraph (g)(1) of this section.
(2) The State-by-State amounts of the NOX budget,
expressed in tons per ozone season, are as follows:
------------------------------------------------------------------------
State Budget
------------------------------------------------------------------------
Alabama.................................................... 172,619
Connecticut................................................ 42,849
Delaware................................................... 22,861
District of Columbia....................................... 6,658
Georgia.................................................... 188,572
Illinois................................................... 270,560
Indiana.................................................... 229,965
[[Page 154]]
Kentucky................................................... 162,272
Maryland................................................... 81,898
Massachusetts.............................................. 84,848
Michigan................................................... 229,702
Missouri................................................... 125,603
New Jersey................................................. 96,876
New York................................................... 240,288
North Carolina............................................. 165,022
Ohio....................................................... 249,274
Pennsylvania............................................... 257,592
Rhode Island............................................... 9,378
South Carolina............................................. 123,105
Tennessee.................................................. 198,045
Virginia................................................... 180,195
West Virginia.............................................. 83,833
Wisconsin.................................................. 135,771
------------
Total.................................................. 3,357,786
------------------------------------------------------------------------
(3)(i) Notwithstanding the State's obligation to comply with the
budgets set forth in paragraph (e)(2) of this section, a SIP revision
may allow sources required by the revision to implement NOX
emission control measures by May 1, 2003 to demonstrate compliance in
the 2003 and 2004 ozone seasons using credit issued from the State's
compliance supplement pool, as set forth in paragraph (e)(3)(iii) of
this section.
(ii) A source may not use credit from the compliance supplement pool
to demonstrate compliance after the 2004 ozone season.
(iii) The State-by-State amounts of the compliance supplement pool
are as follows:
------------------------------------------------------------------------
Compliance
supplement
State pool (tons
of NOX)
------------------------------------------------------------------------
Alabama.................................................... 11,687
Connecticut................................................ 569
Delaware................................................... 168
District of Columbia....................................... 0
Georgia.................................................... 11,440
Illinois................................................... 17,688
Indiana.................................................... 19,915
Kentucky................................................... 13,520
Maryland................................................... 3,882
Massachusetts.............................................. 404
Michigan................................................... 11,356
Missouri................................................... 11,199
New Jersey................................................. 1,550
New York................................................... 2,764
North Carolina............................................. 10,737
Ohio....................................................... 22,301
Pennsylvania............................................... 15,763
Rhode Island............................................... 15
South Carolina............................................. 5,344
Tennessee.................................................. 10,565
Virginia................................................... 5,504
West Virginia.............................................. 16,709
Wisconsin.................................................. 6,920
------------
Total.................................................. 200,000
------------------------------------------------------------------------
(iv) The SIP revision may provide for the distribution of the
compliance supplement pool to sources that are required to implement
control measures using one or both of the following two mechanisms:
(A) The State may issue some or all of the compliance supplement
pool to sources that implement emissions reductions during the ozone
season beyond all applicable requirements in years prior to the year
2003 according to the following provisions:
(1) The State shall complete the issuance process by no later than
May 1, 2003.
(2) The emissions reduction may not be required by the State's SIP
or be otherwise required by the CAA.
(3) The emissions reduction must be verified by the source as
actually having occurred during an ozone season between September 30,
1999 and May 1, 2003.
(4) The emissions reduction must be quantified according to
procedures set forth in the SIP revision and approved by EPA. Emissions
reductions implemented by sources serving electric generators with a
nameplate capacity greater than 25 MWe, or boilers, combustion turbines
or combined cycle units with a maximum design heat input greater than
250 mmBtu/hr, must be quantified according to the requirements in
paragraph (i)(4) of this section.
(5) If the SIP revision contains approved provisions for an
emissions trading program, sources that receive credit according to the
requirements of this paragraph may trade the credit to other sources or
persons according to the provisions in the trading program.
(B) The State may issue some or all of the compliance supplement
pool to sources that demonstrate a need for an extension of the May 1,
2003 compliance deadline according to the following provisions:
(1) The State shall initiate the issuance process by the later date
of September 30, 2002 or after the State issues credit according to the
procedures in paragraph (e)(3)(iv)(A) of this section.
(2) The State shall complete the issuance process by no later than
May 1, 2003.
[[Page 155]]
(3) The State shall issue credit to a source only if the source
demonstrates the following:
(i) For a source used to generate electricity, compliance with the
SIP revision's applicable control measures by May 1, 2003, would create
undue risk for the reliability of the electricity supply. This
demonstration must include a showing that it would not be feasible to
import electricity from other electricity generation systems during the
installation of control technologies necessary to comply with the SIP
revision.
(ii) For a source not used to generate electricity, compliance with
the SIP revision's applicable control measures by May 1, 2003, would
create undue risk for the source or its associated industry to a degree
that is comparable to the risk described in paragraph
(e)(3)(iv)(B)(3)(i) of this section.
(iii) For a source subject to an approved SIP revision that allows
for early reduction credits in accordance with paragraph (e)(3)(iv)(A)
of this section, it was not possible for the source to comply with
applicable control measures by generating early reduction credits or
acquiring early reduction credits from other sources.
(iv) For a source subject to an approved emissions trading program,
it was not possible to comply with applicable control measures by
acquiring sufficient credit from other sources or persons subject to the
emissions trading program.
(4) The State shall ensure the public an opportunity, through a
public hearing process, to comment on the appropriateness of allocating
compliance supplement pool credits to a source under paragraph
(e)(3)(iv)(B) of this section.
(4) If, no later than February 22, 1999, any member of the public
requests revisions to the source-specific data and vehicle miles
traveled (VMT) and nonroad mobile growth rates, VMT distribution by
vehicle class, average speed by roadway type, inspection and maintenance
program parameters, and other input parameters used to establish the
State budgets set forth in paragraph (e)(2) of this section or the 2007
baseline sub-inventory information set forth in paragraph (g)(2)(ii) of
this section, then EPA will act on that request no later than April 23,
1999 provided:
(i) The request is submitted in electronic format;
(ii) Information is provided to corroborate and justify the need for
the requested modification;
(iii) The request includes the following data information regarding
any electricity-generating source at issue:
(A) Federal Information Placement System (FIPS) State Code;
(B) FIPS County Code;
(C) Plant name;
(D) Plant ID numbers (ORIS code preferred, State agency tracking
number also or otherwise);
(E) Unit ID numbers (a unit is a boiler or other combustion device);
(F) Unit type;
(G) Primary fuel on a heat input basis;
(H) Maximum rated heat input capacity of unit;
(I) Nameplate capacity of the largest generator the unit serves;
(J) Ozone season heat inputs for the years 1995 and 1996;
(K) 1996 (or most recent) average NOX rate for the ozone
season;
(L) Latitude and longitude coordinates;
(M) Stack parameter information ;
(N) Operating parameter information;
(O) Identification of specific change to the inventory; and
(P) Reason for the change;
(iv) The request includes the following data information regarding
any non-electricity generating point source at issue:
(A) FIPS State Code;
(B) FIPS County Code;
(C) Plant name;
(D) Facility primary standard industrial classification code (SIC);
(E) Plant ID numbers (NEDS, AIRS/AFS, and State agency tracking
number also or otherwise);
(F) Unit ID numbers (a unit is a boiler or other combustion device);
(G) Primary source classification code (SCC);
(H) Maximum rated heat input capacity of unit;
(I) 1995 ozone season or typical ozone season daily NOX
emissions;
[[Page 156]]
(J) 1995 existing NOX control efficiency;
(K) Latitude and longitude coordinates;
(L) Stack parameter information;
(M) Operating parameter information;
(N) Identification of specific change to the inventory; and
(O) Reason for the change;
(v) The request includes the following data information regarding
any stationary area source or nonroad mobile source at issue:
(A) FIPS State Code;
(B) FIPS County Code;
(C) Primary source classification code (SCC);
(D) 1995 ozone season or typical ozone season daily NOX
emissions;
(E) 1995 existing NOX control efficiency;
(F) Identification of specific change to the inventory; and
(G) Reason for the change;
(vi) The request includes the following data information regarding
any highway mobile source at issue:
(A) FIPS State Code;
(B) FIPS County Code;
(C) Primary source classification code (SCC) or vehicle type;
(D) 1995 ozone season or typical ozone season daily vehicle miles
traveled (VMT);
(E) 1995 existing NOX control programs;
(F) identification of specific change to the inventory; and
(G) reason for the change.
(f) Each SIP revision must set forth control measures to meet the
NOX budget in accordance with paragraph (b)(1)(i) of this
section, which include the following:
(1) A description of enforcement methods including, but not limited
to:
(i) Procedures for monitoring compliance with each of the selected
control measures;
(ii) Procedures for handling violations; and
(iii) A designation of agency responsibility for enforcement of
implementation.
(2) Should a State elect to impose control measures on fossil fuel-
fired NOX sources serving electric generators with a
nameplate capacity greater than 25 MWe or boilers, combustion turbines
or combined cycle units with a maximum design heat input greater than
250 mmBtu/hr as a means of meeting its NOX budget, then those
measures must:
(i)(A) Impose a NOX mass emissions cap on each source;
(B) Impose a NOX emissions rate limit on each source and
assume maximum operating capacity for every such source for purposes of
estimating mass NOX emissions; or
(C) Impose any other regulatory requirement which the State has
demonstrated to EPA provides equivalent or greater assurance than
options in paragraphs (f)(2)(i)(A) or (f)(2)(i)(B) of this section that
the State will comply with its NOX budget in the 2007 ozone
season; and
(ii) Impose enforceable mechanisms, in accordance with paragraphs
(b)(1) (i) and (ii) of this section, to assure that collectively all
such sources, including new or modified units, will not exceed in the
2007 ozone season the total NOX emissions projected for such
sources by the State pursuant to paragraph (g) of this section.
(3) For purposes of paragraph (f)(2) of this section, the term
``fossil fuel-fired'' means, with regard to a NOX source:
(i) The combustion of fossil fuel, alone or in combination with any
other fuel, where fossil fuel actually combusted comprises more than 50
percent of the annual heat input on a Btu basis during any year starting
in 1995 or, if a NOX source had no heat input starting in
1995, during the last year of operation of the NOX source
prior to 1995; or
(ii) The combustion of fossil fuel, alone or in combination with any
other fuel, where fossil fuel is projected to comprise more than 50
percent of the annual heat input on a Btu basis during any year;
provided that the NOX source shall be ``fossil fuel-fired''
as of the date, during such year, on which the NOX source
begins combusting fossil fuel.
(g)(1) Each SIP revision must demonstrate that the control measures
contained in it are adequate to provide for the timely compliance with
the State's NOX budget during the 2007 ozone season.
[[Page 157]]
(2) The demonstration must include the following:
(i) Each revision must contain a detailed baseline inventory of
NOX mass emissions from the following sources in the year
2007, absent the control measures specified in the SIP submission:
electric generating units (EGU), non-electric generating units (non-
EGU), area, nonroad and highway sources. The State must use the same
baseline emissions inventory that EPA used in calculating the State's
NOX budget, as set forth for the State in paragraph
(g)(2)(ii) of this section, except that EPA may direct the State to use
different baseline inventory information if the State fails to certify
that it has implemented all of the control measures assumed in
developing the baseline inventory.
(ii) The revised NOX emissions sub-inventories for each
State, expressed in tons per ozone season, are as follows:
----------------------------------------------------------------------------------------------------------------
State EGU Non-EGU Area Nonroad Highway Total
----------------------------------------------------------------------------------------------------------------
Alabama....................................... 29,022 43,415 28,762 20,146 51,274 172,619
Connecticut................................... 2,652 5,216 4,821 10,736 19,424 42,849
Delaware...................................... 5,250 2,473 1,129 5,651 8,358 22,861
District of Columbia.......................... 207 282 830 3,135 2,204 6,658
Georgia....................................... 30,402 29,716 13,212 26,467 88,775 188,572
Illinois...................................... 32,372 59,577 9,369 56,724 112,518 270,560
Indiana....................................... 47,731 47,363 29,070 26,494 79,307 229,965
Kentucky...................................... 36,503 25,669 31,807 15,025 53,268 162,272
Maryland...................................... 14,656 12,585 4,448 20,026 30,183 81,898
Massachusetts................................. 15,146 10,298 11,048 20,166 28,190 84,848
Michigan...................................... 32,228 60,055 31,721 26,935 78,763 229,702
Missouri...................................... 24,216 21,602 7,341 20,829 51,615 125,603
New Jersey.................................... 10,250 15,464 12,431 23,565 35,166 96,876
New York...................................... 31,036 25,477 17,423 42,091 124,261 240,288
North Carolina................................ 31,821 26,434 11,067 22,005 73,695 165,022
Ohio.......................................... 48,990 40,194 21,860 43,380 94,850 249,274
Pennsylvania.................................. 47,469 70,132 17,842 30,571 91,578 257,592
Rhode Island.................................. 997 1,635 448 2,455 3,843 9,378
South Carolina................................ 16,772 27,787 9,415 14,637 54,494 123,105
Tennessee..................................... 25,814 39,636 13,333 52,920 66,342 198,045
Virginia...................................... 17,187 35,216 27,738 27,859 72,195 180,195
West Virginia................................. 26,859 20,238 5,459 10,433 20,844 83,833
Wisconsin..................................... 17,381 19,853 11,253 17,965 69,319 135,771
-----------------------------------------------------------------
Total..................................... 544,961 640,317 321,827 540,215 1,310,466 3,357,786
----------------------------------------------------------------------------------------------------------------
Note to paragraph (g)(2)(ii): Totals may not sum due to rounding.
(iii) Each revision must contain a summary of NOX mass
emissions in 2007 projected to result from implementation of each of the
control measures specified in the SIP submission and from all
NOX sources together following implementation of all such
control measures, compared to the baseline 2007 NOX emissions
inventory for the State described in paragraph (g)(2)(i) of this
section. The State must provide EPA with a summary of the computations,
assumptions, and judgments used to determine the degree of reduction in
projected 2007 NOX emissions that will be achieved from the
implementation of the new control measures compared to the baseline
emissions inventory.
(iv) Each revision must identify the sources of the data used in the
projection of emissions.
(h) Each revision must comply with Sec. 51.116 of this part
(regarding data availability).
(i) Each revision must provide for monitoring the status of
compliance with any control measures adopted to meet the NOX
budget. Specifically, the revision must meet the following requirements:
(1) The revision must provide for legally enforceable procedures for
requiring owners or operators of stationary sources to maintain records
of and periodically report to the State:
(i) Information on the amount of NOX emissions from the
stationary sources; and
[[Page 158]]
(ii) Other information as may be necessary to enable the State to
determine whether the sources are in compliance with applicable portions
of the control measures;
(2) The revision must comply with Sec. 51.212 of this part
(regarding testing, inspection, enforcement, and complaints);
(3) If the revision contains any transportation control measures,
then the revision must comply with Sec. 51.213 of this part (regarding
transportation control measures);
(4) If the revision contains measures to control fossil fuel-fired
NOX sources serving electric generators with a nameplate
capacity greater than 25 MWe or boilers, combustion turbines or combined
cycle units with a maximum design heat input greater than 250 mmBtu/hr,
then the revision must require such sources to comply with the
monitoring provisions of part 75, subpart H.
(5) For purposes of paragraph (i)(4) of this section, the term
``fossil fuel-fired'' means, with regard to a NOX source:
(i) The combustion of fossil fuel, alone or in combination with any
other fuel, where fossil fuel actually combusted comprises more than 50
percent of the annual heat input on a Btu basis during any year starting
in 1995 or, if a NOX source had no heat input starting in
1995, during the last year of operation of the NOX source
prior to 1995; or
(ii) The combustion of fossil fuel, alone or in combination with any
other fuel, where fossil fuel is projected to comprise more than 50
percent of the annual heat input on a Btu basis during any year,
provided that the NOX source shall be ``fossil fuel-fired''
as of the date, during such year, on which the NOX source
begins combusting fossil fuel.
(j) Each revision must show that the State has legal authority to
carry out the revision, including authority to:
(1) Adopt emissions standards and limitations and any other measures
necessary for attainment and maintenance of the State's NOX
budget specified in paragraph (e) of this section;
(2) Enforce applicable laws, regulations, and standards, and seek
injunctive relief;
(3) Obtain information necessary to determine whether air pollution
sources are in compliance with applicable laws, regulations, and
standards, including authority to require recordkeeping and to make
inspections and conduct tests of air pollution sources;
(4) Require owners or operators of stationary sources to install,
maintain, and use emissions monitoring devices and to make periodic
reports to the State on the nature and amounts of emissions from such
stationary sources; also authority for the State to make such data
available to the public as reported and as correlated with any
applicable emissions standards or limitations.
(k)(1) The provisions of law or regulation which the State
determines provide the authorities required under this section must be
specifically identified, and copies of such laws or regulations must be
submitted with the SIP revision.
(2) Legal authority adequate to fulfill the requirements of
paragraphs (j)(3) and (4) of this section may be delegated to the State
under section 114 of the CAA.
(l)(1) A revision may assign legal authority to local agencies in
accordance with Sec. 51.232 of this part.
(2) Each revision must comply with Sec. 51.240 of this part
(regarding general plan requirements).
(m) Each revision must comply with Sec. 51.280 of this part
(regarding resources).
(n) For purposes of the SIP revisions required by this section, EPA
may make a finding as applicable under section 179(a)(1)-(4) of the CAA,
42 U.S.C. 7509(a)(1)-(4), starting the sanctions process set forth in
section 179(a) of the CAA. Any such finding will be deemed a finding
under Sec. 52.31(c) of this part and sanctions will be imposed in
accordance with the order of sanctions and the terms for such sanctions
established in Sec. 52.31 of this part.
(o) Each revision must provide for State compliance with the
reporting requirements set forth in Sec. 51.122 of this part.
(p)(1) Notwithstanding any other provision of this section, if a
State adopts regulations substantively identical to 40 CFR part 96 (the
model NOX budget
[[Page 159]]
trading program for SIPs), incorporates such part by reference into its
regulations, or adopts regulations that differ substantively from such
part only as set forth in paragraph (p)(2) of this section, then that
portion of the State's SIP revision is automatically approved as
satisfying the same portion of the State's NOX emission
reduction obligations as the State projects such regulations will
satisfy, provided that:
(i) The State has the legal authority to take such action and to
implement its responsibilities under such regulations, and
(ii) The SIP revision accurately reflects the NOX
emissions reductions to be expected from the State's implementation of
such regulations.
(2) If a State adopts an emissions trading program that differs
substantively from 40 CFR part 96 in only the following respects, then
such portion of the State's SIP revision is approved as set forth in
paragraph (p)(1) of this section:
(i) The State may expand the applicability provisions of the trading
program to include units (as defined in 40 CFR 96.2) that are smaller
than the size criteria thresholds set forth in 40 CFR 96.4(a);
(ii) The State may decline to adopt the exemption provisions set
forth in 40 CFR 96.4(b);
(iii) The State may decline to adopt the opt-in provisions set forth
in subpart I of 40 CFR part 96;
(iv) The State may decline to adopt the allocation provisions set
forth in subpart E of 40 CFR part 96 and may instead adopt any
methodology for allocating NOX allowances to individual
sources, provided that:
(A) The State's methodology does not allow the State to allocate
NOX allowances in excess of the total amount of
NOX emissions which the State has assigned to its trading
program; and
(B) The State's methodology conforms with the timing requirements
for submission of allocations to the Administrator set forth in 40 CFR
96.41; and
(v) The State may decline to adopt the early reduction credit
provisions set forth in 40 CFR 96.55(c) and may instead adopt any
methodology for issuing credit from the State's compliance supplement
pool that complies with paragraph (e)(3) of this section.
(3) If a State adopts an emissions trading program that differs
substantively from 40 CFR part 96 other than as set forth in paragraph
(p)(2) of this section, then such portion of the State's SIP revision is
not automatically approved as set forth in paragraph (p)(1) of this
section but will be reviewed by the Administrator for approvability in
accordance with the other provisions of this section.
(q) Stay of Findings of Significant Contribution with respect to the
8-hour standard. Notwithstanding any other provisions of this subpart,
the effectiveness of paragraph (a)(2) of this section is stayed.
[63 FR 57491, Oct. 27, 1998, as amended at 63 FR 71225, Dec. 24, 1998;
64 FR 26305, May 14, 1999; 65 FR 11230, Mar. 2, 2000; 65 FR 56251, Sept.
18, 2000]
Sec. 51.122 Emissions reporting requirements for SIP revisions relating
to budgets for NOX emissions.
(a) For its transport SIP revision under Sec. 51.121 of this part,
each State must submit to EPA NOX emissions data as described
in this section.
(b) Each revision must provide for periodic reporting by the State
of NOX emissions data to demonstrate whether the State's
emissions are consistent with the projections contained in its approved
SIP submission.
(1) Annual reporting. Each revision must provide for annual
reporting of NOX emissions data as follows:
(i) The State must report to EPA emissions data from all
NOX sources within the State for which the State specified
control measures in its SIP submission under Sec. 51.121(g) of this
part. This would include all sources for which the State has adopted
measures that differ from the measures incorporated into the baseline
inventory for the year 2007 that the State developed in accordance with
Sec. 51.121(g) of this part.
(ii) If sources report NOX emissions data to EPA annually
pursuant to a trading program approved under Sec. 51.121(p) of this part
or pursuant to the monitoring and reporting requirements of subpart H of
40 CFR part 75,
[[Page 160]]
then the State need not provide annual reporting to EPA for such
sources.
(2) Triennial reporting. Each plan must provide for triennial (i.e.,
every third year) reporting of NOX emissions data from all
sources within the State.
(3) Year 2007 reporting. Each plan must provide for reporting of
year 2007 NOX emissions data from all sources within the
State.
(4) The data availability requirements in Sec. 51.116 of this part
must be followed for all data submitted to meet the requirements of
paragraphs (b)(1),(2) and (3) of this section.
(c) The data reported in paragraph (b) of this section for
stationary point sources must meet the following minimum criteria:
(1) For annual data reporting purposes the data must include the
following minimum elements:
(i) Inventory year.
(ii) State Federal Information Placement System code.
(iii) County Federal Information Placement System code.
(iv) Federal ID code (plant).
(v) Federal ID code (point).
(vi) Federal ID code (process).
(vii) Federal ID code (stack).
(vii) Site name.
(viii) Physical address.
(ix) SCC.
(x) Pollutant code.
(xi) Ozone season emissions.
(xii) Area designation.
(2) In addition, the annual data must include the following minimum
elements as applicable to the emissions estimation methodology.
(i) Fuel heat content (annual).
(ii) Fuel heat content (seasonal).
(iii) Source of fuel heat content data.
(iv) Activity throughput (annual).
(v) Activity throughput (seasonal).
(vi) Source of activity/throughput data.
(vii) Spring throughput (%).
(viii) Summer throughput (%).
(ix) Fall throughput (%).
(x) Work weekday emissions.
(xi) Emission factor.
(xii) Source of emission factor.
(xiii) Hour/day in operation.
(xiv) Operations Start time (hour).
(xv) Day/week in operation.
(xvi) Week/year in operation.
(3) The triennial and 2007 inventories must include the following
data elements:
(i) The data required in paragraphs (c)(1) and (c)(2) of this
section.
(ii) X coordinate (latitude).
(iii) Y coordinate (longitude).
(iv) Stack height.
(v) Stack diameter.
(vi) Exit gas temperature.
(vii) Exit gas velocity.
(viii) Exit gas flow rate.
(ix) SIC.
(x) Boiler/process throughput design capacity.
(xi) Maximum design rate.
(xii) Maximum capacity.
(xiii) Primary control efficiency.
(xiv) Secondary control efficiency.
(xv) Control device type.
(d) The data reported in paragraph (b) of this section for area
sources must include the following minimum elements:
(1) For annual inventories it must include:
(i) Inventory year.
(ii) State FIPS code.
(iii) County FIPS code.
(iv) SCC.
(v) Emission factor.
(vi) Source of emission factor.
(vii) Activity/throughput level (annual).
(viii) Activity throughput level (seasonal).
(ix) Source of activity/throughput data.
(x) Spring throughput (%).
(xi) Summer throughput (%).
(xii) Fall throughput (%).
(xiii) Control efficiency (%).
(xiv) Pollutant code.
(xv) Ozone season emissions.
(xvi) Source of emissions data.
(xvii) Hour/day in operation.
(xviii) Day/week in operation.
(xix) Week/year in operations.
(2) The triennial and 2007 inventories must contain, at a minimum,
all the data required in paragraph (d)(1) of this section.
(e) The data reported in paragraph (b) of this section for mobile
sources must meet the following minimum criteria:
(1) For the annual, triennial, and 2007 inventory purposes, the
following data must be reported:
(i) Inventory year.
[[Page 161]]
(ii) State FIPS code.
(iii) County FIPS code.
(iv) SCC.
(v) Emission factor.
(vi) Source of emission factor.
(vii) Activity (this must be reported for both highway and nonroad
activity. Submit nonroad activity in the form of hours of activity at
standard load (either full load or average load) for each engine type,
application, and horsepower range. Submit highway activity in the form
of vehicle miles traveled (VMT) by vehicle class on each roadway type.
Report both highway and nonroad activity for a typical ozone season
weekday day, if the State uses EPA's default weekday/weekend activity
ratio. If the State uses a different weekday/weekend activity ratio,
submit separate activity level information for weekday days and weekend
days).
(viii) Source of activity data.
(ix) Pollutant code.
(x) Summer work weekday emissions.
(xi) Ozone season emissions.
(xii) Source of emissions data.
(2) [Reserved]
(f) Approval of ozone season calculation by EPA. Each State must
submit for EPA approval an example of the calculation procedure used to
calculate ozone season emissions along with sufficient information for
EPA to verify the calculated value of ozone season emissions.
(g) Reporting schedules. (1) Annual reports are to begin with data
for emissions occurring in the year 2003.
(2) Triennial reports are to begin with data for emissions occurring
in the year 2002.
(3) Year 2007 data are to be submitted for emissions occurring in
the year 2007.
(4) States must submit data for a required year no later than 12
months after the end of the calendar year for which the data are
collected.
(h) Data reporting procedures. When submitting a formal
NOX budget emissions report and associated data, States shall
notify the appropriate EPA Regional Office.
(1) States are required to report emissions data in an electronic
format to one of the locations listed in this paragraph (h). Several
options are available for data reporting.
(2) An agency may choose to continue reporting to the EPA Aerometric
Information Retrieval System (AIRS) system using the AIRS facility
subsystem (AFS) format for point sources. (This option will continue for
point sources for some period of time after AIRS is reengineered (before
2002), at which time this choice may be discontinued or modified.)
(3) An agency may convert its emissions data into the Emission
Inventory Improvement Program/Electronic Data Interchange (EIIP/EDI)
format. This file can then be made available to any requestor, either
using E-mail, floppy disk, or value added network (VAN), or can be
placed on a file transfer protocol (FTP) site.
(4) An agency may submit its emissions data in a proprietary format
based on the EIIP data model.
(5) For options in paragraphs (h)(3) and (4) of this section, the
terms submitting and reporting data are defined as either providing the
data in the EIIP/EDI format or the EIIP based data model proprietary
format to EPA, Office of Air Quality Planning and Standards, Emission
Factors and Inventory Group, directly or notifying this group that the
data are available in the specified format and at a specific electronic
location (e.g., FTP site).
(6) For annual reporting (not for triennial reports), a State may
have sources submit the data directly to EPA to the extent the sources
are subject to a trading program that qualifies for approval under
Sec. 51.121(q) of this part, and the State has agreed to accept data in
this format. The EPA will make both the raw data submitted in this
format and summary data available to any State that chooses this option.
(i) Definitions. As used in this section, the following words and
terms shall have the meanings set forth below:
(1) Annual emissions. Actual emissions for a plant, point, or
process, either measured or calculated.
(2) Ash content. Inert residual portion of a fuel.
(3) Area designation. The designation of the area in which the
reporting source is located with regard to the
[[Page 162]]
ozone NAAQS. This would include attainment or nonattainment
designations. For nonattainment designations, the classification of the
nonattainment area must be specified, i.e., transitional, marginal,
moderate, serious, severe, or extreme.
(4) Boiler design capacity. A measure of the size of a boiler, based
on the reported maximum continuous steam flow. Capacity is calculated in
units of MMBtu/hr.
(5) Control device type. The name of the type of control device
(e.g., wet scrubber, flaring, or process change).
(6) Control efficiency. The emissions reduction efficiency of a
primary control device, which shows the amount of reductions of a
particular pollutant from a process' emissions due to controls or
material change. Control efficiency is usually expressed as a percentage
or in tenths.
(7) Day/week in operations. Days per week that the emitting process
operates.
(8) Emission factor. Ratio relating emissions of a specific
pollutant to an activity or material throughput level.
(9) Exit gas flow rate. Numeric value of stack gas flow rate.
(10) Exit gas temperature. Numeric value of an exit gas stream
temperature.
(11) Exit gas velocity. Numeric value of an exit gas stream
velocity.
(12) Fall throughput (%). Portion of throughput for the 3 fall
months (September, October, November). This represents the expression of
annual activity information on the basis of four seasons, typically
spring, summer, fall, and winter. It can be represented either as a
percentage of the annual activity (e.g., production in summer is 40
percent of the year's production), or in terms of the units of the
activity (e.g., out of 600 units produced, spring = 150 units, summer =
250 units, fall = 150 units, and winter = 50 units).
(13) Federal ID code (plant). Unique codes for a plant or facility,
containing one or more pollutant-emitting sources.
(14) Federal ID code (point). Unique codes for the point of
generation of emissions, typically a physical piece of equipment.
(15) Federal ID code (stack number). Unique codes for the point
where emissions from one or more processes are released into the
atmosphere.
(16) Federal Information Placement System (FIPS). The system of
unique numeric codes developed by the government to identify States,
counties, towns, and townships for the entire United States, Puerto
Rico, and Guam.
(17) Heat content. The thermal heat energy content of a solid,
liquid, or gaseous fuel. Fuel heat content is typically expressed in
units of Btu/lb of fuel, Btu/gal of fuel, joules/kg of fuel, etc.
(18) Hr/day in operations. Hours per day that the emitting process
operates.
(19) Maximum design rate. Maximum fuel use rate based on the
equipment's or process' physical size or operational capabilities.
(20) Maximum nameplate capacity. A measure of the size of a
generator which is put on the unit's nameplate by the manufacturer. The
data element is reported in megawatts (MW) or kilowatts (KW).
(21) Mobile source. A motor vehicle, nonroad engine or nonroad
vehicle, where:
(i) Motor vehicle means any self-propelled vehicle designed for
transporting persons or property on a street or highway;
(ii) Nonroad engine means an internal combustion engine (including
the fuel system) that is not used in a motor vehicle or a vehicle used
solely for competition, or that is not subject to standards promulgated
under section 111 or section 202 of the CAA;
(iii) Nonroad vehicle means a vehicle that is powered by a nonroad
engine and that is not a motor vehicle or a vehicle used solely for
competition.
(22) Ozone season. The period May 1 through September 30 of a year.
(23) Physical address. Street address of facility.
(24) Point source. A non-mobile source which emits 100 tons of
NOX or more per year unless the State designates as a point
source a non-mobile source emitting at a specified level lower than 100
tons of NOX per year. A non-mobile source which emits less
NOX per year than the point source threshold is an area
source.
[[Page 163]]
(25) Pollutant code. A unique code for each reported pollutant that
has been assigned in the EIIP Data Model. Character names are used for
criteria pollutants, while Chemical Abstracts Service (CAS) numbers are
used for all other pollutants. Some States may be using storage and
retrieval of aerometric data (SAROAD) codes for pollutants, but these
should be able to be mapped to the EIIP Data Model pollutant codes.
(26) Process rate/throughput. A measurable factor or parameter that
is directly or indirectly related to the emissions of an air pollution
source. Depending on the type of source category, activity information
may refer to the amount of fuel combusted, the amount of a raw material
processed, the amount of a product that is manufactured, the amount of a
material that is handled or processed, population, employment, number of
units, or miles traveled. Activity information is typically the value
that is multiplied against an emission factor to generate an emissions
estimate.
(27) SCC. Source category code. A process-level code that describes
the equipment or operation emitting pollutants.
(28) Secondary control efficiency (%). The emissions reductions
efficiency of a secondary control device, which shows the amount of
reductions of a particular pollutant from a process' emissions due to
controls or material change. Control efficiency is usually expressed as
a percentage or in tenths.
(29) SIC. Standard Industrial Classification code. U.S. Department
of Commerce's categorization of businesses by their products or
services.
(30) Site name. The name of the facility.
(31) Spring throughput (%). Portion of throughput or activity for
the 3 spring months (March, April, May). See the definition of Fall
Throughput.
(32) Stack diameter. Stack physical diameter.
(33) Stack height. Stack physical height above the surrounding
terrain.
(34) Start date (inventory year). The calendar year that the
emissions estimates were calculated for and are applicable to.
(35) Start time (hour). Start time (if available) that was
applicable and used for calculations of emissions estimates.
(36) Summer throughput (%). Portion of throughput or activity for
the 3 summer months (June, July, August). See the definition of Fall
Throughput.
(37) Summer work weekday emissions. Average day's emissions for a
typical day.
(38) VMT by Roadway Class. This is an expression of vehicle activity
that is used with emission factors. The emission factors are usually
expressed in terms of grams per mile of travel. Since VMT does not
directly correlate to emissions that occur while the vehicle is not
moving, these non-moving emissions are incorporated into EPA's MOBILE
model emission factors.
(39) Week/year in operation. Weeks per year that the emitting
process operates.
(40) Work Weekday. Any day of the week except Saturday or Sunday.
(41) X coordinate (latitude). East-west geographic coordinate of an
object.
(42) Y coordinate (longitude). North-south geographic coordinate of
an object.
[63 FR 57496, Oct. 27, 1998]
Subpart H--Prevention of Air Pollution Emergency Episodes
Source: 51 FR 40668, Nov. 7, 1986, unless otherwise noted.
Sec. 51.150 Classification of regions for episode plans.
(a) This section continues the classification system for episode
plans. Each region is classified separately with respect to each of the
following pollutants: Sulfur oxides, particulate matter, carbon
monoxide, nitrogen dioxide, and ozone.
(b) Priority I Regions means any area with greater ambient
concentrations than the following:
(1) Sulfur dioxide--100 [mu]g/m\3\ (0.04 ppm) annual arithmetic
mean; 455 [mu]g/m\3\ (0.17 ppm) 24-hour maximum.
(2) Particulate matter--95 [mu]g/m\3\ annual geometric mean; 325
[mu]g/m\3\ 24-hour maximum.
[[Page 164]]
(3) Carbon monoxide--55 mg/m\3\ (48 ppm) 1-hour maximum; 14 mg/m\3\
(12 ppm) 8-hour maximum.
(4) Nitrogen dioxide--100 [mu]g/m\3\ (0.06 ppm) annual arithmetic
mean.
(5) Ozone--195 [mu]g/m\3\ (0.10 ppm) 1-hour maximum.
(c) Priority IA Region means any area which is Priority I primarily
because of emissions from a single point source.
(d) Priority II Region means any area which is not a Priority I
region and has ambient concentrations between the following:
(1) Sulfur Dioxides--60-100 [mu]g/m\3\ (0.02-0.04 ppm) annual
arithmetic mean; 260-445 [mu]g/m\3\ (0.10-0.17 ppm) 24-hour maximum; any
concentration above 1,300 [mu]g/m\3\ (0.50 ppm) three-hour average.
(2) Particulate matter--60-95 [mu]g/m\3\ annual geometric mean; 150-
325 [mu]g/m\3\ 24-hour maximum.
(e) In the absence of adequate monitoring data, appropriate models
must be used to classify an area under paragraph (b) of this section,
consistent with the requirements contained in Sec. 51.112(a).
(f) Areas which do not meet the above criteria are classified
Priority III.
[51 FR 40668, Nov. 7, 1986, as amended at 58 FR 38822, July 20, 1993]
Sec. 51.151 Significant harm levels.
Each plan for a Priority I region must include a contingency plan
which must, as a mimimum, provide for taking action necessary to prevent
ambient pollutant concentrations at any location in such region from
reaching the following levels:
Sulfur dioxide--2.620 [mu]g/m\3\ (1.0 ppm) 24-hour average.
PM10--600 micrograms/cubic meter; 24-hour average.
Carbon monoxide--57.5 mg/m\3\ (50 ppm) 8-hour average; 86.3 mg/m\3\ (75
ppm) 4-hour average; 144 mg/m\3\ (125 ppm) 1-hour average.
Ozone--1,200 ug/m\3\ (0.6 ppm) 2-hour average.
Nitrogen dioxide--3.750 ug/m\3\ (2.0 ppm) 1-hour average; 938 ug/m\3\
(0.5 ppm) 24-hour average.
[51 FR 40668, Nov. 7, 1986, as amended at 52 FR 24713, July 1, 1987]
Sec. 51.152 Contingency plans.
