REGULATIONS AND RESOURCE
| FILE OF CONTINUOUS
g MONITORING INFORMATION
&EPA
Office of Air, Noise and Radiation
Division of Stationary Source Enforcement
Washington, D.C. 20460
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EPA-340/1-81-008
REGULATIONS AND RESOURCE FILE
OF CONTINUOUS MONITORING INFORMATION
October 1981
(Current Through October 1, 1981)
Interim Report
Prepared for:
U. S. ENVIRONMENTAL PROTECTION AGENCY
Office of Enforcement
Office of General Enforcement
Washington, D. C. 20460
by
William J. Pate, P. E.
Kilkelly Environmental Associates, Inc.
Post Office Box 31265
Raleigh, North Carolina 27622
Entropy Environmentalists, Inc. Contract No. 68-01-6317
Kilkelly Environmental Associates, Inc. Subcontract No. 1-81-6317
Task No. 5
EPA Project Officer: Eouis R. Paley, P- E.
National Monitoring Coordinator
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DISCLAIMER
This document was prepared by Kilkelly Environmental Associates, Inc. under
Contract No. 68-01-6317, Task No. 5, and therefore was wholly or partly funded
by the I). S. Environmental Protection Agency. This document has not been sub-
jected to the Agency's required peer and policy review. Therefore this docu-
ment does not necessarily reflect the views of the Agency and official endor-
sement should not be inferred.
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TABLE OF CONTENTS
Page
Introduction iv
I. EPA Continuous Monitoring Contacts I~l
II. Monitoring Regulations II-1
A. NSPS Continuous Emission Monitoring Requirements -
Promulgated . . . . ' • • II-2
Subpart A - General Provisions II-3
Subpart D - Fossil-Fuel Fired Steam Generators ....... II-7
Subpart Da - Electric Utility Steam Generators 11-10
Subpart G - Nitric Acid Plants 11-17
Subpart H - Sulfuric Acid Plants 11-18
Subpart J - Petroleum Refineries 11-19
Subpart P - Primary Copper Smelters 11-21
Subpart Q - Primary Zinc Smelters 11-23
Subpart R - Primary Lead Smelters 11-24
Subpart Z - Ferroalloy Production Facilities 11-25
Subpart AA - Steel Plants: Electric Arc Plants 11-27
Subpart BB - Kraft Pulp Mills 11-28
Subpart HH - Lime Manufacturing Plants 11-31
Appendix A - Reference Methods 1 - 4, 6-9, 19, 20 11-32
Appendix B - Performance Specifications 1, 2, and 3 .... 11-77
B. NSPS Operational Monitoring Requirements - Promulgated . . . 11-89
Subpart N - Iron and Steel Plant (BOPF) 11-90
Subpart T - Wet-Process Phosphoric Acid Plants 11-91
Subpart U - Superphosphoric Acid Plants 11-92
Subpart V - Diammonium Phosphate Plants 11-93
Subpart W - Triple Superphosphate Plants 11-94
Subpart X - Granular Triple Superphosphate Storage
Facilities 11-95
Subpart Y - Coal Preparation Plants 11-96
Subpart GG - Stationary Gas Turbines 11-97
C. NSPS Regulations - Proposed 11-100
October 10, 1979 Proposed Revisions to Performance
Specifications 1, 2, and 3 11-101
January 26, 1981 Proposed Methods 6A and 6B and Reproposed
Revisions to Performance Specifications 2 and 3 11-136
D. SIP Monitoring Requirements - Promulgated (October 6, 1975). 11-149
E. Summary Tables of Monitoring and Emission Regulations
(NSPS and SIPS) (See List of Tables on page iii) .... 11-160
III. Vendors of Continuous Monitoring Equipment III-l
IV. Bibliography of CEM Related Articles IV-1
Availability of EPA Publications IV-6
ii
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LIST OF SUMMARY TABLES
OF MONITORING INFORMATION
Table No. Subject Page
1 NSPS Source Categories Required to Monitor 11-161
Continuously ..
2 Operational Monitoring Requirements (NSPS) 11-165
3 Emission Limitations (NSPS) 11-167
*
4 Proposal and Promulgation Dates of Emission Limitations
for NSPS Source Categories 11-174
5 NSPS Continuous Monitoring Requirements 11-175
6 Quarterly Reporting Requirements (NSPS) 11-176
7 Definitions of Excess Emissions (NSPS) 11-177
8 Spanning and Zeroing (NSPS) .... 11-179
9 Span Specifications (NSPS) 11-180
10 Notifications Requirements (NSPS) . 11-182
11 Subpart Da Emission Limitations (NSPS) 11-183
12 Performance Specifications (NSPS) 11-185
13 When To Run Monitor Performance Test (NSPS) 11-186
14 Requirements for SIP Revisions 11-187
15 Existing Sources Required to Continuously
Monitor Emissions (SIP) 11-188
iii
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INTRODUCTION
On October 6, 1975 the Environmental Protection Agency promulgated con-
tinuous emission monitoring requirements for selected NSPS (40 CFR 60) source
categories. Also on October 6, 1975 EPA promulgated a revision to 40 CFR
Part 51 which required states to revise their State Implementation Plans (SIP)
to include continuous monitori-ng requirements for a minimum number of spe-
cified existing source categories. EPA included in this rulemaking package
performance and test requirements which prescribe minimum design and perfor-
mance crtieria specifications for continuous emission monitors. Since
October 6, 1975, EPA has expanded requirements for continuous monitoring to
additional source categories and has revised the performance specifications.
On June 11, 1979 EPA promulgated major revisions to the Subpart Da NSPS for
new utility steam generating units, including requirements for the use of con-
tinuous emission monitoring systems (GEMS) to demonstrate source compliance
with S02 and NOX emission limitations and the S02 percent reduction standard.
In addition, EPA proposed extensive revisions to the monitor performance spe-
cifications on October 10, 1979 and on January 26, 1981.
This report is a compilation of continuous monitoring information.
Section I identifies some of the EPA personnel responsible for continuous
monitoring implementation. Section II contains updated monitoring regula-
tions excerpted from the Federal Register, along with presently proposed regu-
lations and summary tables of regulatory information. Section III contains a
listing of CEM vendors. Section IV presents a bi-bliography of applicable
literature.
iv
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The EPA, Division of Stationary Source Enforcement first issued this
report in November 1978. It was revised and reissued in October 1979. This
edition has been changed by revising the introduction, the personnel and phone
numbers of the CEM contact lists, Subpart D, and the Summary Tables. The EPA
organization function statements and the excerpts of the preambles which were
in the last report have been deleted. The revised report contains the pro-
posed October 10, 1979 Performance Specifications, the reproposed
January 26, 1981 Performance Specfications, and the proposed Methods 6A and
6B. This report also contains an updated list of CEM vendors and a revised
and updated CEM bibliography.