(a) Each contingency plan must--
(1) Specify two or more stages of episode criteria such as those set
forth in appendix L to this part, or their equivalent;
(2) Provide for public announcement whenever any episode stage has
been determined to exist; and
(3) Specify adequate emission control actions to be taken at each
episode stage. (Examples of emission control actions are set forth in
appendix L.)
(b) Each contingency plan for a Priority I region must provide for
the following:
(1) Prompt acquisition of forecasts of atmospheric stagnation
conditions and of updates of such forecasts as frequently as they are
issued by the National Weather Service.
(2) Inspection of sources to ascertain compliance with applicable
emission control action requirements.
(3) Communications procedures for transmitting status reports and
orders as to emission control actions to be taken during an episode
stage, including procedures for contact with public officials, major
emission sources, public health, safety, and emergency agencies and news
media.
(c) Each plan for a Priority IA and II region must include a
contingency plan that meets, as a minimum, the requirements of
paragraphs (b)(1) and (b)(2) of this section. Areas classified Priority
III do not need to develop episode plans.
(d) Notwithstanding the requirements of paragraphs (b) and (c) of
this section, the Administrator may, at his discretion--
(1) Exempt from the requirements of this section those portions of
Priority I, IA, or II regions which have been designated as attainment
or unclassifiable for national primary and secondary standards under
section 107 of the Act; or
(2) Limit the requirements pertaining to emission control actions in
Priority I regions to--
(i) Urbanized areas as identified in the most recent United States
Census, and
(ii) Major emitting facilities, as defined by section 169(1) of the
Act, outside the urbanized areas.
[[Page 165]]
Sec. 51.153 Reevaluation of episode plans.
(a) States should periodically reevaluate priority classifications
of all Regions or portion of Regions within their borders. The
reevaluation must consider the three most recent years of air quality
data. If the evaluation indicates a change to a higher priority
classification, appropriate changes in the episode plan must be made as
expeditiously as practicable.
(b) [Reserved]
Subpart I--Review of New Sources and Modifications
Source: 51 FR 40669, Nov. 7, 1986, unless otherwise noted.
Sec. 51.160 Legally enforceable procedures.
(a) Each plan must set forth legally enforceable procedures that
enable the State or local agency to determine whether the construction
or modification of a facility, building, structure or installation, or
combination of these will result in--
(1) A violation of applicable portions of the control strategy; or
(2) Interference with attainment or maintenance of a national
standard in the State in which the proposed source (or modification) is
located or in a neighboring State.
(b) Such procedures must include means by which the State or local
agency responsible for final decisionmaking on an application for
approval to construct or modify will prevent such construction or
modification if--
(1) It will result in a violation of applicable portions of the
control strategy; or
(2) It will interfere with the attainment or maintenance of a
national standard.
(c) The procedures must provide for the submission, by the owner or
operator of the building, facility, structure, or installation to be
constructed or modified, of such information on--
(1) The nature and amounts of emissions to be emitted by it or
emitted by associated mobile sources;
(2) The location, design, construction, and operation of such
facility, building, structure, or installation as may be necessary to
permit the State or local agency to make the determination referred to
in paragraph (a) of this section.
(d) The procedures must provide that approval of any construction or
modification must not affect the responsibility to the owner or operator
to comply with applicable portions of the control strategy.
(e) The procedures must identify types and sizes of facilities,
buildings, structures, or installations which will be subject to review
under this section. The plan must discuss the basis for determining
which facilities will be subject to review.
(f) The procedures must discuss the air quality data and the
dispersion or other air quality modeling used to meet the requirements
of this subpart.
(1) All applications of air quality modeling involved in this
subpart shall be based on the applicable models, data bases, and other
requirements specified in appendix W of this part (Guideline on Air
Quality Models).
(2) Where an air quality model specified in appendix W of this part
(Guideline on Air Quality Models) is inappropriate, the model may be
modified or another model substituted. Such a modification or
substitution of a model may be made on a case-by-case basis or, where
appropriate, on a generic basis for a specific State program. Written
approval of the Administrator must be obtained for any modification or
substitution. In addition, use of a modified or substituted model must
be subject to notice and opportunity for public comment under procedures
set forth in Sec. 51.102.
[51 FR 40669, Nov. 7, 1986, as amended at 58 FR 38822, July 20, 1993; 60
FR 40468, Aug. 9, 1995; 61 FR 41840, Aug. 12, 1996]
Sec. 51.161 Public availability of information.
(a) The legally enforceable procedures in Sec. 51.160 must also
require the State or local agency to provide opportunity for public
comment on information submitted by owners and operators. The public
information must include the agency's analysis of the effect of
construction or modification on ambient air quality, including the
[[Page 166]]
agency's proposed approval or disapproval.
(b) For purposes of paragraph (a) of this section, opportunity for
public comment shall include, as a minimum--
(1) Availability for public inspection in at least one location in
the area affected of the information submitted by the owner or operator
and of the State or local agency's analysis of the effect on air
quality;
(2) A 30-day period for submittal of public comment; and
(3) A notice by prominent advertisement in the area affected of the
location of the source information and analysis specified in paragraph
(b)(1) of this section.
(c) Where the 30-day comment period required in paragraph (b) of
this section would conflict with existing requirements for acting on
requests for permission to construct or modify, the State may submit for
approval a comment period which is consistent with such existing
requirements.
(d) A copy of the notice required by paragraph (b) of this section
must also be sent to the Administrator through the appropriate Regional
Office, and to all other State and local air pollution control agencies
having jurisdiction in the region in which such new or modified
installation will be located. The notice also must be sent to any other
agency in the region having responsibility for implementing the
procedures required under this subpart. For lead, a copy of the notice
is required for all point sources. The definition of point for lead is
given in Sec. 51.100(k)(2).
Sec. 51.162 Identification of responsible agency.
Each plan must identify the State or local agency which will be
responsible for meeting the requirements of this subpart in each area of
the State. Where such responsibility rests with an agency other than an
air pollution control agency, such agency will consult with the
appropriate State or local air pollution control agency in carrying out
the provisions of this subpart.
Sec. 51.163 Administrative procedures.
The plan must include the administrative procedures, which will be
followed in making the determination specified in paragraph (a) of
Sec. 51.160.
Sec. 51.164 Stack height procedures.
Such procedures must provide that the degree of emission limitation
required of any source for control of any air pollutant must not be
affected by so much of any source's stack height that exceeds good
engineering practice or by any other dispersion technique, except as
provided in Sec. 51.118(b). Such procedures must provide that before a
State issues a permit to a source based on a good engineering practice
stack height that exceeds the height allowed by Sec. 51.100(ii) (1) or
(2), the State must notify the public of the availability of the
demonstration study and must provide opportunity for public hearing on
it. This section does not require such procedures to restrict in any
manner the actual stack height of any source.
Sec. 51.165 Permit requirements.
(a) State Implementation Plan and Tribal Implementation Plan
provisions satisfying sections 172(c)(5) and 173 of the Act shall meet
the following conditions:
(1) All such plans shall use the specific definitions. Deviations
from the following wording will be approved only if the State
specifically demonstrates that the submitted definition is more
stringent, or at least as stringent, in all respects as the
corresponding definition below:
(i) Stationary source means any building, structure, facility, or
installation which emits or may emit a regulated NSR pollutant.
(ii) Building, structure, facility, or installation means all of the
pollutant-emitting activities which belong to the same industrial
grouping, are located on one or more contiguous or adjacent properties,
and are under the control of the same person (or persons under common
control) except the activities of any vessel. Pollutant-emitting
activities shall be considered as part of the same industrial grouping
if they belong to the same Major Group (i.e., which have the same two-
digit code) as described in the Standard Industrial Classification
Manual, 1972, as amended by the 1977 Supplement (U.S. Government
[[Page 167]]
Printing Office stock numbers 4101-0065 and 003-005-00176-0,
respectively).
(iii) Potential to emit means the maximum capacity of a stationary
source to emit a pollutant under its physical and operational design.
Any physical or operational limitation on the capacity of the source to
emit a pollutant, including air pollution control equipment and
restrictions on hours of operation or on the type or amount of material
combusted, stored, or processed, shall be treated as part of its design
only if the limitation or the effect it would have on emissions is
federally enforceable. Secondary emissions do not count in determining
the potential to emit of a stationary source.
(iv)(A) Major stationary source means:
(1) Any stationary source of air pollutants which emits, or has the
potential to emit 100 tons per year or more of any regulated NSR
pollutant, or
(2) Any physical change that would occur at a stationary source not
qualifying under paragraph (a)(1)(iv)(A)(1) as a major stationary
source, if the change would constitute a major stationary source by
itself.
(B) A major stationary source that is major for volatile organic
compounds shall be considered major for ozone
(C) The fugitive emissions of a stationary source shall not be
included in determining for any of the purposes of this paragraph
whether it is a major stationary source, unless the source belongs to
one of the following categories of stationary sources:
(1) Coal cleaning plants (with thermal dryers);
(2) Kraft pulp mills;
(3) Portland cement plants;
(4) Primary zinc smelters;
(5) Iron and steel mills;
(6) Primary aluminum ore reduction plants;
(7) Primary copper smelters;
(8) Municipal incinerators capable of charging more than 250 tons of
refuse per day;
(9) Hydrofluoric, sulfuric, or nitric acid plants;
(10) Petroleum refineries;
(11) Lime plants;
(12) Phosphate rock processing plants;
(13) Coke oven batteries;
(14) Sulfur recovery plants;
(15) Carbon black plants (furnace process);
(16) Primary lead smelters;
(17) Fuel conversion plants;
(18) Sintering plants;
(19) Secondary metal production plants;
(20) Chemical process plants;
(21) Fossil-fuel boilers (or combination thereof) totaling more than
250 million British thermal units per hour heat input;
(22) Petroleum storage and transfer units with a total storage
capacity exceeding 300,000 barrels;
(23) Taconite ore processing plants;
(24) Glass fiber processing plants;
(25) Charcoal production plants;
(26) Fossil fuel-fired steam electric plants of more than 250
million British thermal units per hour heat input; and
(27) Any other stationary source category which, as of August 7,
1980, is being regulated under section 111 or 112 of the Act.
(v)(A) Major modification means any physical change in or change in
the method of operation of a major stationary source that would result
in:
(1) A significant emissions increase of a regulated NSR pollutant
(as defined in paragraph (a)(1)(xxxvii) of this section); and
(2) A significant net emissions increase of that pollutant from the
major stationary source.
(B) Any significant emissions increase (as defined in paragraph
(a)(1)(xxvii) of this section) from any emissions units or net emissions
increase (as defined in paragraph (a)(1)(vi) of this section) at a major
stationary source that is significant for volatile organic compounds
shall be considered significant for ozone.
(C) A physical change or change in the method of operation shall not
include:
(1) Routine maintenance, repair and replacement;
(2) Use of an alternative fuel or raw material by reason of an order
under sections 2 (a) and (b) of the Energy Supply and Environmental
Coordination Act of 1974 (or any superseding legislation) or by reason
of a natural gas curtailment plan pursuant to the Federal Power Act;
[[Page 168]]
(3) Use of an alternative fuel by reason of an order or rule section
125 of the Act;
(4) Use of an alternative fuel at a steam generating unit to the
extent that the fuel is generated from municipal solid waste;
(5) Use of an alternative fuel or raw material by a stationary
source which;
(i) The source was capable of accommodating before December 21,
1976, unless such change would be prohibited under any federally
enforceable permit condition which was established after December 12,
1976 pursuant to 40 CFR 52.21 or under regulations approved pursuant to
40 CFR subpart I or Sec. 51.166, or
(ii) The source is approved to use under any permit issued under
regulations approved pursuant to this section;
(6) An increase in the hours of operation or in the production rate,
unless such change is prohibited under any federally enforceable permit
condition which was established after December 21, 1976 pursuant to 40
CFR 52.21 or regulations approved pursuant to 40 CFR part 51 subpart I
or 40 CFR 51.166.
(7) Any change in ownership at a stationary source.
(8) The addition, replacement, or use of a PCP, as defined in
paragraph (a)(1)(xxv) of this section, at an existing emissions unit
meeting the requirements of paragraph (e) of this section. A replacement
control technology must provide more effective emissions control than
that of the replaced control technology to qualify for this exclusion.
(9) The installation, operation, cessation, or removal of a
temporary clean coal technology demonstration project, provided that the
project complies with:
(i) The State Implementation Plan for the State in which the project
is located, and
(ii) Other requirements necessary to attain and maintain the
national ambient air quality standard during the project and after it is
terminated.
(D) This definition shall not apply with respect to a particular
regulated NSR pollutant when the major stationary source is complying
with the requirements under paragraph (f) of this section for a PAL for
that pollutant. Instead, the definition at paragraph (f)(2)(viii) of
this section shall apply.
(vi)(A) Net emissions increase means, with respect to any regulated
NSR pollutant emitted by a major stationary source, the amount by which
the sum of the following exceeds zero:
(1) The increase in emissions from a particular physical change or
change in the method of operation at a stationary source as calculated
pursuant to paragraph (a)(2)(ii) of this section; and
(2) Any other increases and decreases in actual emissions at the
major stationary source that are contemporaneous with the particular
change and are otherwise creditable. Baseline actual emissions for
calculating increases and decreases under this paragraph
(a)(1)(vi)(A)(2) shall be determined as provided in paragraph
(a)(1)(xxxv) of this section, except that paragraphs (a)(1)(xxxv)(A)(3)
and (a)(1)(xxxv)(B)(4) of this section shall not apply.
(B) An increase or decrease in actual emissions is contemporaneous
with the increase from the particular change only if it occurs before
the date that the increase from the particular change occurs;
(C) An increase or decrease in actual emissions is creditable only
if:
(1) It occurs within a reasonable period to be specified by the
reviewing authority; and
(2) The reviewing authority has not relied on it in issuing a permit
for the source under regulations approved pursuant to this section,
which permit is in effect when the increase in actual emissions from the
particular change occurs; and
(3) The increase or decrease in emissions did not occur at a Clean
Unit, except as provided in paragraphs (c)(8) and (d)(10) of this
section.
(D) An increase in actual emissions is creditable only to the extent
that the new level of actual emissions exceeds the old level.
(E) A decrease in actual emissions is creditable only to the extent
that:
(1) The old level of actual emission or the old level of allowable
emissions
[[Page 169]]
whichever is lower, exceeds the new level of actual emissions;
(2) It is enforceable as a practical matter at and after the time
that actual construction on the particular change begins; and
(3) The reviewing authority has not relied on it in issuing any
permit under regulations approved pursuant to 40 CFR part 51 subpart I
or the State has not relied on it in demonstrating attainment or
reasonable further progress;
(4) It has approximately the same qualitative significance for
public health and welfare as that attributed to the increase from the
particular change; and
(5) The decrease in actual emissions did not result from the
installation of add-on control technology or application of pollution
prevention practices that were relied on in designating an emissions
unit as a Clean Unit under 40 CFR 52.21(y) or under regulations approved
pursuant to paragraph (d) of this section or Sec. 51.166(u). That is,
once an emissions unit has been designated as a Clean Unit, the owner or
operator cannot later use the emissions reduction from the air pollution
control measures that the Clean Unit designation is based on in
calculating the net emissions increase for another emissions unit (i.e.,
must not use that reduction in a ``netting analysis'' for another
emissions unit). However, any new emissions reductions that were not
relied upon in a PCP excluded pursuant to paragraph (e) of this section
or for a Clean Unit designation are creditable to the extent they meet
the requirements in paragraphs (e)(6)(iv) of this section for the PCP
and paragraphs (c)(8) or (d)(10) of this section for a Clean Unit.
(F) An increase that results from a physical change at a source
occurs when the emissions unit on which construction occurred becomes
operational and begins to emit a particular pollutant. Any replacement
unit that requires shakedown becomes operational only after a reasonable
shakedown period, not to exceed 180 days.
(G) Paragraph (a)(1)(xii)(B) of this section shall not apply for
determining creditable increases and decreases or after a change.
(vii) Emissions unit means any part of a stationary source that
emits or would have the potential to emit any regulated NSR pollutant
and includes an electric steam generating unit as defined in paragraph
(a)(1)(xx) of this section. For purposes of this section, there are two
types of emissions units as described in paragraphs (a)(1)(vii)(A) and
(B) of this section.
(A) A new emissions unit is any emissions unit which is (or will be)
newly constructed and which has existed for less than 2 years from the
date such emissions unit first operated.
(B) An existing emissions unit is any emissions unit that does not
meet the requirements in paragraph (a)(1)(vii)(A) of this section.
(viii) Secondary emissons means emissions which would occur as a
result of the construction or operation of a major stationary source or
major modification, but do not come from the major stationary source or
major modification itself. For the purpose of this section, secondary
emissions must be specific, well defined, quantifiable, and impact the
same general area as the stationary source or modification which causes
the secondary emissions. Secondary emissions include emissions from any
offsite support facility which would not be constructed or increase its
emissions except as a result of the construction of operation of the
major stationary source of major modification. Secondary emissions do
not include any emissions which come directly from a mobile source such
as emissions from the tailpipe of a motor vehicle, from a train, or from
a vessel.
(ix) Fugitive emissions means those emissions which could not
reasonably pass through a stack, chimney, vent or other functionally
equivalent opening.
(x) Significant means, in reference to a net emissions increase pr
the potential of a source to emit any of the following pollutions, as
rate of emissions that would equal or exceed any of the following rates:
Pollutant Emission Rate
Carbon monoxide: 100 tons per year (tpy)
Nitrogen oxides: 40 tpy
Sulfur dioxide: 40 tpy
Ozone: 40 tpy of volatile organic compounds
Lead: 0.6 tpy
[[Page 170]]
(xi) Allowable emissions means the emissions rate of a stationary
source calculated using the maximum rated capacity of the source (unless
the source is subject to federally enforceable limits which restrict the
operating rate, or hours of operation, or both) and the most stringent
of the following:
(A) The applicable standards set forth in 40 CFR part 60 or 61;
(B) Any applicable State Implementation Plan emissions limitation
including those with a future compliance date; or
(C) The emissions rate specified as a federally enforceable permit
condition, including those with a future compliance date.
(xii)(A) Actual emissions means the actual rate of emissions of a
regulated NSR pollutant from an emissions unit, as determined in
accordance with paragraphs (a)(1)(xii)(B) through (D) of this section,
except that this definition shall not apply for calculating whether a
significant emissions increase has occurred, or for establishing a PAL
under paragraph (f) of this section. Instead, paragraphs (a)(1)(xxviii)
and (xxxv) of this section shall apply for those purposes.
(B) In general, actual emissions as of a particular date shall equal
the average rate, in tons per year, at which the unit actually emitted
the pollutant during a consecutive 24-month period which precedes the
particular date and which is representative of normal source operation.
The reviewing authority shall allow the use of a different time period
upon a determination that it is more representative of normal source
operation. Actual emissions shall be calculated using the unit's actual
operating hours, production rates, and types of materials processed,
stored, or combusted during the selected time period.
(C) The reviewing authority may presume that source-specific
allowable emissions for the unit are equivalent to the actual emissions
of the unit.
(D) For any emissions unit that has not begun normal operations on
the particular date, actual emissions shall equal the potential to emit
of the unit on that date.
(xiii) Lowest achievable emission rate (LAER) means, for any source,
the more stringent rate of emissions based on the following:
(A) The most stringent emissions limitation which is contained in
the implementation plan of any State for such class or category of
stationary source, unless the owner or operator of the proposed
stationary source demonstrates that such limitations are not achievable;
or
(B) The most stringent emissions limitation which is achieved in
practice by such class or category of stationary sources. This
limitation, when applied to a modification, means the lowest achievable
emissions rate for the new or modified emissions units within or
stationary source. In no event shall the application of the term permit
a proposed new or modified stationary source to emit any pollutant in
excess of the amount allowable under an applicable new source standard
of performance.
(xiv) Federally enforceable means all limitations and conditions
which are enforceable by the Administrator, including those requirements
developed pursuant to 40 CFR parts 60 and 61, requirements within any
applicable State implementation plan, any permit requirements
established pursuant to 40 CFR 52.21 or under regulations approved
pursuant to 40 CFR part 51, subpart I, including operating permits
issued under an EPA-approved program that is incorporated into the State
implementation plan and expressly requires adherence to any permit
issued under such program.
(xv) Begin actual construction means in general, initiation of
physical on-site construction activities on an emissions unit which are
of a permanent nature. Such activities include, but are not limited to,
installation of building supports and foundations, laying of underground
pipework, and construction of permanent storage structures. With respect
to a change in method of operating this term refers to those on-site
activities other than preparatory activities which mark the initiation
of the change.
(xvi) Commence as applied to construction of a major stationary
source or major modification means that the
[[Page 171]]
owner or operator has all necessary preconstruction approvals or permits
and either has:
(A) Begun, or caused to begin, a continuous program of actual on-
site construction of the source, to be completed within a reasonable
time; or
(B) Entered into binding agreements or contractual obligations,
which cannot be canceled or modified without substantial loss to the
owner or operator, to undertake a program of actual construction of the
source to be completed within a reasonable time.
(xvii) Necessary preconstruction approvals or permits means those
Federal air quality control laws and regulations and those air quality
control laws and regulations which are part of the applicable State
Implementation Plan.
(xviii) Construction means any physical change or change in the
method of operation (including fabrication, erection, installation,
demolition, or modification of an emissions unit) that would result in a
change in emissions.
(xix)Volatile organic compounds (VOC) is as defined in
Sec. 51.100(s) of this part.
(xx) Electric utility steam generating unit means any steam electric
generating unit that is constructed for the purpose of supplying more
than one-third of its potential electric output capacity and more than
25 MW electrical output to any utility power distribution system for
sale. Any steam supplied to a steam distribution system for the purpose
of providing steam to a steam-electric generator that would produce
electrical energy for sale is also considered in determining the
electrical energy output capacity of the affected facility.
(xxi) [Reserved]
(xxii) Temporary clean coal technology demonstration project means a
clean coal technology demonstration project that is operated for a
period of 5 years or less, and which complies with the State
Implementation Plan for the State in which the project is located and
other requirements necessary to attain and maintain the national ambient
air quality standards during the project and after it is terminated.
(xxiii) Clean coal technology means any technology, including
technologies applied at the precombustion, combustion, or post
combustion stage, at a new or existing facility which will achieve
significant reductions in air emissions of sulfur dioxide or oxides of
nitrogen associated with the utilization of coal in the generation of
electricity, or process steam which was not in widespread use as of
November 15, 1990.
(xxiv) Clean coal technology demonstration project means a project
using funds appropriated under the heading ``Department of Energy-Clean
Coal Technology,'' up to a total amount of $2,500,000,000 for commercial
demonstration of clean coal technology, or similar projects funded
through appropriations for the Environmental Protection Agency. The
Federal contribution for a qualifying project shall be at least 20
percent of the total cost of the demonstration project.
(xxv) Pollution control project (PCP) means any activity, set of
work practices or project (including pollution prevention as defined
under paragraph (a)(1)(xxvi) of this section) undertaken at an existing
emissions unit that reduces emissions of air pollutants from such unit.
Such qualifying activities or projects can include the replacement or
upgrade of an existing emissions control technology with a more
effective unit. Other changes that may occur at the source are not
considered part of the PCP if they are not necessary to reduce emissions
through the PCP. Projects listed in paragraphs (a)(1)(xxv)(A) through
(F) of this section are presumed to be environmentally beneficial
pursuant to paragraph (e)(2)(i) of this section. Projects not listed in
these paragraphs may qualify for a case-specific PCP exclusion pursuant
to the requirements of paragraphs (e)(2) and (e)(5) of this section.
(A) Conventional or advanced flue gas desulfurization or sorbent
injection for control of SO2.
(B) Electrostatic precipitators, baghouses, high efficiency
multiclones, or scrubbers for control of particulate matter or other
pollutants.
(C) Flue gas recirculation, low-NOX burners or
combustors, selective non-catalytic reduction, selective catalytic
reduction, low emission combustion (for IC engines), and oxidation/
absorption catalyst for control of NOX.
[[Page 172]]
(D) Regenerative thermal oxidizers, catalytic oxidizers, condensers,
thermal incinerators, hydrocarbon combustion flares, biofiltration,
absorbers and adsorbers, and floating roofs for storage vessels for
control of volatile organic compounds or hazardous air pollutants. For
the purpose of this section, ``hydrocarbon combustion flare'' means
either a flare used to comply with an applicable NSPS or MACT standard
(including uses of flares during startup, shutdown, or malfunction
permitted under such a standard), or a flare that serves to control
emissions of waste streams comprised predominately of hydrocarbons and
containing no more than 230 mg/dscm hydrogen sulfide.
(E) Activities or projects undertaken to accommodate switching (or
partially switching) to an inherently less polluting fuel, to be limited
to the following fuel switches:
(1) Switching from a heavier grade of fuel oil to a lighter fuel
oil, or any grade of oil to 0.05 percent sulfur diesel (i.e., from a
higher sulfur content 2 fuel or from 6 fuel, to CA
0.05 percent sulfur 2 diesel);
(2) Switching from coal, oil, or any solid fuel to natural gas,
propane, or gasified coal;
(3) Switching from coal to wood, excluding construction or
demolition waste, chemical or pesticide treated wood, and other forms of
``unclean'' wood;
(4) Switching from coal to 2 fuel oil (0.5 percent maximum
sulfur content); and
(5) Switching from high sulfur coal to low sulfur coal (maximum 1.2
percent sulfur content).
(F) Activities or projects undertaken to accommodate switching from
the use of one ozone depleting substance (ODS) to the use of a substance
with a lower or zero ozone depletion potential (ODP), including changes
to equipment needed to accommodate the activity or project, that meet
the requirements of paragraphs (a)(1)(xxv)(F)(1) and (2) of this
section.
(1) The productive capacity of the equipment is not increased as a
result of the activity or project.
(2) The projected usage of the new substance is lower, on an ODP-
weighted basis, than the baseline usage of the replaced ODS. To make
this determination, follow the procedure in paragraphs
(a)(1)(xxv)(F)(2)(i) through (iv) of this section.
(i) Determine the ODP of the substances by consulting 40 CFR part
82, subpart A, appendices A and B.
(ii) Calculate the replaced ODP-weighted amount by multiplying the
baseline actual usage (using the annualized average of any 24
consecutive months of usage within the past 10 years) by the ODP of the
replaced ODS.
(iii) Calculate the projected ODP-weighted amount by multiplying the
projected future annual usage of the new substance by its ODP.
(iv) If the value calculated in paragraph (a)(1)(xxv)(F)(2)(ii) of
this section is more than the value calculated in paragraph
(a)(1)(xxv)(F)(2)(iii) of this section, then the projected use of the
new substance is lower, on an ODP-weighted basis, than the baseline
usage of the replaced ODS.
(xxvi) Pollution prevention means any activity that through process
changes, product reformulation or redesign, or substitution of less
polluting raw materials, eliminates or reduces the release of air
pollutants (including fugitive emissions) and other pollutants to the
environment prior to recycling, treatment, or disposal; it does not mean
recycling (other than certain ``in-process recycling'' practices),
energy recovery, treatment, or disposal.
(xxvii) Significant emissions increase means, for a regulated NSR
pollutant, an increase in emissions that is significant (as defined in
paragraph (a)(1)(x) of this section) for that pollutant.
(xxviii)(A) Projected actual emissions means, the maximum annual
rate, in tons per year, at which an existing emissions unit is projected
to emit a regulated NSR pollutant in any one of the 5 years (12-month
period) following the date the unit resumes regular operation after the
project, or in any one of the 10 years following that date, if the
project involves increasing the emissions unit's design capacity or its
potential to emit of that regulated NSR pollutant and full utilization
of the unit would result in a significant emissions increase or a
significant net
[[Page 173]]
emissions increase at the major stationary source.
(B) In determining the projected actual emissions under paragraph
(a)(1)(xxviii)(A) of this section before beginning actual construction,
the owner or operator of the major stationary source:
(1) Shall consider all relevant information, including but not
limited to, historical operational data, the company's own
representations, the company's expected business activity and the
company's highest projections of business activity, the company's
filings with the State or Federal regulatory authorities, and compliance
plans under the approved plan; and
(2) Shall include fugitive emissions to the extent quantifiable, and
emissions associated with startups, shutdowns, and malfunctions; and
(3) Shall exclude, in calculating any increase in emissions that
results from the particular project, that portion of the unit's
emissions following the project that an existing unit could have
accommodated during the consecutive 24-month period used to establish
the baseline actual emissions under paragraph (a)(1)(xxxv) of this
section and that are also unrelated to the particular project, including
any increased utilization due to product demand growth; or,
(4) In lieu of using the method set out in paragraphs
(a)(1)(xxviii)(B)(1) through (3) of this section, may elect to use the
emissions unit's potential to emit, in tons per year, as defined under
paragraph (a)(1)(iii) of this section.
(xxix) Clean Unit means any emissions unit that has been issued a
major NSR permit that requires compliance with BACT or LAER, that is
complying with such BACT/LAER requirements, and qualifies as a Clean
Unit pursuant to regulations approved by the Administrator in accordance
with paragraph (c) of this section; or any emissions unit that has been
designated by a reviewing authority as a Clean Unit, based on the
criteria in paragraphs (d)(3)(i) through (iv) of this section, using a
plan-approved permitting process; or any emissions unit that has been
designated as a Clean Unit by the Administrator in accordance with
Sec. 52.21(y)(3)(i) through (iv) of this chapter.
(xxx) Nonattainment major new source review (NSR) program means a
major source preconstruction permit program that has been approved by
the Administrator and incorporated into the plan to implement the
requirements of this section, or a program that implements part 51,
appendix S, Sections I through VI of this chapter. Any permit issued
under such a program is a major NSR permit.
(xxxi) Continuous emissions monitoring system (CEMS) means all of
the equipment that may be required to meet the data acquisition and
availability requirements of this section, to sample, condition (if
applicable), analyze, and provide a record of emissions on a continuous
basis.
(xxxii) Predictive emissions monitoring system (PEMS) means all of
the equipment necessary to monitor process and control device
operational parameters (for example, control device secondary voltages
and electric currents) and other information (for example, gas flow
rate, O2 or CO2 concentrations), and calculate and
record the mass emissions rate (for example, lb/hr) on a continuous
basis.
(xxxiii) Continuous parameter monitoring system (CPMS) means all of
the equipment necessary to meet the data acquisition and availability
requirements of this section, to monitor process and control device
operational parameters (for example, control device secondary voltages
and electric currents) and other information (for example, gas flow
rate, O2 or CO2 concentrations), and to record
average operational parameter value(s) on a continuous basis.
(xxxiv) Continuous emissions rate monitoring system (CERMS) means
the total equipment required for the determination and recording of the
pollutant mass emissions rate (in terms of mass per unit of time).
(xxxv) Baseline actual emissions means the rate of emissions, in
tons per year, of a regulated NSR pollutant, as determined in accordance
with paragraphs (a)(1)(xxxv)(A) through (D) of this section.
(A) For any existing electric utility steam generating unit,
baseline actual
[[Page 174]]
emissions means the average rate, in tons per year, at which the unit
actually emitted the pollutant during any consecutive 24-month period
selected by the owner or operator within the 5-year period immediately
preceding when the owner or operator begins actual construction of the
project. The reviewing authority shall allow the use of a different time
period upon a determination that it is more representative of normal
source operation.
(1) The average rate shall include fugitive emissions to the extent
quantifiable, and emissions associated with startups, shutdowns, and
malfunctions.
(2) The average rate shall be adjusted downward to exclude any non-
compliant emissions that occurred while the source was operating above
any emission limitation that was legally enforceable during the
consecutive 24-month period.
(3) For a regulated NSR pollutant, when a project involves multiple
emissions units, only one consecutive 24-month period must be used to
determine the baseline actual emissions for the emissions units being
changed. A different consecutive 24-month period can be used for each
regulated NSR pollutant.
(4) The average rate shall not be based on any consecutive 24-month
period for which there is inadequate information for determining annual
emissions, in tons per year, and for adjusting this amount if required
by paragraph (a)(1)(xxxv)(A)(2) of this section.
(B) For an existing emissions unit (other than an electric utility
steam generating unit), baseline actual emissions means the average
rate, in tons per year, at which the emissions unit actually emitted the
pollutant during any consecutive 24-month period selected by the owner
or operator within the 10-year period immediately preceding either the
date the owner or operator begins actual construction of the project, or
the date a complete permit application is received by the reviewing
authority for a permit required either under this section or under a
plan approved by the Administrator, whichever is earlier, except that
the 10-year period shall not include any period earlier than November
15, 1990.
(1) The average rate shall include fugitive emissions to the extent
quantifiable, and emissions associated with startups, shutdowns, and
malfunctions.
(2) The average rate shall be adjusted downward to exclude any non-
compliant emissions that occurred while the source was operating above
an emission limitation that was legally enforceable during the
consecutive 24-month period.
(3) The average rate shall be adjusted downward to exclude any
emissions that would have exceeded an emission limitation with which the
major stationary source must currently comply, had such major stationary
source been required to comply with such limitations during the
consecutive 24-month period. However, if an emission limitation is part
of a maximum achievable control technology standard that the
Administrator proposed or promulgated under part 63 of this chapter, the
baseline actual emissions need only be adjusted if the State has taken
credit for such emissions reductions in an attainment demonstration or
maintenance plan consistent with the requirements of paragraph
(a)(3)(ii)(G) of this section.
(4) For a regulated NSR pollutant, when a project involves multiple
emissions units, only one consecutive 24-month period must be used to
determine the baseline actual emissions for the emissions units being
changed. A different consecutive 24-month period can be used For each
regulated NSR pollutant.
(5) The average rate shall not be based on any consecutive 24-month
period for which there is inadequate information for determining annual
emissions, in tons per year, and for adjusting this amount if required
by paragraphs (a)(1)(xxxv)(B)(2) and (3) of this section.
(C) For a new emissions unit, the baseline actual emissions for
purposes of determining the emissions increase that will result from the
initial construction and operation of such unit shall equal zero; and
thereafter, for all other purposes, shall equal the unit's potential to
emit.
(D) For a PAL for a major stationary source, the baseline actual
emissions shall be calculated for existing electric
[[Page 175]]
utility steam generating units in accordance with the procedures
contained in paragraph (a)(1)(xxxv)(A) of this section, for other
existing emissions units in accordance with the procedures contained in
paragraph (a)(1)(xxxv)(B) of this section, and for a new emissions unit
in accordance with the procedures contained in paragraph (a)(1)(xxxv)(C)
of this section.
(xxxvi) [Reserved]
(xxxvii) Regulated NSR pollutant, for purposes of this section,
means the following:
(A) Nitrogen oxides or any volatile organic compounds;
(B) Any pollutant for which a national ambient air quality standard
has been promulgated; or
(C) Any pollutant that is a constituent or precursor of a general
pollutant listed under paragraphs (a)(1)(xxxvii)(A) or (B) of this
section, provided that a constituent or precursor pollutant may only be
regulated under NSR as part of regulation of the general pollutant.
(xxxviii) Reviewing authority means the State air pollution control
agency, local agency, other State agency, Indian tribe, or other agency
authorized by the Administrator to carry out a permit program under this
section and Sec. 51.166, or the Administrator in the case of EPA-
implemented permit programs under Sec. 52.21.
(xxxix) Project means a physical change in, or change in the method
of operation of, an existing major stationary source.
(xl) Best available control technology (BACT) means an emissions
limitation (including a visible emissions standard) based on the maximum
degree of reduction for each regulated NSR pollutant which would be
emitted from any proposed major stationary source or major modification
which the reviewing authority, on a case-by-case basis, taking into
account energy, environmental, and economic impacts and other costs,
determines is achievable for such source or modification through
application of production processes or available methods, systems, and
techniques, including fuel cleaning or treatment or innovative fuel
combustion techniques for control of such pollutant. In no event shall
application of best available control technology result in emissions of
any pollutant which would exceed the emissions allowed by any applicable
standard under 40 CFR part 60 or 61. If the reviewing authority
determines that technological or economic limitations on the application
of measurement methodology to a particular emissions unit would make the
imposition of an emissions standard infeasible, a design, equipment,
work practice, operational standard, or combination thereof, may be
prescribed instead to satisfy the requirement for the application of
BACT. Such standard shall, to the degree possible, set forth the
emissions reduction achievable by implementation of such design,
equipment, work practice or operation, and shall provide for compliance
by means which achieve equivalent results.
(xli) Prevention of Significant Deterioration (PSD) permit means any
permit that is issued under a major source preconstruction permit
program that has been approved by the Administrator and incorporated
into the plan to implement the requirements of Sec. 51.166 of this
chapter, or under the program in Sec. 52.21 of this chapter.
(xlii) Federal Land Manager means, with respect to any lands in the
United States, the Secretary of the department with authority over such
lands.
(2) Applicability procedures. (i) Each plan shall adopt a
preconstruction review program to satisfy the requirements of sections
172(c)(5) and 173 of the Act for any area designated nonattainment for
any national ambient air quality standard under subpart C of 40 CFR part
81. Such a program shall apply to any new major stationary source or
major modification that is major for the pollutant for which the area is
designated nonattainment under section 107(d)(1)(A)(i) of the Act, if
the stationary source or modification would locate anywhere in the
designated nonattainment area.
(ii) Each plan shall use the specific provisions of paragraphs
(a)(2)(ii)(A) through (F) of this section. Deviations from these
provisions will be approved only if the State specifically demonstrates
that the submitted provisions are more stringent than or at least as
stringent in all respects as the
[[Page 176]]
corresponding provisions in paragraphs (a)(2)(ii)(A) through (F) of this
section.
(A) Except as otherwise provided in paragraphs (a)(2)(iii) and (iv)
of this section, and consistent with the definition of major
modification contained in paragraph (a)(1)(v)(A) of this section, a
project is a major modification for a regulated NSR pollutant if it
causes two types of emissions increases--a significant emissions
increase (as defined in paragraph (a)(1)(xxvii) of this section), and a
significant net emissions increase (as defined in paragraphs (a)(1)(vi)
and (x) of this section). The project is not a major modification if it
does not cause a significant emissions increase. If the project causes a
significant emissions increase, then the project is a major modification
only if it also results in a significant net emissions increase.
(B) The procedure for calculating (before beginning actual
construction) whether a significant emissions increase (i.e., the first
step of the process) will occur depends upon the type of emissions units
being modified, according to paragraphs (a)(2)(ii)(C) through (F) of
this section. The procedure for calculating (before beginning actual
construction) whether a significant net emissions increase will occur at
the major stationary source (i.e., the second step of the process) is
contained in the definition in paragraph (a)(1)(vi) of this section.
Regardless of any such preconstruction projections, a major modification
results if the project causes a significant emissions increase and a
significant net emissions increase.
(C) Actual-to-projected-actual applicability test for projects that
only involve existing emissions units. A significant emissions increase
of a regulated NSR pollutant is projected to occur if the sum of the
difference between the projected actual emissions (as defined in
paragraph (a)(1)(xxviii) of this section) and the baseline actual
emissions (as defined in paragraphs (a)(1)(xxxv)(A) and (B) of this
section, as applicable), for each existing emissions unit, equals or
exceeds the significant amount for that pollutant (as defined in
paragraph (a)(1)(x) of this section).
(D) Actual-to-potential test for projects that only involve
construction of a new emissions unit(s). A significant emissions
increase of a regulated NSR pollutant is projected to occur if the sum
of the difference between the potential to emit (as defined in paragraph
(a)(1)(iii) of this section) from each new emissions unit following
completion of the project and the baseline actual emissions (as defined
in paragraph (a)(1)(xxxv)(C) of this section) of these units before the
project equals or exceeds the significant amount for that pollutant (as
defined in paragraph (a)(1)(x) of this section).
(E) Emission test for projects that involve Clean Units. For a
project that will be constructed and operated at a Clean Unit without
causing the emissions unit to lose its Clean Unit designation, no
emissions increase is deemed to occur.
(F) Hybrid test for projects that involve multiple types of
emissions units. A significant emissions increase of a regulated NSR
pollutant is projected to occur if the sum of the emissions increases
for each emissions unit, using the method specified in paragraphs
(a)(2)(ii)(C) through (E) of this section as applicable with respect to
each emissions unit, for each type of emissions unit equals or exceeds
the significant amount for that pollutant (as defined in paragraph
(a)(1)(x) of this section). For example, if a project involves both an
existing emissions unit and a Clean Unit, the projected increase is
determined by summing the values determined using the method specified
in paragraph (a)(2)(ii)(C) of this section for the existing unit and
using the method specified in paragraph (a)(2)(ii)(E) of this section
for the Clean Unit.
(iii) The plan shall require that for any major stationary source
for a PAL for a regulated NSR pollutant, the major stationary source
shall comply with requirements under paragraph (f) of this section.
(iv) The plan shall require that an owner or operator undertaking a
PCP (as defined in paragraph (a)(1)(xxv) of this section) shall comply
with the requirements under paragraph (e) of this section.
(3)(i) Each plan shall provide that for sources and modifications
subject to any preconstruction review program
[[Page 177]]
adopted pursuant to this subsection the baseline for determining credit
for emissions reductions is the emissions limit under the applicable
State Implementation Plan in effect at the time the application to
construct is filed, except that the offset baseline shall be the actual
emissions of the source from which offset credit is obtained where;
(A) The demonstration of reasonable further progress and attainment
of ambient air quality standards is based upon the actual emissions of
sources located within a designated nonattainment area for which the
preconstruction review program was adopted; or
(B) The applicable State Implementation Plan does not contain an
emissions limitation for that source or source category.
(ii) The plan shall further provide that:
(A) Where the emissions limit under the applicable State
Implementation Plan allows greater emissions than the potential to emit
of the source, emissions offset credit will be allowed only for control
below this potential;
(B) For an existing fuel combustion source, credit shall be based on
the allowable emissions under the applicable State Implementation Plan
for the type of fuel being burned at the time the application to
construct is filed. If the existing source commits to switch to a
cleaner fuel at some future date, emissions offset credit based on the
allowable (or actual) emissions for the fuels involved is not
acceptable, unless the permit is conditioned to require the use of a
specified alternative control measure which would achieve the same
degree of emissions reduction should the source switch back to a dirtier
fuel at some later date. The reviewing authority should ensure that
adequate long-term supplies of the new fuel are available before
granting emissions offset credit for fuel switches,
(C)(1) Emissions reductions achieved by shutting down an existing
source or curtailing production or operating hours below baseline levels
may be generally credited if such reductions are permanent,
quantifiable, and federally enforceable, and if the area has an EPA-
approved attainment plan. In addition, the shutdown or curtailment is
creditable only if it occurred on or after the date specified for this
purpose in the plan, and if such date is on or after the date of the
most recent emissions inventory used in the plan's demonstration of
attainment. Where the plan does not specify a cutoff date for shutdown
credits, the date of the most recent emissions inventory or attainment
demonstration, as the case may be, shall apply. However, in no event may
credit be given for shutdowns which occurred prior to August 7, 1977.
For purposes of this paragraph, a permitting authority may choose to
consider a prior shutdown or curtailment to have occurred after the date
of its most recent emissions inventory, if the inventory explicitly
includes as current existing emissions the emissions from such
previously shutdown or curtailed sources.
(2) Such reductions may be credited in the absence of an approved
attainment demonstration only if the shutdown or curtailment occurred on
or after the date the new source permit application is filed, or, if the
applicant can establish that the proposed new source is a replacement
for the shutdown or curtailed source, and the cutoff date provisions of
Sec. 51.165(a)(3)(ii)(C)(1) are observed.
(D) No emissions credit may be allowed for replacing one hydrocarbon
compound with another of lesser reactivity, except for those compounds
listed in Table 1 of EPA's ``Recommended Policy on Control of Volatile
Organic Compounds'' (42 FR 35314, July 8, 1977; (This document is also
available from Mr. Ted Creekmore, Office of Air Quality Planning and
Standards, (MD-15) Research Triangle Park, NC 27711.))
(E) All emission reductions claimed as offset credit shall be
federally enforceable;
(F) Procedures relating to the permissible location of offsetting
emissions shall be followed which are at least as stringent as those set
out in 40 CFR part 51 appendix S section IV.D.
(G) Credit for an emissions reduction can be claimed to the extent
that the reviewing authority has not relied on it in issuing any permit
under regulations approved pursuant to 40 CFR part 51 subpart I or the
State has not relied
[[Page 178]]
on it in demonstration attainment or reasonable further progress.
(H) Decreases in actual emissions resulting from the installation of
add-on control technology or application of pollution prevention
measures that were relied upon in designating an emissions unit as a
Clean Unit or a project as a PCP cannot be used as offsets.
(I) Decreases in actual emissions occurring at a Clean Unit cannot
be used as offsets, except as provided in paragraphs (c)(8) and (d)(10)
of this section. Similarly, decreases in actual emissions occurring at a
PCP cannot be used as offsets, except as provided in paragraph
(e)(6)(iv) of this section.
(J) The total tonnage of increased emissions, in tons per year,
resulting from a major modification that must be offset in accordance
with section 173 of the Act shall be determined by summing the
difference between the allowable emissions after the modification (as
defined by paragraph (a)(1)(xi) of this section) and the actual
emissions before the modification (as defined in paragraph (a)(1)(xii)
of this section) for each emissions unit.
(4) Each plan may provide that the provisions of this paragraph do
not apply to a source or modification that would be a major stationary
source or major modification only if fugitive emission to the extent
quantifiable are considered in calculating the potential to emit of the
stationary source or modification and the source does not belong to any
of the following categories:
(i) Coal cleaning plants (with thermal dryers);
(ii) Kraft pulp mills;
(iii) Portland cement plants;
(iv) Primary zinc smelters;
(v) Iron and steel mills;
(vi) Primary aluminum ore reduction plants;
(vii) Primary copper smelters;
(viii) Municipal incinerators capable of charging more than 250 tons
of refuse per day;
(ix) Hydrofluoric, sulfuric, or citric acid plants;
(x) Petroleum refineries;
(xi) Lime plants;
(xii) Phosphate rock processing plants;
(xiii) Coke oven batteries;
(xiv) Sulfur recovery plants;
(xv) Carbon black plants (furnace process);
(xvi) Primary lead smelters;
(xvii) Fuel conversion plants;
(xviii) Sintering plants;
(xix) Secondary metal production plants;
(xx) Chemical process plants;
(xxi) Fossil-fuel boilers (or combination thereof) totaling more
than 250 million British thermal units per hour heat input;
(xxii) Petroleum storage and transfer units with a total storage
capacity exceeding 300,000 barrels;
(xxiii) Taconite ore processing plants;
(xxiv) Glass fiber processing plants;
(xxv) Charcoal production plants;
(xxvi) Fossil fuel-fired steam electric plants of more than 250
million British thermal units per hour heat input;
(xxvii) Any other stationary source category which, as of August 7,
1980, is being regulated under section 111 or 112 of the Act.
(5) Each plan shall include enforceable procedures to provide that:
(i) Approval to construct shall not relieve any owner or operator of
the responsibility to comply fully with applicable provision of the plan
and any other requirements under local, State or Federal law.
(ii) At such time that a particular source or modification becomes a
major stationary source or major modification solely by virtue of a
relaxation in any enforcement limitation which was established after
August 7, 1980, on the capacity of the source or modification otherwise
to emit a pollutant, such as a restriction on hours of operation, then
the requirements of regulations approved pursuant to this section shall
apply to the source or modification as though construction had not yet
commenced on the source or modification;
(6) Each plan shall provide that the following specific provisions
apply to projects at existing emissions units at a major stationary
source (other than projects at a Clean Unit or at a source with a PAL)
in circumstances where there is a reasonable possibility that a project
that is not a part of a major
[[Page 179]]
modification may result in a significant emissions increase and the
owner or operator elects to use the method specified in paragraphs
(a)(1)(xxviii)(B)(1) through (3) of this section for calculating
projected actual emissions. Deviations from these provisions will be
approved only if the State specifically demonstrates that the submitted
provisions are more stringent than or at least as stringent in all
respects as the corresponding provisions in paragraphs (a)(6)(i) through
(v) of this section.
(i) Before beginning actual construction of the project, the owner
or operator shall document and maintain a record of the following
information:
(A) A description of the project;
(B) Identification of the emissions unit(s) whose emissions of a
regulated NSR pollutant could be affected by the project; and
(C) A description of the applicability test used to determine that
the project is not a major modification for any regulated NSR pollutant,
including the baseline actual emissions, the projected actual emissions,
the amount of emissions excluded under paragraph (a)(1)(xxviii)(B)(3) of
this section and an explanation for why such amount was excluded, and
any netting calculations, if applicable.
(ii) If the emissions unit is an existing electric utility steam
generating unit, before beginning actual construction, the owner or
operator shall provide a copy of the information set out in paragraph
(a)(6)(i) of this section to the reviewing authority. Nothing in this
paragraph (a)(6)(ii) shall be construed to require the owner or operator
of such a unit to obtain any determination from the reviewing authority
before beginning actual construction.
(iii) The owner or operator shall monitor the emissions of any
regulated NSR pollutant that could increase as a result of the project
and that is emitted by any emissions units identified in paragraph
(a)(6)(i)(B) of this section; and calculate and maintain a record of the
annual emissions, in tons per year on a calendar year basis, for a
period of 5 years following resumption of regular operations after the
change, or for a period of 10 years following resumption of regular
operations after the change if the project increases the design capacity
or potential to emit of that regulated NSR pollutant at such emissions
unit.
(iv) If the unit is an existing electric utility steam generating
unit, the owner or operator shall submit a report to the reviewing
authority within 60 days after the end of each year during which records
must be generated under paragraph (a)(6)(iii) of this section setting
out the unit's annual emissions during the year that preceded submission
of the report.
(v) If the unit is an existing unit other than an electric utility
steam generating unit, the owner or operator shall submit a report to
the reviewing authority if the annual emissions, in tons per year, from
the project identified in paragraph (a)(6)(i) of this section, exceed
the baseline actual emissions (as documented and maintained pursuant to
paragraph (a)(6)(i)(C) of this section, by a significant amount (as
defined in paragraph (a)(1)(x) of this section) for that regulated NSR
pollutant, and if such emissions differ from the preconstruction
projection as documented and maintained pursuant to paragraph
(a)(6)(i)(C) of this section. Such report shall be submitted to the
reviewing authority within 60 days after the end of such year. The
report shall contain the following:
(A) The name, address and telephone number of the major stationary
source;
(B) The annual emissions as calculated pursuant to paragraph
(a)(6)(iii) of this section; and
(C) Any other information that the owner or operator wishes to
include in the report (e.g., an explanation as to why the emissions
differ from the preconstruction projection).
(7) Each plan shall provide that the owner or operator of the source
shall make the information required to be documented and maintained
pursuant to paragraph (a)(6) of this section available for review upon a
request for inspection by the reviewing authority or the general public
pursuant to the requirements contained in Sec. 70.4(b)(3)(viii) of this
chapter.
(b)(1) Each plan shall include a preconstruction review permit
program or its equivalent to satisfy the requirements of section
110(a)(2)(D)(i) of the
[[Page 180]]
Act for any new major stationary source or major modification as defined
in paragraphs (a)(1) (iv) and (v) of this section. Such a program shall
apply to any such source or modification that would locate in any area
designated as attainment or unclassifiable for any national ambient air
quality standard pursuant to section 107 of the Act, when it would cause
or contribute to a violation of any national ambient air quality
standard.
(2) A major source or major modification will be considered to cause
or contribute to a violation of a national ambient air quality standard
when such source or modification would, at a minimum, exceed the
following significance levels at any locality that does not or would not
meet the applicable national standard:
--------------------------------------------------------------------------------------------------------------------------------------------------------
Averaging time (hours)
Pollutant Annual --------------------------------------------------------------------------------------------
24 8 3 1
--------------------------------------------------------------------------------------------------------------------------------------------------------
SO2................................ 1.0 [mu]g/m\3\........ 5 [mu]g/m\3\.......... ................... 25 [mu]g/m\3\........
PM10............................... 1.0 [mu]g/m\3\........ 5 [mu]g/m\3\.......... ................... ...................
NO2................................ 1.0 [mu]g/m\3\........ .................... ................... ...................
CO................................. .................... .................... 0.5 mg/m\3\.......... ................... 2 mg/m\3\
--------------------------------------------------------------------------------------------------------------------------------------------------------
(3) Such a program may include a provision which allows a proposed
major source or major modification subject to paragraph (b) of this
section to reduce the impact of its emissions upon air quality by
obtaining sufficient emission reductions to, at a minimum, compensate
for its adverse ambient impact where the major source or major
modification would otherwise cause or contribute to a violation of any
national ambient air quality standard. The plan shall require that, in
the absence of such emission reductions, the State or local agency shall
deny the proposed construction.
(4) The requirements of paragraph (b) of this section shall not
apply to a major stationary source or major modification with respect to
a particular pollutant if the owner or operator demonstrates that, as to
that pollutant, the source or modification is located in an area
designated as nonattainment pursuant to section 107 of the Act.
(c) Clean Unit Test for emissions units that are subject to LAER.
The plan shall provide an owner or operator of a major stationary source
the option of using the Clean Unit Test to determine whether emissions
increases at a Clean Unit are part of a project that is a major
modification according to the provisions in paragraphs (c)(1) through
(9) of this section.
(1) Applicability. The provisions of this paragraph (c) apply to any
emissions unit for which the reviewing authority has issued a major NSR
permit within the past 10 years.
(2) General provisions for Clean Units. The provisions in paragraphs
(c)(2)(i) through (v) of this section apply to a Clean Unit.
(i) Any project for which the owner or operator begins actual
construction after the effective date of the Clean Unit designation (as
determined in accordance with paragraph (c)(4) of this section) and
before the expiration date (as determined in accordance with paragraph
(c)(5) of this section) will be considered to have occurred while the
emissions unit was a Clean Unit.
(ii) If a project at a Clean Unit does not cause the need for a
change in the emission limitations or work practice requirements in the
permit for the unit that were adopted in conjunction with LAER and the
project would not alter any physical or operational characteristics that
formed the basis for the LAER determination as specified in paragraph
(c)(6)(iv) of this section, the emissions unit remains a Clean Unit.
(iii) If a project causes the need for a change in the emission
limitations or work practice requirements in the permit for the unit
that were adopted in conjunction with LAER or the project would alter
any physical or operational characteristics that formed the basis for
the LAER determination as specified in paragraph (c)(6)(iv) of this
section, then the emissions unit loses its designation as a Clean Unit
upon
[[Page 181]]
issuance of the necessary permit revisions (unless the unit requalifies
as a Clean Unit pursuant to paragraph (c)(3)(iii) of this section). If
the owner or operator begins actual construction on the project without
first applying to revise the emissions unit's permit, the Clean Unit
designation ends immediately prior to the time when actual construction
begins.
(iv) A project that causes an emissions unit to lose its designation
as a Clean Unit is subject to the applicability requirements of
paragraphs (a)(2)(ii)(A) through (D) and paragraph (a)(2)(ii)(F) of this
section as if the emissions unit is not a Clean Unit.
(v) Certain Emissions Units with PSD permits. For emissions units
that meet the requirements of paragraphs (c)(2)(v)(A) and (B) of this
section, the BACT level of emissions reductions and/or work practice
requirements shall satisfy the requirement for LAER in meeting the
requirements for Clean Units under paragraphs (c)(3) through (8) of this
section. For these emissions units, all requirements for the LAER
determination under paragraphs (c)(2)(ii) and (iii) of this section
shall also apply to the BACT permit terms and conditions. In addition,
the requirements of paragraph (c)(7)(i)(B) of this section do not apply
to emissions units that qualify for Clean Unit status under this
paragraph (c)(2)(v).
(A) The emissions unit must have received a PSD permit within the
last 10 years and such permit must require the emissions unit to comply
with BACT.
(B) The emissions unit must be located in an area that was
redesignated as nonattainment for the relevant pollutant(s) after
issuance of the PSD permit and before the effective date of the Clean
Unit Test provisions in the area.
(3) Qualifying or re-qualifying to use the Clean Unit applicability
test. An emissions unit automatically qualifies as a Clean Unit when the
unit meets the criteria in paragraphs (c)(3)(i) and (ii) of this
section. After the original Clean Unit designation expires in accordance
with paragraph (c)(5) of this section or is lost pursuant to paragraph
(c)(2)(iii) of this section, such emissions unit may re-qualify as a
Clean Unit under either paragraph (c)(3)(iii) of this section, or under
the Clean Unit provisions in paragraph (d) of this section. To re-
qualify as a Clean Unit under paragraph (c)(3)(iii) of this section, the
emissions unit must obtain a new major NSR permit issued through the
applicable nonattainment major NSR program and meet all the criteria in
paragraph (c)(3)(iii) of this section. Clean Unit designation applies
individually for each pollutant emitted by the emissions unit.
(i) Permitting requirement. The emissions unit must have received a
major NSR permit within the past 10 years. The owner or operator must
maintain and be able to provide information that would demonstrate that
this permitting requirement is met.
(ii) Qualifying air pollution control technologies. Air pollutant
emissions from the emissions unit must be reduced through the use of an
air pollution control technology (which includes pollution prevention as
defined under paragraph (a)(1)(xxvi) of this section or work practices)
that meets both the following requirements in paragraphs (c)(3)(ii)(A)
and (B) of this section.
(A) The control technology achieves the LAER level of emissions
reductions as determined through issuance of a major NSR permit within
the past 10 years. However, the emissions unit is not eligible for Clean
Unit designation if the LAER determination resulted in no requirement to
reduce emissions below the level of a standard, uncontrolled, new
emissions unit of the same type.
(B) The owner or operator made an investment to install the control
technology. For the purpose of this determination, an investment
includes expenses to research the application of a pollution prevention
technique to the emissions unit or expenses to apply a pollution
prevention technique to an emissions unit.
(iii) Re-qualifying for the Clean Unit designation. The emissions
unit must obtain a new major NSR permit that requires compliance with
the current-day LAER, and the emissions unit must meet the requirements
in paragraphs (c)(3)(i) and (c)(3)(ii) of this section.
[[Page 182]]
(4) Effective date of the Clean Unit designation. The effective date
of an emissions unit's Clean Unit designation (that is, the date on
which the owner or operator may begin to use the Clean Unit Test to
determine whether a project at the emissions unit is a major
modification) is determined according to the applicable paragraph
(c)(4)(i) or (c)(4)(ii) of this section.
(i) Original Clean Unit designation, and emissions units that re-
qualify as Clean Units by implementing a new control technology to meet
current-day LAER. The effective date is the date the emissions unit's
air pollution control technology is placed into service, or 3 years
after the issuance date of the major NSR permit, whichever is earlier,
but no sooner than the date that provisions for the Clean Unit
applicability test are approved by the Administrator for incorporation
into the plan and become effective for the State in which the unit is
located.
(ii) Emissions units that re-qualify for the Clean Unit designation
using an existing control technology. The effective date is the date the
new, major NSR permit is issued.
(5) Clean Unit expiration. An emissions unit's Clean Unit
designation expires (that is, the date on which the owner or operator
may no longer use the Clean Unit Test to determine whether a project
affecting the emissions unit is, or is part of, a major modification)
according to the applicable paragraph (c)(5)(i) or (ii) of this section.
(i) Original Clean Unit designation, and emissions units that re-
qualify by implementing new control technology to meet current-day LAER.
For any emissions unit that automatically qualifies as a Clean Unit
under paragraphs (c)(3)(i) and (ii) of this section, the Clean Unit
designation expires 10 years after the effective date, or the date the
equipment went into service, whichever is earlier; or, it expires at any
time the owner or operator fails to comply with the provisions for
maintaining Clean Unit designation in paragraph (c)(7) of this section.
(ii) Emissions units that re-qualify for the Clean Unit designation
using an existing control technology. For any emissions unit that re-
qualifies as a Clean Unit under paragraph (c)(3)(iii) of this section,
the Clean Unit designation expires 10 years after the effective date;
or, it expires any time the owner or operator fails to comply with the
provisions for maintaining the Clean Unit Designation in paragraph
(c)(7) of this section.
(6) Required title V permit content for a Clean Unit. After the
effective date of the Clean Unit designation, and in accordance with the
provisions of the applicable title V permit program under part 70 or
part 71 of this chapter, but no later than when the title V permit is
renewed, the title V permit for the major stationary source must include
the following terms and conditions in paragraphs (c)(6)(i) through (vi)
of this section related to the Clean Unit.
(i) A statement indicating that the emissions unit qualifies as a
Clean Unit and identifying the pollutant(s) for which this Clean Unit
designation applies.
(ii) The effective date of the Clean Unit designation. If this date
is not known when the Clean Unit designation is initially recorded in
the title V permit (e.g., because the air pollution control technology
is not yet in service), the permit must describe the event that will
determine the effective date (e.g., the date the control technology is
placed into service). Once the effective date is determined, the owner
or operator must notify the reviewing authority of the exact date. This
specific effective date must be added to the source's title V permit at
the first opportunity, such as a modification, revision, reopening, or
renewal of the title V permit for any reason, whichever comes first, but
in no case later than the next renewal.
(iii) The expiration date of the Clean Unit designation. If this
date is not known when the Clean Unit designation is initially recorded
into the title V permit (e.g., because the air pollution control
technology is not yet in service), then the permit must describe the
event that will determine the expiration date (e.g., the date the
control technology is placed into service). Once the expiration date is
determined, the owner or operator must notify the reviewing authority of
the exact date. The expiration date must be added to
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the source's title V permit at the first opportunity, such as a
modification, revision, reopening, or renewal of the title V permit for
any reason, whichever comes first, but in no case later than the next
renewal.
(iv) All emission limitations and work practice requirements adopted
in conjunction with the LAER, and any physical or operational
characteristics that formed the basis for the LAER determination (e.g.,
possibly the emissions unit's capacity or throughput).
(v) Monitoring, recordkeeping, and reporting requirements as
necessary to demonstrate that the emissions unit continues to meet the
criteria for maintaining the Clean Unit designation. (See paragraph
(c)(7) of this section.)
(vi) Terms reflecting the owner or operator's duties to maintain the
Clean Unit designation and the consequences of failing to do so, as
presented in paragraph (c)(7) of this section.
(7) Maintaining the Clean Unit designation. To maintain the Clean
Unit designation, the owner or operator must conform to all the
restrictions listed in paragraphs (c)(7)(i) through (iii) of this
section. This paragraph (c)(7) applies independently to each pollutant
for which the emissions unit has the Clean Unit designation. That is,
failing to conform to the restrictions for one pollutant affects Clean
Unit designation only for that pollutant.
(i) The Clean Unit must comply with the emission limitation(s) and/
or work practice requirements adopted in conjunction with the LAER that
is recorded in the major NSR permit, and subsequently reflected in the
title V permit.
(A) The owner or operator may not make a physical change in or
change in the method of operation of the Clean Unit that causes the
emissions unit to function in a manner that is inconsistent with the
physical or operational characteristics that formed the basis for the
LAER determination (e.g., possibly the emissions unit's capacity or
throughput).
(B) The Clean Unit may not emit above a level that has been offset.
(ii) The Clean Unit must comply with any terms and conditions in the
title V permit related to the unit's Clean Unit designation.
(iii) The Clean Unit must continue to control emissions using the
specific air pollution control technology that was the basis for its
Clean Unit designation. If the emissions unit or control technology is
replaced, then the Clean Unit designation ends.
(8) Offsets and netting at Clean Units. Emissions changes that occur
at a Clean Unit must not be included in calculating a significant net
emissions increase (that is, must not be used in a ``netting
analysis''), or be used for generating offsets unless such use occurs
before the effective date of the Clean Unit designation, or after the
Clean Unit designation expires; or, unless the emissions unit reduces
emissions below the level that qualified the unit as a Clean Unit.
However, if the Clean Unit reduces emissions below the level that
qualified the unit as a Clean Unit, then, the owner or operator may
generate a credit for the difference between the level that qualified
the unit as a Clean Unit and the new emission limitation if such
reductions are surplus, quantifiable, and permanent. For purposes of
generating offsets, the reductions must also be federally enforceable.
For purposes of determining creditable net emissions increases and
decreases, the reductions must also be enforceable as a practical
matter.
(9) Effect of redesignation on the Clean Unit designation. The Clean
Unit designation of an emissions unit is not affected by redesignation
of the attainment status of the area in which it is located. That is, if
a Clean Unit is located in an attainment area and the area is
redesignated to nonattainment, its Clean Unit designation is not
affected. Similarly, redesignation from nonattainment to attainment does
not affect the Clean Unit designation. However, if an existing Clean
Unit designation expires, it must re-qualify under the requirements that
are currently applicable in the area.
(d) Clean Unit provisions for emissions units that achieve an
emission limitation comparable to LAER. The plan shall provide an owner
or operator of a major stationary source the option of using the Clean
Unit Test to determine whether emissions increases at a Clean
[[Page 184]]
Unit are part of a project that is a major modification according to the
provisions in paragraphs (d)(1) through (11) of this section.
(1) Applicability. The provisions of this paragraph (d) apply to
emissions units which do not qualify as Clean Units under paragraph (c)
of this section, but which are achieving a level of emissions control
comparable to LAER, as determined by the reviewing authority in
accordance with this paragraph (d).
(2) General provisions for Clean Units. The provisions in paragraphs
(d)(2)(i) through (iv) of this section apply to a Clean Unit (designated
under this paragraph (d)).
(i) Any project for which the owner or operator begins actual
construction after the effective date of the Clean Unit designation (as
determined in accordance with paragraph (d)(5) of this section) and
before the expiration date (as determined in accordance with paragraph
(d)(6) of this section) will be considered to have occurred while the
emissions unit was a Clean Unit.
(ii) If a project at a Clean Unit does not cause the need for a
change in the emission limitations or work practice requirements in the
permit for the unit that have been determined (pursuant to paragraph
(d)(4) of this section) to be comparable to LAER, and the project would
not alter any physical or operational characteristics that formed the
basis for determining that the emissions unit's control technology
achieves a level of emissions control comparable to LAER as specified in
paragraph (d)(8)(iv) of this section, the emissions unit remains a Clean
Unit.
(iii) If a project causes the need for a change in the emission
limitations or work practice requirements in the permit for the unit
that have been determined (pursuant to paragraph (d)(4) of this section)
to be comparable to LAER, or the project would alter any physical or
operational characteristics that formed the basis for determining that
the emissions unit's control technology achieves a level of emissions
control comparable to LAER as specified in paragraph (d)(8)(iv) of this
section, then the emissions unit loses its designation as a Clean Unit
upon issuance of the necessary permit revisions (unless the unit re-
qualifies as a Clean Unit pursuant to paragraph (d)(3)(iv) of this
section). If the owner or operator begins actual construction on the
project without first applying to revise the emissions unit's permit,
the Clean Unit designation ends immediately prior to the time when
actual construction begins.
(iv) A project that causes an emissions unit to lose its designation
as a Clean Unit is subject to the applicability requirements of
paragraphs (a)(2)(ii)(A) through (D) and paragraph (a)(2)(ii)(F) of this
section as if the emissions unit were never a Clean Unit.
(3) Qualifying or re-qualifying to use the Clean Unit applicability
test. An emissions unit qualifies as a Clean Unit when the unit meets
the criteria in paragraphs (d)(3)(i) through (iii) of this section.
After the original Clean Unit designation expires in accordance with
paragraph (d)(6) of this section or is lost pursuant to paragraph
(d)(2)(iii) of this section, such emissions unit may re-qualify as a
Clean Unit under either paragraph (d)(3)(iv) of this section, or under
the Clean Unit provisions in paragraph (c) of this section. To re-
qualify as a Clean Unit under paragraph (d)(3)(iv) of this section, the
emissions unit must obtain a new permit issued pursuant to the
requirements in paragraphs (d)(7) and (8) of this section and meet all
the criteria in paragraph (d)(3)(iv) of this section. The reviewing
authority will make a separate Clean Unit designation for each pollutant
emitted by the emissions unit for which the emissions unit qualifies as
a Clean Unit.
(i) Qualifying air pollution control technologies. Air pollutant
emissions from the emissions unit must be reduced through the use of air
pollution control technology (which includes pollution prevention as
defined under paragraph (a)(1)(xxvi) of this section or work practices)
that meets both the following requirements in paragraphs (d)(3)(i)(A)
and (B) of this section.
(A) The owner or operator has demonstrated that the emissions unit's
control technology is comparable to LAER according to the requirements
of paragraph (d)(4) of this section. However, the emissions unit is not
eligible
[[Page 185]]
for the Clean Unit designation if its emissions are not reduced below
the level of a standard, uncontrolled emissions unit of the same type
(e.g., if the LAER determinations to which it is compared have resulted
in a determination that no control measures are required).
(B) The owner or operator made an investment to install the control
technology. For the purpose of this determination, an investment
includes expenses to research the application of a pollution prevention
technique to the emissions unit or to retool the unit to apply a
pollution prevention technique.
(ii) Impact of emissions from the unit. The reviewing authority must
determine that the allowable emissions from the emissions unit will not
cause or contribute to a violation of any national ambient air quality
standard or PSD increment, or adversely impact an air quality related
value (such as visibility) that has been identified for a Federal Class
I area by a Federal Land Manager and for which information is available
to the general public.
(iii) Date of installation. An emissions unit may qualify as a Clean
Unit even if the control technology, on which the Clean Unit designation
is based, was installed before the effective date of plan requirements
to implement the requirements of this paragraph (d)(3)(iii). However,
for such emissions units, the owner or operator must apply for the Clean
Unit designation within 2 years after the plan requirements become
effective. For technologies installed after the plan requirements become
effective, the owner or operator must apply for the Clean Unit
designation at the time the control technology is installed.
(iv) Re-qualifying as a Clean Unit. The emissions unit must obtain a
new permit (pursuant to requirements in paragraphs (d)(7) and (8) of
this section) that demonstrates that the emissions unit's control
technology is achieving a level of emission control comparable to
current-day LAER, and the emissions unit must meet the requirements in
paragraphs (d)(3)(i)(A) and (d)(3)(ii) of this section.
(4) Demonstrating control effectiveness comparable to LAER. The
owner or operator may demonstrate that the emissions unit's control
technology is comparable to LAER for purposes of paragraph (d)(3)(i) of
this section according to either paragraph (d)(4)(i) or (ii) of this
section. Paragraph (d)(4)(iii) of this section specifies the time for
making this comparison.
(i) Comparison to previous LAER determinations. The administrator
maintains an on-line data base of previous determinations of RACT, BACT,
and LAER in the RACT/BACT/LAER Clearinghouse (RBLC). The emissions
unit's control technology is presumed to be comparable to LAER if it
achieves an emission limitation that is at least as stringent as any one
of the five best-performing similar sources for which a LAER
determination has been made within the preceding 5 years, and for which
information has been entered into the RBLC. The reviewing authority
shall also compare this presumption to any additional LAER
determinations of which it is aware, and shall consider any information
on achieved-in-practice pollution control technologies provided during
the public comment period, to determine whether any presumptive
determination that the control technology is comparable to LAER is
correct.
(ii) The substantially-as-effective test. The owner or operator may
demonstrate that the emissions unit's control technology is
substantially as effective as LAER. In addition, any other person may
present evidence related to whether the control technology is
substantially as effective as LAER during the public participation
process required under paragraph (d)(7) of this section. The reviewing
authority shall consider such evidence on a case-by-case basis and
determine whether the emissions unit's air pollution control technology
is substantially as effective as LAER.
(iii) Time of comparison--(A) Emissions units with control
technologies that are installed before the effective date of plan
requirements implementing this paragraph. The owner or operator of an
emissions unit whose control technology is installed before the
effective date of plan requirements implementing this paragraph (d) may,
at its option, either demonstrate that the emission limitation achieved
by the
[[Page 186]]
emissions unit's control technology is comparable to the LAER
requirements that applied at the time the control technology was
installed, or demonstrate that the emission limitation achieved by the
emissions unit's control technology is comparable to current-day LAER
requirements. The expiration date of the Clean Unit designation will
depend on which option the owner or operator uses, as specified in
paragraph (d)(6) of this section.
(B) Emissions units with control technologies that are installed
after the effective date of plan requirements implementing this
paragraph. The owner or operator must demonstrate that the emission
limitation achieved by the emissions unit's control technology is
comparable to current-day LAER requirements.
(5) Effective date of the Clean Unit designation. The effective date
of an emissions unit's Clean Unit designation (that is, the date on
which the owner or operator may begin to use the Clean Unit Test to
determine whether a project involving the emissions unit is a major
modification) is the date that the permit required by paragraph (d)(7)
of this section is issued or the date that the emissions unit's air
pollution control technology is placed into service, whichever is later.
(6) Clean Unit expiration. If the owner or operator demonstrates
that the emission limitation achieved by the emissions unit's control
technology is comparable to the LAER requirements that applied at the
time the control technology was installed, then the Clean Unit
designation expires 10 years from the date that the control technology
was installed. For all other emissions units, the Clean Unit designation
expires 10 years from the effective date of the Clean Unit designation,
as determined according to paragraph (d)(5) of this section. In
addition, for all emissions units, the Clean Unit designation expires
any time the owner or operator fails to comply with the provisions for
maintaining the Clean Unit designation in paragraph (d)(9) of this
section.
(7) Procedures for designating emissions units as Clean Units. The
reviewing authority shall designate an emissions unit a Clean Unit only
by issuing a permit through a permitting program that has been approved
by the Administrator and that conforms with the requirements of
Secs. 51.160 through 51.164 of this chapter including requirements for
public notice of the proposed Clean Unit designation and opportunity for
public comment. Such permit must also meet the requirements in paragraph
(d)(8).