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SECTION I
EPA CONTINUOUS MONITORING CONTACTS
1-1
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EPA REGIONAL CONTINUOUS MONITORING CONTACTS
Person
REGION I:
Frank Li Hey
REGION II:
Marcus Kantz
Ann Cownir
Dennis Santella
REGION III:
Gary Gross
Andrew Kolarski
REGION IV:
Brian Seals
Keith Colamarino
Jim Littell
Joe Riley
Bill Voshell
REGION V:
Larry Kertcher
Pat McCoy
Ed Zylstra
REGION VI:
Phil Schwindt
Stanley Spruiell
REGION VII:
John Giar
JoAnn Heiman
Mike Sanderson
Tony Wayne
REGION VIII:
Keith Tipton
Roxann Varzeas
Steven Frey
REGION IX:
Alvin
Steve
Chuck
Helen
Paula
Chun
Cimperman
Seeley
Okamoto
Bission
REGION X:
Paul Boys
Wayne Grother
Division
New England Regional Laboratory
Environmental Services Division
Environmental Services Division
Air & Waste Management Division
Air & Waste Management Division
Air & Waste Management Division
Air & Waste Management Division
Air 8 Waste Management Division
Air & Waste Management Division
Air & Waste Management Division
Air & Waste Management Division
Air Management Division
Air Management Division
Environmental Services Division
Environmental Services Division
Air & Waste Materials Division
Environmental Services Division
Air & Waste Management Division
Air & Waste Management Division
Air & Waste Management Division
Environmental Services Division
Air & Waste Management Division
Air & Waste Management Division
Air Management Division
Air Management Division
Air Management Division
Air Management Division
Air Management Division
Environmental Services Division
Air Management Division
Phone Number
(FTS/Comm)
617-861-6700
FTS-340-6690/201-321-6690
FTS-340-6690/201-321-6690
FTS-264-9628/212-264-9628
FTS-597-8907/304-597-8907
FTS-923-1050/304-233-1271
FTS-257-4552/404-881-4552
FTS-257-4298/404-881-4298
FTS-257-4552/404-881-4552
FTS-257-4552/404-881-4552
FTS-257-4862/404-881-4901
FTS-353-2086/312-353-2086
FTS-353-2086/312-353-2086
FTS-353-9771/312-353-9771
FTS-729-2724/214-767-2724
FTS-729-2755/214-767-2755
FTS-758-4461/816-374-4461
FTS-758-7131/816-374-7131
FTS-758-5082/816-374-5082
FTS-758-7130/816-374-7130
FTS-327-4561/303-837-4261
FTS-327-6046/303-837-6046
FTS-327-6047/303-837-6047
FTS-454-8230/415-556-8230
FTS-454-8230/415-556-8230
FTS-454-8038/415-556-8038
FTS-454-8038/415-556-8038
FTS-454-8038/415-556-8038
FTS-399-1106/206-442-1106
FTS-399-1387/206-442-1387
1-2
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EPA CONTINUOUS MONITORING CONTACTS
Subject
Regulations Development
CEM Enforcement
Quality Assurance
Methods Development
and Evaluation
Emissions Measurements
Gas Monitor Research
Opacity Research
Person-Divison
Larry Jones - ESED
Gene Smith - ESED
* Louis Paley - DSSE
Kirk Foster - DSSE
Tom Logan - QAD
Darryl Von Lehmden - QAD
Roger Shigehara - ESED
Peter Westlin - ESED
George Walsh - ESED
Jim Cheney - ESRL
Bill Conner- ESRL
Ken Knapp - ESRL
State Implementation Plans Joseph Sableski - CPDD
John Silvasi - CPDD
Continuous Monitor
Demonstration
D. Bruce Harris - IERL
Phone Number
Commercial/FTS
919-541-5421
629-5421
919-541-5421
629-5421
202-382-2884
382-2884
919-541-4571
629-4571
919-541-2580
629-2580
919-541-2415
629-2415
919-541-2237
629-2237
919-541-2237
629-2237
919-541-5243
629-5243
919-541-3085
629-3085
919-541-3085
629-3085
919-541-3085
629-3085
919-541-5437
629-5437
919-541-5437
629-5437
919-541-7807
629-7807
1-3
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EPA REGIONAL COAL SAMPLING AND ANALYSIS CONTACTS
NAME
Region I:
John Carlson
Region II:
Dennis Santella
Region III;
Peter Schaul
Region IV:
Jim Manning
Region V:
David Schultz
Region VI:
Phil Schwindt
Region VII:
Tony Wayne
Region VIII:
Steven Frey
Region IX:
DIVISION
PHONE NUMBER
New England Regional Laboratory 617-861-6700
Air & Waste Management Division FTS-264-9628/212-264-9628
Air & Waste Management Division FTS-597-3437/304-597-3437
Air & Waste Management Division FTS-881-3286/404-881-3286
Air Management Division FTS-353-2088/312-353-2088
Environmental Services Division FTS-729-2724/214-767-2724
Air & Waste Management Division FTS-758-7130/816-374-7130
Air & Waste Management Division FTS-327-6047/303-837-6047
Region X:
Paul Boys
Environmental Services Division FTS-399-1106/206-442-1106
1-4
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SECTION II
MONITORING REGULATIONS
II-1
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NSPS CONTINUOUS EMISSION MONITORING REQUIREMENTS - PROMULGATED
II-2
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Swbpart A C«iwol Previsions
160.1 Applicability.
Except AS provided In Subparts B and
C, tee provisions of this part apply to
the owner or operator of any stationary
source which contains an affected facil-
ity, the construction or modification of
which is commenced after the date of
publication in tills part of any standard
(or, if earlier, the date of publication of
any proposed standard) applicable to
that facility.
160.2 Definition*.
As used in this part, all terms not
denned herein shall have the meaning
given them in the Act:
(a) "Act" means the Clean Air Act
(42 UJB.C. 1857 et seq., as amended by
Public Law 91-604, 84 Stat. 1876).
(b) "Administrator" means the Ad-
ministrator of the Environmental Pro-
tection Agency or his authorized repre-
sentative.
(c) "Standard" means a standard of
performance proposed or promulgated
under this part.
(d) "Stationary source" means any
building, structure, facility, or installa-
tion which emits or may emit any air
pollutant and which contains any one or
combination of the following:
(1) Affected facilities.
(2) Existing facilities.
(3) Facilities of the type for which no
standards have been promulgated in this
part.
(e) "Affected facility" means, with
reference to a stationary source, any ap-
paratus to which a standard is applicable.
(f) "Owner or operator" means any
person who owns, leases, operates, con-
trols, or supervises an affected facility
or a stationary source of which an af-
fected facility is a part.
(g) "Construction" means fabrication,
erection, or fn»taii«.Hnn of an affected
facility.
(h) "Modification" means any physi-
cal change in, or change in the method
of operation of, an existing facility which
increases the amount of any air pollutant
(to which a standard applies) emitted
into the atmosphere by that facility or
which results in the emission of any air
pollutant (to which a standard- applies)
into the atmosphere not previously
emitted.
(1) "Commenced" means, with respect
to the definition of "new source" In sec-
tion 111 (a) (2) of the Act, that an owner
or operator has undertaken a continuous
program of construction or modification
or that an owner or operator has entered
into a contractual obligation to under-
take and complete, within a reasonable
time, a continuous program of construc-
tion or modification.
(j) "Opacity" means the degree to
which emissions reduce the transmission
of light and obscure the view of an object
m the background.
(k) "Nitrogen oxides" means all oz-
i of nitrogen except nitrous oxide, as
measured by test methods set forth in
this part.
(1) "Standard conditions" means a
temperature of 20*C (68°P) and a pres-
sure of 760 mm of Hg (29.92 In. of Hg).
(m) "Proportional sampling" means
sampling at a rate that produces a con-
stant ratio of sampling rate to stack i**
flow rate.
(n) "Isoldnetic sampling" means
sampling in which the linear velocity of
the gas entering the sampling nozzle is
equal to that of the undisturbed gaa
stream at the sample point.
(o) "Startup" means the setting in
operation 6f an affected facility for any
purpose.
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nature of the intern repair* or adjust-
ments.
(4) When no excess emissions nave
occurred or the continuous monitoring
system u; iivs net, been inoperative, re-
paired, or adjusted, such information
•hall be stated in the report.
(d) Any owner or operator subject to
the provisions ol this part shall maintain
a file of all measurements, including con-
tinuous monitoring system, monitoring
device, and performance testing meas-
urements; all continuous monitoring sys-
tem performance evaluations; all con-
tinuous monitoring system or monitoring
device calibration checks; adjustments
and maintenance performed on these
systems or devices; and all other infor-
mation required by this part recorded in
a permanent form suitable for inspec-
tion. The file shall be retained for at least
two years following the date of such
measurement, ^^^^Tift"^, rcporto, and
records.
| 60.8 Performance le*tt.
(a) Within 60 days after achieving the
maximum production rate at which the
affected facility will be operated, but not
later than 180 days after initial startup
of such facility and at such other times
as may be required by the Administrator
under section 114 of the Act, the owner
or operator of such facility shall conduct
performance test(s) and furnish the Ad-
ministrator a written report of the results
of such performance test(s).
§ 60.11 Compliance with ttandarcU ami
Buintenance requirement*.
(a) Compliance with standards In this
part, other than opacity standards, shall
be determined only by performance testa
established by ! 60.8.
(b) Compliance with opacity stand-
ards in this part shall be determined by
conducting observations ID accordance
with Reference Method t la Appendix A
of this part or any alternative method
that is approved by the Administrator.
Opacity readings of portions of plume*
which contain condensed, uncomblned
water vapor shall not be used for pur-
poses of determining compliance with
opacity standards. The results of con-
tinuous monitoring by transmlssometer
which indicate that the opacity at the
time visual observations were made was
not In excess of the standard are proba-
tive but not conclusive evidence of the
actual opacity of an emission, provided
that the source shall meet the burden of
proving that the Instrument used meets
(at the time of the alleged violation)
Performance Specification 1 In Appendix
B of this part, has been properly main-
tained and (at the time of the alleged
violation) calibrated, and that the
resulting data have not been tampered
with In any way.
(c) The opacity standards set forth In
this part shall apply at all times except
during periods of startup, shutdown, mal-
function, and as otherwise provided in
the applicable standard.
(d) At all times, including periods of
startup, shutdown, and malfunction,
owners and operators shall, to the extent
practicable, maintain and operate any
affected facility including associated air
pollution control equipment in a manner
consistent with good air pollution control
practice for minimizing emissions. De-
termination of whether acceptable oper-
ating and maintenance procedures are
being used will be based on Information
available to the Administrator which may
include, but is not limited to, monitoring
results, opacity observations, review of
operating and maintenance procedures,
and Inspection of the source.
(e) (1) An owner or operator of an af-
fected facility may request the Admin-
istrator to determine opacity of emis-
sions from the affected facility during
the initial performance tests required by
f 60.8.
(2) Upon receipt from such owner or
operator of the written report of the re-
lults of the performance tests required
by f 60.8, the Administrator will make
a finding concerning compliance with
opacity and other applicable standards.
If the Administrator finds that an af-
fected facility is in compliance with all
applicable standards for which perform-
ance tests are conducted In accordance
with I 60.8 of this part but during the
time such performance tests are being
conducted falls to meet any applicable
opacity standard, he shall notify the
owner or operator and advise him that he
may petition the Administrator within
10 days of receipt of notification to make
appropriate adjustment to the opacity
standard for the affected facility.
(3) The Administrator will grant such
a petition upon a demonstration by the
owner or operator that the affected fa-
cility and associated air pollution con-
trol equipment was operated and main-
tained in a manner to minimize the
opacity of emissions during the perform-
ance tests; that the performance tests
were performed under the conditions es-
tablished by the Administrator; and that
the affected facility and associated air
pollution control equipment were in-
capable of being adjusted or operated to
meet the applicable opacity standard.
(4) The Administrator will establish
an opacity standard for the affected
facility meeting the above requirements
at a level at which the source will be
able, as Indicated by the performance
and opacity tests, to meet the opacity
standard at all times during which the
source is meeting the mass or concentra-
tion emission standard. The Adminis-
trator will promulgate the new opacity
standard in the FIDUUL Rzomxi.
9 60.13 Monitoring requirements.
(a) For the purposes of this section,
all continuous monitoring systems re-
quired under applicable subparts shall
be subject to the provisions of this sec-
tion upon promulgation of perform-
ance specifications for continuous
monitoring system under Appendix B
to this part, unless:
(1) The continnods monitoring
system is subject to the provisions ol
paragraphs (c)(2) and (c)(3) of this
section, or
(2) otherwise specified in an applica-
ble subpart or by the Administrator.
(b) All continuous monitoring systems
and monitoring devices shall be installed
and operational prior to conducting per-
formance tests under ( 60.8. Verification
of operational status shall, as a mini-
mum, consist of the following:
(1) For continuous -monitoring sys-
tems referenced in paragraph (c) (1) of
this section, completion of the condi-
tioning period specified by applicable
requirements In Appendix B.
(2) For continuous monitoring sys-
tems referenced in paragraph (c) (2) of
this section, completion of seven days of
operation.
(3) For monitoring devices referenced
in applicable subparts, completion of the
manufacturer's written requirements or
recommendations for checking the op-
eration or calibration of the device.
(c) During any performance tests
required under {60.8 or within 30 days
thereafter and at such other times at
may be required by the Administrator
under section 114 of the Act the owner
or operator of any affected facility shall
conduct continuous monitoring system
performance evaluations and furnish the
Administrator within 60 days thereof two
or, upon request, more copies of a written
report of the results of such tests. These
continuous monitoring system perform-
ance evaluations shall be conducted In
accordance with the following specifica-
tions and procedures:
(1) Continuous monitoring systems
listed within this paragraph except as
provided in paragraph (c) (2) of this sec-
tion shall be evaluated in accordance
with the requirements and procedures
contained in the applicable perform-
ance specification of Appendix B as
follows:
(1) Continuous monitoring systems for
measuring opacity of emissions shall
comply with Performance Specification 1.
(11) Continuous monitoring systems for
measuring nitrogen oxides emissions
shall comply with Performance Specifi-
cation 2.
(ill) Continuous monitoring systems for
measuring sulfur dioxide emissions shall
comply with Performance Specification 2.
(iv) Continuous monitoring systems for
measuring the oxygen content or carbon
dioxide content of effluent gases shall
comply with Performance Specification
I.
(2) An owner or operator who, prior
to September 11, 1974, entered into a
binding contractual obligation to pur-
chase specific continuous monitoring
system components except as referenced
by paragraph (c) (2) (ill) of this section
shall comply with the following require-
ments:
(i) Continuous monitoring systems for
measuring opacity of emissions shall be
capable of -measuring emission levels
within ±20 percent with a confidence
level of 95 percent. The Calibration Error
Test and associated calculation proce-
dures set forth In Performance Specifl-
II-4
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cation 1 of Appendix B ihall be UMd for
demonstrating compliance with this
•peclflcatlon.
(11) Continuous monitoring systems
for measurement of nitrogen oxides or
sulfur dioxide shall be capable of meas-
uring emission levels within ±20 percent
with a confidence level of 95 percent The
Calibration Error Test, the Field Test
for Accuracy (Relative), and associated
operating and calculation procedures set
forth in Performance Specification 2 of
Appendix B shall be used for demon-
strating compliance with this specifica-
tion.
(Ill) Owners or operators of all con-
tinuous monitoring systems Installed on
an affected facility prior to October 6,
1975 are not required to conduct
tests under paragraphs (c) (2) (1) and/or
(11) of this section unless requested by
the Administrator.
(3) All continuous monitoring systems
referenced by paragraph (c) (2) of this
section shall be upgraded or replaced (if
necessary) with new continuous moni-
toring systems, and the new or improved
systems shall be demonstrated to com-
ply with applicable performance speci-
fications under paragraph (c) (1) of this
section on or before September 11. 1979.
(d) Owners or operators of all con-
tinuous monitoring systems Installed in
accordance with the provisions of this
part shall check the zero and span drift
at least once daily in accordance with
the method prescribed by the manufac-
turer of such systems unless the manu-
facturer recommends adjustments at
* shorter Intervals. In which case such
recommendations shall be followed. The
sero and span shall, as a minimum, be
adjusted whenever the 24-hour zero drift
or 24-hour calibration drift limits of the
applicable performance specifications in
Appendix B are exceeded. For continuous
monitoring systems measuring opacity of
emissions, the optical surfaces exposed
to the effluent gases shall be cleaned prior
to performing the zero or span drift ad-
justments except that for systems using
automatic zero adjustments, the optical
surfaces shall be cleaned when the cum-
ulative automatic zero compensation ex-
ceeds four percent opacity. Unless other-
wise approved by the Administrator, the
following procedures, as applicable, shall
be followed:
(1) For extractive continuous moni-
toring systems measuring gases, mini-
mum procedures shall include -introduc-
ing applicable zero and span gas mixtures
into the measurement system as near the
probe as is practical. Span and zero gases
certified by their manufacturer to be
traceable to National Bureau of Stand-
ards reference gases shall be used when-
ever these reference gases are available.
The span and zero gas mixtures shall be
the same composition as specified In Ap-
pendix B of this part. Every six months
from date of manufacture, span and zero
gases shall be reanalyzed by conducting
triplicate analyses with Reference Meth-
ods 6 for SO,, 7 for NO,, and J for O,
and CO: respectively. The gases may be
analyzed at less frequent Intervals If
longer chelf lives are guaranteed by the
manufacturer.
(2) For non-extractive continuous
monitoring systems measuring gases,
minimum procedures shall Include up-
scale check (s) using a certified calibra-
tion gas cell or test cell which is func-
tionally equivalent to a known gas con-
centration. The zero check may be per-
formed by computing the zero value from
upscale measurements or by mechani-
cally producing a zero condition.