(8) Required permit content. The permit required by paragraph (d)(7)
of this section shall include the terms and conditions set forth in
paragraphs (d)(8)(i) through (vi) of this section. Such terms and
conditions shall be incorporated into the major stationary source's
title V permit in accordance with the provisions of the applicable title
V permit program under part 70 or part 71 of this chapter, but no later
than when the title V permit is renewed.
(i) A statement indicating that the emissions unit qualifies as a
Clean Unit and identifying the pollutant(s) for which this designation
applies.
(ii) The effective date of the Clean Unit designation. If this date
is not known when the reviewing authority issues the permit (e.g.,
because the air pollution control technology is not yet in service),
then the permit must describe the event that will determine the
effective date (e.g., the date the control technology is placed into
service). Once the effective date is known, then the owner or operator
must notify the reviewing authority of the exact date. This specific
effective date must be added to the source's title V permit at the first
opportunity, such as a modification, revision, reopening, or renewal of
the title V permit for any reason, whichever comes first, but in no case
later than the next renewal.
(iii) The expiration date of the Clean Unit designation. If this
date is not known when the reviewing authority issues the permit (e.g.,
because the air pollution control technology is not yet in service),
then the permit must describe the event that will determine the
expiration date (e.g., the date the control technology is placed into
service). Once the expiration date is known, then the owner or operator
must notify the reviewing authority of the exact date. The expiration
date
[[Page 187]]
must be added to the source's title V permit at the first opportunity,
such as a modification, revision, reopening, or renewal of the title V
permit for any reason, whichever comes first, but in no case later than
the next renewal.
(iv) All emission limitations and work practice requirements adopted
in conjunction with emission limitations necessary to assure that the
control technology continues to achieve an emission limitation
comparable to LAER, and any physical or operational characteristics that
formed the basis for determining that the emissions unit's control
technology achieves a level of emissions control comparable to LAER
(e.g., possibly the emissions unit's capacity or throughput).
(v) Monitoring, recordkeeping, and reporting requirements as
necessary to demonstrate that the emissions unit continues to meet the
criteria for maintaining its Clean Unit designation. (See paragraph
(d)(9) of this section.)
(vi) Terms reflecting the owner or operator's duties to maintain the
Clean Unit designation and the consequences of failing to do so, as
presented in paragraph (d)(9) of this section.
(9) Maintaining Clean Unit designation. To maintain Clean Unit
designation, the owner or operator must conform to all the restrictions
listed in paragraphs (d)(9)(i) through (v) of this section. This
paragraph (d)(9) applies independently to each pollutant for which the
reviewing authority has designated the emissions unit a Clean Unit. That
is, failing to conform to the restrictions for one pollutant affects the
Clean Unit designation only for that pollutant.
(i) The Clean Unit must comply with the emission limitation(s) and/
or work practice requirements adopted to ensure that the control
technology continues to achieve emission control comparable to LAER.
(ii) The owner or operator may not make a physical change in or
change in the method of operation of the Clean Unit that causes the
emissions unit to function in a manner that is inconsistent with the
physical or operational characteristics that formed the basis for the
determination that the control technology is achieving a level of
emission control that is comparable to LAER (e.g., possibly the
emissions unit's capacity or throughput).
(iii) The Clean Unit may not emit above a level that has been
offset.
(iv) The Clean Unit must comply with any terms and conditions in the
title V permit related to the unit's Clean Unit designation.
(v) The Clean Unit must continue to control emissions using the
specific air pollution control technology that was the basis for its
Clean Unit designation. If the emissions unit or control technology is
replaced, then the Clean Unit designation ends.
(10) Offsets and Netting at Clean Units. Emissions changes that
occur at a Clean Unit must not be included in calculating a significant
net emissions increase (that is, must not be used in a ``netting
analysis''), or be used for generating offsets unless such use occurs
before the effective date of plan requirements adopted to implement this
paragraph (d) or after the Clean Unit designation expires; or, unless
the emissions unit reduces emissions below the level that qualified the
unit as a Clean Unit. However, if the Clean Unit reduces emissions below
the level that qualified the unit as a Clean Unit, then the owner or
operator may generate a credit for the difference between the level that
qualified the unit as a Clean Unit and the emissions unit's new emission
limitation if such reductions are surplus, quantifiable, and permanent.
For purposes of generating offsets, the reductions must also be
federally enforceable. For purposes of determining creditable net
emissions increases and decreases, the reductions must also be
enforceable as a practical matter.
(11) Effect of redesignation on the Clean Unit designation. The
Clean Unit designation of an emissions unit is not affected by
redesignation of the attainment status of the area in which it is
located. That is, if a Clean Unit is located in an attainment area and
the area is redesignated to nonattainment, its Clean Unit designation is
not affected. Similarly, redesignation from nonattainment to attainment
does not affect the Clean Unit designation. However, if a Clean Unit's
designation expires or is lost pursuant to paragraphs (c)(2)(iii) and
(d)(2)(iii) of this section,
[[Page 188]]
it must re-qualify under the requirements that are currently applicable.
(e) PCP exclusion procedural requirements. Each plan shall include
provisions for PCPs equivalent to those contained in paragraphs (e)(1)
through (6) of this section.
(1) Before an owner or operator begins actual construction of a PCP,
the owner or operator must either submit a notice to the reviewing
authority if the project is listed in paragraphs (a)(1)(xxv)(A) through
(F) of this section, or if the project is not listed in paragraphs
(a)(1)(xxv)(A) through (F) of this section, then the owner or operator
must submit a permit application and obtain approval to use the PCP
exclusion from the reviewing authority consistent with the requirements
in paragraph (e)(5) of this section. Regardless of whether the owner or
operator submits a notice or a permit application, the project must meet
the requirements in paragraph (e)(2) of this section, and the notice or
permit application must contain the information required in paragraph
(e)(3) of this section.
(2) Any project that relies on the PCP exclusion must meet the
requirements in paragraphs (e)(2)(i) and (ii) of this section.
(i) Environmentally beneficial analysis. The environmental benefit
from the emission reductions of pollutants regulated under the Act must
outweigh the environmental detriment of emissions increases in
pollutants regulated under the Act. A statement that a technology from
paragraphs (a)(1)(xxv)(A) through (F) of this section is being used
shall be presumed to satisfy this requirement.
(ii) Air quality analysis. The emissions increases from the project
will not cause or contribute to a violation of any national ambient air
quality standard or PSD increment, or adversely impact an air quality
related value (such as visibility) that has been identified for a
Federal Class I area by a Federal Land Manager and for which information
is available to the general public.
(3) Content of notice or permit application. In the notice or permit
application sent to the reviewing authority, the owner or operator must
include, at a minimum, the information listed in paragraphs (e)(3)(i)
through (v) of this section.
(i) A description of the project.
(ii) The potential emissions increases and decreases of any
pollutant regulated under the Act and the projected emissions increases
and decreases using the methodology in paragraph (a)(2)(ii) of this
section, that will result from the project, and a copy of the
environmentally beneficial analysis required by paragraph (e)(2)(i) of
this section.
(iii) A description of monitoring and recordkeeping, and all other
methods, to be used on an ongoing basis to demonstrate that the project
is environmentally beneficial. Methods should be sufficient to meet the
requirements in part 70 and part 71.
(iv) A certification that the project will be designed and operated
in a manner that is consistent with proper industry and engineering
practices, in a manner that is consistent with the environmentally
beneficial analysis and air quality analysis required by paragraphs
(e)(2)(i) and (ii) of this section, with information submitted in the
notice or permit application, and in such a way as to minimize, within
the physical configuration and operational standards usually associated
with the emissions control device or strategy, emissions of collateral
pollutants.
(v) Demonstration that the PCP will not have an adverse air quality
impact (e.g., modeling, screening level modeling results, or a statement
that the collateral emissions increase is included within the parameters
used in the most recent modeling exercise) as required by paragraph
(e)(2)(ii) of this section. An air quality impact analysis is not
required for any pollutant which will not experience a significant
emissions increase as a result of the project.
(4) Notice process for listed projects. For projects listed in
paragraphs (a)(1)(xxv)(A) through (F) of this section, the owner or
operator may begin actual construction of the project immediately after
notice is sent to the reviewing authority (unless otherwise prohibited
under requirements of the applicable plan). The owner or operator
[[Page 189]]
shall respond to any requests by its reviewing authority for additional
information that the reviewing authority determines is necessary to
evaluate the suitability of the project for the PCP exclusion.
(5) Permit process for unlisted projects. Before an owner or
operator may begin actual construction of a PCP project that is not
listed in paragraphs (a)(1)(xxv)(A) through (F) of this section, the
project must be approved by the reviewing authority and recorded in a
plan-approved permit or title V permit using procedures that are
consistent with Secs. 51.160 and 51.161 of this chapter. This includes
the requirement that the reviewing authority provide the public with
notice of the proposed approval, with access to the environmentally
beneficial analysis and the air quality analysis, and provide at least a
30-day period for the public and the Administrator to submit comments.
The reviewing authority must address all material comments received by
the end of the comment period before taking final action on the permit.
(6) Operational requirements. Upon installation of the PCP, the
owner or operator must comply with the requirements of paragraphs
(e)(6)(i) through (iii) of this section.
(i) General duty. The owner or operator must operate the PCP in a
manner consistent with proper industry and engineering practices, in a
manner that is consistent with the environmentally beneficial analysis
and air quality analysis required by paragraphs (e)(2)(i) and (ii) of
this section, with information submitted in the notice or permit
application required by paragraph (e)(3) of this section, and in such a
way as to minimize, within the physical configuration and operational
standards usually associated with the emissions control device or
strategy, emissions of collateral pollutants.
(ii) Recordkeeping. The owner or operator must maintain copies on
site of the environmentally beneficial analysis, the air quality impacts
analysis, and monitoring and other emission records to prove that the
PCP operated consistent with the general duty requirements in paragraph
(e)(6)(i) of this section.
(iii) Permit requirements. The owner or operator must comply with
any provisions in the plan-approved permit or title V permit related to
use and approval of the PCP exclusion.
(iv) Generation of emission reduction credits. Emission reductions
created by a PCP shall not be included in calculating a significant net
emissions increase, or be used for generating offsets, unless the
emissions unit further reduces emissions after qualifying for the PCP
exclusion (e.g., taking an operational restriction on the hours of
operation). The owner or operator may generate a credit for the
difference between the level of reduction which was used to qualify for
the PCP exclusion and the new emission limitation if such reductions are
surplus, quantifiable, and permanent. For purposes of generating
offsets, the reductions must also be federally enforceable. For purposes
of determining creditable net emissions increases and decreases, the
reductions must also be enforceable as a practical matter.
(f) Actuals PALs. The plan shall provide for PALs according to the
provisions in paragraphs (f)(1) through (15) of this section.
(1) Applicability.
(i) The reviewing authority may approve the use of an actuals PAL
for any existing major stationary source (except as provided in
paragraph (f)(1)(ii) of this section) if the PAL meets the requirements
in paragraphs (f)(1) through (15) of this section. The term ``PAL''
shall mean ``actuals PAL'' throughout paragraph (f) of this section.
(ii) The reviewing authority shall not allow an actuals PAL for VOC
or NOX for any major stationary source located in an extreme
ozone nonattainment area.
(iii) Any physical change in or change in the method of operation of
a major stationary source that maintains its total source-wide emissions
below the PAL level, meets the requirements in paragraphs (f)(1) through
(15) of this section, and complies with the PAL permit:
(A) Is not a major modification for the PAL pollutant;
[[Page 190]]
(B) Does not have to be approved through the plan's nonattainment
major NSR program; and
(C) Is not subject to the provisions in paragraph (a)(5)(ii) of this
section (restrictions on relaxing enforceable emission limitations that
the major stationary source used to avoid applicability of the
nonattainment major NSR program).
(iv) Except as provided under paragraph (f)(1)(iii)(C) of this
section, a major stationary source shall continue to comply with all
applicable Federal or State requirements, emission limitations, and work
practice requirements that were established prior to the effective date
of the PAL.
(2) Definitions. The plan shall use the definitions in paragraphs
(f)(2)(i) through (xi) of this section for the purpose of developing and
implementing regulations that authorize the use of actuals PALs
consistent with paragraphs (f)(1) through (15) of this section. When a
term is not defined in these paragraphs, it shall have the meaning given
in paragraph (a)(1) of this section or in the Act.
(i) Actuals PAL for a major stationary source means a PAL based on
the baseline actual emissions (as defined in paragraph (a)(1)(xxxv) of
this section) of all emissions units (as defined in paragraph
(a)(1)(vii) of this section) at the source, that emit or have the
potential to emit the PAL pollutant.
(ii) Allowable emissions means ``allowable emissions'' as defined in
paragraph (a)(1)(xi) of this section, except as this definition is
modified according to paragraphs (f)(2)(ii)(A) through (B) of this
section.
(A) The allowable emissions for any emissions unit shall be
calculated considering any emission limitations that are enforceable as
a practical matter on the emissions unit's potential to emit.
(B) An emissions unit's potential to emit shall be determined using
the definition in paragraph (a)(1)(iii) of this section, except that the
words ``or enforceable as a practical matter'' should be added after
``federally enforceable.''
(iii) Small emissions unit means an emissions unit that emits or has
the potential to emit the PAL pollutant in an amount less than the
significant level for that PAL pollutant, as defined in paragraph
(a)(1)(x) of this section or in the Act, whichever is lower.
(iv) Major emissions unit means:
(A) Any emissions unit that emits or has the potential to emit 100
tons per year or more of the PAL pollutant in an attainment area; or
(B) Any emissions unit that emits or has the potential to emit the
PAL pollutant in an amount that is equal to or greater than the major
source threshold for the PAL pollutant as defined by the Act for
nonattainment areas. For example, in accordance with the definition of
major stationary source in section 182(c) of the Act, an emissions unit
would be a major emissions unit for VOC if the emissions unit is located
in a serious ozone nonattainment area and it emits or has the potential
to emit 50 or more tons of VOC per year.
(v) Plantwide applicability limitation (PAL) means an emission
limitation expressed in tons per year, for a pollutant at a major
stationary source, that is enforceable as a practical matter and
established source-wide in accordance with paragraphs (f)(1) through
(f)(15) of this section.
(vi) PAL effective date generally means the date of issuance of the
PAL permit. However, the PAL effective date for an increased PAL is the
date any emissions unit which is part of the PAL major modification
becomes operational and begins to emit the PAL pollutant.
(vii) PAL effective period means the period beginning with the PAL
effective date and ending 10 years later.
(viii) PAL major modification means, notwithstanding paragraphs
(a)(1)(v) and (vi) of this section (the definitions for major
modification and net emissions increase), any physical change in or
change in the method of operation of the PAL source that causes it to
emit the PAL pollutant at a level equal to or greater than the PAL.
(ix) PAL permit means the major NSR permit, the minor NSR permit, or
the State operating permit under a program that is approved into the
plan, or the title V permit issued by the reviewing authority that
establishes a PAL for a major stationary source.
[[Page 191]]
(x) PAL pollutant means the pollutant for which a PAL is established
at a major stationary source.
(xi) Significant emissions unit means an emissions unit that emits
or has the potential to emit a PAL pollutant in an amount that is equal
to or greater than the significant level (as defined in paragraph
(a)(1)(x) of this section or in the Act, whichever is lower) for that
PAL pollutant, but less than the amount that would qualify the unit as a
major emissions unit as defined in paragraph (f)(2)(iv) of this section.
(3) Permit application requirements. As part of a permit application
requesting a PAL, the owner or operator of a major stationary source
shall submit the following information to the reviewing authority for
approval:
(i) A list of all emissions units at the source designated as small,
significant or major based on their potential to emit. In addition, the
owner or operator of the source shall indicate which, if any, Federal or
State applicable requirements, emission limitations or work practices
apply to each unit.
(ii) Calculations of the baseline actual emissions (with supporting
documentation). Baseline actual emissions are to include emissions
associated not only with operation of the unit, but also emissions
associated with startup, shutdown and malfunction.
(iii) The calculation procedures that the major stationary source
owner or operator proposes to use to convert the monitoring system data
to monthly emissions and annual emissions based on a 12-month rolling
total for each month as required by paragraph (f)(13)(i) of this
section.
(4) General requirements for establishing PALs. (i) The plan allows
the reviewing authority to establish a PAL at a major stationary source,
provided that at a minimum, the requirements in paragraphs (f)(4)(i)(A)
through (G) of this section are met.
(A) The PAL shall impose an annual emission limitation in tons per
year, that is enforceable as a practical matter, for the entire major
stationary source. For each month during the PAL effective period after
the first 12 months of establishing a PAL, the major stationary source
owner or operator shall show that the sum of the monthly emissions from
each emissions unit under the PAL for the previous 12 consecutive months
is less than the PAL (a 12-month average, rolled monthly). For each
month during the first 11 months from the PAL effective date, the major
stationary source owner or operator shall show that the sum of the
preceding monthly emissions from the PAL effective date for each
emissions unit under the PAL is less than the PAL.
(B) The PAL shall be established in a PAL permit that meets the
public participation requirements in paragraph (f)(5) of this section.
(C) The PAL permit shall contain all the requirements of paragraph
(f)(7) of this section.
(D) The PAL shall include fugitive emissions, to the extent
quantifiable, from all emissions units that emit or have the potential
to emit the PAL pollutant at the major stationary source.
(E) Each PAL shall regulate emissions of only one pollutant.
(F) Each PAL shall have a PAL effective period of 10 years.
(G) The owner or operator of the major stationary source with a PAL
shall comply with the monitoring, recordkeeping, and reporting
requirements provided in paragraphs (f)(12) through (14) of this section
for each emissions unit under the PAL through the PAL effective period.
(ii) At no time (during or after the PAL effective period) are
emissions reductions of a PAL pollutant, which occur during the PAL
effective period, creditable as decreases for purposes of offsets under
paragraph (a)(3)(ii) of this section unless the level of the PAL is
reduced by the amount of such emissions reductions and such reductions
would be creditable in the absence of the PAL.
(5) Public participation requirement for PALs. PALs for existing
major stationary sources shall be established, renewed, or increased
through a procedure that is consistent with Secs. 51.160 and 51.161 of
this chapter. This includes the requirement that the reviewing authority
provide the public with notice of the proposed approval of a PAL permit
and at least a 30-day period for
[[Page 192]]
submittal of public comment. The reviewing authority must address all
material comments before taking final action on the permit.
(6) Setting the 10-year actuals PAL level. The plan shall provide
that the actuals PAL level for a major stationary source shall be
established as the sum of the baseline actual emissions (as defined in
paragraph (a)(1)(xxxv) of this section) of the PAL pollutant for each
emissions unit at the source; plus an amount equal to the applicable
significant level for the PAL pollutant under paragraph (a)(1)(x) of
this section or under the Act, whichever is lower. When establishing the
actuals PAL level, for a PAL pollutant, only one consecutive 24-month
period must be used to determine the baseline actual emissions for all
existing emissions units. However, a different consecutive 24-month
period may be used for each different PAL pollutant. Emissions
associated with units that were permanently shutdown after this 24-month
period must be subtracted from the PAL level. Emissions from units on
which actual construction began after the 24-month period must be added
to the PAL level in an amount equal to the potential to emit of the
units. The reviewing authority shall specify a reduced PAL level(s) (in
tons/yr) in the PAL permit to become effective on the future compliance
date(s) of any applicable Federal or State regulatory requirement(s)
that the reviewing authority is aware of prior to issuance of the PAL
permit. For instance, if the source owner or operator will be required
to reduce emissions from industrial boilers in half from baseline
emissions of 60 ppm NOX to a new rule limit of 30 ppm, then
the permit shall contain a future effective PAL level that is equal to
the current PAL level reduced by half of the original baseline emissions
of such unit(s).
(7) Contents of the PAL permit. The plan shall require that the PAL
permit contain, at a minimum, the information in paragraphs (f)(7)(i)
through (x) of this section.
(i) The PAL pollutant and the applicable source-wide emission
limitation in tons per year.
(ii) The PAL permit effective date and the expiration date of the
PAL (PAL effective period).
(iii) Specification in the PAL permit that if a major stationary
source owner or operator applies to renew a PAL in accordance with
paragraph (f)(10) of this section before the end of the PAL effective
period, then the PAL shall not expire at the end of the PAL effective
period. It shall remain in effect until a revised PAL permit is issued
by the reviewing authority.
(iv) A requirement that emission calculations for compliance
purposes include emissions from startups, shutdowns and malfunctions.
(v) A requirement that, once the PAL expires, the major stationary
source is subject to the requirements of paragraph (f)(9) of this
section.
(vi) The calculation procedures that the major stationary source
owner or operator shall use to convert the monitoring system data to
monthly emissions and annual emissions based on a 12-month rolling total
for each month as required by paragraph (f)(13)(i) of this section.
(vii) A requirement that the major stationary source owner or
operator monitor all emissions units in accordance with the provisions
under paragraph (f)(12) of this section.
(viii) A requirement to retain the records required under paragraph
(f)(13) of this section on site. Such records may be retained in an
electronic format.
(ix) A requirement to submit the reports required under paragraph
(f)(14) of this section by the required deadlines.
(x) Any other requirements that the reviewing authority deems
necessary to implement and enforce the PAL.
(8) PAL effective period and reopening of the PAL permit. The plan
shall require the information in paragraphs (f)(8)(i) and (ii) of this
section.
(i) PAL effective period. The reviewing authority shall specify a
PAL effective period of 10 years.
(ii) Reopening of the PAL permit. (A) During the PAL effective
period, the plan shall require the reviewing authority to reopen the PAL
permit to:
[[Page 193]]
(1) Correct typographical/calculation errors made in setting the PAL
or reflect a more accurate determination of emissions used to establish
the PAL.
(2) Reduce the PAL if the owner or operator of the major stationary
source creates creditable emissions reductions for use as offsets under
paragraph (a)(3)(ii) of this section.
(3) Revise the PAL to reflect an increase in the PAL as provided
under paragraph (f)(11) of this section.
(B) The plan shall provide the reviewing authority discretion to
reopen the PAL permit for the following:
(1) Reduce the PAL to reflect newly applicable Federal requirements
(for example, NSPS) with compliance dates after the PAL effective date.
(2) Reduce the PAL consistent with any other requirement, that is
enforceable as a practical matter, and that the State may impose on the
major stationary source under the plan.
(3) Reduce the PAL if the reviewing authority determines that a
reduction is necessary to avoid causing or contributing to a NAAQS or
PSD increment violation, or to an adverse impact on an air quality
related value that has been identified for a Federal Class I area by a
Federal Land Manager and for which information is available to the
general public.
(C) Except for the permit reopening in paragraph (f)(8)(ii)(A)(1) of
this section for the correction of typographical/calculation errors that
do not increase the PAL level, all other reopenings shall be carried out
in accordance with the public participation requirements of paragraph
(f)(5) of this section.
(9) Expiration of a PAL. Any PAL which is not renewed in accordance
with the procedures in paragraph (f)(10) of this section shall expire at
the end of the PAL effective period, and the requirements in paragraphs
(f)(9)(i) through (v) of this section shall apply.
(i) Each emissions unit (or each group of emissions units) that
existed under the PAL shall comply with an allowable emission limitation
under a revised permit established according to the procedures in
paragraphs (f)(9)(i)(A) through (B) of this section.
(A) Within the time frame specified for PAL renewals in paragraph
(f)(10)(ii) of this section, the major stationary source shall submit a
proposed allowable emission limitation for each emissions unit (or each
group of emissions units, if such a distribution is more appropriate as
decided by the reviewing authority) by distributing the PAL allowable
emissions for the major stationary source among each of the emissions
units that existed under the PAL. If the PAL had not yet been adjusted
for an applicable requirement that became effective during the PAL
effective period, as required under paragraph (f)(10)(v) of this
section, such distribution shall be made as if the PAL had been
adjusted.
(B) The reviewing authority shall decide whether and how the PAL
allowable emissions will be distributed and issue a revised permit
incorporating allowable limits for each emissions unit, or each group of
emissions units, as the reviewing authority determines is appropriate.
(ii) Each emissions unit(s) shall comply with the allowable emission
limitation on a 12-month rolling basis. The reviewing authority may
approve the use of monitoring systems (source testing, emission factors,
etc.) other than CEMS, CERMS, PEMS or CPMS to demonstrate compliance
with the allowable emission limitation.
(iii) Until the reviewing authority issues the revised permit
incorporating allowable limits for each emissions unit, or each group of
emissions units, as required under paragraph (f)(9)(i)(A) of this
section, the source shall continue to comply with a source-wide, multi-
unit emissions cap equivalent to the level of the PAL emission
limitation.
(iv) Any physical change or change in the method of operation at the
major stationary source will be subject to the nonattainment major NSR
requirements if such change meets the definition of major modification
in paragraph (a)(1)(v) of this section.
(v) The major stationary source owner or operator shall continue to
comply with any State or Federal applicable requirements (BACT, RACT,
NSPS, etc.) that may have applied either during the PAL effective period
or prior to the PAL effective period except for those emission
limitations
[[Page 194]]
that had been established pursuant to paragraph (a)(5)(ii) of this
section, but were eliminated by the PAL in accordance with the
provisions in paragraph (f)(1)(iii)(C) of this section.
(10) Renewal of a PAL. (i) The reviewing authority shall follow the
procedures specified in paragraph (f)(5) of this section in approving
any request to renew a PAL for a major stationary source, and shall
provide both the proposed PAL level and a written rationale for the
proposed PAL level to the public for review and comment. During such
public review, any person may propose a PAL level for the source for
consideration by the reviewing authority.
(ii) Application deadline. The plan shall require that a major
stationary source owner or operator shall submit a timely application to
the reviewing authority to request renewal of a PAL. A timely
application is one that is submitted at least 6 months prior to, but not
earlier than 18 months from, the date of permit expiration. This
deadline for application submittal is to ensure that the permit will not
expire before the permit is renewed. If the owner or operator of a major
stationary source submits a complete application to renew the PAL within
this time period, then the PAL shall continue to be effective until the
revised permit with the renewed PAL is issued.
(iii) Application requirements. The application to renew a PAL
permit shall contain the information required in paragraphs
(f)(10)(iii)(A) through (D) of this section.
(A) The information required in paragraphs (f)(3)(i) through (iii)
of this section.
(B) A proposed PAL level.
(C) The sum of the potential to emit of all emissions units under
the PAL (with supporting documentation).
(D) Any other information the owner or operator wishes the reviewing
authority to consider in determining the appropriate level for renewing
the PAL.
(iv) PAL adjustment. In determining whether and how to adjust the
PAL, the reviewing authority shall consider the options outlined in
paragraphs (f)(10)(iv)(A) and (B) of this section. However, in no case
may any such adjustment fail to comply with paragraph (f)(10)(iv)(C) of
this section.
(A) If the emissions level calculated in accordance with paragraph
(f)(6) of this section is equal to or greater than 80 percent of the PAL
level, the reviewing authority may renew the PAL at the same level
without considering the factors set forth in paragraph (f)(10)(iv)(B) of
this section; or
(B) The reviewing authority may set the PAL at a level that it
determines to be more representative of the source's baseline actual
emissions, or that it determines to be appropriate considering air
quality needs, advances in control technology, anticipated economic
growth in the area, desire to reward or encourage the source's voluntary
emissions reductions, or other factors as specifically identified by the
reviewing authority in its written rationale.
(C) Notwithstanding paragraphs (f)(10)(iv)(A) and (B) of this
section,
(1) If the potential to emit of the major stationary source is less
than the PAL, the reviewing authority shall adjust the PAL to a level no
greater than the potential to emit of the source; and
(2) The reviewing authority shall not approve a renewed PAL level
higher than the current PAL, unless the major stationary source has
complied with the provisions of paragraph (f)(11) of this section
(increasing a PAL).
(v) If the compliance date for a State or Federal requirement that
applies to the PAL source occurs during the PAL effective period, and if
the reviewing authority has not already adjusted for such requirement,
the PAL shall be adjusted at the time of PAL permit renewal or title V
permit renewal, whichever occurs first.
(11) Increasing a PAL during the PAL effective period. (i) The plan
shall require that the reviewing authority may increase a PAL emission
limitation only if the major stationary source complies with the
provisions in paragraphs (f)(11)(i)(A) through (D) of this section.
(A) The owner or operator of the major stationary source shall
submit a complete application to request an increase in the PAL limit
for a PAL major modification. Such application
[[Page 195]]
shall identify the emissions unit(s) contributing to the increase in
emissions so as to cause the major stationary source's emissions to
equal or exceed its PAL.
(B) As part of this application, the major stationary source owner
or operator shall demonstrate that the sum of the baseline actual
emissions of the small emissions units, plus the sum of the baseline
actual emissions of the significant and major emissions units assuming
application of BACT equivalent controls, plus the sum of the allowable
emissions of the new or modified emissions unit(s) exceeds the PAL. The
level of control that would result from BACT equivalent controls on each
significant or major emissions unit shall be determined by conducting a
new BACT analysis at the time the application is submitted, unless the
emissions unit is currently required to comply with a BACT or LAER
requirement that was established within the preceding 10 years. In such
a case, the assumed control level for that emissions unit shall be equal
to the level of BACT or LAER with which that emissions unit must
currently comply.
(C) The owner or operator obtains a major NSR permit for all
emissions unit(s) identified in paragraph (f)(11)(i)(A) of this section,
regardless of the magnitude of the emissions increase resulting from
them (that is, no significant levels apply). These emissions unit(s)
shall comply with any emissions requirements resulting from the
nonattainment major NSR program process (for example, LAER), even though
they have also become subject to the PAL or continue to be subject to
the PAL.
(D) The PAL permit shall require that the increased PAL level shall
be effective on the day any emissions unit that is part of the PAL major
modification becomes operational and begins to emit the PAL pollutant.
(ii) The reviewing authority shall calculate the new PAL as the sum
of the allowable emissions for each modified or new emissions unit, plus
the sum of the baseline actual emissions of the significant and major
emissions units (assuming application of BACT equivalent controls as
determined in accordance with paragraph (f)(11)(i)(B)), plus the sum of
the baseline actual emissions of the small emissions units.
(iii) The PAL permit shall be revised to reflect the increased PAL
level pursuant to the public notice requirements of paragraph (f)(5) of
this section.
(12) Monitoring requirements for PALs--(i) General requirements.
(A) Each PAL permit must contain enforceable requirements for the
monitoring system that accurately determines plantwide emissions of the
PAL pollutant in terms of mass per unit of time. Any monitoring system
authorized for use in the PAL permit must be based on sound science and
meet generally acceptable scientific procedures for data quality and
manipulation. Additionally, the information generated by such system
must meet minimum legal requirements for admissibility in a judicial
proceeding to enforce the PAL permit.
(B) The PAL monitoring system must employ one or more of the four
general monitoring approaches meeting the minimum requirements set forth
in paragraphs (f)(12)(ii)(A) through (D) of this section and must be
approved by the reviewing authority.
(C) Notwithstanding paragraph (f)(12)(i)(B) of this section, you may
also employ an alternative monitoring approach that meets paragraph
(f)(12)(i)(A) of this section if approved by the reviewing authority.
(D) Failure to use a monitoring system that meets the requirements
of this section renders the PAL invalid.
(ii) Minimum Performance Requirements for Approved Monitoring
Approaches. The following are acceptable general monitoring approaches
when conducted in accordance with the minimum requirements in paragraphs
(f)(12)(iii) through (ix) of this section:
(A) Mass balance calculations for activities using coatings or
solvents;
(B) CEMS;
(C) CPMS or PEMS; and
(D) Emission Factors.
(iii) Mass Balance Calculations. An owner or operator using mass
balance calculations to monitor PAL pollutant emissions from activities
using coating or solvents shall meet the following requirements:
[[Page 196]]
(A) Provide a demonstrated means of validating the published content
of the PAL pollutant that is contained in or created by all materials
used in or at the emissions unit;
(B) Assume that the emissions unit emits all of the PAL pollutant
that is contained in or created by any raw material or fuel used in or
at the emissions unit, if it cannot otherwise be accounted for in the
process; and
(C) Where the vendor of a material or fuel, which is used in or at
the emissions unit, publishes a range of pollutant content from such
material, the owner or operator must use the highest value of the range
to calculate the PAL pollutant emissions unless the reviewing authority
determines there is site-specific data or a site-specific monitoring
program to support another content within the range.
(iv) CEMS. An owner or operator using CEMS to monitor PAL pollutant
emissions shall meet the following requirements:
(A) CEMS must comply with applicable Performance Specifications
found in 40 CFR part 60, appendix B; and
(B) CEMS must sample, analyze and record data at least every 15
minutes while the emissions unit is operating.
(v) CPMS or PEMS. An owner or operator using CPMS or PEMS to monitor
PAL pollutant emissions shall meet the following requirements:
(A) The CPMS or the PEMS must be based on current site-specific data
demonstrating a correlation between the monitored parameter(s) and the
PAL pollutant emissions across the range of operation of the emissions
unit; and
(B) Each CPMS or PEMS must sample, analyze, and record data at least
every 15 minutes, or at another less frequent interval approved by the
reviewing authority, while the emissions unit is operating.
(vi) Emission factors. An owner or operator using emission factors
to monitor PAL pollutant emissions shall meet the following
requirements:
(A) All emission factors shall be adjusted, if appropriate, to
account for the degree of uncertainty or limitations in the factors'
development;
(B) The emissions unit shall operate within the designated range of
use for the emission factor, if applicable; and
(C) If technically practicable, the owner or operator of a
significant emissions unit that relies on an emission factor to
calculate PAL pollutant emissions shall conduct validation testing to
determine a site-specific emission factor within 6 months of PAL permit
issuance, unless the reviewing authority determines that testing is not
required.
(vii) A source owner or operator must record and report maximum
potential emissions without considering enforceable emission limitations
or operational restrictions for an emissions unit during any period of
time that there is no monitoring data, unless another method for
determining emissions during such periods is specified in the PAL
permit.
(viii) Notwithstanding the requirements in paragraphs (f)(12)(iii)
through (vii) of this section, where an owner or operator of an
emissions unit cannot demonstrate a correlation between the monitored
parameter(s) and the PAL pollutant emissions rate at all operating
points of the emissions unit, the reviewing authority shall, at the time
of permit issuance:
(A) Establish default value(s) for determining compliance with the
PAL based on the highest potential emissions reasonably estimated at
such operating point(s); or
(B) Determine that operation of the emissions unit during operating
conditions when there is no correlation between monitored parameter(s)
and the PAL pollutant emissions is a violation of the PAL.
(ix) Re-validation. All data used to establish the PAL pollutant
must be re-validated through performance testing or other scientifically
valid means approved by the reviewing authority. Such testing must occur
at least once every 5 years after issuance of the PAL.
(13) Recordkeeping requirements. (i) The PAL permit shall require an
owner or operator to retain a copy of all records necessary to determine
compliance with any requirement of paragraph (f) of this section and of
the PAL, including a determination of each
[[Page 197]]
emissions unit's 12-month rolling total emissions, for 5 years from the
date of such record.
(ii) The PAL permit shall require an owner or operator to retain a
copy of the following records for the duration of the PAL effective
period plus 5 years:
(A) A copy of the PAL permit application and any applications for
revisions to the PAL; and
(B) Each annual certification of compliance pursuant to title V and
the data relied on in certifying the compliance.
(14) Reporting and notification requirements. The owner or operator
shall submit semi-annual monitoring reports and prompt deviation reports
to the reviewing authority in accordance with the applicable title V
operating permit program. The reports shall meet the requirements in
paragraphs (f)(14)(i) through (iii).
(i) Semi-Annual Report. The semi-annual report shall be submitted to
the reviewing authority within 30 days of the end of each reporting
period. This report shall contain the information required in paragraphs
(f)(14)(i)(A) through (G) of this section.
(A) The identification of owner and operator and the permit number.
(B) Total annual emissions (tons/year) based on a 12-month rolling
total for each month in the reporting period recorded pursuant to
paragraph (f)(13)(i) of this section.
(C) All data relied upon, including, but not limited to, any Quality
Assurance or Quality Control data, in calculating the monthly and annual
PAL pollutant emissions.
(D) A list of any emissions units modified or added to the major
stationary source during the preceding 6-month period.
(E) The number, duration, and cause of any deviations or monitoring
malfunctions (other than the time associated with zero and span
calibration checks), and any corrective action taken.
(F) A notification of a shutdown of any monitoring system, whether
the shutdown was permanent or temporary, the reason for the shutdown,
the anticipated date that the monitoring system will be fully
operational or replaced with another monitoring system, and whether the
emissions unit monitored by the monitoring system continued to operate,
and the calculation of the emissions of the pollutant or the number
determined by method included in the permit, as provided by paragraph
(f)(12)(vii) of this section.
(G) A signed statement by the responsible official (as defined by
the applicable title V operating permit program) certifying the truth,
accuracy, and completeness of the information provided in the report.
(ii) Deviation report. The major stationary source owner or operator
shall promptly submit reports of any deviations or exceedance of the PAL
requirements, including periods where no monitoring is available. A
report submitted pursuant to Sec. 70.6(a)(3)(iii)(B) of this chapter
shall satisfy this reporting requirement. The deviation reports shall be
submitted within the time limits prescribed by the applicable program
implementing Sec. 70.6(a)(3)(iii)(B) of this chapter. The reports shall
contain the following information:
(A) The identification of owner and operator and the permit number;
(B) The PAL requirement that experienced the deviation or that was
exceeded;
(C) Emissions resulting from the deviation or the exceedance; and
(D) A signed statement by the responsible official (as defined by
the applicable title V operating permit program) certifying the truth,
accuracy, and completeness of the information provided in the report.
(iii) Re-validation results. The owner or operator shall submit to
the reviewing authority the results of any re-validation test or method
within 3 months after completion of such test or method.
(15) Transition requirements. (i) No reviewing authority may issue a
PAL that does not comply with the requirements in paragraphs (f)(1)
through (15) of this section after the Administrator has approved
regulations incorporating these requirements into a plan.
(ii) The reviewing authority may supersede any PAL which was
established prior to the date of approval of the plan by the
Administrator with a PAL
[[Page 198]]
that complies with the requirements of paragraphs (f)(1) through (15) of
this section.
(g) If any provision of this section, or the application of such
provision to any person or circumstance, is held invalid, the remainder
of this section, or the application of such provision to persons or
circumstances other than those as to which it is held invalid, shall not
be affected thereby.
[51 FR 40669, Nov. 7, 1986, as amended at 52 FR 24713, July 1, 1987; 52
FR 29386, Aug 7, 1987; 54 FR 27285, 27299 June 28, 1989; 57 FR 3946,
Feb. 3, 1992; 57 FR 32334, July 21, 1992; 67 FR 80244, Dec. 31, 2002]
Sec. 51.166 Prevention of significant deterioration of air quality.
(a)(1) Plan requirements. In accordance with the policy of section
101(b)(1) of the Act and the purposes of section 160 of the Act, each
applicable State Implementation Plan and each applicable Tribal
Implementation Plan shall contain emission limitations and such other
measures as may be necessary to prevent significant deterioration of air
quality.
(2) Plan revisions. If a State Implementation Plan revision would
result in increased air quality deterioration over any baseline
concentration, the plan revision shall include a demonstration that it
will not cause or contribute to a violation of the applicable
increment(s). If a plan revision proposing less restrictive requirements
was submitted after August 7, 1977 but on or before any applicable
baseline date and was pending action by the Administrator on that date,
no such demonstration is necessary with respect to the area for which a
baseline date would be established before final action is taken on the
plan revision. Instead, the assessment described in paragraph (a)(4) of
this section, shall review the expected impact to the applicable
increment(s).
(3) Required plan revision. If the State or the Administrator
determines that a plan is substantially inadequate to prevent
significant deterioration or that an applicable increment is being
violated, the plan shall be revised to correct the inadequacy or the
violation. The plan shall be revised within 60 days of such a finding by
a State or within 60 days following notification by the Administrator,
or by such later date as prescribed by the Administrator after
consultation with the State.
(4) Plan assessment. The State shall review the adequacy of a plan
on a periodic basis and within 60 days of such time as information
becomes available that an applicable increment is being violated.
(5) Public participation. Any State action taken under this
paragraph shall be subject to the opportunity for public hearing in
accordance with procedures equivalent to those established in
Sec. 51.102.
(6) Amendments. (i) Any State required to revise its implementation
plan by reason of an amendment to this section, including any amendment
adopted simultaneously with this paragraph (a)(6)(i), shall adopt and
submit such plan revision to the Administrator for approval no later
than three years after such amendment is published in the Federal
Register.
(ii) Any revision to an implementation plan that would amend the
provisions for the prevention of significant air quality deterioration
in the plan shall specify when and as to what sources and modifications
the revision is to take effect.
(iii) Any revision to an implementation plan that an amendment to
this section required shall take effect no later than the date of its
approval and may operate prospectively.
(7) Applicability. Each plan shall contain procedures that
incorporate the requirements in paragraphs (a)(7)(i) through (vi) of
this section.
(i) The requirements of this section apply to the construction of
any new major stationary source (as defined in paragraph (b)(1) of this
section) or any project at an existing major stationary source in an
area designated as attainment or unclassifiable under sections
107(d)(1)(A)(ii) or (iii) of the Act.
(ii) The requirements of paragraphs (j) through (r) of this section
apply to the construction of any new major stationary source or the
major modification of any existing major stationary source, except as
this section otherwise provides.
[[Page 199]]
(iii) No new major stationary source or major modification to which
the requirements of paragraphs (j) through (r)(5) of this section apply
shall begin actual construction without a permit that states that the
major stationary source or major modification will meet those
requirements.
(iv) Each plan shall use the specific provisions of paragraphs
(a)(7)(iv)(a) through (f) of this section. Deviations from these
provisions will be approved only if the State specifically demonstrates
that the submitted provisions are more stringent than or at least as
stringent in all respects as the corresponding provisions in paragraphs
(a)(7)(iv)(a) through (f) of this section.
(a) Except as otherwise provided in paragraphs (a)(7)(v) and (vi) of
this section, and consistent with the definition of major modification
contained in paragraph (b)(2) of this section, a project is a major
modification for a regulated NSR pollutant if it causes two types of
emissions increases--a significant emissions increase (as defined in
paragraph (b)(39) of this section), and a significant net emissions
increase (as defined in paragraphs (b)(3) and (b)(23) of this section).
The project is not a major modification if it does not cause a
significant emissions increase. If the project causes a significant
emissions increase, then the project is a major modification only if it
also results in a significant net emissions increase.
(b) The procedure for calculating (before beginning actual
construction) whether a significant emissions increase (i.e., the first
step of the process) will occur depends upon the type of emissions units
being modified, according to paragraphs (a)(7)(iv)(c) through (f) of
this section. The procedure for calculating (before beginning actual
construction) whether a significant net emissions increase will occur at
the major stationary source (i.e., the second step of the process) is
contained in the definition in paragraph (b)(3) of this section.
Regardless of any such preconstruction projections, a major modification
results if the project causes a significant emissions increase and a
significant net emissions increase.
(c) Actual-to-projected-actual applicability test for projects that
only involve existing emissions units. A significant emissions increase
of a regulated NSR pollutant is projected to occur if the sum of the
difference between the projected actual emissions (as defined in
paragraph (b)(40) of this section) and the baseline actual emissions (as
defined in paragraphs (b)(47)(i) and (ii) of this section) for each
existing emissions unit, equals or exceeds the significant amount for
that pollutant (as defined in paragraph (b)(23) of this section).
(d) Actual-to-potential test for projects that only involve
construction of a new emissions unit(s). A significant emissions
increase of a regulated NSR pollutant is projected to occur if the sum
of the difference between the potential to emit (as defined in paragraph
(b)(4) of this section) from each new emissions unit following
completion of the project and the baseline actual emissions (as defined
in paragraph (b)(47)(iii) of this section) of these units before the
project equals or exceeds the significant amount for that pollutant (as
defined in paragraph (b)(23) of this section).
(e) Emission test for projects that involve Clean Units. For a
project that will be constructed and operated at a Clean Unit without
causing the emissions unit to lose its Clean Unit designation, no
emissions increase is deemed to occur.
(f) Hybrid test for projects that involve multiple types of
emissions units. A significant emissions increase of a regulated NSR
pollutant is projected to occur if the sum of the emissions increases
for each emissions unit, using the method specified in paragraphs
(a)(7)(iv)(c) through (e) of this section as applicable with respect to
each emissions unit, for each type of emissions unit equals or exceeds
the significant amount for that pollutant (as defined in paragraph
(b)(23) of this section). For example, if a project involves both an
existing emissions unit and a Clean Unit, the projected increase is
determined by summing the values determined using the method specified
in paragraph (a)(7)(iv)(c) of this section for the existing unit and
determined using the method specified
[[Page 200]]
in paragraph (a)(7)(iv)(e) of this section for the Clean Unit.
(v) The plan shall require that for any major stationary source for
a PAL for a regulated NSR pollutant, the major stationary source shall
comply with requirements under paragraph (w) of this section.
(vi) The plan shall require that an owner or operator undertaking a
PCP (as defined in paragraph (b)(31) of this section) shall comply with
the requirements under paragraph (v) of this section.
(b) Definitions. All State plans shall use the following definitions
for the purposes of this section. Deviations from the following wording
will be approved only if the State specifically demonstrates that the
submitted definition is more stringent, or at least as stringent, in all
respects as the corresponding definitions below:
(1)(i) Major stationary source means:
(a) Any of the following stationary sources of air pollutants which
emits, or has the potential to emit, 100 tons per year or more of any a
regulated NSR pollutant: Fossil fuel-fired steam electric plants of more
than 250 million British thermal units per hour heat input, coal
cleaning plants (with thermal dryers), kraft pulp mills, portland cement
plants, primary zinc smelters, iron and steel mill plants, primary
aluminum ore reduction plants, primary copper smelters, municipal
incinerators capable of charging more than 250 tons of refuse per day,
hydrofluoric, sulfuric, and nitric acid plants, petroleum refineries,
lime plants, phosphate rock processing plants, coke oven batteries,
sulfur recovery plants, carbon black plants (furnace process), primary
lead smelters, fuel conversion plants, sintering plants, secondary metal
production plants, chemical process plants, fossil fuel boilers (or
combinations thereof) totaling more than 250 million British thermal
units per hour heat input, petroleum storage and transfer units with a
total storage capacity exceeding 300,000 barrels, taconite ore
processing plants, glass fiber processing plants, and charcoal
production plants;
(b) Notwithstanding the stationary source size specified in
paragraph (b)(1)(i)(a) of this section, any stationary source which
emits, or has the potential to emit, 250 tons per year or more of a
regulated NSR pollutant; or
(c) Any physical change that would occur at a stationary source not
otherwise qualifying under paragraph (b)(1) of this section, as a major
stationary source if the change would constitute a major stationary
source by itself.
(ii) A major source that is major for volatile organic compounds
shall be considered major for ozone.
(iii) The fugitive emissions of a stationary source shall not be
included in determining for any of the purposes of this section whether
it is a major stationary source, unless the source belongs to one of the
following categories of stationary sources:
(a) Coal cleaning plants (with thermal dryers);
(b) Kraft pulp mills;
(c) Portland cement plants;
(d) Primary zinc smelters;
(e) Iron and steel mills;
(f) Primary aluminum ore reduction plants;
(g) Primary copper smelters;
(h) Municipal incinerators capable of charging more than 250 tons of
refuse per day;
(i) Hydrofluoric, sulfuric, or nitric acid plants;
(j) Petroleum refineries;
(k) Lime plants;
(l) Phosphate rock processing plants;
(m) Coke oven batteries;
(n) Sulfur recovery plants;
(o) Carbon black plants (furnace process);
(p) Primary lead smelters;
(q) Fuel conversion plants;
(r) Sintering plants;
(s) Secondary metal production plants;
(t) Chemical process plants;
(u) Fossil-fuel boilers (or combination thereof) totaling more than
250 million British thermal units per hour heat input;
(v) Petroleum storage and transfer units with a total storage
capacity exceeding 300,000 barrels;
(w) Taconite ore processing plants;
(x) Glass fiber processing plants;
(y) Charcoal production plants;
(z) Fossil fuel-fired steam electric plants of more that 250 million
British thermal units per hour heat input;
[[Page 201]]
(aa) Any other stationary source category which, as of August 7,
1980, is being regulated under section 111 or 112 of the Act.
(2)(i) Major modification means any physical change in or change in
the method of operation of a major stationary source that would result
in: a significant emissions increase (as defined in paragraph (b)(39) of
this section) of a regulated NSR pollutant (as defined in paragraph
(b)(49) of this section); and a significant net emissions increase of
that pollutant from the major stationary source.
(ii) Any significant emissions increase (as defined at paragraph
(b)(39) of this section) from any emissions units or net emissions
increase (as defined at paragraph (b)(3) of this section) at a major
stationary source that is significant for volatile organic compounds
shall be considered significant for ozone.
(iii) A physical change or change in the method of operation shall
not include:
(a) Routine maintenance, repair, and replacement;
(b) Use of an alternative fuel or raw material by reason of any
order under section 2 (a) and (b) of the Energy Supply and Environmental
Coordination Act of 1974 (or any superseding legislation) or by reason
of a natural gas curtailment plan pursuant to the Federal Power Act;
(c) Use of an alternative fuel by reason of an order or rule under
section 125 of the Act;
(d) Use of an alternative fuel at a steam generating unit to the
extent that the fuel is generated from municipal solid waste;
(e) Use of an alternative fuel or raw material by a stationary
source which:
(1) The source was capable of accommodating before January 6, 1975,
unless such change would be prohibited under any federally enforceable
permit condition which was established after January 6, 1975 pursuant to
40 CFR 52.21 or under regulations approved pursuant to 40 CFR subpart I
or Sec. 51.166; or
(2) The source is approved to use under any permit issued under 40
CFR 52.21 or under regulations approved pursuant to 40 CFR 51.166;
(f) An increase in the hours of operation or in the production rate,
unless such change would be prohibited under any federally enforceable
permit condition which was established after January 6, 1975, pursuant
to 40 CFR 52.21 or under regulations approved pursuant to 40 CFR subpart
I or Sec. 51.166.
(g) Any change in ownership at a stationary source.
(h) The addition, replacement, or use of a PCP, as defined in
paragraph (b)(31) of this section, at an existing emissions unit meeting
the requirements of paragraph (v) of this section. A replacement control
technology must provide more effective emission control than that of the
replaced control technology to qualify for this exclusion.
(i) The installation, operation, cessation, or removal of a
temporary clean coal technology demonstration project, provided that the
project complies with:
(1) The State implementation plan for the State in which the project
is located; and
(2) Other requirements necessary to attain and maintain the national
ambient air quality standards during the project and after it is
terminated.
(j) The installation or operation of a permanent clean coal
technology demonstration project that constitutes repowering, provided
that the project does not result in an increase in the potential to emit
of any regulated pollutant emitted by the unit. This exemption shall
apply on a pollutant-by-pollutant basis.
(k) The reactivation of a very clean coal-fired electric utility
steam generating unit.
(iv) This definition shall not apply with respect to a particular
regulated NSR pollutant when the major stationary source is complying
with the requirements under paragraph (w) of this section for a PAL for
that pollutant. Instead, the definition at paragraph (w)(2)(viii) of
this section shall apply.
(3)(i) Net emissions increase means, with respect to any regulated
NSR pollutant emitted by a major stationary source, the amount by which
the sum of the following exceeds zero:
[[Page 202]]
(a) The increase in emissions from a particular physical change or
change in the method of operation at a stationary source as calculated
pursuant to paragraph (a)(7)(iv) of this section; and
(b) Any other increases and decreases in actual emissions at the
major stationary source that are contemporaneous with the particular
change and are otherwise creditable. Baseline actual emissions for
calculating increases and decreases under this paragraph (b)(3)(i)(b)
shall be determined as provided in paragraph (b)(47), except that
paragraphs (b)(47)(i)(c) and (b)(47)(ii)(d) of this section shall not
apply.
(ii) An increase or decrease in actual emissions is contemporaneous
with the increase from the particular change only if it occurs within a
reasonable period (to be specified by the State) before the date that
the increase from the particular change occurs.
(iii) An increase or decrease in actual emissions is creditable only
if:
(a) It occurs within a reasonable period (to be specified by the
reviewing authority); and
(b) The reviewing authority has not relied on it in issuing a permit
for the source under regulations approved pursuant to this section,
which permit is in effect when the increase in actual emissions from the
particular change occurs; and
(c) The increase or decrease in emissions did not occur at a Clean
Unit, except as provided in paragraphs (t)(8) and (u)(10) of this
section.
(iv) An increase or decrease in actual emissions of sulfur dioxide,
particulate matter, or nitrogen oxides that occurs before the applicable
minor source baseline date is creditable only if it is required to be
considered in calculating the amount of maximum allowable increases
remaining available.
(v) An increase in actual emissions is creditable only to the extent
that the new level of actual emissions exceeds the old level.
(vi) A decrease in actual emissions is creditable only to the extent
that:
(a) The old level of actual emissions or the old level of allowable
emissions, whichever is lower, exceeds the new level of actual
emissions;
(b) It is enforceable as a practical matter at and after the time
that actual construction on the particular change begins;
(c) It has approximately the same qualitative significance for
public health and welfare as that attributed to the increase from the
particular change; and
(d) The decrease in actual emissions did not result from the
installation of add-on control technology or application of pollution
prevention practices that were relied on in designating an emissions
unit as a Clean Unit under Sec. 52.21(y) or under regulations approved
pursuant to paragraph (u) of this section or Sec. 51.165(d). That is,
once an emissions unit has been designated as a Clean Unit, the owner or
operator cannot later use the emissions reduction from the air pollution
control measures that the Clean Unit designation is based on in
calculating the net emissions increase for another emissions unit (i.e.,
must not use that reduction in a ``netting analysis'' for another
emissions unit). However, any new emissions reductions that were not
relied upon in a PCP excluded pursuant to paragraph (v) of this section
or for the Clean Unit designation are creditable to the extent they meet
the requirements in paragraph (v)(6)(iv) of this section for the PCP and
paragraph (t)(8) or (u)(10) of this section for a Clean Unit.
(vii) An increase that results from a physical change at a source
occurs when the emissions unit on which construction occurred becomes
operational and begins to emit a particular pollutant. Any replacement
unit that requires shakedown becomes operational only after a reasonable
shakedown period, not to exceed 180 days.
(viii) Paragraph (b)(21)(ii) of this section shall not apply for
determining creditable increases and decreases.
(4) Potential to emit means the maximum capacity of a stationary
source to emit a pollutant under its physical and operational design.
Any physical or operational limitation on the capacity of the source to
emit a pollutant, including air pollution control equipment and
restrictions on hours of operation or on the type or amount of material
combusted, stored, or processed,
[[Page 203]]
shall be treated as part of its design if the limitation or the effect
it would have on emissions is federally enforceable. Secondary emissions
do not count in determining the potential to emit of a stationary
source.
(5) Stationary source means any building, structure, facility, or
installation which emits or may emit a regulated NSR pollutant.
(6) Building, structure, facility, or installation means all of the
pollutant-emitting activities which belong to the same industrial
grouping, are located on one or more contiguous or adjacent properties,
and are under the control of the same person (or persons under common
control) except the activities of any vessel. Pollutant-emitting
activities shall be considered as part of the same industrial grouping
if they belong to the same Major Group (i.e., which have the same two-
digit code) as described in the Standard Industrial Classification
Manual, 1972, as amended by the 1977 Supplement (U.S. Government
Printing Office stock numbers 4101-0066 and 003-005-00176-0,
respectively).
(7) Emissions unit means any part of a stationary source that emits
or would have the potential to emit any regulated NSR pollutant and
includes an electric utility steam generating unit as defined in
paragraph (b)(30) of this section. For purposes of this section, there
are two types of emissions units as described in paragraphs (b)(7)(i)
and (ii) of this section.
(i) A new emissions unit is any emissions unit that is (or will be)
newly constructed and that has existed for less than 2 years from the
date such emissions unit first operated.
(ii) An existing emissions unit is any emissions unit that does not
meet the requirements in paragraph (b)(7)(i) of this section.
(8) Construction means any physical change or change in the method
of operation (including fabrication, erection, installation, demolition,
or modification of an emissions unit) that would result in a change in
emissions.
(9) Commence as applied to construction of a major stationary source
or major modification means that the owner or operator has all necessary
preconstruction approvals or permits and either has:
(i) Begun, or caused to begin, a continuous program of actual on-
site construction of the source, to be completed within a reasonable
time; or
(ii) Entered into binding agreements or contractual obligations,
which cannot be cancelled or modified without substantial loss to the
owner or operator, to undertake a program of actual construction of the
source to be completed within a reasonable time.
(10) Necessary preconstruction approvals or permits means those
permits or approvals required under Federal air quality control laws and
regulations and those air quality control laws and regulations which are
part of the applicable State Implementation Plan.
(11) Begin actual construction means, in general, initiation of
physical on-site construction activities on an emissions unit which are
of a permanent nature. Such activities include, but are not limited to,
installation of building supports and foundations, laying of underground
pipework, and construction of permanent storage structures. With respect
to a change in method of operation this term refers to those on-site
activities, other than preparatory activities, which mark the initiation
of the change.
(12) Best available control technology means an emissions limitation
(including a visible emissions standard) based on the maximum degree of
reduction for each a regulated NSR pollutant which would be emitted from
any proposed major stationary source or major modification which the
reviewing authority, on a case-by-case basis, taking into account
energy, environmental, and economic impacts and other costs, determines
is achievable for such source or modification through application of
production processes or available methods, systems, and techniques,
including fuel cleaning or treatment or innovative fuel combination
techniques for control of such pollutant. In no event shall application
of best available control technology result in emissions of any
pollutant which would exceed the emissions allowed by any applicable
standard under 40 CFR parts 60 and 61. If the reviewing authority
determines that technological or economic limitations on the application
of
[[Page 204]]
measurement methodology to a particular emissions unit would make the
imposition of an emissions standard infeasible, a design, equipment,
work practice, operational standard or combination thereof, may be
prescribed instead to satisfy the requirement for the application of
best available control technology. Such standard shall, to the degree
possible, set forth the emissions reduction achievable by implementation
of such design, equipment, work practice or operation, and shall provide
for compliance by means which achieve equivalent results.
(13)(i) Baseline concentration means that ambient concentration
level that exists in the baseline area at the time of the applicable
minor source baseline date. A baseline concentration is determined for
each pollutant for which a minor source baseline date is established and
shall include:
(a) The actual emissions, as defined in paragraph (b)(21) of this
section, representative of sources in existence on the applicable minor
source baseline date, except as provided in paragraph (b)(13)(ii) of
this section;
(b) The allowable emissions of major stationary sources that
commenced construction before the major source baseline date, but were
not in operation by the applicable minor source baseline date.
(ii) The following will not be included in the baseline
concentration and will affect the applicable maximum allowable
increase(s):
(a) Actual emissions, as defined in paragraph (b)(21) of this
section, from any major stationary source on which construction
commenced after the major source baseline date; and
(b) Actual emissions increases and decreases, as defined in
paragraph (b)(21) of this section, at any stationary source occurring
after the minor source baseline date.
(14)(i) Major source baseline date means:
(a) In the case of particulate matter and sulfur dioxide, January 6,
1975, and
(b) In the case of nitrogen dioxide, February 8, 1988.
(ii) Minor source baseline date means the earliest date after the
trigger date on which a major stationary source or a major modification
subject to 40 CFR 52.21 or to regulations approved pursuant to 40 CFR
51.166 submits a complete application under the relevant regulations.
The trigger date is:
(a) In the case of particulate matter and sulfur dioxide, August 7,
1977, and
(b) In the case of nitrogen dioxide, February 8, 1988.
(iii) The baseline date is established for each pollutant for which
increments or other equivalent measures have been established if:
(a) The area in which the proposed source or modification would
construct is designated as attainment or unclassifiable under section
107(d)(i) (D) or (E) of the Act for the pollutant on the date of its
complete application under 40 CFR 52.21 or under regulations approved
pursuant to 40 CFR 51.166; and
(b) In the case of a major stationary source, the pollutant would be
emitted in significant amounts, or, in the case of a major modification,
there would be a significant net emissions increase of the pollutant.
(iv) Any minor source baseline date established originally for the
TSP increments shall remain in effect and shall apply for purposes of
determining the amount of available PM-10 increments, except that the
reviewing authority may rescind any such minor source baseline date
where it can be shown, to the satisfaction of the reviewing authority,
that the emissions increase from the major stationary source, or the net
emissions increase from the major modification, responsible for
triggering that date did not result in a significant amount of PM-10
emissions.
(15)(i) Baseline area means any intrastate area (and every part
thereof) designated as attainment or unclassifiable under section
107(d)(1) (D) or (E) of the Act in which the major source or major
modification establishing the minor source baseline date would construct
or would have an air quality impact equal to or greater than 1 [mu]g/
m\3\ (annual average) of the pollutant for which the minor source
baseline date is established.
(ii) Area redesignations under section 107(d)(1) (D) or (E) of the
Act cannot intersect or be smaller than the area of impact of any major
stationary source or major modification which:
[[Page 205]]
(a) Establishes a minor source baseline date; or
(b) Is subject to 40 CFR 52.21 or under regulations approved
pursuant to 40 CFR 51.166, and would be constructed in the same State as
the State proposing the redesignation.
(iii) Any baseline area established originally for the TSP
increments shall remain in effect and shall apply for purposes of
determining the amount of available PM-10 increments, except that such
baseline area shall not remain in effect if the permit authority
rescinds the corresponding minor source baseline date in accordance with
paragraph (b)(14)(iv) of this section.
(16) Allowable emissions means the emissions rate of a stationary
source calculated using the maximum rated capacity of the source (unless
the source is subject to federally enforceable limits which restrict the
operating rate, or hours of operation, or both) and the most stringent
of the following:
(i) The applicable standards as set forth in 40 CFR parts 60 and 61;
(ii) The applicable State Implementation Plan emissions limitation,
including those with a future compliance date; or
(iii) The emissions rate specified as a federally enforceable permit
condition.
(17) Federally enforceable means all limitations and conditions
which are enforceable by the Administrator, including those requirements
developed pursuant to 40 CFR parts 60 and 61, requirements within any
applicable State implementation plan, any permit requirements
established pursuant to 40 CFR 52.21 or under regulations approved
pursuant to 40 CFR part 51, subpart I, including operating permits
issued under an EPA-approved program that is incorporated into the State
implementation plan and expressly requires adherence to any permit
issued under such program.
(18) Secondary emissions means emissions which occur as a result of
the construction or operation of a major stationary source or major
modification, but do not come from the major stationary source or major
modification itself. For the purposes of this section, secondary
emissions must be specific, well defined, quantifiable, and impact the
same general areas the stationary source modification which causes the
secondary emissions. Secondary emissions include emissions from any
offsite support facility which would not be constructed or increase its
emissions except as a result of the construction or operation of the
major stationary source or major modification. Secondary emissions do
not include any emissions which come directly from a mobile source, such
as emissions from the tailpipe of a motor vehicle, from a train, or from
a vessel.
(19) Innovative control technology means any system of air pollution
control that has not been adequately demonstrated in practice, but would
have a substantial likelihood of achieving greater continuous emissions
reduction than any control system in current practice or of achieving at
least comparable reductions at lower cost in terms of energy, economics,
or nonair quality environmental impacts.
(20) Fugitive emissions means those emissions which could not
reasonably pass through a stack, chimney, vent, or other functionally
equivalent opening.
(21)(i) Actual emissions means the actual rate of emissions of a
regulated NSR pollutant from an emissions unit, as determined in
accordance with paragraphs (b)(21)(ii) through (iv) of this section,
except that this definition shall not apply for calculating whether a
significant emissions increase has occurred, or for establishing a PAL
under paragraph (w) of this section. Instead, paragraphs (b)(40) and
(b)(47) of this section shall apply for those purposes.
(ii) In general, actual emissions as of a particular date shall
equal the average rate, in tons per year, at which the unit actually
emitted the pollutant during a consecutive 24-month period which
precedes the particular date and which is representative of normal
source operation. The reviewing authority shall allow the use of a
different time period upon a determination that it is more
representative of normal source operation. Actual emissions shall be
calculated using the unit's actual operating hours, production rates,
and types of materials processed, stored, or combusted during the
selected time period.
[[Page 206]]
(iii) The reviewing authority may presume that source-specific
allowable emissions for the unit are equivalent to the actual emissions
of the unit.
(iv) For any emissions unit that has not begun normal operations on
the particular date, actual emissions shall equal the potential to emit
of the unit on that date.
(22) Complete means, in reference to an application for a permit,
that the application contains all the information necessary for
processing the application. Designating an application complete for
purposes of permit processing does not preclude the reviewing authority
from requesting or accepting any additional information.
(23)(i) Significant means, in reference to a net emissions increase
or the potential of a source to emit any of the following pollutants, a
rate of emissions that would equal or exceed any of the following rates:
Pollutant and Emissions Rate
Carbon monoxide: 100 tons per year (tpy)
Nitrogen oxides: 40 tpy
Sulfur dioxide: 40 tpy
Particulate matter: 25 tpy of particulate matter emissions. 15 tpy of
PM10 emissions.
Ozone: 40 tpy of volatile organic compounds
Lead: 0.6 tpy
Fluorides: 3 tpy
Sulfuric acid mist: 7 tpy
Hydrogen sulfide (H2 S): 10 tpy
Total reduced sulfur (including H2 S): 10 tpy
Reduced sulfur compounds (including H2 S): 10 tpy
Municipal waste combustor organics (measured as total tetra- through
octa-chlorinated dibenzo-p-dioxins and dibenzofurans): 3.2 x
10-6 megagrams per year (3.5 x 10-6 tons per year)
Municipal waste combustor metals (measured as articulate matter): 14
megagrams per year (15 tons per year) Municipal waste combustor acid
gases (measured as sulfur dioxide and hydrogen chloride): 36 megagrams
per year (40 tons per year)
Municipal solid waste landfill emissions (measured as nonmethane organic
compounds): 45 megagrams per year (50 tons per year)
(ii) Significant means, in reference to a net emissions increase or
the potential of a source to emit a a regulated NSR pollutant that
paragraph (b)(23)(i) of this section, does not list, any emissions rate.
(iii) Notwithstanding paragraph (b)(23)(i) of this section,
significant means any emissions rate or any net emissions increase
associated with a major stationary source or major modification, which
would construct within 10 kilometers of a Class I area, and have an
impact on such area equal to or greater than 1 [mu]g/m\3\ (24-hour
average).
(24) Federal Land Manager means, with respect to any lands in the
United States, the Secretary of the department with authority over such
lands.
(25) High terrain means any area having an elevation 900 feet or
more above the base of the stack of a source.
(26) Low terrain means any area other than high terrain.
(27) Indian Reservation means any federally recognized reservation
established by Treaty, Agreement, Executive Order, or Act of Congress.
(28) Indian Governing Body means the governing body of any tribe,
band, or group of Indians subject to the jurisdiction of the United
States and recognized by the United States as possessing power of self-
government.
(29) Volatile organic compounds (VOC) is as defined in
Sec. 51.100(s) of this part.
(30) Electric utility steam generating unit means any steam electric
generating unit that is constructed for the purpose of supplying more
than one-third of its potential electric output capacity and more than
25 MW electrical output to any utility power distribution system for
sale. Any steam supplied to a steam distribution system for the purpose
of providing steam to a steam-electric generator that would produce
electrical energy for sale is also considered in determining the
electrical energy output capacity of the affected facility.
(31) Pollution control project (PCP) means any activity, set of work
practices or project (including pollution prevention as defined under
paragraph (b)(38) of this section) undertaken at an existing emissions
unit that reduces emissions of air pollutants from such unit. Such
qualifying activities or projects can include the replacement or upgrade
of an existing emissions control technology with a more effective unit.
Other changes that may occur at the source are not considered part of
the PCP if they are not necessary to reduce emissions through the
[[Page 207]]
PCP. Projects listed in paragraphs (b)(31)(i) through (vi) of this
section are presumed to be environmentally beneficial pursuant to
paragraph (v)(2)(i) of this section. Projects not listed in these
paragraphs may qualify for a case-specific PCP exclusion pursuant to the
requirements of paragraphs (v)(2) and (v)(5) of this section.
(i) Conventional or advanced flue gas desulfurization or sorbent
injection for control of SO2.
(ii) Electrostatic precipitators, baghouses, high efficiency
multiclones, or scrubbers for control of particulate matter or other
pollutants.
(iii) Flue gas recirculation, low-NOX burners or
combustors, selective non-catalytic reduction, selective catalytic
reduction, low emission combustion (for IC engines), and oxidation/
absorption catalyst for control of NOX.
(iv) Regenerative thermal oxidizers, catalytic oxidizers,
condensers, thermal incinerators, hydrocarbon combustion flares,
biofiltration, absorbers and adsorbers, and floating roofs for storage
vessels for control of volatile organic compounds or hazardous air
pollutants. For the purpose of this section, ``hydrocarbon combustion
flare'' means either a flare used to comply with an applicable NSPS or
MACT standard (including uses of flares during startup, shutdown, or
malfunction permitted under such a standard), or a flare that serves to
control emissions of waste streams comprised predominately of
hydrocarbons and containing no more than 230 mg/dscm hydrogen sulfide.
(v) Activities or projects undertaken to accommodate switching (or
partially switching) to an inherently less polluting fuel, to be limited
to the following fuel switches:
(a) Switching from a heavier grade of fuel oil to a lighter fuel
oil, or any grade of oil to 0.05 percent sulfur diesel (i.e., from a
higher sulfur content 2 fuel or from 6 fuel, to CA
0.05 percent sulfur 2 diesel);
(b) Switching from coal, oil, or any solid fuel to natural gas,
propane, or gasified coal;
(c) Switching from coal to wood, excluding construction or
demolition waste, chemical or pesticide treated wood, and other forms of
``unclean'' wood;
(d) Switching from coal to 2 fuel oil (0.5 percent maximum
sulfur content); and
(e) Switching from high sulfur coal to low sulfur coal (maximum 1.2
percent sulfur content).
(vi) Activities or projects undertaken to accommodate switching from
the use of one ozone depleting substance (ODS) to the use of a substance
with a lower or zero ozone depletion potential (ODP), including changes
to equipment needed to accommodate the activity or project, that meet
the requirements of paragraphs (b)(31)(vi)(a) and (b) of this section.
(a) The productive capacity of the equipment is not increased as a
result of the activity or project.
(b) The projected usage of the new substance is lower, on an ODP-
weighted basis, than the baseline usage of the replaced ODS. To make
this determination, follow the procedure in paragraphs (b)(31)(vi)(b)(1)
through (4) of this section.
(1) Determine the ODP of the substances by consulting 40 CFR part
82, subpart A, appendices A and B.
(2) Calculate the replaced ODP-weighted amount by multiplying the
baseline actual usage (using the annualized average of any 24
consecutive months of usage within the past 10 years) by the ODP of the
replaced ODS.
(3) Calculate the projected ODP-weighted amount by multiplying the
projected annual usage of the new substance by its ODP.
(4) If the value calculated in paragraph (b)(31)(vi)(b)(2) of this
section is more than the value calculated in paragraph (b)(31)(vi)(b)(3)
of this section, then the projected use of the new substance is lower,
on an ODP-weighted basis, than the baseline usage of the replaced ODS.
(32) [Reserved]
(33) Clean coal technology means any technology, including
technologies applied at the precombustion, combustion, or post
combustion stage, at a new or existing facility which will achieve
significant reductions in air emissions of sulfur dioxide or oxides of
[[Page 208]]
nitrogen associated with the utilization of coal in the generation of
electricity, or process steam which was not in widespread use as of
November 15, 1990.
(34) Clean coal technology demonstration project means a project
using funds appropriated under the heading ``Department of Energy--Clean
Coal Technology'', up to a total amount of $2,500,000,000 for commercial
demonstration of clean coal technology, or similar projects funded
through appropriations for the Environmental Protection Agency. The
Federal contribution for a qualifying project shall be at least 20
percent of the total cost of the demonstration project.
(35) Temporary clean coal technology demonstration project means a
clean coal technology demonstration project that is operated for a
period of 5 years or less, and which complies with the State
implementation plan for the State in which the project is located and
other requirements necessary to attain and maintain the national ambient
air quality standards during and after the project is terminated.
(36)(i) Repowering means replacement of an existing coal-fired
boiler with one of the following clean coal technologies: atmospheric or
pressurized fluidized bed combustion, integrated gasification combined
cycle, magnetohydrodynamics, direct and indirect coal-fired turbines,
integrated gasification fuel cells, or as determined by the
Administrator, in consultation with the Secretary of Energy, a
derivative of one or more of these technologies, and any other
technology capable of controlling multiple combustion emissions
simultaneously with improved boiler or generation efficiency and with
significantly greater waste reduction relative to the performance of
technology in widespread commercial use as of November 15, 1990.
(ii) Repowering shall also include any oil and/or gas-fired unit
which has been awarded clean coal technology demonstration funding as of
January 1, 1991, by the Department of Energy.
(iii) The reviewing authority shall give expedited consideration to
permit applications for any source that satisfies the requirements of
this subsection and is granted an extension under section 409 of the
Clean Air Act.
(37) Reactivation of a very clean coal-fired electric utility steam
generating unit means any physical change or change in the method of
operation associated with the commencement of commercial operations by a
coal-fired utility unit after a period of discontinued operation where
the unit:
(i) Has not been in operation for the two-year period prior to the
enactment of the Clean Air Act Amendments of 1990, and the emissions
from such unit continue to be carried in the permitting authority's
emissions inventory at the time of enactment;
(ii) Was equipped prior to shutdown with a continuous system of
emissions control that achieves a removal efficiency for sulfur dioxide
of no less than 85 percent and a removal efficiency for particulates of
no less than 98 percent;
(iii) Is equipped with low-NOX burners prior to the time
of commencement of operations following reactivation; and
(iv) Is otherwise in compliance with the requirements of the Clean
Air Act.