(3) For continuous monitoring systems
measuring opacity of emissions, mini-
mum procedures shall include a method
for producing a simulated zero opacity
condition and an upscale (span) opacity
condition using a certified neutral den-
sity filter or other related technique to
produce a known obscuration of the light
beam. Such procedures shall provide a
system check of the analyzer internal
optical surfaces and all electronic cir-
cuitry Including the lamp and photode-
tector assembly.
Except for system breakdowns, re-
pairs, calibration checks, and zero and
span adjustments required under para-
graph (d) of this section, all continuous
monitoring systems shall be in contin-
uous operation and shall meet minimum
frequency of operation requirements as
follows:
(1) All continuous monitoring sys-
tems referenced by paragraphs (c)(l)
and (c) (2) of this section for measuring
opacity of emissions shall complete a
minimum of one cycle of sampling and
analyzing for gy^h successive ten-second
period and one cycle of data recording
for each successive six-minute period.
(2) All continuous monitoring systems
referenced by paragraph (c)(l) of this
section for measuring oxides of nitrogen,
sulfur dioxide, carbon dioxide, or oxygen
shall complete a minimum of one cycle
of operation (sampling, analyzing, and
data recording) for each successive 15-
mlnute period.
(3) All continuous monitoring systems
referenced by paragraph (c) (2) of this
section, except opacity, shall complete a
minimum of one cycle of operation (sam-
pling, analyzing, and data recording)
for each successive one-hour period.
(f) All continuous monitoring systems
or monitoring devices shall be Installed
such that representative measurements
of emissions or process parameters from
the affected facility are obtained. Addi-
tional procedures for location of contin-
uous monitoring systems contained In
the applicable Performance Specifica-
tions of Appendix B of this part shall be
used.
(g) When the effluents from a single
affected facility or two or more affected
facilities subject to the same emission
standards are combined before being re-
leased to the atmosphere, the owner or
operator may install applicable contin-
uous monitoring systems on each effluent
or on the combined effluent. When the af-
fected facilities are not subject to the
same emission standards, separate con-
tinuous monitoring systems shall be in-
stalled on each effluent. When the efflu-
ent from one affected facility is released
II-5
to the atmosphere through more than
one point, the owner or operator shall
Install applicable continuous monitoring
systems on each separate effluent unless
the Installation of fewer systems is ap-
proved by the Administrator.
(h) Owners or operators of all con-
tinuous monitoring systems for measure-
ment of opacity shall reduce all data to
six-minute averages and for systems
other than opacity to one-hour averages
for time periods under i 60.2 (x) and (r)
respectively. Six-minute opacity averages
sha'l be ca. -Ur ,-d from 24 or more data
points equaJy spaced over each six-
minute period. For systems other than
opacity, one-hour averages shall be com-
puted from four or more data points
equally spaced over each one-hour pe-
riod. Data recorded during periods of sys-
tem breakdowns, repairs, calibration
checks, and zero and span adjustments
shall not be included in the data averages
computed under this paragraph. An
arithmetic or integrated average of all
data may be used. The data output of all
continuous monitoring systems may be
recorded in reduced or nonreduced form
(e.g. ppm pollutant and percent O* or
Ib/mllllon Btu of pollutant). All excess
emissions shall be converted into units
of the standard using the applicable con-
version procedures specified in subparts.
After conversion into units of the stand-
ard, the data may be rounded to the same
number of significant digits used in sub-
parts to specify the applicable standard
(e.g., rounded to the nearest one percent
opacity).
O) After receipt and consideration of
written application, the Administrator
may approve alternatives to any moni-
toring procedures or requirements of this
part including, but not limited to the
following:
(1) Alternative monitoring require-
ments when installation of a continuous
monitoring system or monitoring device
specified by this part would not provide
accurate measurements due to liquid wa-
ter or other interferences caused by sub-
stances with the effluent gases.
(2) Alternative monitoring require-
ments when the affected facility is infre-
quently operated.
(3) Alternative monitoring require-
ments to accommodate continuous moni-
toring systems that require additional
measurements to correct for stack mois-
ture conditions.
(4) Alternative locations for installing
continuous monitoring systems or moni-
toring devices when the owner or opera-
tor can demonstrate that installation at
alternate locations will enable accurate
and representative measurements.
(5) Alternative methods of converting
pollutant concentration measurements to
units of the standards.
(6) Alternative procedures for per-
forming daily checks of zero and span
drift that do not involve use of span gases
or test cells.
(7) Alternatives to the A.S.T.M. test
methods or sampling procedures specified
by any lubpart.
-------
(8) Alternative continuous monitor-
ing systems that do not meet the design
or performance requirements In Perform-
ance Specification 1, Appendix B, but
adequately demonstrate a definite and
consistent relationship between its meas-
urements and the measurements of
opacity by a system complying with the
requirements in Performance Specifica-
tion 1. The Administrator may require
that such demonstration be performed
for each affected facility.
(9) Alternative monitoring require-
ments when the effluent from a single
affected facility or the combined effluent
from two or more affected facilities are
released to the atmosphere through more
than one point.
(••e. 114 at tht Ctaaa Air Aet m MM^*
(U VAC. 1M70-4).).
II-6
-------
Swbperf D—Standards of Performance
for Fo«sll-Fu«l Firvd Stoem Generator*
I 60.40 Api>Iirabllilr and dmiffnallon of
• fftvted facility.
(•) The affected facilities to which the
provisions of this subpart apply we: •
U) Each fosstl-fuel-ftred steam gen-
erating unit of more than 73 megawatts
heat input rate (250 million Btu per
hour).
(2) Each fossil-fuel and wood-residue*
fired steam generating unit capable of
firing fossil fuel at a heat input rate of
more than 73 megawatt* (250 million
Btu per hour).
(b) Any change to an existing foutl-
fuel-flred steam generating unit to
accommodate the use of combustible
materials, other than fossil fuels ai
denned in this subpart. shall not bring
that unit under the applicability of this
cubpart.
(c) Except as provided In paragraph
(d) of this section, any facility under
paragraph (a) of this section that com-
menced construction or modification
after August 17, 1971, Is subject to the
requirements of this subpart.
(d) The requirements of
§S 60.44(aX4), (a)(5), (b), and (dT, and
60.4S(fX4Xvi) are applicable to lignite-
fired steam generating units that com-
menced construction or modification
after December 22,1976.
1 60.41 Definition*.
As used in tills subpart, all terms not
defined herein shall have the meaning
given them In the Act, and In subpart A
of this part.
(a) "Fossil fuel-fired steam generat-
ing unit" means a furnace or boiler used
in the process of burning fossil fuel for
the purpose of producing steam by heat
transfer.
"Coal refuse" means waste-prod-
ucts of ooal mining, cloning, and coal
preparation operations (e.g. culm, gob.
etc.) containing coal, matrix material.
claj, and other organic aad Inorganic
(d> Toesfl fuel and wood residue-fired
•team generating unit" means a furnace
or boiler used in the process of burning
fossil fuel and wood residue for the pur-
pose of producing steam by heat transfer.
"Wood residue" means bark, saw-
dust. slabs, chips, shavings, null trim.
and other wood product* derived from
wood processing and forest management
°?Jr S5" means all solid fuels clas-
sified as anthracite, bituminous, subbi-
tumtaous, or lignite by the American
Society for Testing Material. Designa-
tion D 388-66.
| 60.42 Statwlartf for
(a) On and after the date on which
the performance test required to be con-
ducted by | 60.8 Is completed, no owner
or operator subject to the provisions of
this lubpart shall cause to be discharged
kUo the atmosphere from aoy affected
facility any gam which:
(2) Exhibit greater than 20 percent
opacity except for one six-minute
period per hour of not more than 27
percent Opacity.
| 60.44 Standard for mttmr d*KhU.
(a) On and after the date on which
the performance test required to be con-
ducted by | M.t U completed, ao owner
or operator subject to the provisions of
this subpart shall cawe to be discharged
mto the atmosphere from any affected
facility any gases which contain sulfur
•oxide m excess of:
(1) 340 nanoerams per joule beat in-
put (0.80 Ib per million Btu) derived
from liquid fossil fuel or liquid fossil fuel
and wood residue.
, (2) 520 nanograms per joule heat in-
i put (1.2 lb per million Btu) derived from
•olid fossil fuel or solid fossil fuel and
: wood residue.