(38) Pollution prevention means any activity that through process
changes, product reformulation or redesign, or substitution of less
polluting raw materials, eliminates or reduces the release of air
pollutants (including fugitive emissions) and other pollutants to the
environment prior to recycling, treatment, or disposal; it does not mean
recycling (other than certain ``in-process recycling'' practices),
energy recovery, treatment, or disposal.
(39) Significant emissions increase means, for a regulated NSR
pollutant, an increase in emissions that is significant (as defined in
paragraph (b)(23) of this section) for that pollutant.
(40)(i) Projected actual emissions means the maximum annual rate, in
tons per year, at which an existing emissions unit is projected to emit
a regulated NSR pollutant in any one of the 5 years (12-month period)
following the date the unit resumes regular operation after the project,
or in any one of the 10 years following that date, if the project
involves increasing the emissions unit's design capacity or its
potential to emit that regulated NSR pollutant, and full utilization of
the unit
[[Page 209]]
would result in a significant emissions increase, or a significant net
emissions increase at the major stationary source.
(ii) In determining the projected actual emissions under paragraph
(b)(40)(i) of this section (before beginning actual construction), the
owner or operator of the major stationary source:
(a) Shall consider all relevant information, including but not
limited to, historical operational data, the company's own
representations, the company's expected business activity and the
company's highest projections of business activity, the company's
filings with the State or Federal regulatory authorities, and compliance
plans under the approved plan; and
(b) Shall include fugitive emissions to the extent quantifiable and
emissions associated with startups, shutdowns, and malfunctions; and
(c) Shall exclude, in calculating any increase in emissions that
results from the particular project, that portion of the unit's
emissions following the project that an existing unit could have
accommodated during the consecutive 24-month period used to establish
the baseline actual emissions under paragraph (b)(47) of this section
and that are also unrelated to the particular project, including any
increased utilization due to product demand growth; or,
(d) In lieu of using the method set out in paragraphs (b)(40)(ii)(a)
through (c) of this section, may elect to use the emissions unit's
potential to emit, in tons per year, as defined under paragraph (b)(4)
of this section.
(41) Clean Unit means any emissions unit that has been issued a
major NSR permit that requires compliance with BACT or LAER, is
complying with such BACT/LAER requirements, and qualifies as a Clean
Unit pursuant to regulations approved by the Administrator in accordance
with paragraph (t) of this section; or any emissions unit that has been
designated by a reviewing authority as a Clean Unit, based on the
criteria in paragraphs (u)(3)(i) through (iv) of this section, using a
plan-approved permitting process; or any emissions unit that has been
designated as a Clean Unit by the Administrator in accordance with 52.21
(y)(3)(i) through (iv) of this chapter.
(42) Prevention of Significant Deterioration Program (PSD) program
means a major source preconstruction permit program that has been
approved by the Administrator and incorporated into the plan to
implement the requirements of this section, or the program in Sec. 52.21
of this chapter. Any permit issued under such a program is a major NSR
permit.
(43) Continuous emissions monitoring system (CEMS) means all of the
equipment that may be required to meet the data acquisition and
availability requirements of this section, to sample, condition (if
applicable), analyze, and provide a record of emissions on a continuous
basis.
(44) Predictive emissions monitoring system (PEMS) means all of the
equipment necessary to monitor process and control device operational
parameters (for example, control device secondary voltages and electric
currents) and other information (for example, gas flow rate, O\2\ or
CO\2\ concentrations), and calculate and record the mass emissions rate
(for example, lb/hr) on a continuous basis.
(45) Continuous parameter monitoring system (CPMS) means all of the
equipment necessary to meet the data acquisition and availability
requirements of this section, to monitor process and control device
operational parameters (for example, control device secondary voltages
and electric currents) and other information (for example, gas flow
rate, O\2\ or CO\2\ concentrations), and to record average operational
parameter value(s) on a continuous basis.
(46) Continuous emissions rate monitoring system (CERMS) means the
total equipment required for the determination and recording of the
pollutant mass emissions rate (in terms of mass per unit of time).
(47) Baseline actual emissions means the rate of emissions, in tons
per year, of a regulated NSR pollutant, as determined in accordance with
paragraphs (b)(47)(i) through (iv) of this section.
(i) For any existing electric utility steam generating unit,
baseline actual emissions means the average rate, in tons per year, at
which the unit actually emitted the pollutant during any
[[Page 210]]
consecutive 24-month period selected by the owner or operator within the
5-year period immediately preceding when the owner or operator begins
actual construction of the project. The reviewing authority shall allow
the use of a different time period upon a determination that it is more
representative of normal source operation.
(a) The average rate shall include fugitive emissions to the extent
quantifiable, and emissions associated with startups, shutdowns, and
malfunctions.
(b) The average rate shall be adjusted downward to exclude any non-
compliant emissions that occurred while the source was operating above
an emission limitation that was legally enforceable during the
consecutive 24-month period.
(c) For a regulated NSR pollutant, when a project involves multiple
emissions units, only one consecutive 24-month period must be used to
determine the baseline actual emissions for the emissions units being
changed. A different consecutive 24-month period can be used For each
regulated NSR pollutant.
(d) The average rate shall not be based on any consecutive 24-month
period for which there is inadequate information for determining annual
emissions, in tons per year, and for adjusting this amount if required
by paragraph (b)(47)(i)(b) of this section.
(ii) For an existing emissions unit (other than an electric utility
steam generating unit), baseline actual emissions means the average
rate, in tons per year, at which the emissions unit actually emitted the
pollutant during any consecutive 24-month period selected by the owner
or operator within the 10-year period immediately preceding either the
date the owner or operator begins actual construction of the project, or
the date a complete permit application is received by the reviewing
authority for a permit required either under this section or under a
plan approved by the Administrator, whichever is earlier, except that
the 10-year period shall not include any period earlier than November
15, 1990.
(a) The average rate shall include fugitive emissions to the extent
quantifiable, and emissions associated with startups, shutdowns, and
malfunctions.
(b) The average rate shall be adjusted downward to exclude any non-
compliant emissions that occurred while the source was operating above
an emission limitation that was legally enforceable during the
consecutive 24-month period.
(c) The average rate shall be adjusted downward to exclude any
emissions that would have exceeded an emission limitation with which the
major stationary source must currently comply, had such major stationary
source been required to comply with such limitations during the
consecutive 24-month period. However, if an emission limitation is part
of a maximum achievable control technology standard that the
Administrator proposed or promulgated under part 63 of this chapter, the
baseline actual emissions need only be adjusted if the State has taken
credit for such emissions reductions in an attainment demonstration or
maintenance plan consistent with the requirements of
Sec. 51.165(a)(3)(ii)(G).
(d) For a regulated NSR pollutant, when a project involves multiple
emissions units, only one consecutive 24-month period must be used to
determine the baseline actual emissions for the emissions units being
changed. A different consecutive 24-month period can be used For each
regulated NSR pollutant.
(e) The average rate shall not be based on any consecutive 24-month
period for which there is inadequate information for determining annual
emissions, in tons per year, and for adjusting this amount if required
by paragraphs (b)(47)(ii)(b) and (c) of this section.
(iii) For a new emissions unit, the baseline actual emissions for
purposes of determining the emissions increase that will result from the
initial construction and operation of such unit shall equal zero; and
thereafter, for all other purposes, shall equal the unit's potential to
emit.
(iv) For a PAL for a stationary source, the baseline actual
emissions shall be calculated for existing electric utility steam
generating units in accordance with the procedures contained in
paragraph (b)(47)(i) of this section, for other existing emissions
[[Page 211]]
units in accordance with the procedures contained in paragraph
(b)(47)(ii) of this section, and for a new emissions unit in accordance
with the procedures contained in paragraph (b)(47)(iii) of this section.
(48) [Reserved]
(49) Regulated NSR pollutant, for purposes of this section, means
the following:
(i) Any pollutant for which a national ambient air quality standard
has been promulgated and any constituents or precursors for such
pollutants identified by the Administrator (e.g., volatile organic
compounds are precursors for ozone);
(ii) Any pollutant that is subject to any standard promulgated under
section 111 of the Act;
(iii) Any Class I or II substance subject to a standard promulgated
under or established by title VI of the Act; or
(iv) Any pollutant that otherwise is subject to regulation under the
Act; except that any or all hazardous air pollutants either listed in
section 112 of the Act or added to the list pursuant to section
112(b)(2) of the Act, which have not been delisted pursuant to section
112(b)(3) of the Act, are not regulated NSR pollutants unless the listed
hazardous air pollutant is also regulated as a constituent or precursor
of a general pollutant listed under section 108 of the Act.
(50) Reviewing authority means the State air pollution control
agency, local agency, other State agency, Indian tribe, or other agency
authorized by the Administrator to carry out a permit program under
Sec. 51.165 and this section, or the Administrator in the case of EPA-
implemented permit programs under Sec. 52.21 of this chapter.
(51) Project means a physical change in, or change in method of
operation of, an existing major stationary source.
(52) Lowest achievable emission rate (LAER) is as defined in
Sec. 51.165(a)(1)(xiii).
(c) Ambient air increments. The plan shall contain emission
limitations and such other measures as may be necessary to assure that
in areas designated as Class I, II, or III, increases in pollutant
concentration over the baseline concentration shall be limited to the
following:
------------------------------------------------------------------------
Maximum
allowable
increase
Pollutant (micrograms
per cubic
meter)
------------------------------------------------------------------------
Class I
------------------------------------------------------------------------
Particulate matter:
PM-10, annual arithmetic mean.......................... 4
PM-10, 24-hr maximum................................... 8
Sulfur dioxide:
Annual arithmetic mean................................. 2
24-hr maximum.......................................... 5
3-hr maximum........................................... 25
Nitrogen dioxide: Annual arithmetic mean................... 2.5
------------------------------------------------------------------------
Class II
------------------------------------------------------------------------
Particulate matter:
PM-10, annual arithmetic mean.......................... 17
PM-10, 24-hr maximum................................... 30
Sulfur dioxide:
Annual arithmetic mean................................. 20
24-hr maximum.......................................... 91
3-hr maximum........................................... 512
Nitrogen dioxide:
Annual arithmetic mean................................. 25
------------------------------------------------------------------------
Class III
------------------------------------------------------------------------
Particulate matter:
PM-10, annual arithmetic mean.......................... 34
PM-10, 24-hr maximum................................... 60
Sulfur dioxide:
Annual arithmetic mean................................. 40
24-hr maximum.......................................... 182
3-hr maximum........................................... 700
Nitrogen dioxide: Annual arithmetic mean................... 50
------------------------------------------------------------------------
For any period other than an annual period, the applicable maximum
allowable increase may be exceeded during one such period per year at
any one location.
(d) Ambient air ceilings. The plan shall provide that no
concentration of a pollutant shall exceed:
(1) The concentration permitted under the national secondary ambient
air quality standard, or
(2) The concentration permitted under the national primary ambient
air quality standard, whichever concentration is lowest for the
pollutant for a period of exposure.
(e) Restrictions on area classifications. The plan shall provide
that--
(1) All of the following areas which were in existence on August 7,
1977, shall be Class I areas and may not be redesignated:
(i) International parks,
(ii) National wilderness areas which exceed 5,000 acres in size,
[[Page 212]]
(iii) National memorial parks which exceed 5,000 acres in size, and
(iv) National parks which exceed 6,000 acres in size.
(2) Areas which were redesignated as Class I under regulations
promulgated before August 7, 1977, shall remain Class I, but may be
redesignated as provided in this section.
(3) Any other area, unless otherwise specified in the legislation
creating such an area, is initially designated Class II, but may be
redesignated as provided in this section.
(4) The following areas may be redesignated only as Class I or II:
(i) An area which as of August 7, 1977, exceeded 10,000 acres in
size and was a national monument, a national primitive area, a national
preserve, a national recreational area, a national wild and scenic
river, a national wildlife refuge, a national lakeshore or seashore; and
(ii) A national park or national wilderness area established after
August 7, 1977, which exceeds 10,000 acres in size.
(f) Exclusions from increment consumption. (1) The plan may provide
that the following concentrations shall be excluded in determining
compliance with a maximum allowable increase:
(i) Concentrations attributable to the increase in emissions from
stationary sources which have converted from the use of petroleum
products, natural gas, or both by reason of an order in effect under
section 2 (a) and (b) of the Energy Supply and Environmental
Coordination Act of 1974 (or any superseding legislation) over the
emissions from such sources before the effective date of such an order;
(ii) Concentrations attributable to the increase in emissions from
sources which have converted from using natural gas by reason of natural
gas curtailment plan in effect pursuant to the Federal Power Act over
the emissions from such sources before the effective date of such plan;
(iii) Concentrations of particulate matter attributable to the
increase in emissions from construction or other temporary emission-
related activities of new or modified sources;
(iv) The increase in concentrations attributable to new sources
outside the United States over the concentrations attributable to
existing sources which are included in the baseline concentration; and
(v) Concentrations attributable to the temporary increase in
emissions of sulfur dioxide, particulate matter, or nitrogen oxides from
stationary sources which are affected by plan revisions approved by the
Administrator as meeting the criteria specified in paragraph (f)(4) of
this section.
(2) If the plan provides that the concentrations to which paragraph
(f)(1) (i) or (ii) of this section, refers shall be excluded, it shall
also provide that no exclusion of such concentrations shall apply more
than five years after the effective date of the order to which paragraph
(f)(1)(i) of this section, refers or the plan to which paragraph
(f)(1)(ii) of this section, refers, whichever is applicable. If both
such order and plan are applicable, no such exclusion shall apply more
than five years after the later of such effective dates.
(3) [Reserved]
(4) For purposes of excluding concentrations pursuant to paragraph
(f)(1)(v) of this section, the Administrator may approve a plan revision
that:
(i) Specifies the time over which the temporary emissions increase
of sulfur dioxide, particulate matter, or nitrogen oxides would occur.
Such time is not to exceed 2 years in duration unless a longer time is
approved by the Administrator.
(ii) Specifies that the time period for excluding certain
contributions in accordance with paragraph (f)(4)(i) of this section, is
not renewable;
(iii) Allows no emissions increase from a stationary source which
would:
(a) Impact a Class I area or an area where an applicable increment
is known to be violated; or
(b) Cause or contribute to the violation of a national ambient air
quality standard;
(iv) Requires limitations to be in effect the end of the time period
specified in accordance with paragraph (f)(4)(i) of this section, which
would ensure that the emissions levels from stationary sources affected
by the plan revision would not exceed those levels occurring from such
sources before the plan revision was approved.
[[Page 213]]
(g) Redesignation. (1) The plan shall provide that all areas of the
State (except as otherwise provided under paragraph (e) of this section)
shall be designated either Class I, Class II, or Class III. Any
designation other than Class II shall be subject to the redesignation
procedures of this paragraph. Redesignation (except as otherwise
precluded by paragraph (e) of this section) may be proposed by the
respective States or Indian Governing Bodies, as provided below, subject
to approval by the Administrator as a revision to the applicable State
implementation plan.
(2) The plan may provide that the State may submit to the
Administrator a proposal to redesignate areas of the State Class I or
Class II: Provided, That:
(i) At least one public hearing has been held in accordance with
procedures established in Sec. 51.102.
(ii) Other States, Indian Governing Bodies, and Federal Land
Managers whose lands may be affected by the proposed redesignation were
notified at least 30 days prior to the public hearing;
(iii) A discussion of the reasons for the proposed redesignation,
including a satisfactory description and analysis of the health,
environmental, economic, social, and energy effects of the proposed
redesignation, was prepared and made available for public inspection at
least 30 days prior to the hearing and the notice announcing the hearing
contained appropriate notification of the availability of such
discussion;
(iv) Prior to the issuance of notice respecting the redesignation of
an area that includes any Federal lands, the State has provided written
notice to the appropriate Federal Land Manager and afforded adequate
opportunity (not in excess of 60 days) to confer with the State
respecting the redesignation and to submit written comments and
recommendations. In redesignating any area with respect to which any
Federal Land Manager had submitted written comments and recommendations,
the State shall have published a list of any inconsistency between such
redesignation and such comments and recommendations (together with the
reasons for making such redesignation against the recommendation of the
Federal Land Manager); and
(v) The State has proposed the redesignation after consultation with
the elected leadership of local and other substate general purpose
governments in the area covered by the proposed redesignation.
(3) The plan may provide that any area other than an area to which
paragraph (e) of this section refers may be redesignated as Class III
if--
(i) The redesignation would meet the requirements of provisions
established in accordance with paragraph (g)(2) of this section;
(ii) The redesignation, except any established by an Indian
Governing Body, has been specifically approved by the Governor of the
State, after consultation with the appropriate committees of the
legislature, if it is in session, or with the leadership of the
legislature, if it is not in session (unless State law provides that
such redesignation must be specifically approved by State legislation)
and if general purpose units of local government representing a majority
of the residents of the area to be redesignated enact legislation
(including resolutions where appropriate) concurring in the
redesignation;
(iii) The redesignation would not cause, or contribute to, a
concentration of any air pollutant which would exceed any maximum
allowable increase permitted under the classification of any other area
or any national ambient air quality standard; and
(iv) Any permit application for any major stationary source or major
modification subject to provisions established in accordance with
paragraph (l) of this section which could receive a permit only if the
area in question were redesignated as Class III, and any material
submitted as part of that application, were available, insofar as was
practicable, for public inspection prior to any public hearing on
redesignation of any area as Class III.
(4) The plan shall provide that lands within the exterior boundaries
of Indian Reservations may be redesignated only by the appropriate
Indian Governing Body. The appropriate Indian Governing Body may submit
to the Administrator a proposal to redesignate
[[Page 214]]
areas Class I, Class II, or Class III: Provided, That:
(i) The Indian Governing Body has followed procedures equivalent to
those required of a State under paragraphs (g) (2), (3)(iii), and
(3)(iv) of this section; and
(ii) Such redesignation is proposed after consultation with the
State(s) in which the Indian Reservation is located and which border the
Indian Reservation.
(5) The Administrator shall disapprove, within 90 days of
submission, a proposed redesignation of any area only if he finds, after
notice and opportunity for public hearing, that such redesignation does
not meet the procedural requirements of this section or is inconsistent
with paragraph (e) of this section. If any such disapproval occurs, the
classification of the area shall be that which was in effect prior to
the redesignation which was disapproved.
(6) If the Administrator disapproves any proposed area designation,
the State or Indian Governing Body, as appropriate, may resubmit the
proposal after correcting the deficiencies noted by the Administrator.
(h) Stack heights. The plan shall provide, as a minimum, that the
degree of emission limitation required for control of any air pollutant
under the plan shall not be affected in any manner by--
(1) So much of a stack height, not in existence before December 31,
1970, as exceeds good engineering practice, or
(2) Any other dispersion technique not implemented before then.
(i) Exemptions.
(1) The plan may provide that requirements equivalent to those
contained in paragraphs (j) through (r) of this section do not apply to
a particular major stationary source or major modification if:
(i) The major stationary source would be a nonprofit health or
nonprofit educational institution or a major modification that would
occur at such an institution; or
(ii) The source or modification would be a major stationary source
or major modification only if fugitive emissions, to the extent
quantifiable, are considered in calculating the potential to emit of the
stationary source or modification and such source does not belong to any
following categories:
(a) Coal cleaning plants (with thermal dryers);
(b) Kraft pulp mills;
(c) Portland cement plants;
(d) Primary zinc smelters;
(e) Iron and steel mills;
(f) Primary aluminum ore reduction plants;
(g) Primary copper smelters;
(h) Municipal incinerators capable of charging more than 250 tons of
refuse per day;
(i) Hydrofluoric, sulfuric, or nitric acid plants;
(j) Petroleum refineries;
(k) Lime plants;
(l) Phosphate rock processing plants;
(m) Coke oven batteries;
(n) Sulfur recovery plants;
(o) Carbon black plants (furnace process);
(p) Primary lead smelters;
(q) Fuel conversion plants;
(r) Sintering plants;
(s) Secondary metal production plants;
(t) Chemical process plants;
(u) Fossil-fuel boilers (or combination thereof) totaling more than
250 million British thermal units per hour heat input;
(v) Petroleum storage and transfer units with a total storage
capacity exceeding 300,000 barrels;
(w) Taconite ore processing plants;
(x) Glass fiber processing plants;
(y) Charcoal production plants;
(z) Fossil fuel-fired steam electric plants of more than 250 million
British thermal units per hour heat input;
(aa) Any other stationary source category which, as of August 7,
1980, is being regulated under section 111 or 112 of the Act; or
(iii) The source or modification is a portable stationary source
which has previously received a permit under requirements equivalent to
those contained in paragraphs (j) through (r) of this section, if:
(a) The source proposes to relocate and emissions of the source at
the new location would be temporary; and
(b) The emissions from the source would not exceed its allowable
emissions; and
(c) The emissions from the source would impact no Class I area and
no
[[Page 215]]
area where an applicable increment is known to be violated; and
(d) Reasonable notice is given to the reviewing authority prior to
the relocation identifying the proposed new location and the probable
duration of operation at the new location. Such notice shall be given to
the reviewing authority not less than 10 days in advance of the proposed
relocation unless a different time duration is previously approved by
the reviewing authority.
(2) The plan may provide that requirements equivalent to those
contained in paragraphs (j) through (r) of this section do not apply to
a major stationary source or major modification with respect to a
particular pollutant if the owner or operator demonstrates that, as to
that pollutant, the source or modification is located in an area
designated as nonattainment under section 107 of the Act.
(3) The plan may provide that requirements equivalent to those
contained in paragraphs (k), (m), and (o) of this section do not apply
to a proposed major stationary source or major modification with respect
to a particular pollutant, if the allowable emissions of that pollutant
from a new source, or the net emissions increase of that pollutant from
a modification, would be temporary and impact no Class I area and no
area where an applicable increment is known to be violated.
(4) The plan may provide that requirements equivalent to those
contained in paragraphs (k), (m), and (o) of this section as they relate
to any maximum allowable increase for a Class II area do not apply to a
modification of a major stationary source that was in existence on March
1, 1978, if the net increase in allowable emissions of each a regulated
NSR pollutant from the modification after the application of best
available control technology would be less than 50 tons per year.
(5) The plan may provide that the reviewing authority may exempt a
proposed major stationary source or major modification from the
requirements of paragraph (m) of this section, with respect to
monitoring for a particular pollutant, if:
(i) The emissions increase of the pollutant from a new stationary
source or the net emissions increase of the pollutant from a
modification would cause, in any area, air quality impacts less than the
following amounts:
(a) Carbon monoxide--575 ug/m\3\, 8-hour average;
(b) Nitrogen dioxide--14 ug/m\3\, annual average;
(c) Particulate matter--10 [mu]g/m\3\ of PM-10, 24-hour average.
(d) Sulfur dioxide--13 ug/m\3\, 24-hour average;
(e) Ozone; \1\
---------------------------------------------------------------------------
\1\ No de minimis air quality level is provided for ozone. However,
any net increase of 100 tons per year or more of volatile organic
compounds subject to PSD would be required to perform and ambient impact
analysis, including the gathering of ambient air quality data.
---------------------------------------------------------------------------
(f) Lead--0.1 [mu]g/m\3\, 3-month average.
(g) Fluorides--0.25 [mu]g/m3, 24-hour average;
(h) Total reduced sulfur--10 [mu]g/m3, 1-hour average
(i) Hydrogen sulfide--0.2 [mu]g/m3, 1-hour average;
(j) Reduced sulfur compounds--10 [mu]g/m3, 1-hour
average; or
(ii) The concentrations of the pollutant in the area that the source
or modification would affect are less than the concentrations listed in
(i)(8)(i) of this section; or
(iii) The pollutants is not listed in paragraph (i)(8)(i) of this
section.
(6) If EPA approves a plan revision under 40 CFR 51.166 as in effect
before August 7, 1980, any subsequent revision which meets the
requirements of this section may contain transition provisions which
parallel the transition provisions of 40 CFR 52.21(i)(9), (i)(10) and
(m)(1)(v) as in effect on that date, which provisions relate to
requirements for best available control technology and air quality
analyses. Any such subsequent revision may not contain any transition
provision which in the context of the revision would operate any less
stringently than would its counterpart in 40 CFR 52.21.
(7) If EPA approves a plan revision under Sec. 51.166 as in effect
[before July 31, 1987], any subsequent revision which meets the
requirements of this section may contain transition provisions which
parallel the transition provisions of Sec. 52.21 (i)(11), and (m)(1)
(vii)
[[Page 216]]
and (viii) of this chapter as in effect on that date, these provisions
being related to monitoring requirements for particulate matter. Any
such subsequent revision may not contain any transition provision which
in the context of the revision would operate any less stringently than
would its counterpart in Sec. 52.21 of this chapter.
(8) The plan may provide that the permitting requirements equivalent
to those contained in paragraph (k)(2) of this section do not apply to a
stationary source or modification with respect to any maximum allowable
increase for nitrogen oxides if the owner or operator of the source or
modification submitted an application for a permit under the applicable
permit program approved or promulgated under the Act before the
provisions embodying the maximum allowable increase took effect as part
of the plan and the permitting authority subsequently determined that
the application as submitted before that date was complete.
(9) The plan may provide that the permitting requirements equivalent
to those contained in paragraph (k)(2) of this section shall not apply
to a stationary source or modification with respect to any maximum
allowable increase for PM-10 if (i) the owner or operator of the source
or modification submitted an application for a permit under the
applicable permit program approved under the Act before the provisions
embodying the maximum allowable increases for PM-10 took effect as part
of the plan, and (ii) the permitting authority subsequently determined
that the application as submitted before that date was complete.
Instead, the applicable requirements equivalent to paragraph (k)(2)
shall apply with respect to the maximum allowable increases for TSP as
in effect on the date the application was submitted.
(j) Control technology review. The plan shall provide that:
(1) A major stationary source or major modification shall meet each
applicable emissions limitation under the State Implementation Plan and
each applicable emission standards and standard of performance under 40
CFR parts 60 and 61.
(2) A new major stationary source shall apply best available control
technology for each a regulated NSR pollutant that it would have the
potential to emit in significant amounts.
(3) A major modification shall apply best available control
technology for each a regulated NSR pollutant for which it would be a
significant net emissions increase at the source. This requirement
applies to each proposed emissions unit at which a net emissions
increase in the pollutant would occur as a result of a physical change
or change in the method of operation in the unit.
(4) For phased construction projects, the determination of best
available control technology shall be reviewed and modified as
appropriate at the least reasonable time which occurs no later than 18
months prior to commencement of construction of each independent phase
of the project. At such time, the owner or operator of the applicable
stationary source may be required to demonstrate the adequacy of any
previous determination of best available control technology for the
source.
(k) Source impact analysis. The plan shall provide that the owner or
operator of the proposed source or modification shall demonstrate that
allowable emission increases from the proposed source or modification,
in conjunction with all other applicable emissions increases or
reduction (including secondary emissions) would not cause or contribute
to air pollution in violation of:
(1) Any national ambient air quality standard in any air quality
control region; or
(2) Any applicable maximum allowable increase over the baseline
concentration in any area.
(l) Air quality models. The plan shall provide for procedures which
specify that--
(1) All applications of air quality modeling involved in this
subpart shall be based on the applicable models, data bases, and other
requirements specified in appendix W of this part (Guideline on Air
Quality Models).
[[Page 217]]
(2) Where an air quality model specified in appendix W of this part
(Guideline on Air Quality Models) is inappropriate, the model may be
modified or another model substituted. Such a modification or
substitution of a model may be made on a case-by-case basis or, where
appropriate, on a generic basis for a specific State program. Written
approval of the Administrator must be obtained for any modification or
substitution. In addition, use of a modified or substituted model must
be subject to notice and opportunity for public comment under procedures
set forth in Sec. 51.102.
(m) Air quality analysis--(1) Preapplication analysis. (i) The plan
shall provide that any application for a permit under regulations
approved pursuant to this section shall contain an analysis of ambient
air quality in the area that the major stationary source or major
modification would affect for each of the following pollutants:
(a) For the source, each pollutant that it would have the potential
to emit in a significant amount;
(b) For the modification, each pollutant for which it would result
in a significant net emissions increase.
(ii) The plan shall provide that, with respect to any such pollutant
for which no National Ambient Air Quality Standard exists, the analysis
shall contain such air quality monitoring data as the reviewing
authority determines is necessary to assess ambient air quality for that
pollutant in any area that the emissions of that pollutant would affect.
(iii) The plan shall provide that with respect to any such pollutant
(other than nonmethane hydrocarbons) for which such a standard does
exist, the analysis shall contain continuous air quality monitoring data
gathered for purposes of determining whether emissions of that pollutant
would cause or contribute to a violation of the standard or any maxiumum
allowable increase.
(iv) The plan shall provide that, in general, the continuous air
monitoring data that is required shall have been gathered over a period
of one year and shall represent the year preceding receipt of the
application, except that, if the reviewing authority determines that a
complete and adequate analysis can be accomplished with monitoring data
gathered over a period shorter than one year (but not to be less than
four months), the data that is required shall have been gathered over at
least that shorter period.
(v) The plan may provide that the owner or operator of a proposed
major stationary source or major modification of volatile organic
compounds who satisfies all conditions of 40 CFR part 51 appendix S,
section IV may provide postapproval monitoring data for ozone in lieu of
providing preconstruction data as required under paragraph (m)(1) of
this section.
(2) Post-construction monitoring. The plan shall provide that the
owner or operator of a major stationary source or major modification
shall, after construction of the stationary source or modification,
conduct such ambient monitoring as the reviewing authority determines is
necessary to determine the effect emissions from the stationary source
or modification may have, or are having, on air quality in any area.
(3) Operation of monitoring stations. The plan shall provide that
the owner or operator of a major stationary source or major modification
shall meet the requirements of appendix B to part 58 of this chapter
during the operation of monitoring stations for purposes of satisfying
paragraph (m) of this section.
(n) Source information. (1) The plan shall provide that the owner or
operator of a proposed source or modification shall submit all
information necessary to perform any analysis or make any determination
required under procedures established in accordance with this section.
(2) The plan may provide that such information shall include:
(i) A description of the nature, location, design capacity, and
typical operating schedule of the source or modification, including
specifications and drawings showing its design and plant layout;
(ii) A detailed schedule for construction of the source or
modification;
[[Page 218]]
(iii) A detailed description as to what system of continuous
emission reduction is planned by the source or modification, emission
estimates, and any other information as necessary to determine that best
available control technology as applicable would be applied;
(3) The plan shall provide that upon request of the State, the owner
or operator shall also provide information on:
(i) The air quality impact of the source or modification, including
meteorological and topographical data necessary to estimate such impact;
and
(ii) The air quality impacts and the nature and extent of any or all
general commercial, residential, industrial, and other growth which has
occurred since August 7, 1977, in the area the source or modification
would affect.
(o) Additional impact analyses. The plan shall provide that--
(1) The owner or operator shall provide an analysis of the
impairment to visibility, soils, and vegetation that would occur as a
result of the source or modification and general commercial,
residential, industrial, and other growth associated with the source or
modification. The owner or operator need not provide an analysis of the
impact on vegetation having no significant commercial or recreational
value.
(2) The owner or operator shall provide an analysis of the air
quality impact projected for the area as a result of general commercial,
residential, industrial, and other growth associated with the source or
modification.
(p) Sources impacting Federal Class I areas--additional
requirements--(1) Notice to EPA. The plan shall provide that the
reviewing authority shall transmit to the Administrator a copy of each
permit application relating to a major stationary source or major
modification and provide notice to the Administrator of every action
related to the consideration of such permit.
(2) Federal Land Manager. The Federal Land Manager and the Federal
official charged with direct responsibility for management of Class I
lands have an affirmative responsibility to protect the air quality
related values (including visibility) of any such lands and to consider,
in consultation with the Administrator, whether a proposed source or
modification would have an adverse impact on such values.
(3) Denial--impact on air quality related values. The plan shall
provide a mechanism whereby a Federal Land Manager of any such lands may
present to the State, after the reviewing authority's preliminary
determination required under procedures developed in accordance with
paragraph (r) of this section, a demonstration that the emissions from
the proposed source or modification would have an adverse impact on the
air quality-related values (including visibility) of any Federal
mandatory Class I lands, notwithstanding that the change in air quality
resulting from emissions from such source or modification would not
cause or contribute to concentrations which would exceed the maximum
allowable increases for a Class I area. If the State concurs with such
demonstration, the reviewing authority shall not issue the permit.
(4) Class I Variances. The plan may provide that the owner or
operator of a proposed source or modification may demonstrate to the
Federal Land Manager that the emissions from such source would have no
adverse impact on the air quality related values of such lands
(including visibility), notwithstanding that the change in air quality
resulting from emissions from such source or modification would cause or
contribute to concentrations which would exceed the maximum allowable
increases for a Class I area. If the Federal land manager concurs with
such demonstration and so certifies to the State, the reviewing
authority may: Provided, That applicable requirements are otherwise met,
issue the permit with such emission limitations as may be necessary to
assure that emissions of sulfur dioxide, particulate matter, and
nitrogen oxides would not exceed the following maximum allowable
increases over minor source baseline concentration for such pollutants:
------------------------------------------------------------------------
Maximum
allowable
increase
Pollutant (micrograms
per cubic
meter)
------------------------------------------------------------------------
Particulate matter:
PM-10, annual arithmetic mean.......................... 17
PM-10, 24-hour maximum................................. 30
[[Page 219]]
Sulfur dioxide:
Annual arithmetic mean................................. 20
24-hr maximum.......................................... 91
3-hr maximum........................................... 325
Nitrogen dioxide: Annual arithmetic mean................... 25
------------------------------------------------------------------------
(5) Sulfur dioxide variance by Governor with Federal Land Manager's
concurrence. The plan may provide that--
(i) The owner or operator of a proposed source or modification which
cannot be approved under procedures developed pursuant to paragraph
(q)(4) of this section may demonstrate to the Governor that the source
or modification cannot be constructed by reason of any maximum allowable
increase for sulfur dioxide for periods of twenty-four hours or less
applicable to any Class I area and, in the case of Federal mandatory
Class I areas, that a variance under this clause would not adversely
affect the air quality related values of the area (including
visibility);
(ii) The Governor, after consideration of the Federal Land Manager's
recommendation (if any) and subject to his concurrence, may grant, after
notice and an opportunity for a public hearing, a variance from such
maximum allowable increase; and
(iii) If such variance is granted, the reviewing authority may issue
a permit to such source or modification in accordance with provisions
developed pursuant to paragraph (q)(7) of this section: Provided, That
the applicable requirements of the plan are otherwise met.
(6) Variance by the Governor with the President's concurrence. The
plan may provide that--
(i) The recommendations of the Governor and the Federal Land Manager
shall be transferred to the President in any case where the Governor
recommends a variance in which the Federal Land Manager does not concur;
(ii) The President may approve the Governor's recommendation if he
finds that such variance is in the national interest; and
(iii) If such a variance is approved, the reviewing authority may
issue a permit in accordance with provisions developed pursuant to the
requirements of paragraph (q)(7) of this section: Provided, That the
applicable requirements of the plan are otherwise met.
(7) Emission limitations for Presidential or gubernatorial variance.
The plan shall provide that in the case of a permit issued under
procedures developed pursuant to paragraph (q) (5) or (6) of this
section, the source or modification shall comply with emission
limitations as may be necessary to assure that emissions of sulfur
dioxide from the source or modification would not (during any day on
which the otherwise applicable maximum allowable increases are exceeded)
cause or contribute to concentrations which would exceed the following
maximum allowable increases over the baseline concentration and to
assure that such emissions would not cause or contribute to
concentrations which exceed the otherwise applicable maximum allowable
increases for periods of exposure of 24 hours or less for more than 18
days, not necessarily consecutive, during any annual period:
Maximum Allowable Increase
[Micrograms per cubic meter]
------------------------------------------------------------------------
Terrain areas
Period of exposure -----------------
Low High
------------------------------------------------------------------------
24-hr maximum......................................... 36 62
3-hr maximum.......................................... 130 221
------------------------------------------------------------------------
(q) Public participation. The plan shall provide that--
(1) The reviewing authority shall notify all applicants within a
specified time period as to the completeness of the application or any
deficiency in the application or information submitted. In the event of
such a deficiency, the date of receipt of the application shall be the
date on which the reviewing authority received all required information.
(2) Within one year after receipt of a complete application, the
reviewing authority shall:
(i) Make a preliminary determination whether construction should be
approved, approved with conditions, or disapproved.
[[Page 220]]
(ii) Make available in at least one location in each region in which
the proposed source would be constructed a copy of all materials the
applicant submitted, a copy of the preliminary determination, and a copy
or summary of other materials, if any, considered in making the
preliminary determination.