(b) When different fossil fuels are
', burned simultaneously in any combina-
tion, the applicable standard (in og/J)
•hall be determined by proration using
the following formula:
y(340)+»(520)
PS.
where:
PS»oj >' thf prorated standard for sulfur
dioxide when burning different fuels
simultaneously, ia ninograms per
joule beat input derived from all
fossil fuels fired or from all fotsil fueli
and wood residue 5red,
IT is the percentage of total beat input
derived from liquid fossil fuel, and
t is the percentage of total heat input
derived from wlid fooil fuel.
(c) Compliance ah»T] be tinned on the
total heat Input from aH fossfl fuel*
buroed. including gaseous fuel*.
14*44 9uW«r4 f«r
(a) On and after the date on which
9te performance test required to be con-
ducted by | 60.8 is completed, no owner
or operator subject to the provisions of
fhk subpart shall cause to be discharged
into the atmosphere from any affected
facility any gases which contain nitro-
gen oxttes, expressed at NO, In exce« of:
(1) 86 nanograms per joule heat input
(0.20 lb per million Btu) derived from
gaseous fossil fuel or gaseous fossil fuel
and wood residue.
II-7
(2) 130 nanograms per joule heat in-
put (0.30 lb per million Btu) derived
from liquid fossil fuel or liquid fossil fuel
and wood residue.
(3) 300 nanograms per joule heat In-
put (0.70 lb per million Btu) derived
from solid fossil fuel or solid fossil fuel
and wood residue (except lignite or a
•olid fossil fuel containing 25 percent.
by weight, or more of coal refuse).
(4) 280 nanograms per joule heat
input (0.60 lb per million Btu). derived
frora^Mgnite or ligHtee and wood resi-
due (except as provided under para-
graph (aXS) of this section).
(5) 340 nanograms per joule heat
input (0.80 lb per million Btu) derived
from lignite which is mined In North
Dakota, South Dakota,- or Montana
and which is burned In a cyclone-fired
(b) Except as provided under para-
graphs (c) and (d) of this section,
when different fossil fuels are burned
simultaneously in any combination,
the applicable standard (in ng/J) is de-
termined by proration using the fol-
lowing formula:
PSn.- tfl(MO)-n
-------
(b) Certain of the continuous moni-
toring system requirements under para-
graph (a) of this section do not apply
to owners or operators under the follow-
ing conditions:
(1) For a fossil fuel-fired steam gen-
erator that bums only gaseous fossil
fuel, continuous monitoring systems for
measuring the opacity of emissions and
sulfur dioxide emissions are not re-
quired.
<8> For a fossil fuel-fired steam gen-
erator that does not use a flue gas de-
culfurization device, a continuous moni-
toring system for measuring sulfur di-
oxide emissions is not required If the
•owner or operator monitors sulfur di-
oxide emissions by fuel sampling and
analysis under paragraph (d) of this
section.
(3) Notwithstanding | M.13(o>. In-
stallation of a continuous monitoring
system for nitrogen oxides may be de-
layed "until after the initial performance
tests under f 60.8 have been conducted.
If the owner or operator demonstrates
during the performance test that emis-
sions of nitrogen oxides are less than 70
percent of the applicable standards in
I 60.44, a continuous monitoring system
for measuring nitrogen oxides emissions'
Is not required. If the Initial performance
test results show that nitrogen oxide
emissions are greater than 70 percent of
the applicable standard, the owner or
operator shall install a continuous moni-
toring system for nitrogen oxides within
on* year after the date of the Initial per-
formance test* under I 60.8 and comply
with all other applicable monitoring re-
quirements under this part.
(4) If an owner or operator does not
install any continuous monitoring sys-
tems for sulfur oxides and nitrogen ox-
Ides, as provided under paragraphs (b>
(1) and (b)(3) or paragraphs (b) (2)
and (b)(3) of this section a continuous
monitoring system for measuring either
oxygen or carbon dioxide is not required.
(c> For performance evaluations un-
der I60.13(c) and calibration cheers
under |60.13(d), the following proce-
dures shall be used:
. (1) Reference Methods 6 or 7, as ap-
plicable, .shall be uced for conducting
performance evaluations of sulfur diox-
ide and nitrogen oxides continuous mon-
itoring systems.
(2) Sulfur dioxide or nitric oxide, as
applicable, shall be used for preparing
calibration gas mixtures under Perform-
ance Specification 2 of Appendix B to
this part.
(3) For affected facilities burning fos-
sil fuel(s), the span value for a continu-
ous monitoring system measuring the
opacity of emissions shall be 60, 90. or
100 percent and for a continuous moni-
toring system measuring sulfur oxides or
nitrogen oxides the span value shall be
determined as follows:
(In peril pv mflUoo]
Poedl fuel Bp*r ntoe (or Spin ftiat lot
•aUw 4loBd< altncw aite
Om --------
liquid __
0)
Solid
LOOD
L100
**
BO
HO
i Not tppUeibk.
where:
c-tb* fraction of total but Input derived
from gueoui fouil fuel, and
y-tne fraction of toUl be»t input derived
from liquid fowll fuel, and
s-tbc fraction of total beat input derived
tram ioUd foidl fuel.
(4) All span values computed under
paragraph -
(vi) For lignite coal as classified ac-
cording to A.S.T.M. D 388-«.
F= 2.659x10-' dscm/J (9900 dscf/ffifl-
Jion Btu) and Ft=0.516xlO-' scm CCV
J (1920 scf CO,/million Btu).
(S> The owner or operator may use the
following equation to determine an F
factor (dscm/J or dscf/million Btu) on.
a dry basU (If it is desired to calculate f
on a wet basis, consult the Administra-
tor) or Ff factor (scm COt/J, or scf COi/
million Btu) on either basis In lieu of the
F or Ft factors specified in paragraph
(f)(4) of this section:
II-8
-------
(pet. H)+»S.5 (pet. C) -I- 35.6 (pot. 8)+8.7 (pet. N)-28.7 (pet O)l
GCV - — - •
(81 unJU)
(English units)
m _a.OX10-« (pet. C)
ocv—-'
(SI units)
f _821X10'(%C)
OCV
(English units)
(1) H, C, 8. N, and O art content by
weight of hydrogen, carbon, sulfur, ni-
trogen, and oxygen (expressed as per-
cent) , respectively, at determined on the
•MM basis M OCV by ultimate analytic
of the fuel fired. uilng A.S.T.M. method
D3 178-74 or D3176 (solid fuels) , or com-
puted from results using A.S.T.M. meth-
ods D1137-M(70), DlM5-«4(73). or
01946-67(72) (gaseous fuels) as applica-
nt) OCV is the cross calorific value
(kJ/kg. Btu/lb) of the fuel combusted.
determined by the A.S.T.M test methods
D 2015-S6C72) for solid fuels and D 1826-
64(70) for gaseous fuels as applicable.
(ill) For affected facilities which fire
both fossil fuels and nonfossll fuels, the
F or F, value shall be subject to the
Administrator's approval.
(6) For affected facilities firing com-
binations of fossil fuels or fossil fuels and
wood residue, the F or F, factors deter-
mined by paragraphs (f ) (4) or (f) (5) at
this section shall be prorated in accord-
ance with the applicable formula as fal-
lows:
wtten:
ft or (
ttoe fr»ction of total beat Input
derlTtd from each typ* of fuel
(*4 natural gai. bituminou*
coal, wood residue, etc.)
th* applicable T or F,. factor for
each fuel type determined in
accordance with paragraphs
(f)(4) and (J)(S) of UxJj
•ection
tbe number of faeli being
burned In combination.
• (g) For the purpose of reports required
under ! 60.7(c). periods of excess emis-
sions that shall be reported are defined
as follows:
(1) Opacity. Excess emissions are de-
fined as any six-minute period during
which the average opacity of emissions
exceeds 20 percent opacity, except
that one six-minute average per hour
of up to 27 percent opacity need not
be reported.
(2) Sulfur dioxide. Kctss emissions
for affected facilities are defined as:
(1) Any three-hour period during
which the average emissions (arithmetic
average of three contiguous one-hour p4-
riods) of sulfur dioxide as measured by a
continuous monitoring system exceed the
applicable standard under { 60.43.
(ii) [Reserved]
(3) Nitrogen oxides. Excess emissions
for affected facilities using a continuous
monitoring system for measuring nitro-
gen oxides are defined as any three-hour
period during which the average emis-
sions (arithmetic average ofthree con-
tiguous one-hour periods) exceed the ap-
plicable standards under 5 60.44.