(iii) Notify the public, by advertisement in a newspaper of general
circulation in each region in which the proposed source would be
constructed, of the application, the preliminary determination, the
degree of increment consumption that is expected from the source or
modification, and of the opportunity for comment at a public hearing as
well as written public comment.
(iv) Send a copy of the notice of public comment to the applicant,
the Administrator and to officials and agencies having cognizance over
the location where the proposed construction would occur as follows: Any
other State or local air pollution control agencies, the chief
executives of the city and county where the source would be located; any
comprehensive regional land use planning agency, and any State, Federal
Land Manager, or Indian Governing body whose lands may be affected by
emissions from the source or modification.
(v) Provide opportunity for a public hearing for interested persons
to appear and submit written or oral comments on the air quality impact
of the source, alternatives to it, the control technology required, and
other appropriate considerations.
(vi) Consider all written comments submitted within a time specified
in the notice of public comment and all comments received at any public
hearing(s) in making a final decision on the approvability of the
application. The reviewing authority shall make all comments available
for public inspection in the same locations where the reviewing
authority made available preconstruction information relating to the
proposed source or modification.
(vii) Make a final determination whether construction should be
approved, approved with conditions, or disapproved.
(viii) Notify the applicant in writing of the final determination
and make such notification available for public inspection at the same
location where the reviewing authority made available preconstruction
information and public comments relating to the source.
(r) Source obligation. (1) The plan shall include enforceable
procedures to provide that approval to construct shall not relieve any
owner or operator of the responsibility to comply fully with applicable
provisions of the plan and any other requirements under local, State or
Federal law.
(2) The plan shall provide that at such time that a particular
source or modification becomes a major stationary source or major
modification solely by virtue of a relaxation in any enforceable
limitation which was established after August 7, 1980, on the capacity
of the source or modification otherwise to emit a pollutant, such as a
restriction on hours of operation, then the requirements of paragraphs
(j) through (s) of this section shall apply to the source or
modification as though construction had not yet commenced on the source
or modification.
(3)-(5) [Reserved]
(6) Each plan shall provide that the following specific provisions
apply to projects at existing emissions units at a major stationary
source (other than projects at a Clean Unit or at a source with a PAL)
in circumstances where there is a reasonable possibility that a project
that is not a part of a major modification may result in a significant
emissions increase and the owner or operator elects to use the method
specified in paragraphs (b)(40)(ii)(a) through (c) of this section for
calculating projected actual emissions. Deviations from these provisions
will be approved only if the State specifically demonstrates that the
submitted provisions are more stringent than or at least as stringent in
all respects as the corresponding provisions in paragraphs (r)(6)(i)
through (v) of this section.
(i) Before beginning actual construction of the project, the owner
or operator shall document and maintain a record of the following
information:
(a) A description of the project;
(b) Identification of the emissions unit(s) whose emissions of a
regulated
[[Page 221]]
NSR pollutant could be affected by the project; and
(c) A description of the applicability test used to determine that
the project is not a major modification for any regulated NSR pollutant,
including the baseline actual emissions, the projected actual emissions,
the amount of emissions excluded under paragraph (b)(40)(ii)(c) of this
section and an explanation for why such amount was excluded, and any
netting calculations, if applicable.
(ii) If the emissions unit is an existing electric utility steam
generating unit, before beginning actual construction, the owner or
operator shall provide a copy of the information set out in paragraph
(r)(6)(i) of this section to the reviewing authority. Nothing in this
paragraph (r)(6)(ii) shall be construed to require the owner or operator
of such a unit to obtain any determination from the reviewing authority
before beginning actual construction.
(iii) The owner or operator shall monitor the emissions of any
regulated NSR pollutant that could increase as a result of the project
and that is emitted by any emissions unit identified in paragraph
(r)(6)(i)(b) of this section; and calculate and maintain a record of the
annual emissions, in tons per year on a calendar year basis, for a
period of 5 years following resumption of regular operations after the
change, or for a period of 10 years following resumption of regular
operations after the change if the project increases the design capacity
or potential to emit of that regulated NSR pollutant at such emissions
unit.
(iv) If the unit is an existing electric utility steam generating
unit, the owner or operator shall submit a report to the reviewing
authority within 60 days after the end of each year during which records
must be generated under paragraph (r)(6)(iii) of this section setting
out the unit's annual emissions during the calendar year that preceded
submission of the report.
(v) If the unit is an existing unit other than an electric utility
steam generating unit, the owner or operator shall submit a report to
the reviewing authority if the annual emissions, in tons per year, from
the project identified in paragraph (r)(6)(i) of this section, exceed
the baseline actual emissions (as documented and maintained pursuant to
paragraph (r)(6)(i)(c) of this section) by a significant amount (as
defined in paragraph (b)(23) of this section) for that regulated NSR
pollutant, and if such emissions differ from the preconstruction
projection as documented and maintained pursuant to paragraph
(r)(6)(i)(c) of this section. Such report shall be submitted to the
reviewing authority within 60 days after the end of such year. The
report shall contain the following:
(a) The name, address and telephone number of the major stationary
source;
(b) The annual emissions as calculated pursuant to paragraph
(r)(6)(iii) of this section; and
(c) Any other information that the owner or operator wishes to
include in the report (e.g., an explanation as to why the emissions
differ from the preconstruction projection).
(7) Each plan shall provide that the owner or operator of the source
shall make the information required to be documented and maintained
pursuant to paragraph (r)(6) of this section available for review upon
request for inspection by the reviewing authority or the general public
pursuant to the requirements contained in Sec. 70.4(b)(3)(viii) of this
chapter.
(s) Innovative control technology. (1) The plan may provide that an
owner or operator of a proposed major stationary source or major
modification may request the reviewing authority to approve a system of
innovative control technology.
(2) The plan may provide that the reviewing authority may, with the
consent of the Governor(s) of other affected State(s), determine that
the source or modification may employ a system of innovative control
technology, if:
(i) The proposed control system would not cause or contribute to an
unreasonable risk to public health, welfare, or safety in its operation
or function;
(ii) The owner or operator agrees to achieve a level of continuous
emissions reduction equivalent to that which would have been required
under paragraph (j)(2) of this section, by a date specified by the
reviewing authority.
[[Page 222]]
Such date shall not be later than 4 years from the time of startup or 7
years from permit issuance;
(iii) The source or modification would meet the requirements
equivalent to those in paragraphs (j) and (k) of this section, based on
the emissions rate that the stationary source employing the system of
innovative control technology would be required to meet on the date
specified by the reviewing authority;
(iv) The source or modification would not before the date specified
by the reviewing authority:
(a) Cause or contribute to any violation of an applicable national
ambient air quality standard; or
(b) Impact any area where an applicable increment is known to be
violated;
(v) All other applicable requirements including those for public
participation have been met.
(vi) The provisions of paragraph (p) of this section (relating to
Class I areas) have been satisfied with respect to all periods during
the life of the source or modification.
(3) The plan shall provide that the reviewing authority shall
withdraw any approval to employ a system of innovative control
technology made under this section, if:
(i) The proposed system fails by the specified date to achieve the
required continuous emissions reduction rate; or
(ii) The proposed system fails before the specified date so as to
contribute to an unreasonable risk to public health, welfare, or safety;
or
(iii) The reviewing authority decides at any time that the proposed
system is unlikely to achieve the required level of control or to
protect the public health, welfare, or safety.
(4) The plan may provide that if a source or modification fails to
meet the required level of continuous emissions reduction within the
specified time period, or if the approval is withdrawn in accordance
with paragraph (s)(3) of this section, the reviewing authority may allow
the source or modification up to an additional 3 years to meet the
requirement for the application of best available control technology
through use of a demonstrated system of control.
(t) Clean Unit Test for emissions units that are subject to BACT or
LAER. The plan shall provide an owner or operator of a major stationary
source the option of using the Clean Unit Test to determine whether
emissions increases at a Clean Unit are part of a project that is a
major modification according to the provisions in paragraphs (t)(1)
through (9) of this section.
(1) Applicability. The provisions of this paragraph (t) apply to any
emissions unit for which the reviewing authority has issued a major NSR
permit within the past 10 years.
(2) General provisions for Clean Units. The provisions in paragraphs
(t)(2)(i) through (iv) of this section apply to a Clean Unit.
(i) Any project for which the owner or operator begins actual
construction after the effective date of the Clean Unit designation (as
determined in accordance with paragraph (t)(4) of this section) and
before the expiration date (as determined in accordance with paragraph
(t)(5) of this section) will be considered to have occurred while the
emissions unit was a Clean Unit.
(ii) If a project at a Clean Unit does not cause the need for a
change in the emission limitations or work practice requirements in the
permit for the unit that were adopted in conjunction with BACT and the
project would not alter any physical or operational characteristics that
formed the basis for the BACT determination as specified in paragraph
(t)(6)(iv) of this section, the emissions unit remains a Clean Unit.
(iii) If a project causes the need for a change in the emission
limitations or work practice requirements in the permit for the unit
that were adopted in conjunction with BACT or the project would alter
any physical or operational characteristics that formed the basis for
the BACT determination as specified in paragraph (t)(6)(iv) of this
section, then the emissions unit loses its designation as a Clean Unit
upon issuance of the necessary permit revisions (unless the unit re-
qualifies as a Clean Unit pursuant to paragraph (t)(3)(iii) of this
section). If the owner or operator begins actual construction on the
project without first applying to revise the emissions unit's permit,
the
[[Page 223]]
Clean Unit designation ends immediately prior to the time when actual
construction begins.
(iv) A project that causes an emissions unit to lose its designation
as a Clean Unit is subject to the applicability requirements of
paragraphs (a)(7)(iv)(a) through (d) and paragraph (a)(7)(iv)(f) of this
section as if the emissions unit is not a Clean Unit.
(3) Qualifying or re-qualifying to use the Clean Unit Applicability
Test. An emissions unit automatically qualifies as a Clean Unit when the
unit meets the criteria in paragraphs (t)(3)(i) and (ii) of this
section. After the original Clean Unit designation expires in accordance
with paragraph (t)(5) of this section or is lost pursuant to paragraph
(t)(2)(iii) of this section, such emissions unit may re-qualify as a
Clean Unit under either paragraph (t)(3)(iii) of this section, or under
the Clean Unit provisions in paragraph (u) of this section. To re-
qualify as a Clean Unit under paragraph (t)(3)(iii) of this section, the
emissions unit must obtain a new major NSR permit issued through the
applicable PSD program and meet all the criteria in paragraph
(t)(3)(iii) of this section. The Clean Unit designation applies
individually for each pollutant emitted by the emissions unit.
(i) Permitting requirement. The emissions unit must have received a
major NSR permit within the past 10 years. The owner or operator must
maintain and be able to provide information that would demonstrate that
this permitting requirement is met.
(ii) Qualifying air pollution control technologies. Air pollutant
emissions from the emissions unit must be reduced through the use of air
pollution control technology (which includes pollution prevention as
defined under paragraph (b)(38) of this section or work practices) that
meets both the following requirements in paragraphs (t)(3)(ii)(a) and
(b) of this section.
(a) The control technology achieves the BACT or LAER level of
emissions reductions as determined through issuance of a major NSR
permit within the past 10 years. However, the emissions unit is not
eligible for the Clean Unit designation if the BACT determination
resulted in no requirement to reduce emissions below the level of a
standard, uncontrolled, new emissions unit of the same type.
(b) The owner or operator made an investment to install the control
technology. For the purpose of this determination, an investment
includes expenses to research the application of a pollution prevention
technique to the emissions unit or expenses to apply a pollution
prevention technique to an emissions unit.
(iii) Re-qualifying for the Clean Unit designation. The emissions
unit must obtain a new major NSR permit that requires compliance with
the current-day BACT (or LAER), and the emissions unit must meet the
requirements in paragraphs (t)(3)(i) and (t)(3)(ii) of this section.
(4) Effective date of the Clean Unit designation. The effective date
of an emissions unit's Clean Unit designation (that is, the date on
which the owner or operator may begin to use the Clean Unit Test to
determine whether a project at the emissions unit is a major
modification) is determined according to the applicable paragraph
(t)(4)(i) or (t)(4)(ii) of this section.
(i) Original Clean Unit designation, and emissions units that re-
qualify as Clean Units by implementing a new control technology to meet
current-day BACT. The effective date is the date the emissions unit's
air pollution control technology is placed into service, or 3 years
after the issuance date of the major NSR permit, whichever is earlier,
but no sooner than the date that provisions for the Clean Unit
applicability test are approved by the Administrator for incorporation
into the plan and become effective for the State in which the unit is
located.
(ii) Emissions Units that re-qualify for the Clean Unit designation
using an existing control technology. The effective date is the date the
new, major NSR permit is issued.
(5) Clean Unit expiration. An emissions unit's Clean Unit
designation expires (that is, the date on which the owner or operator
may no longer use the Clean Unit Test to determine whether a project
affecting the emissions unit is, or is part of, a major
[[Page 224]]
modification) according to the applicable paragraph (t)(5)(i) or (ii) of
this section.
(i) Original Clean Unit designation, and emissions units that re-
qualify by implementing new control technology to meet current-day BACT.
For any emissions unit that automatically qualifies as a Clean Unit
under paragraphs (t)(3)(i) and (ii) of this section or re-qualifies by
implementing new control technology to meet current-day BACT under
paragraph (t)(3)(iii) of this section, the Clean Unit designation
expires 10 years after the effective date, or the date the equipment
went into service, whichever is earlier; or, it expires at any time the
owner or operator fails to comply with the provisions for maintaining
the Clean Unit designation in paragraph (t)(7) of this section.
(ii) Emissions units that re-qualify for the Clean Unit designation
using an existing control technology. For any emissions unit that re-
qualifies as a Clean Unit under paragraph (t)(3)(iii) of this section
using an existing control technology, the Clean Unit designation expires
10 years after the effective date; or, it expires any time the owner or
operator fails to comply with the provisions for maintaining the Clean
Unit designation in paragraph (t)(7) of this section.
(6) Required title V permit content for a Clean Unit. After the
effective date of the Clean Unit designation, and in accordance with the
provisions of the applicable title V permit program under part 70 or
part 71 of this chapter, but no later than when the title V permit is
renewed, the title V permit for the major stationary source must include
the following terms and conditions related to the Clean Unit in
paragraphs (t)(6)(i) through (vi) of this section.
(i) A statement indicating that the emissions unit qualifies as a
Clean Unit and identifying the pollutant(s) for which this Clean Unit
designation applies.
(ii) The effective date of the Clean Unit designation. If this date
is not known when the Clean Unit designation is initially recorded in
the title V permit (e.g., because the air pollution control technology
is not yet in service), the permit must describe the event that will
determine the effective date (e.g., the date the control technology is
placed into service). Once the effective date is determined, the owner
or operator must notify the reviewing authority of the exact date. This
specific effective date must be added to the source's title V permit at
the first opportunity, such as a modification, revision, reopening, or
renewal of the title V permit for any reason, whichever comes first, but
in no case later than the next renewal.
(iii) The expiration date of the Clean Unit designation. If this
date is not known when the Clean Unit designation is initially recorded
into the title V permit (e.g., because the air pollution control
technology is not yet in service), then the permit must describe the
event that will determine the expiration date (e.g., the date the
control technology is placed into service). Once the expiration date is
determined, the owner or operator must notify the reviewing authority of
the exact date. The expiration date must be added to the source's title
V permit at the first opportunity, such as a modification, revision,
reopening, or renewal of the title V permit for any reason, whichever
comes first, but in no case later than the next renewal.
(iv) All emission limitations and work practice requirements adopted
in conjunction with BACT, and any physical or operational
characteristics that formed the basis for the BACT determination (e.g.,
possibly the emissions unit's capacity or throughput).
(v) Monitoring, recordkeeping, and reporting requirements as
necessary to demonstrate that the emissions unit continues to meet the
criteria for maintaining the Clean Unit designation. (See paragraph
(t)(7) of this section.)
(vi) Terms reflecting the owner or operator's duties to maintain the
Clean Unit designation and the consequences of failing to do so, as
presented in paragraph (t)(7) of this section.
(7) Maintaining the Clean Unit designation. To maintain the Clean
Unit designation, the owner or operator must conform to all the
restrictions listed in paragraphs (t)(7)(i) through (iii) of this
section. This paragraph (t)(7) applies independently to each pollutant
for which the emissions unit has the Clean
[[Page 225]]
Unit designation. That is, failing to conform to the restrictions for
one pollutant affects the Clean Unit designation only for that
pollutant.
(i) The Clean Unit must comply with the emission limitation(s) and/
or work practice requirements adopted in conjunction with the BACT that
is recorded in the major NSR permit, and subsequently reflected in the
title V permit. The owner or operator may not make a physical change in
or change in the method of operation of the Clean Unit that causes the
emissions unit to function in a manner that is inconsistent with the
physical or operational characteristics that formed the basis for the
BACT determination (e.g., possibly the emissions unit's capacity or
throughput).
(ii) The Clean Unit must comply with any terms and conditions in the
title V permit related to the unit's Clean Unit designation.
(iii) The Clean Unit must continue to control emissions using the
specific air pollution control technology that was the basis for its
Clean Unit designation. If the emissions unit or control technology is
replaced, then the Clean Unit designation ends.
(8) Netting at Clean Units. Emissions changes that occur at a Clean
Unit must not be included in calculating a significant net emissions
increase (that is, must not be used in a ``netting analysis''), unless
such use occurs before the effective date of the Clean Unit designation,
or after the Clean Unit designation expires; or, unless the emissions
unit reduces emissions below the level that qualified the unit as a
Clean Unit. However, if the Clean Unit reduces emissions below the level
that qualified the unit as a Clean Unit, then the owner or operator may
generate a credit for the difference between the level that qualified
the unit as a Clean Unit and the new emission limitation if such
reductions are surplus, quantifiable, and permanent. For purposes of
generating offsets, the reductions must also be federally enforceable.
For purposes of determining creditable net emissions increases and
decreases, the reductions must also be enforceable as a practical
matter.
(9) Effect of redesignation on the Clean Unit designation. The Clean
Unit designation of an emissions unit is not affected by redesignation
of the attainment status of the area in which it is located. That is, if
a Clean Unit is located in an attainment area and the area is
redesignated to nonattainment, its Clean Unit designation is not
affected. Similarly, redesignation from nonattainment to attainment does
not affect the Clean Unit designation. However, if an existing Clean
Unit designation expires, it must re-qualify under the requirements that
are currently applicable in the area.
(u) Clean Unit provisions for emissions units that achieve an
emission limitation comparable to BACT. The plan shall provide an owner
or operator of a major stationary source the option of using the Clean
Unit Test to determine whether emissions increases at a Clean Unit are
part of a project that is a major modification according to the
provisions in paragraphs (u)(1) through (11) of this section.
(1) Applicability. The provisions of this paragraph (u) apply to
emissions units which do not qualify as Clean Units under paragraph (t)
of this section, but which are achieving a level of emissions control
comparable to BACT, as determined by the reviewing authority in
accordance with this paragraph (u).
(2) General provisions for Clean Units. The provisions in paragraphs
(u)(2)(i) through (iv) of this section apply to a Clean Unit.
(i) Any project for which the owner or operator begins actual
construction after the effective date of the Clean Unit designation (as
determined in accordance with paragraph (u)(5) of this section) and
before the expiration date (as determined in accordance with paragraph
(u)(6) of this section) will be considered to have occurred while the
emissions unit was a Clean Unit.
(ii) If a project at a Clean Unit does not cause the need for a
change in the emission limitations or work practice requirements in the
permit for the unit that have been determined (pursuant to paragraph
(u)(4) of this section) to be comparable to BACT, and the project would
not alter any physical or operational characteristics that formed the
basis for determining that the emissions unit's control technology
[[Page 226]]
achieves a level of emissions control comparable to BACT as specified in
paragraph (u)(8)(iv) of this section, the emissions unit remains a Clean
Unit.
(iii) If a project causes the need for a change in the emission
limitations or work practice requirements in the permit for the unit
that have been determined (pursuant to paragraph (u)(4) of this section)
to be comparable to BACT, or the project would alter any physical or
operational characteristics that formed the basis for determining that
the emissions unit's control technology achieves a level of emissions
control comparable to BACT as specified in paragraph (u)(8)(iv) of this
section, then the emissions unit loses its designation as a Clean Unit
upon issuance of the necessary permit revisions (unless the unit re-
qualifies as a Clean Unit pursuant to paragraph (u)(3)(iv) of this
section). If the owner or operator begins actual construction on the
project without first applying to revise the emissions unit's permit,
the Clean Unit designation ends immediately prior to the time when
actual construction begins.
(iv) A project that causes an emissions unit to lose its designation
as a Clean Unit is subject to the applicability requirements of
paragraphs (a)(7)(iv)(a) through (d) and paragraph (a)(7)(iv)(f) of this
section as if the emissions unit is not a Clean Unit.
(3) Qualifying or re-qualifying to use the Clean Unit applicability
test. An emissions unit qualifies as a Clean Unit when the unit meets
the criteria in paragraphs (u)(3)(i) through (iii) of this section.
After the original Clean Unit designation expires in accordance with
paragraph (u)(6) of this section or is lost pursuant to paragraph
(u)(2)(iii) of this section, such emissions unit may re-qualify as a
Clean Unit under either paragraph (u)(3)(iv) of this section, or under
the Clean Unit provisions in paragraph (t) of this section. To re-
qualify as a Clean Unit under paragraph (u)(3)(iv) of this section, the
emissions unit must obtain a new permit issued pursuant to the
requirements in paragraphs (u)(7) and (8) of this section and meet all
the criteria in paragraph (u)(3)(iv) of this section. The reviewing
authority will make a separate Clean Unit designation for each pollutant
emitted by the emissions unit for which the emissions unit qualifies as
a Clean Unit.
(i) Qualifying air pollution control technologies. Air pollutant
emissions from the emissions unit must be reduced through the use of air
pollution control technology (which includes pollution prevention as
defined under paragraph (b)(38) or work practices) that meets both the
following requirements in paragraphs (u)(3)(i)(a) and (b) of this
section.
(a) The owner or operator has demonstrated that the emissions unit's
control technology is comparable to BACT according to the requirements
of paragraph (u)(4) of this section. However, the emissions unit is not
eligible for the Clean Unit designation if its emissions are not reduced
below the level of a standard, uncontrolled emissions unit of the same
type (e.g., if the BACT determinations to which it is compared have
resulted in a determination that no control measures are required).
(b) The owner or operator made an investment to install the control
technology. For the purpose of this determination, an investment
includes expenses to research the application of a pollution prevention
technique to the emissions unit or to retool the unit to apply a
pollution prevention technique.
(ii) Impact of emissions from the unit. The reviewing authority must
determine that the allowable emissions from the emissions unit will not
cause or contribute to a violation of any national ambient air quality
standard or PSD increment, or adversely impact an air quality related
value (such as visibility) that has been identified for a Federal Class
I area by a Federal Land Manager and for which information is available
to the general public.
(iii) Date of installation. An emissions unit may qualify as a Clean
Unit even if the control technology, on which the Clean Unit designation
is based, was installed before the effective date of plan requirements
to implement the requirements of this paragraph (u)(3)(iii). However,
for such emissions units, the owner or operator must apply for the Clean
Unit designation
[[Page 227]]
within 2 years after the plan requirements become effective. For
technologies installed after the plan requirements become effective, the
owner or operator must apply for the Clean Unit designation at the time
the control technology is installed.
(iv) Re-qualifying as a Clean Unit. The emissions unit must obtain a
new permit (pursuant to requirements in paragraphs (u)(7) and (8) of
this section) that demonstrates that the emissions unit's control
technology is achieving a level of emission control comparable to
current-day BACT, and the emissions unit must meet the requirements in
paragraphs (u)(3)(i)(a) and (u)(3)(ii) of this section.
(4) Demonstrating control effectiveness comparable to BACT. The
owner or operator may demonstrate that the emissions unit's control
technology is comparable to BACT for purposes of paragraph (u)(3)(i) of
this section according to either paragraph (u)(4)(i) or (ii) of this
section. Paragraph (u)(4)(iii) of this section specifies the time for
making this comparison.
(i) Comparison to previous BACT and LAER determinations. The
Administrator maintains an on-line data base of previous determinations
of RACT, BACT, and LAER in the RACT/BACT/LAER Clearinghouse (RBLC). The
emissions unit's control technology is presumed to be comparable to BACT
if it achieves an emission limitation that is equal to or better than
the average of the emission limitations achieved by all the sources for
which a BACT or LAER determination has been made within the preceding 5
years and entered into the RBLC, and for which it is technically
feasible to apply the BACT or LAER control technology to the emissions
unit. The reviewing authority shall also compare this presumption to any
additional BACT or LAER determinations of which it is aware, and shall
consider any information on achieved-in-practice pollution control
technologies provided during the public comment period, to determine
whether any presumptive determination that the control technology is
comparable to BACT is correct.
(ii) The substantially-as-effective test. The owner or operator may
demonstrate that the emissions unit's control technology is
substantially as effective as BACT. In addition, any other person may
present evidence related to whether the control technology is
substantially as effective as BACT during the public participation
process required under paragraph (u)(7) of this section. The reviewing
authority shall consider such evidence on a case-by-case basis and
determine whether the emissions unit's air pollution control technology
is substantially as effective as BACT.
(iii) Time of comparison--(a) Emissions units with control
technologies that are installed before the effective date of plan
requirements implementing this paragraph. The owner or operator of an
emissions unit whose control technology is installed before the
effective date of plan requirements implementing this paragraph (u) may,
at its option, either demonstrate that the emission limitation achieved
by the emissions unit's control technology is comparable to the BACT
requirements that applied at the time the control technology was
installed, or demonstrate that the emission limitation achieved by the
emissions unit's control technology is comparable to current-day BACT
requirements. The expiration date of the Clean Unit designation will
depend on which option the owner or operator uses, as specified in
paragraph (u)(6) of this section.
(b) Emissions units with control technologies that are installed
after the effective date of plan requirements implementing this
paragraph. The owner or operator must demonstrate that the emission
limitation achieved by the emissions unit's control technology is
comparable to current-day BACT requirements.
(5) Effective date of the Clean Unit designation. The effective date
of an emissions unit's Clean Unit designation (that is, the date on
which the owner or operator may begin to use the Clean Unit Test to
determine whether a project involving the emissions unit is a major
modification) is the date that the permit required by paragraph (u)(7)
of this section is issued or the date that the emissions unit's air
pollution control technology is placed into service, whichever is later.
[[Page 228]]
(6) Clean Unit expiration. If the owner or operator demonstrates
that the emission limitation achieved by the emissions unit's control
technology is comparable to the BACT requirements that applied at the
time the control technology was installed, then the Clean Unit
designation expires 10 years from the date that the control technology
was installed. For all other emissions units, the Clean Unit designation
expires 10 years from the effective date of the Clean Unit designation,
as determined according to paragraph (u)(5) of this section. In
addition, for all emissions units, the Clean Unit designation expires
any time the owner or operator fails to comply with the provisions for
maintaining the Clean Unit designation in paragraph (u)(9) of this
section.
(7) Procedures for designating emissions units as Clean Units. The
reviewing authority shall designate an emissions unit a Clean Unit only
by issuing a permit through a permitting program that has been approved
by the Administrator and that conforms with the requirements of
Secs. 51.160 through 51.164 of this chapter, including requirements for
public notice of the proposed Clean Unit designation and opportunity for
public comment. Such permit must also meet the requirements in paragraph
(u)(8) of this section.
(8) Required permit content. The permit required by paragraph (u)(7)
of this section shall include the terms and conditions set forth in
paragraphs (u)(8)(i) through (vi). Such terms and conditions shall be
incorporated into the major stationary source's title V permit in
accordance with the provisions of the applicable title V permit program
under part 70 or part 71 of this chapter, but no later than when the
title V permit is renewed.
(i) A statement indicating that the emissions unit qualifies as a
Clean Unit and identifying the pollutant(s) for which the Clean Unit
designation applies.
(ii) The effective date of the Clean Unit designation. If this date
is not known when the reviewing authority issues the permit (e.g.,
because the air pollution control technology is not yet in service),
then the permit must describe the event that will determine the
effective date (e.g., the date the control technology is placed into
service). Once the effective date is known, then the owner or operator
must notify the reviewing authority of the exact date. This specific
effective date must be added to the source's title V permit at the first
opportunity, such as a modification, revision, reopening, or renewal of
the title V permit for any reason, whichever comes first, but in no case
later than the next renewal.
(iii) The expiration date of the Clean Unit designation. If this
date is not known when the reviewing authority issues the permit (e.g.,
because the air pollution control technology is not yet in service),
then the permit must describe the event that will determine the
expiration date (e.g., the date the control technology is placed into
service). Once the expiration date is known, then the owner or operator
must notify the reviewing authority of the exact date. The expiration
date must be added to the source's title V permit at the first
opportunity, such as a modification, revision, reopening, or renewal of
the title V permit for any reason, whichever comes first, but in no case
later than the next renewal.
(iv) All emission limitations and work practice requirements adopted
in conjunction with emission limitations necessary to assure that the
control technology continues to achieve an emission limitation
comparable to BACT, and any physical or operational characteristics that
formed the basis for determining that the emissions unit's control
technology achieves a level of emissions control comparable to BACT
(e.g., possibly the emissions unit's capacity or throughput).
(v) Monitoring, recordkeeping, and reporting requirements as
necessary to demonstrate that the emissions unit continues to meet the
criteria for maintaining its Clean Unit designation. (See paragraph
(u)(9) of this section.)
(vi) Terms reflecting the owner or operator's duties to maintain the
Clean Unit designation and the consequences of failing to do so, as
presented in paragraph (u)(9) of this section.
(9) Maintaining the Clean Unit designation. To maintain the Clean
Unit designation, the owner or operator must
[[Page 229]]
conform to all the restrictions listed in paragraphs (u)(9)(i) through
(v) of this section. This paragraph (u)(9) applies independently to each
pollutant for which the reviewing authority has designated the emissions
unit a Clean Unit. That is, failing to conform to the restrictions for
one pollutant affects the Clean Unit designation only for that
pollutant.
(i) The Clean Unit must comply with the emission limitation(s) and/
or work practice requirements adopted to ensure that the control
technology continues to achieve emission control comparable to BACT.
(ii) The owner or operator may not make a physical change in or
change in the method of operation of the Clean Unit that causes the
emissions unit to function in a manner that is inconsistent with the
physical or operational characteristics that formed the basis for the
determination that the control technology is achieving a level of
emission control that is comparable to BACT (e.g., possibly the
emissions unit's capacity or throughput).
(iii) [Reserved]
(iv) The Clean Unit must comply with any terms and conditions in the
title V permit related to the unit's Clean Unit designation.
(v) The Clean Unit must continue to control emissions using the
specific air pollution control technology that was the basis for its
Clean Unit designation. If the emissions unit or control technology is
replaced, then the Clean Unit designation ends.
(10) Netting at Clean Units. Emissions changes that occur at a Clean
Unit must not be included in calculating a significant net emissions
increase (that is, must not be used in a ``netting analysis'') unless
such use occurs before the effective date of plan requirements adopted
to implement this paragraph (u) or after the Clean Unit designation
expires; or, unless the emissions unit reduces emissions below the level
that qualified the unit as a Clean Unit. However, if the Clean Unit
reduces emissions below the level that qualified the unit as a Clean
Unit, then the owner or operator may generate a credit for the
difference between the level that qualified the unit as a Clean Unit and
the emissions unit's new emission limitation if such reductions are
surplus, quantifiable, and permanent. For purposes of generating
offsets, the reductions must also be federally enforceable. For purposes
of determining creditable net emissions increases and decreases, the
reductions must also be enforceable as a practical matter.
(11) Effect of redesignation on the Clean Unit designation. The
Clean Unit designation of an emissions unit is not affected by
redesignation of the attainment designation of the area in which it is
located. That is, if a Clean Unit is located in an attainment area and
the area is redesignated to nonattainment, its Clean Unit designation is
not affected. Similarly, redesignation from nonattainment to attainment
does not affect the Clean Unit designation. However, if a Clean Unit's
designation expires or is lost pursuant to paragraphs (t)(2)(iii) and
(u)(2)(iii) of this section, it must re-qualify under the requirements
that are currently applicable.
(v) PCP exclusion procedural requirements. Each plan shall include
provisions for PCPs equivalent to those contained in paragraphs (v)(1)
through (6) of this section.
(1) Before an owner or operator begins actual construction of a PCP,
the owner or operator must either submit a notice to the reviewing
authority if the project is listed in paragraphs (b)(31)(i) through (vi)
of this section, or if the project is not listed in paragraphs
(b)(31)(i) through (vi) of this section, then the owner or operator must
submit a permit application and obtain approval to use the PCP exclusion
from the reviewing authority consistent with the requirements in
paragraph (v)(5) of this section. Regardless of whether the owner or
operator submits a notice or a permit application, the project must meet
the requirements in paragraph (v)(2) of this section, and the notice or
permit application must contain the information required in paragraph
(v)(3) of this section.
(2) Any project that relies on the PCP exclusion must meet the
requirements in paragraphs (v)(2)(i) and (ii) of this section.
(i) Environmentally beneficial analysis. The environmental benefit
from the emission reductions of pollutants regulated under the Act must
outweigh the
[[Page 230]]
environmental detriment of emissions increases in pollutants regulated
under the Act. A statement that a technology from paragraphs (b)(31)(i)
through (vi) of this section is being used shall be presumed to satisfy
this requirement.
(ii) Air quality analysis. The emissions increases from the project
will not cause or contribute to a violation of any national ambient air
quality standard or PSD increment, or adversely impact an air quality
related value (such as visibility) that has been identified for a
Federal Class I area by a Federal Land Manager and for which information
is available to the general public.
(3) Content of notice or permit application. In the notice or permit
application sent to the reviewing authority, the owner or operator must
include, at a minimum, the information listed in paragraphs (v)(3)(i)
through (v) of this section.
(i) A description of the project.
(ii) The potential emissions increases and decreases of any
pollutant regulated under the Act and the projected emissions increases
and decreases using the methodology in paragraph (a)(7)(vi) of this
section, that will result from the project, and a copy of the
environmentally beneficial analysis required by paragraph (v)(2)(i) of
this section.
(iii) A description of monitoring and recordkeeping, and all other
methods, to be used on an ongoing basis to demonstrate that the project
is environmentally beneficial. Methods should be sufficient to meet the
requirements in part 70 and part 71.
(iv) A certification that the project will be designed and operated
in a manner that is consistent with proper industry and engineering
practices, in a manner that is consistent with the environmentally
beneficial analysis and air quality analysis required by paragraphs
(v)(2)(i) and (ii) of this section, with information submitted in the
notice or permit application, and in such a way as to minimize, within
the physical configuration and operational standards usually associated
with the emissions control device or strategy, emissions of collateral
pollutants.
(v) Demonstration that the PCP will not have an adverse air quality
impact (e.g., modeling, screening level modeling results, or a statement
that the collateral emissions increase is included within the parameters
used in the most recent modeling exercise) as required by paragraph
(v)(2)(ii) of this section. An air quality impact analysis is not
required for any pollutant that will not experience a significant
emissions increase as a result of the project.
(4) Notice process for listed projects. For projects listed in
paragraphs (b)(31)(i) through (vi) of this section, the owner or
operator may begin actual construction of the project immediately after
notice is sent to the reviewing authority (unless otherwise prohibited
under requirements of the applicable plan). The owner or operator shall
respond to any requests by its reviewing authority for additional
information that the reviewing authority determines is necessary to
evaluate the suitability of the project for the PCP exclusion.
(5) Permit process for unlisted projects. Before an owner or
operator may begin actual construction of a PCP project that is not
listed in paragraphs (b)(31)(i) through (vi) of this section, the
project must be approved by the reviewing authority and recorded in a
plan-approved permit or title V permit using procedures that are
consistent with Secs. 51.160 and 51.161 of this chapter. This includes
the requirement that the reviewing authority provide the public with
notice of the proposed approval, with access to the environmentally
beneficial analysis and the air quality analysis, and provide at least a
30-day period for the public and the Administrator to submit comments.
The reviewing authority must address all material comments received by
the end of the comment period before taking final action on the permit.
(6) Operational requirements. Upon installation of the PCP, the
owner or operator must comply with the requirements of paragraphs
(v)(6)(i) through (iv) of this section.
(i) General duty. The owner or operator must operate the PCP
consistent with proper industry and engineering practices, in a manner
that is consistent with the environmentally beneficial analysis and air
quality analysis required by paragraphs (v)(2)(i) and (ii)
[[Page 231]]
of this section, with information submitted in the notice or permit
application required by paragraph (v)(3), and in such a way as to
minimize, within the physical configuration and operational standards
usually associated with the emissions control device or strategy,
emissions of collateral pollutants.