§ 60.46 Tesl methods and procedures.
(a) The reference methods in Appen-
dix A of this part, except as provided in
I 60.8'b), shall be used to determine com-
pliance with the standards as prescribed
in 3$ 60.42. 60.43, and 60.44 as follows:
11) Method 1 for selection of sampling
site and sample traverses.
(2) Method 3 for gas analysis to bs
used when applying Reference Methods
5, 6 and 7.
(3) Method 5 for concentration of par-
ticulate matter and the associated mois-
ture content.
(4) Method 6 for concentration of SO-,
and
(5> Method 7 for concentration of
NOx.
For Method 5, Method 1 shall be
used to select the sampling site and the
number of traverse sampling points. The
sampling time for each run shall be at
least SO minutes arHtttJ minimum sam-
pling volume shall be 0.85 dscm (30 dscf)
II-9
except that smaller sampling times or
volumes, when necessitated by process
variables .or other factors, may be ap-
proved by the Administrator. The probe
and filter holder heating systems in the
sampling rrain shall be set to provide a.
sas temperature no greater than 160° C
(320= F).
(c>" For Methods 5 and 7, the sampling
site shall be the same as that selected
for Method 5. The sampling point in the
duct shall be at the centroid of the cross
section or at a point no closer to the
walls than 1 m (3.28 ft). For Method 6,
the sample shall be extracted at a rate
proportional to the gas velocity at the
sampling point.
'(d) For Method 6, the minimum sam-
pling time shall be 20 minutes and the
minimum sampling volume 0.02 dscm
(0.71 dscf) for each sample. The arith-
metic mean of two samples shall con-
stitute one run. Samples shall be taken
at approximately 30-minute intervals.
•' (e) For Method 7, each run shall con-
sist of at least four grab samples taken
at approximately 15-minute intervals.
The arithmetic mean of the samples
shall constitute the run value.
(f) For each run using the methods
specified by paragraphs (a) (3), (4), and
(5) of this section, the emissions ex-
pressed in g/mil!ion cal (Ib/million Btu)
shall be determined by the following
procedure:
CF
/ 20.
\2Q.V-
where:
(1) E = pollutant emission g/million cal
lib/million Btu).
(2) C = pollutant concentration, g/dscm»
(Ib/dscf), determined by Methods 5, 6, or 7.
(3) riO. = oxygen content by volume
(expressed as percent), dry basis. Percent
oxygen shall be determined by rslng the In-
tegrated or jrab sampling and analysis pro-
cedures ot Method 3 as applicable. The sam-
ple shall be obtained as follows:
(i) For determination of sulfur diox-
ide and nitrogen oxides emissions, the
oxygen sample shall be obtained simul-
taneously at the same point in the duct
as used to obtain the samples for Meth-
ods 6 and 7 determinations, respectively
[§ 60.46(c)h For Method 7. the oxygen
sample shall be obtained using the grab
sampling and analysis procedures of
Method 3.
(ii) For determination of particulate
emissions, the oxygen sample shall be
obtained simultaneously by traversing
the duct at the same sampling location
used for each run of Method 5 under
paragraph (b) of this section. Method .1
shall be used for selection of the number
of traverse points except that no more
than 12 sample points are required.
(4) F = a factor as determined in
paragraphs (f) (4;, (5) or (5) of •; 60.45.
(g) When combinations of fossil fuels
ire fired, the heat input, expressed in
cal/hr (Btu/hr), shall be determined
during each testing period by multiply-
ing the gross calorific value of each fuel
fired by the rate of each fuel burned.
Gross calorific value shall be determined
in accordance with A.S.T.AI. methods
D2015-66(72) (solid fuels). D240-64(73>
(liquid fuels). or D1826-64(~0> (gaseous
fuels) as applicable. The rate of fuels
burned during each testing period shall
be determined bv suitabls method? and
shall be confirmed by a material balance
over the stearr. generation system.
-------
Authority: Sec. 111. 301(a) of the Clean Air
Act a» amended (42 U.S.C. 7411. 7801(a)), and
additional authority as noted below.
Subpart Da—Standards of
Performance for Electric Utility Steam
Generating Units for Which
Construction Is Commenced After
September 18,1978
{ M.40a Applicability and designation of
affected facility.
(a) The affected facility to which this
subpart applies is each electric utility
steam generating unit:
(1) That is capable of combusting
more than 73 megawatts (250 million
Btu/hour) heat input of fossil fuel (either
alone or in combination with any other
fuel); and
(2) For which construction or
modification is commenced after
September 18,1978.
(b) This subpart. applies to electric
utility combined cycle gas turbines that
are capable of combusting more than 73
megawatts (250 million Btu/hour) heat
input of fossil fuel in the steam
generator. Only emissions resulting from
combustion of fuels in the steam
generating unit are subject to this
subpart (The gas turbine emissions are
subject to Subpart GG.)
(c) Any change to an existing fossil-
fuel-fired steam generating unit to
accommodate the use of combustible
materials, other than fossil fuels, shall
not bring that unit under the
applicability of this subpart.
(d) Any change to an existing steam
generating unit originally designed to
fire gaseous or liquid fossil fuels, to
accommodate the use of any other fuel
(fossil or nonfossil) shall not bring that
unit under the applicability of this
subpart.
§60.41a Definitions.
As used in this subpart, all terms not
defined herein shall have the meaning
given them in the Act and in subpart A
of this part.
"Steam generating unit" means any
furnace, boiler, or other device used for
combusting fuel for the purpose of
producing steam (including fossil-fuel-
fired steam generators associated with
combined cycle gas turbines; nuclear
steam generators are not included).
"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.
"Fossil fuel" means natural gas,
petroleum, coal, and any form of solid,
liquid, or gaseous fuel derived from such
material for the purpose of creating
useful heat.
"Subbituminous coal" means coal that
is classified as subbituminous A, B, or C
according to the American Society of
Testing and Materials' (ASTM)
Standard Specification for Classification
of Coals by Rank D388-68.
"Lignite" means coal that is classified
as lignite A or B according to the
American Society of Testing and
Materials' (ASTM) Standard
Specification for Classification of Coals
by Rank D388-66.
"Coal refuse" means waste products
of coal mining, physical coal cleaning,
and coal preparation operations (e.g.
culm, gob, etc.) containing coal, matrix
material, clay, and other organic and
inorganic material.
"Potential combustion concentration"
means the theoretical emissions (ng/J,
Ib/million Btu heat input) that would
result from combustion of a fuel in an
uncleaned state Swithout emission
control systems) and:
(a) For participate matter is:
(1) 3,000 ng/J (7.0 Ib/million Btu) heat
input for solid fuel; and
(2) 75 ng/J (0.17 Ib/million Btu) heat
input for liquid fuels.
(b) For sulfur dioxide is determined
under § 60.48a(b).
(c) For nitrogen oxides is:
(1) 290 ng/J (0.67 Ib/million Btu) heat
input for gaseous fuels;
(2) 310 ng/J (0.72 Ib/million Btu) heat
input for liquid fuels; and
(3) 990 ng/J (2.30 Ib/million Btu) heat
input for solid fuels.
"Combined cycle gas turbine" means
a stationary turbine combustion system
where heat from the turbine exhaust
gases is recovered by a steam
generating unit.
"Interconnected" means that two or
more electric generating units are
electrically tied together by a network of
power transmission lines, and other
power transmission equipment.
"Electric utility company" means the
largest interconnected organization,
business, or governmental entity that
generates electric power for sale (e.g., a
holding company with operating
subsidiary companies).
"Principal company" means the
electric utility company or companies
which own the affected facility.
"Neighboring company" means any
one of those electric utility companies
11-10
with one or more electric power
interconnections to th« principal
company and which have
geographically adjoining service areas.
"Net system capacity" means the sum
of the net electric generating capability.
(not necessarily equal to rated capacity)
of all electric generating equipment
owned by an electric utility company
(including steam generating units.
internal.combustion engines, gas
turbines, nuclear units, hydroelectric
units, and all other electric generating
' equipment) plus firm contractual
purchases that are interconnected to the
affected facility that has the
malfunctioning flue gas desulfurization
system. The electric generating
capability of equipment under multiple
ownership is prorated based on
ownership unless the proportional
entitlement to electric output is
otherwise established by contractual
arrangement.
"System load" means the entire
electric demand of an electric utility
company's service area interconnected
with the affected facility that has the
malfunctioning flue gas desulfurization
system plus firm contractual sales to
other electric utility companies. Sales to
other electric utility companies (e.g.,
emergency power) not on a firm
contractual basis may also be included
in the system load when no available
system capacity exists in the electric
utility company to which the power is
supplied for sale.
"System emergency reserves" means
an amount of electric generating
capacity equivalent to the rated
capacity of the single largest electric
generating unit in the electric utility
company (including steam generating
units, internal combustion engines, gas
turbines, nuclear units, hydroelectric
units, and all other electric generating
equipment) which is interconnected with
the affected facility that has the
malfunctioning flue gas desulfurization
system. The electric generating
capability of equipment under multiple
ownership is prorated based on
ownership unless the proportional
entitlement to electric output is
otherwise established by contractual
arrangement.
"Available system capacity" means
the capacity determined by subtracting
the system load and the system
emergency reserves from the net system
capacity.
"Spinning reserve" means the sum of
the unutilized net generating capability
of all units of the electric utility
company that are synchronized to the
power distribution system and that are
capable of immediately accepting
-------
additional load. The electric generating
capability of equipment under multiple
ownership is prorated based on
ownership unless the proportional
entitlement to electric output is
otherwise established by contractual
arrangement.
"Available purchase power" means
the lesser of the following;
(a) The sum of available system
capacity in all neighboring companies.
(b) The sum of the rated capacities of
the power interconnection devices
between the principal company and all
neighboring companies, minus the sum
of the electric power load on these
interconnections.
(c) The rated capacity of the power
transmission lines between the power
interconnection devices and the electric
generating units (the unit in the principal
company that has the malfunctioning
flue gas desulfurization system and the
unit(s) in the neighboring company
supplying replacement electrical power)
less the electric power load on these
transmission lines.
"Spare flue gas desulfurization system
module" means a separate system of
sulfur dioxide emission control
equipment capable of treating an
amount of flue gas equal to the total
amount of flue gas generated by an
affected facility when operated at
maximum capacity divided by the total
number of nonspare flue gas
desulfurization modules in the system.
"Emergency condition" means that
period of time when:
(a) The electric generation output of
an affected facility with a
malfunctioning flue gas desulfurization
system cannot be reduced or electrical
output must be increased because:
(1) All available system capacity in
the principal company interconnected
with the affected facility is being
operated, and
(2) All available purchase power
interconnected with the affected facility
is being obtained, or
(b) The electric generation demand is
being shifted as quickly as possible from
an affected facility with a
malfunctioning flue gas desulfurization
system to one or more electrical
generating units held in reserve by the
principal company or by a neighboring
company, or
(c) An affected facility with a
malfunctioning flue gas desulfurization
system becomes the only available unit
to maintain a part or all of the principal
company's system emergency reserves
and the unit is operated in spinning
reserve at the lowest practical electric
generation load consistent with not
causing significant physical damage to
the unit If the unit is operated, at a
higher load to meet load demand, an
emergency condition would not exist
unless the conditions under (a) of this
definition apply.
"Electric utility combined cycle gas
turbine" means any combined cycle gas
turbine used for electric generation 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 distribution system that
is constructed for the purpose of
providing steam to a steam electric
generator that would produce electrical
power for sale is also considered in
determining the electrical energy output
capacity of the affected facility.
"Potential electrical output capacity"
is defined as 33 percent of the maximum
design heat input capacity of the steam
generating unit (e.g., a steam generating
- unit with a 100-MW (340 million Btu/hr)
fossil-fuel heat input capacity would
have a 33-MW potential electrical
output capacity). For electric utility
combined cycle gas turbines the
potential electrical output capacity is
determined on the basis of the fossil-fuel
firing capacity of the steam generator
exclusive of the heat input and electrical
power contribution by the gas turbine.
"Anthracite" means coal that is
classified as anthracite according to the
American Society of Testing and
Materials' (ASTM) Standard
Specification for Classification of Coals
by Rank D388-66.
. "Solid-derived fuel" means any solid,
liquid, or gaseous fuel derived from solid
fuel for the purpose of creating useful
heat and includes, but is not limited to,
solvent refined coal, liquified coal, and
gasified coal.
"24-hour period" means the period of
time between 12:01 a.m. and 12:00
midnight.
"Resource recovery unit" means a
facility that combusts more than 75
percent non-fossil fuel on a quarterly
(calendar) heat input basis.
"Noncontinental area" means the
State of Hawaii, the Virgin Islands,
Guam, American Samoa, the
Commonwealth of Puerto Rico, or the
Northern Mariana Islands.
"Boiler operating day" means a 24-
hour period during which fossil fuel is
combusted in a steam generating unit for
the entire 24 hours.
§ 60.42a Standard (or participate matter.
(a) On and after the date on which the
performance test required to be
conducted under § 60.8 is completed, no
owner or operator subject to the
11-11
provisions ot this subpar: i..-.. ~^*>*<- M
be discharged into the atmosphere from
any affected facility any gases which
contain particulate matter in excess of:
(1) 13 ng/J (0.03 Ib/million Btu) heat
input derived frpm the combustion of
solid, liquid, or gaseous fuel;
(2) 1 percent of the potential
combustion concentration (99 percent
reduction) when combusting solid fuel;
and
(3) 30 percent of potential combustion
concentration (70 percent reduction)
when combusting liquid fuel.
(b) On and after the date the
particulate matter performance test
required to be conducted under § 60.8 is
completed, no owner or operator subject
to the provisions of this subpart shall
cause to be discharged into the
atmosphere from any affected facility
any gases which exhibit greater than 20
percent opacity (6-minute average),
except for one 6-minute period per hour
of not more than 27 percent opacity.
§ 60.43a Standard for sulfur dioxide.
(a) On and after the date on which the
initial performance test required to be
conducted under § 60.8 is completed, no
owner or operator subject to the
provisions of this subpart shall cause to
be discharged into the atmosphere from
any affected facility which combusts
.solid fuel or solid-derived fuel, except as
provided under paragraphs (c), (d), (f) or
(h) of this section, any gases which
contain sulfur dioxide in excess of:
(1) 520 ng/J (1-20 Ib/million Btu) heat
input and 10 percent of the potential
combustion concentration (90 percent
reduction), or
(2) 30 percent of the potential
combustion concentration (70 percent
reduction), when emissions are less than
260 ng/J (0.60 Ib/milliori Btu) heat input.
(b) On and after the date on which the
initial performance test required to be
conducted under § 60.8 is completed, no
owner or operator subject to the
provisions of this subpart shall cause to
be discharged into the atmosphere from
any affected facility which combusts
liquid or gaseous fuels (except for liquid
or gaseous fuels derived from solid fuels
and as provided under paragraphs (e) or
(h) of this section), any gases which
contain sulfur dioxide in excess of:
(1) 340 ng/J (0.80 Ib/million Btu) heat
input and 10 percent of the potential
combustion concentration (90 percent
reduction), or
(2) 100 percent of the potential
combustion concentration (zero percent
reduction) when emissions are less than
86 ng/J (0.20 Ib/million Btu) heat input.
(c) On and after the date on which the
initial performance test required to be
-------
conducted under § 60.8 is complete, no
owner or operator subject to the
provisions of this subpart shall cause to
be discharged into the atmosphere from
any affected facility which combusts
solid solvent refined coal (SRC-I) any
gases which contain sulfur dioxide in
excess of 520 ng/J (1.20 Ib/million Btu)
heat input and 15 percent of the
potential combustion concentration (85
percent reduction) except as provided
under paragraph (f) of this section;
compliance with the emission limitation
is determined on a 30-day rolling
average basis and compliance with the
percent reduction requirement is
determined on a 24-hour basis.
(d) Sulfur dioxide emissions are
limited to 520 ng/J (1.20 Ib/million Btu)
heat input from any affected facility
which:
(1) Combusts 100 percent anthracite,
(2) Is classified as a resource recovery
facility, or
(3) Is located in a noncontinental area
and combusts solid fuel or solid-derived
fuel.
(e] Sulfur dixoide emissions are
limited to 340 ng/J (0.80 Ib/million Btu)
heat input from any affected facility
which is located in a noncontinental
' area and combusts liquid or gaseous
fuels (excluding solid-derived fuels).
(f) The emission reduction
requirements under this section do not
apply to any affected facility that is
operated under an SO: commercial
demonstration permit issued by the
Administrator in accordance with-the
provisions of § 60.45a.