(ii) Recordkeeping. The owner or operator must maintain copies on
site of the environmentally beneficial analysis, the air quality impacts
analysis, and monitoring and other emission records to prove that the
PCP operated consistent with the general duty requirements in paragraph
(v)(6)(i) of this section.
(iii) Permit requirements. The owner or operator must comply with
any provisions in the plan-approved permit or title V permit related to
use and approval of the PCP exclusion.
(iv) Generation of Emission Reduction Credits. Emission reductions
created by a PCP shall not be included in calculating a significant net
emissions increase unless the emissions unit further reduces emissions
after qualifying for the PCP exclusion (e.g., taking an operational
restriction on the hours of operation.) The owner or operator may
generate a credit for the difference between the level of reduction
which was used to qualify for the PCP exclusion and the new emission
limitation if such reductions are surplus, quantifiable, and permanent.
For purposes of generating offsets, the reductions must also be
federally enforceable. For purposes of determining creditable net
emissions increases and decreases, the reductions must also be
enforceable as a practical matter.
(w) Actuals PALs. The plan shall provide for PALs according to the
provisions in paragraphs (w)(1) through (15) of this section.
(1) Applicability. (i) The reviewing authority may approve the use
of an actuals PAL for any existing major stationary source if the PAL
meets the requirements in paragraphs (w)(1) through (15) of this
section. The term ``PAL'' shall mean ``actuals PAL'' throughout
paragraph (w) of this section.
(ii) Any physical change in or change in the method of operation of
a major stationary source that maintains its total source-wide emissions
below the PAL level, meets the requirements in paragraphs (w)(1) through
(15) of this section, and complies with the PAL permit:
(a) Is not a major modification for the PAL pollutant;
(b) Does not have to be approved through the plan's major NSR
program; and
(c) Is not subject to the provisions in paragraph (r)(2) of this
section (restrictions on relaxing enforceable emission limitations that
the major stationary source used to avoid applicability of the major NSR
program).
(iii) Except as provided under paragraph (w)(1)(ii)(c) of this
section, a major stationary source shall continue to comply with all
applicable Federal or State requirements, emission limitations, and work
practice requirements that were established prior to the effective date
of the PAL.
(2) Definitions. The plan shall use the definitions in paragraphs
(w)(2)(i) through (xi) of this section for the purpose of developing and
implementing regulations that authorize the use of actuals PALs
consistent with paragraphs (w)(1) through (15) of this section. When a
term is not defined in these paragraphs, it shall have the meaning given
in paragraph (b) of this section or in the Act.
(i) Actuals PAL for a major stationary source means a PAL based on
the baseline actual emissions (as defined in paragraph (b)(47) of this
section) of all emissions units (as defined in paragraph (b)(7) of this
section) at the source, that emit or have the potential to emit the PAL
pollutant.
(ii) Allowable emissions means ``allowable emissions'' as defined in
paragraph (b)(16) of this section, except as this definition is modified
according to paragraphs (w)(2)(ii)(a) and (b) of this section.
(a) The allowable emissions for any emissions unit shall be
calculated considering any emission limitations that are enforceable as
a practical matter on the emissions unit's potential to emit.
[[Page 232]]
(b) An emissions unit's potential to emit shall be determined using
the definition in paragraph (b)(4) of this section, except that the
words ``or enforceable as a practical matter'' should be added after
``federally enforceable.''
(iii) Small emissions unit means an emissions unit that emits or has
the potential to emit the PAL pollutant in an amount less than the
significant level for that PAL pollutant, as defined in paragraph
(b)(23) of this section or in the Act, whichever is lower.
(iv) Major emissions unit means:
(a) Any emissions unit that emits or has the potential to emit 100
tons per year or more of the PAL pollutant in an attainment area; or
(b) Any emissions unit that emits or has the potential to emit the
PAL pollutant in an amount that is equal to or greater than the major
source threshold for the PAL pollutant as defined by the Act for
nonattainment areas. For example, in accordance with the definition of
major stationary source in section 182(c) of the Act, an emissions unit
would be a major emissions unit for VOC if the emissions unit is located
in a serious ozone nonattainment area and it emits or has the potential
to emit 50 or more tons of VOC per year.
(v) Plantwide applicability limitation (PAL) means an emission
limitation expressed in tons per year, for a pollutant at a major
stationary source, that is enforceable as a practical matter and
established source-wide in accordance with paragraphs (w)(1) through
(15) of this section.
(vi) PAL effective date generally means the date of issuance of the
PAL permit. However, the PAL effective date for an increased PAL is the
date any emissions unit that is part of the PAL major modification
becomes operational and begins to emit the PAL pollutant.
(vii) PAL effective period means the period beginning with the PAL
effective date and ending 10 years later.
(viii) PAL major modification means, notwithstanding paragraphs
(b)(2) and (b)(3) of this section (the definitions for major
modification and net emissions increase), any physical change in or
change in the method of operation of the PAL source that causes it to
emit the PAL pollutant at a level equal to or greater than the PAL.
(ix) PAL permit means the major NSR permit, the minor NSR permit, or
the State operating permit under a program that is approved into the
plan, or the title V permit issued by the reviewing authority that
establishes a PAL for a major stationary source.
(x) PAL pollutant means the pollutant for which a PAL is established
at a major stationary source.
(xi) Significant emissions unit means an emissions unit that emits
or has the potential to emit a PAL pollutant in an amount that is equal
to or greater than the significant level (as defined in paragraph
(b)(23) of this section or in the Act, whichever is lower) for that PAL
pollutant, but less than the amount that would qualify the unit as a
major emissions unit as defined in paragraph (w)(2)(iv) of this section.
(3) Permit application requirements. As part of a permit application
requesting a PAL, the owner or operator of a major stationary source
shall submit the following information in paragraphs (w)(3)(i) through
(iii) of this section to the reviewing authority for approval.
(i) A list of all emissions units at the source designated as small,
significant or major based on their potential to emit. In addition, the
owner or operator of the source shall indicate which, if any, Federal or
State applicable requirements, emission limitations, or work practices
apply to each unit.
(ii) Calculations of the baseline actual emissions (with supporting
documentation). Baseline actual emissions are to include emissions
associated not only with operation of the unit, but also emissions
associated with startup, shutdown, and malfunction.
(iii) The calculation procedures that the major stationary source
owner or operator proposes to use to convert the monitoring system data
to monthly emissions and annual emissions based on a 12-month rolling
total for each month as required by paragraph (w)(13)(i) of this
section.
(4) General requirements for establishing PALs. (i) The plan allows
the reviewing authority to establish a PAL at a major stationary source,
provided that at a minimum, the requirements
[[Page 233]]
in paragraphs (w)(4)(i)(a) through (g) of this section are met.
(a) The PAL shall impose an annual emission limitation in tons per
year, that is enforceable as a practical matter, for the entire major
stationary source. For each month during the PAL effective period after
the first 12 months of establishing a PAL, the major stationary source
owner or operator shall show that the sum of the monthly emissions from
each emissions unit under the PAL for the previous 12 consecutive months
is less than the PAL (a 12-month average, rolled monthly). For each
month during the first 11 months from the PAL effective date, the major
stationary source owner or operator shall show that the sum of the
preceding monthly emissions from the PAL effective date for each
emissions unit under the PAL is less than the PAL.
(b) The PAL shall be established in a PAL permit that meets the
public participation requirements in paragraph (w)(5) of this section.
(c) The PAL permit shall contain all the requirements of paragraph
(w)(7) of this section.
(d) The PAL shall include fugitive emissions, to the extent
quantifiable, from all emissions units that emit or have the potential
to emit the PAL pollutant at the major stationary source.
(e) Each PAL shall regulate emissions of only one pollutant.
(f) Each PAL shall have a PAL effective period of 10 years.
(g) The owner or operator of the major stationary source with a PAL
shall comply with the monitoring, recordkeeping, and reporting
requirements provided in paragraphs (w)(12) through (14) of this section
for each emissions unit under the PAL through the PAL effective period.
(ii) At no time (during or after the PAL effective period) are
emissions reductions of a PAL pollutant that occur during the PAL
effective period creditable as decreases for purposes of offsets under
Sec. 51.165(a)(3)(ii) of this chapter unless the level of the PAL is
reduced by the amount of such emissions reductions and such reductions
would be creditable in the absence of the PAL.
(5) Public participation requirements for PALs. PALs for existing
major stationary sources shall be established, renewed, or increased,
through a procedure that is consistent with Secs. 51.160 and 51.161 of
this chapter. This includes the requirement that the reviewing authority
provide the public with notice of the proposed approval of a PAL permit
and at least a 30-day period for submittal of public comment. The
reviewing authority must address all material comments before taking
final action on the permit.
(6) Setting the 10-year actuals PAL level. The plan shall provide
that the actuals PAL level for a major stationary source shall be
established as the sum of the baseline actual emissions (as defined in
paragraph (b)(47) of this section) of the PAL pollutant for each
emissions unit at the source; plus an amount equal to the applicable
significant level for the PAL pollutant under paragraph (b)(23) of this
section or under the Act, whichever is lower. When establishing the
actuals PAL level, for a PAL pollutant, only one consecutive 24-month
period must be used to determine the baseline actual emissions for all
existing emissions units. However, a different consecutive 24-month
period may be used for each different PAL pollutant. Emissions
associated with units that were permanently shutdown after this 24-month
period must be subtracted from the PAL level. Emissions from units on
which actual construction began after the 24-month period must be added
to the PAL level in an amount equal to the potential to emit of the
units. The reviewing authority shall specify a reduced PAL level(s) (in
tons/yr) in the PAL permit to become effective on the future compliance
date(s) of any applicable Federal or State regulatory requirement(s)
that the reviewing authority is aware of prior to issuance of the PAL
permit. For instance, if the source owner or operator will be required
to reduce emissions from industrial boilers in half from baseline
emissions of 60 ppm NOX to a new rule limit of 30 ppm, then
the permit shall contain a future effective PAL level that is equal to
the current PAL level reduced by half of the original baseline emissions
of such unit(s).
[[Page 234]]
(7) Contents of the PAL permit. The plan shall require that the PAL
permit contain, at a minimum, the information in paragraphs (w)(7)(i)
through (x) of this section.
(i) The PAL pollutant and the applicable source-wide emission
limitation in tons per year.
(ii) The PAL permit effective date and the expiration date of the
PAL (PAL effective period).
(iii) Specification in the PAL permit that if a major stationary
source owner or operator applies to renew a PAL in accordance with
paragraph (w)(10) of this section before the end of the PAL effective
period, then the PAL shall not expire at the end of the PAL effective
period. It shall remain in effect until a revised PAL permit is issued
by the reviewing authority.
(iv) A requirement that emission calculations for compliance
purposes include emissions from startups, shutdowns and malfunctions.
(v) A requirement that, once the PAL expires, the major stationary
source is subject to the requirements of paragraph (w)(9) of this
section.
(vi) The calculation procedures that the major stationary source
owner or operator shall use to convert the monitoring system data to
monthly emissions and annual emissions based on a 12-month rolling total
for each month as required by paragraph (w)(3)(i) of this section.
(vii) A requirement that the major stationary source owner or
operator monitor all emissions units in accordance with the provisions
under paragraph (w)(13) of this section.
(viii) A requirement to retain the records required under paragraph
(w)(13) of this section on site. Such records may be retained in an
electronic format.
(ix) A requirement to submit the reports required under paragraph
(w)(14) of this section by the required deadlines.
(x) Any other requirements that the reviewing authority deems
necessary to implement and enforce the PAL.
(8) PAL effective period and reopening of the PAL permit. The plan
shall require the information in paragraphs (w)(8)(i) and (ii) of this
section.
(i) PAL effective period. The reviewing authority shall specify a
PAL effective period of 10 years.
(ii) Reopening of the PAL permit.
(a) During the PAL effective period, the plan shall require the
reviewing authority to reopen the PAL permit to:
(1) Correct typographical/calculation errors made in setting the PAL
or reflect a more accurate determination of emissions used to establish
the PAL;
(2) Reduce the PAL if the owner or operator of the major stationary
source creates creditable emissions reductions for use as offsets under
Sec. 51.165(a)(3)(ii) of this chapter; and
(3) Revise the PAL to reflect an increase in the PAL as provided
under paragraph (w)(11) of this section.
(b) The plan shall provide the reviewing authority discretion to
reopen the PAL permit for the following:
(1) Reduce the PAL to reflect newly applicable Federal requirements
(for example, NSPS) with compliance dates after the PAL effective date;
(2) Reduce the PAL consistent with any other requirement, that is
enforceable as a practical matter, and that the State may impose on the
major stationary source under the plan; and
(3) Reduce the PAL if the reviewing authority determines that a
reduction is necessary to avoid causing or contributing to a NAAQS or
PSD increment violation, or to an adverse impact on an AQRV that has
been identified for a Federal Class I area by a Federal Land Manager and
for which information is available to the general public.
(c) Except for the permit reopening in paragraph (w)(8)(ii)(a)(1) of
this section for the correction of typographical/calculation errors that
do not increase the PAL level, all reopenings shall be carried out in
accordance with the public participation requirements of paragraph
(w)(5) of this section.
(9) Expiration of a PAL. Any PAL that is not renewed in accordance
with the procedures in paragraph (w)(10) of this section shall expire at
the end of the PAL effective period, and the requirements in paragraphs
(w)(9)(i) through (v) of this section shall apply.
(i) Each emissions unit (or each group of emissions units) that
existed
[[Page 235]]
under the PAL shall comply with an allowable emission limitation under a
revised permit established according to the procedures in paragraphs
(w)(9)(i)(a) and (b) of this section.
(a) Within the time frame specified for PAL renewals in paragraph
(w)(10)(ii) of this section, the major stationary source shall submit a
proposed allowable emission limitation for each emissions unit (or each
group of emissions units, if such a distribution is more appropriate as
decided by the reviewing authority) by distributing the PAL allowable
emissions for the major stationary source among each of the emissions
units that existed under the PAL. If the PAL had not yet been adjusted
for an applicable requirement that became effective during the PAL
effective period, as required under paragraph (w)(10)(v) of this
section, such distribution shall be made as if the PAL had been
adjusted.
(b) The reviewing authority shall decide whether and how the PAL
allowable emissions will be distributed and issue a revised permit
incorporating allowable limits for each emissions unit, or each group of
emissions units, as the reviewing authority determines is appropriate.
(ii) Each emissions unit(s) shall comply with the allowable emission
limitation on a 12-month rolling basis. The reviewing authority may
approve the use of monitoring systems (source testing,emission factors,
etc.) other than CEMS, CERMS, PEMS or CPMS to demonstrate compliance
with the allowable emission limitation.
(iii) Until the reviewing authority issues the revised permit
incorporating allowable limits for each emissions unit, or each group of
emissions units, as required under paragraph (w)(9)(i)(b) of this
section, the source shall continue to comply with a source-wide, multi-
unit emissions cap equivalent to the level of the PAL emission
limitation.
(iv) Any physical change or change in the method of operation at the
major stationary source will be subject to major NSR requirements if
such change meets the definition of major modification in paragraph
(b)(2) of this section.
(v) The major stationary source owner or operator shall continue to
comply with any State or Federal applicable requirements (BACT, RACT,
NSPS, etc.) that may have applied either during the PAL effective period
or prior to the PAL effective period except for those emission
limitations that had been established pursuant to paragraph (r)(2) of
this section, but were eliminated by the PAL in accordance with the
provisions in paragraph (w)(1)(ii)(c) of this section.
(10) Renewal of a PAL. (i) The reviewing authority shall follow the
procedures specified in paragraph (w)(5) of this section in approving
any request to renew a PAL for a major stationary source, and shall
provide both the proposed PAL level and a written rationale for the
proposed PAL level to the public for review and comment. During such
public review, any person may propose a PAL level for the source for
consideration by the reviewing authority.
(ii) Application deadline. The plan shall require that a major
stationary source owner or operator shall submit a timely application to
the reviewing authority to request renewal of a PAL. A timely
application is one that is submitted at least 6 months prior to, but not
earlier than 18 months from, the date of permit expiration. This
deadline for application submittal is to ensure that the permit will not
expire before the permit is renewed. If the owner or operator of a major
stationary source submits a complete application to renew the PAL within
this time period, then the PAL shall continue to be effective until the
revised permit with the renewed PAL is issued.
(iii) Application requirements. The application to renew a PAL
permit shall contain the information required in paragraphs (w)(10)(iii)
(a) through (d) of this section.
(a) The information required in paragraphs (w)(3)(i) through (iii)
of this section.
(b) A proposed PAL level.
(c) The sum of the potential to emit of all emissions units under
the PAL (with supporting documentation).
(d) Any other information the owner or operator wishes the reviewing
authority to consider in determining the
[[Page 236]]
appropriate level for renewing the PAL.
(iv) PAL adjustment. In determining whether and how to adjust the
PAL, the reviewing authority shall consider the options outlined in
paragraphs (w)(10)(iv) (a) and (b) of this section. However, in no case
may any such adjustment fail to comply with paragraph (w)(10)(iv)(c) of
this section.
(a) If the emissions level calculated in accordance with paragraph
(w)(6) of this section is equal to or greater than 80 percent of the PAL
level, the reviewing authority may renew the PAL at the same level
without considering the factors set forth in paragraph (w)(10)(iv)(b) of
this section; or
(b) The reviewing authority may set the PAL at a level that it
determines to be more representative of the source's baseline actual
emissions, or that it determines to be appropriate considering air
quality needs, advances in control technology, anticipated economic
growth in the area, desire to reward or encourage the source's voluntary
emissions reductions, or other factors as specifically identified by the
reviewing authority in its written rationale.
(c) Notwithstanding paragraphs (w)(10)(iv) (a) and (b) of this
section:
(1) If the potential to emit of the major stationary source is less
than the PAL, the reviewing authority shall adjust the PAL to a level no
greater than the potential to emit of the source; and
(2) The reviewing authority shall not approve a renewed PAL level
higher than the current PAL, unless the major stationary source has
complied with the provisions of paragraph (w)(11) of this section
(increasing a PAL).
(v) If the compliance date for a State or Federal requirement that
applies to the PAL source occurs during the PAL effective period, and if
the reviewing authority has not already adjusted for such requirement,
the PAL shall be adjusted at the time of PAL permit renewal or title V
permit renewal, whichever occurs first.
(11) Increasing a PAL during the PAL effective period. (i) The plan
shall require that the reviewing authority may increase a PAL emission
limitation only if the major stationary source complies with the
provisions in paragraphs (w)(11)(i) (a) through (d) of this section.
(a) The owner or operator of the major stationary source shall
submit a complete application to request an increase in the PAL limit
for a PAL major modification. Such application shall identify the
emissions unit(s) contributing to the increase in emissions so as to
cause the major stationary source's emissions to equal or exceed its
PAL.
(b) As part of this application, the major stationary source owner
or operator shall demonstrate that the sum of the baseline actual
emissions of the small emissions units, plus the sum of the baseline
actual emissions of the significant and major emissions units assuming
application of BACT equivalent controls, plus the sum of the allowable
emissions of the new or modified emissions unit(s), exceeds the PAL. The
level of control that would result from BACT equivalent controls on each
significant or major emissions unit shall be determined by conducting a
new BACT analysis at the time the application is submitted, unless the
emissions unit is currently required to comply with a BACT or LAER
requirement that was established within the preceding 10 years. In such
a case, the assumed control level for that emissions unit shall be equal
to the level of BACT or LAER with which that emissions unit must
currently comply.
(c) The owner or operator obtains a major NSR permit for all
emissions unit(s) identified in paragraph (w)(11)(i)(a) of this section,
regardless of the magnitude of the emissions increase resulting from
them (that is, no significant levels apply). These emissions unit(s)
shall comply with any emissions requirements resulting from the major
NSR process (for example, BACT), even though they have also become
subject to the PAL or continue to be subject to the PAL.
(d) The PAL permit shall require that the increased PAL level shall
be effective on the day any emissions unit that is part of the PAL major
modification becomes operational and begins to emit the PAL pollutant.
(ii) The reviewing authority shall calculate the new PAL as the sum
of
[[Page 237]]
the allowable emissions for each modified or new emissions unit, plus
the sum of the baseline actual emissions of the significant and major
emissions units (assuming application of BACT equivalent controls as
determined in accordance with paragraph (w)(11)(i)(b) of this section),
plus the sum of the baseline actual emissions of the small emissions
units.
(iii) The PAL permit shall be revised to reflect the increased PAL
level pursuant to the public notice requirements of paragraph (w)(5) of
this section.
(12) Monitoring requirements for PALs--(i) General requirements. (a)
Each PAL permit must contain enforceable requirements for the monitoring
system that accurately determines plantwide emissions of the PAL
pollutant in terms of mass per unit of time. Any monitoring system
authorized for use in the PAL permit must be based on sound science and
meet generally acceptable scientific procedures for data quality and
manipulation. Additionally, the information generated by such system
must meet minimum legal requirements for admissibility in a judicial
proceeding to enforce the PAL permit.
(b) The PAL monitoring system must employ one or more of the four
general monitoring approaches meeting the minimum requirements set forth
in paragraphs (w)(12)(ii) (a) through (d) of this section and must be
approved by the reviewing authority.
(c) Notwithstanding paragraph (w)(12)(i)(b) of this section, you may
also employ an alternative monitoring approach that meets paragraph
(w)(12)(i)(a) of this section if approved by the reviewing authority.
(d) Failure to use a monitoring system that meets the requirements
of this section renders the PAL invalid.
(ii) Minimum performance requirements for approved monitoring
approaches. The following are acceptable general monitoring approaches
when conducted in accordance with the minimum requirements in paragraphs
(w)(12)(iii) through (ix) of this section:
(a) Mass balance calculations for activities using coatings or
solvents;
(b) CEMS;
(c) CPMS or PEMS; and
(d) Emission factors.
(iii) Mass balance calculations. An owner or operator using mass
balance calculations to monitor PAL pollutant emissions from activities
using coating or solvents shall meet the following requirements:
(a) Provide a demonstrated means of validating the published content
of the PAL pollutant that is contained in or created by all materials
used in or at the emissions unit;
(b) Assume that the emissions unit emits all of the PAL pollutant
that is contained in or created by any raw material or fuel used in or
at the emissions unit, if it cannot otherwise be accounted for in the
process; and
(c) Where the vendor of a material or fuel, which is used in or at
the emissions unit, publishes a range of pollutant content from such
material, the owner or operator must use the highest value of the range
to calculate the PAL pollutant emissions unless the reviewing authority
determines there is site-specific data or a site-specific monitoring
program to support another content within the range.
(iv) CEMS. An owner or operator using CEMS to monitor PAL pollutant
emissions shall meet the following requirements:
(a) CEMS must comply with applicable Performance Specifications
found in 40 CFR part 60, appendix B; and
(b) CEMS must sample, analyze, and record data at least every 15
minutes while the emissions unit is operating.
(v) CPMS or PEMS. An owner or operator using CPMS or PEMS to monitor
PAL pollutant emissions shall meet the following requirements:
(a) The CPMS or the PEMS must be based on current site-specific data
demonstrating a correlation between the monitored parameter(s) and the
PAL pollutant emissions across the range of operation of the emissions
unit; and
(b) Each CPMS or PEMS must sample, analyze, and record data at least
every 15 minutes, or at another less frequent interval approved by the
reviewing authority, while the emissions unit is operating.
(vi) Emission factors. An owner or operator using emission factors
to
[[Page 238]]
monitor PAL pollutant emissions shall meet the following requirements:
(a) All emission factors shall be adjusted, if appropriate, to
account for the degree of uncertainty or limitations in the factors'
development;
(b) The emissions unit shall operate within the designated range of
use for the emission factor, if applicable; and
(c) If technically practicable, the owner or operator of a
significant emissions unit that relies on an emission factor to
calculate PAL pollutant emissions shall conduct validation testing to
determine a site-specific emission factor within 6 months of PAL permit
issuance, unless the reviewing authority determines that testing is not
required.
(vii) A source owner or operator must record and report maximum
potential emissions without considering enforceable emission limitations
or operational restrictions for an emissions unit during any period of
time that there is no monitoring data, unless another method for
determining emissions during such periods is specified in the PAL
permit.
(viii) Notwithstanding the requirements in paragraphs (w)(12)(iii)
through (vii) of this section, where an owner or operator of an
emissions unit cannot demonstrate a correlation between the monitored
parameter(s) and the PAL pollutant emissions rate at all operating
points of the emissions unit, the reviewing authority shall, at the time
of permit issuance:
(a) Establish default value(s) for determining compliance with the
PAL based on the highest potential emissions reasonably estimated at
such operating point(s); or
(b) Determine that operation of the emissions unit during operating
conditions when there is no correlation between monitored parameter(s)
and the PAL pollutant emissions is a violation of the PAL.
(ix) Re-validation. All data used to establish the PAL pollutant
must be re-validated through performance testing or other scientifically
valid means approved by the reviewing authority. Such testing must occur
at least once every 5 years after issuance of the PAL.
(13) Recordkeeping requirements.
(i) The PAL permit shall require an owner or operator to retain a
copy of all records necessary to determine compliance with any
requirement of paragraph (w) of this section and of the PAL, including a
determination of each emissions unit's 12-month rolling total emissions,
for 5 years from the date of such record.
(ii) The PAL permit shall require an owner or operator to retain a
copy of the following records, for the duration of the PAL effective
period plus 5 years:
(a) A copy of the PAL permit application and any applications for
revisions to the PAL; and
(b) Each annual certification of compliance pursuant to title V and
the data relied on in certifying the compliance.
(14) Reporting and notification requirements. The owner or operator
shall submit semi-annual monitoring reports and prompt deviation reports
to the reviewing authority in accordance with the applicable title V
operating permit program. The reports shall meet the requirements in
paragraphs (w)(14)(i) through (iii) of this section.
(i) Semi-annual report. The semi-annual report shall be submitted to
the reviewing authority within 30 days of the end of each reporting
period. This report shall contain the information required in paragraphs
(w)(14)(i)(a) through (g) of this section.
(a) The identification of owner and operator and the permit number.
(b) Total annual emissions (tons/year) based on a 12-month rolling
total for each month in the reporting period recorded pursuant to
paragraph (w)(13)(i) of this section.
(c) All data relied upon, including, but not limited to, any Quality
Assurance or Quality Control data, in calculating the monthly and annual
PAL pollutant emissions.
(d) A list of any emissions units modified or added to the major
stationary source during the preceding 6-month period.
(e) The number, duration, and cause of any deviations or monitoring
malfunctions (other than the time associated with zero and span
calibration checks), and any corrective action taken.
[[Page 239]]
(f) A notification of a shutdown of any monitoring system, whether
the shutdown was permanent or temporary, the reason for the shutdown,
the anticipated date that the monitoring system will be fully
operational or replaced with another monitoring system, and whether the
emissions unit monitored by the monitoring system continued to operate,
and the calculation of the emissions of the pollutant or the number
determined by method included in the permit, as provided by paragraph
(w)(12)(vii) of this section.
(g) A signed statement by the responsible official (as defined by
the applicable title V operating permit program) certifying the truth,
accuracy, and completeness of the information provided in the report.
(ii) Deviation report. The major stationary source owner or operator
shall promptly submit reports of any deviations or exceedance of the PAL
requirements, including periods where no monitoring is available. A
report submitted pursuant to Sec. 70.6(a)(3)(iii)(B) of this chapter
shall satisfy this reporting requirement. The deviation reports shall be
submitted within the time limits prescribed by the applicable program
implementing Sec. 70.6(a)(3)(iii)(B) of this chapter. The reports shall
contain the following information:
(a) The identification of owner and operator and the permit number;
(b) The PAL requirement that experienced the deviation or that was
exceeded;
(c) Emissions resulting from the deviation or the exceedance; and
(d) A signed statement by the responsible official (as defined by
the applicable title V operating permit program) certifying the truth,
accuracy, and completeness of the information provided in the report.
(iii) Re-validation results. The owner or operator shall submit to
the reviewing authority the results of any re-validation test or method
within three months after completion of such test or method.
(15) Transition requirements. (i) No reviewing authority may issue a
PAL that does not comply with the requirements in paragraphs (w)(1)
through (15) of this section after the Administrator has approved
regulations incorporating these requirements into a plan.
(ii) The reviewing authority may supersede any PAL which was
established prior to the date of approval of the plan by the
Administrator with a PAL that complies with the requirements of
paragraphs (w)(1) through (15) of this section.
(x) If any provision of this section, or the application of such
provision to any person or circumstance, is held invalid, the remainder
of this section, or the application of such provision to persons or
circumstances other than those as to which it is held invalid, shall not
be affected thereby.
(Secs. 101(b)(1), 110, 160-169, 171-178, and 301(a), Clean Air Act, as
amended (42 U.S.C. 7401(b)(1), 7410, 7470-7479, 7501-7508, and 7601(a));
sec. 129(a), Clean Air Act Amendments of 1977 (Pub. L. 95-95, 91 Stat.
685 (Aug. 7, 1977)))
[43 FR 26382, June 19, 1978]
Editorial Note: For Federal Register citations affecting
Sec. 51.166, see the List of CFR Sections Affected, which appears in the
Finding Aids section of the printed volume and on GPO Access.
Subpart J--Ambient Air Quality Surveillance
Authority: Secs. 110, 301(a), 313, 319, Clean Air Act (42 U.S.C.
7410, 7601(a), 7613, 7619).
Sec. 51.190 Ambient air quality monitoring requirements.
The requirements for monitoring ambient air quality for purposes of
the plan are located in subpart C of part 58 of this chapter.
[44 FR 27569, May 10, 1979]
Subpart K--Source Survelliance
Source: 51 FR 40673, Nov. 7, 1986, unless otherwise noted.
Sec. 51.210 General.
Each plan must provide for monitoring the status of compliance with
any rules and regulations that set forth any portion of the control
strategy. Specifically, the plan must meet the requirements of this
subpart.
[[Page 240]]
Sec. 51.211 Emission reports and recordkeeping.
The plan must provide for legally enforceable procedures for
requiring owners or operators of stationary sources to maintain records
of and periodically report to the State--
(a) Information on the nature and amount of emissions from the
stationary sources; and
(b) Other information as may be necessary to enable the State to
determine whether the sources are in compliance with applicable portions
of the control strategy.
Sec. 51.212 Testing, inspection, enforcement, and complaints.
The plan must provide for--
(a) Periodic testing and inspection of stationary sources; and
(b) Establishment of a system for detecting violations of any rules
and regulations through the enforcement of appropriate visible emission
limitations and for investigating complaints.
(c) Enforceable test methods for each emission limit specified in
the plan. For the purpose of submitting compliance certifications or
establishing whether or not a person has violated or is in violation of
any standard in this part, the plan must not preclude the use, including
the exclusive use, of any credible evidence or information, relevant to
whether a source would have been in compliance with applicable
requirements if the appropriate performance or compliance test or
procedure had been performed. As an enforceable method, States may use:
(1) Any of the appropriate methods in appendix M to this part,
Recommended Test Methods for State Implementation Plans; or
(2) An alternative method following review and approval of that
method by the Administrator; or
(3) Any appropriate method in appendix A to 40 CFR part 60.
[51 FR 40673, Nov. 7, 1986, as amended at 55 FR 14249, Apr. 17, 1990; 62
FR 8328, Feb. 24, 1997]
Sec. 51.213 Transportation control measures.
(a) The plan must contain procedures for obtaining and maintaining
data on actual emissions reductions achieved as a result of implementing
transportation control measures.
(b) In the case of measures based on traffic flow changes or
reductions in vehicle use, the data must include observed changes in
vehicle miles traveled and average speeds.
(c) The data must be maintained in such a way as to facilitate
comparison of the planned and actual efficacy of the transportation
control measures.
[61 FR 30163, June 14, 1996]
Sec. 51.214 Continuous emission monitoring.
(a) The plan must contain legally enforceable procedures to--
(1) Require stationary sources subject to emission standards as part
of an applicable plan to install, calibrate, maintain, and operate
equipment for continuously monitoring and recording emissions; and
(2) Provide other information as specified in appendix P of this
part.
(b) The procedures must--
(1) Identify the types of sources, by source category and capacity,
that must install the equipment; and
(2) Identify for each source category the pollutants which must be
monitored.
(c) The procedures must, as a minimum, require the types of sources
set forth in appendix P of this part to meet the applicable requirements
set forth therein.
(d)(1) The procedures must contain provisions that require the owner
or operator of each source subject to continuous emission monitoring and
recording requirements to maintain a file of all pertinent information
for at least two years following the date of collection of that
information.
(2) The information must include emission measurements, continuous
monitoring system performance testing measurements, performance
evaluations, calibration checks, and adjustments and maintenance
performed on such monitoring systems and other reports and records
required by appendix P of this part.
(e) The procedures must require the source owner or operator to
submit information relating to emissions and operation of the emission
monitors to the
[[Page 241]]
State to the extent described in appendix P at least as frequently as
described therein.
(f)(1) The procedures must provide that sources subject to the
requirements of paragraph (c) of this section must have installed all
necessary equipment and shall have begun monitoring and recording within
18 months after either--
(i) The approval of a State plan requiring monitoring for that
source; or
(ii) Promulgation by the Agency of monitoring requirements for that
source.
(2) The State may grant reasonable extensions of this period to
sources that--
(i) Have made good faith efforts to purchases, install, and begin
the monitoring and recording of emission data; and
(ii) Have been unable to complete the installation within the
period.
Subpart L--Legal Authority
Source: 51 FR 40673, Nov. 7, 1986, unless otherwise noted.
Sec. 51.230 Requirements for all plans.
Each plan must show that the State has legal authority to carry out
the plan, including authority to:
(a) Adopt emission standards and limitations and any other measures
necessary for attainment and maintenance of national standards.
(b) Enforce applicable laws, regulations, and standards, and seek
injunctive relief.
(c) Abate pollutant emissions on an emergency basis to prevent
substantial endangerment to the health of persons, i.e., authority
comparable to that available to the Administrator under section 305 of
the Act.
(d) Prevent construction, modification, or operation of a facility,
building, structure, or installation, or combination thereof, which
directly or indirectly results or may result in emissions of any air
pollutant at any location which will prevent the attainment or
maintenance of a national standard.
(e) Obtain information necessary to determine whether air pollution
sources are in compliance with applicable laws, regulations, and
standards, including authority to require recordkeeping and to make
inspections and conduct tests of air pollution sources.
(f) Require owners or operators of stationary sources to install,
maintain, and use emission monitoring devices and to make periodic
reports to the State on the nature and amounts of emissions from such
stationary sources; also authority for the State to make such data
available to the public as reported and as correlated with any
applicable emission standards or limitations.
Sec. 51.231 Identification of legal authority.
(a) The provisions of law or regulation which the State determines
provide the authorities required under this section must be specifically
identified, and copies of such laws or regulations be submitted with the
plan.
(b) The plan must show that the legal authorities specified in this
subpart are available to the State at the time of submission of the
plan.
(c) Legal authority adequate to fulfill the requirements of
Sec. 51.230 (e) and (f) of this subpart may be delegated to the State
under section 114 of the Act.
Sec. 51.232 Assignment of legal authority to local agencies.
(a) A State government agency other than the State air pollution
control agency may be assigned responsibility for carrying out a portion
of a plan if the plan demonstrates to the Administrator's satisfaction
that the State governmental agency has the legal authority necessary to
carry out the portion of plan.
(b) The State may authorize a local agency to carry out a plan, or
portion thereof, within such local agency's jurisdiction if--
(1) The plan demonstrates to the Administrator's satisfaction that
the local agency has the legal authority necessary to implement the plan
or portion of it; and
(2) This authorization does not relieve the State of responsibility
under the Act for carrying out such plan, or portion thereof.
[[Page 242]]
Subpart M--Intergovernmental Consultation
Authority: Secs. 110, 121, 174(a), 301(a), Clean Air Act, as amended
(42 U.S.C. 7410, 7421, 7504, and 7601(a)).
Source: 44 FR 35179, June 18, 1979, unless otherwise noted.
Agency Designation
Sec. 51.240 General plan requirements.
Each State implementation plan must identify organizations, by
official title, that will participate in developing, implementing, and
enforcing the plan and the responsibilities of such organizations. The
plan shall include any related agreements or memoranda of understanding
among the organizations.
Sec. 51.241 Nonattainment areas for carbon monoxide and ozone.
(a) For each AQCR or portion of an AQCR in which the national
primary standard for carbon monoxide or ozone will not be attained by
July 1, 1979, the Governor (or Governors for interstate areas) shall
certify, after consultation with local officials, the organization
responsible for developing the revised implementation plan or portions
thereof for such AQCR.
(b)-(f) [Reserved]
[44 FR 35179, June 18, 1979, as amended at 48 FR 29302, June 24, 1983;
60 FR 33922, June 29, 1995; 61 FR 16060, Apr. 11, 1996]
Sec. 51.242 [Reserved]
Subpart N--Compliance Schedules
Source: 51 FR 40673, Nov. 7, 1986, unless otherwise noted.