(g) Compliance with the emission
limitation and percent reduction
requirements under this section are both
determined on a 30-day rolling average
basis except as provided under
paragraph (c) of this section.
(h) When different fuels are
combusted simultaneously, the
applicable standard is determined by
proration using the following formula:
(1) If emissions of sulfur dioxide to the
atmosphere are greater than 260 ng/J
(0.60 Ib/million Btu) heat input
EM, = [340 x + 520 y]/100 and
Pjo, — 10 percent
(2) It' emissions of sulfur dioxide to the
atmosphere are equal to or less than 260
ng/J (0.60 Ib/million Btu) heat input:
E», = [340 x + 520 y]/100 and
P»o, = [90 x + 70 yj/100
where:
ESO, la the prorated sulfur dioxide emission
limit (ng/J heat input),
Pgo, is the percentage of potential sulfur
dioxide emission allowed (percent
reduction required = 100-PW>),
x i» the percentage of total henl input derived
from the combustion of liquid or gaseous
fuels (excluding solid-derived fuels)
y is the percentage of total heat inpul derived
from the combustion of solid fuel
(including solid-derived fuels)
§ 60.44a Standard for nitrogen oxides.
(a) On and after the date on which the
initial performance test required to be
conducted under | 60.8 is completed, no
owner or operator subject to the
provisions of this subpart shall cause to
be discharged into the atmosphere from
any affected facility, except as provided
under paragraph (b) of this section, any
gases which contain nitrogen oxides in
excess of the following emission limits,
based on a 30-day rolling average.
(1) NO, Emission Limits—
Fuel type
' Emission SrnH
ng/J (Os/mUlwo Btu)
heal input
Gaseous Fuels:
CoeMferived fuels -
AS other fuels
Liquid Fuels:
CoeMJerwed fuels -
Snalooi
A» other fuels
Soid Fuels:
(0.50)
210
210 (0.50)
210 (0.50)
130 (0.30)
CoaMenved fuels
Any fuel contanng more man
25%, by weight, coal refuse .
210
(0.50)
Any fuel containing more than
25%. by weight, lignite it me
ignite is mined m Norm
Dakota. South Dakota, or
Montana, and 8 combusted
in a stag lap furnace
Lignite not subject to the 340
ng/J heat input emission limit
Exempt from NO,
standards and NO,
monltoong
fsojuvsfnents
Anthracite <
340
260
210
260
260
280
(0*))
(0.60)
(0-SO)
(0.60)
(0.60)
(0.60)
(2) NO, reduction requirements—
Fuel type
Percwil reduction
01 potential
combustion
concentration
Gaseous fuels-
Liquid fuels
Solid fuels
25%
30%
65%
(b) The emission limitations under
paragraph (a) of this section do not
•apply to any affected facility which is
combusting coal-derived liquid fuel and
is operating under a commercial
demonstration permit issued by the
Administrator in accordance with the
provisions of § 60.45a.
(c) When two or more fuels are
combusted simultaneously, the
applicable standard is determined by
proration using the following formula:
Em, = [86 w+130 x+210 y+260 z]/100
where:
ENO, is the applicable standard for nitrogen
'oxides when multiple fuels are
combusted simultaneously (ng/J heat
input):
w is the percentage of total heat input
derived from the combustion of fuels
subject to the 86 ng/J heat input
standard;
x is the percentage of total heat input derived
from the combustion of fuels subject to
the 130 ng/J heat input standard:
y is the percentage of total heat input derived
from the combustion of fuels subject to
the 210 ng/J heat input standard; and
2 is the percentage of total heat input derived
from the combustion of fuels subject to
the 260-ng/J heat input standard.
§ 60.45a ^Commercial demonstration
permit
(a) An owner or operator of an
affected facility proposing to
demonstrate an emerging technology
may apply to the Administrator for a
commercial demonstration permit. The
Administrator will issue a Commercial
demonstration permit in accordance
with paragraph (e) of this section. '
Commercial demonstration permits may
be issued only by the Administrator,
and this authority will not be delegated.
(b) An owner or operator of an
affected facility that combusts solid
solvent refined coal (SRC-I) and who is
issued a commercial demonstration
permit by the Administrator is not
subject to the SO? emission reduction
requirements under § 60.43a(c) but must,
as a minimum, reduce SO» emissions to
20 percent of the potential combustion
concentration (80 percent reduction] for
each 24-hour period of steam generator
operation and to less than 520 ng/J (1.20
Ib/million Btu) heat input on a 30-day
rolling average basis.
(c) An owner or operator of a fluidized
bed combustion electric utility steam
generator (atmospheric or pressurized]
who is issued a commercial
demonstration permit by the
Administrator is not subject to the S0>
emission reduction requirements under
S 60.43a(a) but must, as a minimum,
reduce SO, emissions to 15 percent of
the potential combustion concentration
(85 percent reduction) on a 30-day
rolling average basis and to less than
520 ng/J (1.20 Ib/million Btu) heat input
on a 30-day rolling average basis.
(d) The owner or operator of an
affected facility that combusts coal-
derived liquid fuel and who is issued a
commercial demonstration permit by the
Administrator is not subject to the
applicable NO, emission limitation and
percent reduction under § 60.44a(a) but
must, as a minimum, reduce emissions
to less than 300 ng/J (0.70 Ib/million Btu)
11-12
-------
heat input on a 30-day rolling average
basis.
(e) Commercial demonstration permits
may not exceed the following equivalent
MW electrical generation capacity for
any one technology category, and the
total equivalent MW electrical
generation capacity for all commercial
demonstration plants may not exceed
15.000 MW.
Mutant
alactncal
capacity
(UWdwmcal
output)
SoM iotw
-------
potential sulfur dioxide emissions in
place of a continuous sulfur dioxide
emission monitor at the inlet to the
sulfur dioxide control device as required
under paragraph (b)(l) of this section.
(c) The owner or operator of an
affected facility shall install, calibrate,
maintain, and operate a continuous
monitoring system, and record the
output of the system, for measuring
nitrogen oxides emissions discharged to
the atmosphere.
(d) The owner or operator of an
affected facility shall install, calibrate,
maintain, and operate a continuous
monitoring system, and record the
output of the system, for measuring the
oxygen or carbon dioxide content of the
flue gases at each location where sulfur
dioxide or nitrogen oxides emissions are
monitored.
(e) The continuous monitoring
systems under paragraphs (b), (c), and
(d) of this section are operated and data
recorded during all periods of operation
of the affected facility including periods
of startup, shutdown, malfunction or
emergency conditions, except for
continuous monitoring system
breakdowns, repairs, calibration checks,
and zero and span adjustments.
(f) When emission data are not
obtained because of continuous
monitoring system breakdowns, repairs,
calibration checks and zero and span
adjustments, emission data will be
obtained by using other monitoring
systems as approved by_the
Administrator or the reference methods
as described in paragraph (h) of this
section to provide emission data for a
minimum of 18 hours in at least 22 out of
30 successive boiler operating days.
(g) The 1-hour averages required -
under paragraph § 60.13(h) are
expressed in ng/J.(lbs/million Btu] heat
input and used to calculate the average
emission rates under | 60.46a. The 1-
hour averages are calculated using the
data points required under § 60.13(b). At
least two data points must be used to
calculate the 1-hour averages.
(h) Reference methods used to
supplement continuous monitoring
system data to meet the minimum data
requirements in paragraph 5 60.47a(f)
will be used as specified below or
otherwise approved by the
Administrator.
(1) Reference Methods 3, 6, and 7, as
applicable, are used. The sampling
location(s) are the same as those used
for the continuous monitoring system.
(2) For Method 6, the minimum
sampling time is 20 minutes and the
minimum sampling volume is 0.02 dscm
(0.71 dscf) for each sample. Samples are
taken at approximately 60-minute
intervals. Each sample represents a 1-
hour average.
(3) For Method 7, samples are taken at
approximately 30-minute intervals. The
arithmetic average of these two
consective samples represent a 1-hour
average.
,(4) For Method 3, the oxygen or
carbon dioxide sample is to be taken for
each hour when continuous SOj and
NO, data are taken or when Methods 6
and 7 are required. Each sample shall be
taken for a minimum of 30 minutes in
each hour using the integrated bag
method specified in Method 3. Each
sample represents a 1-hour average.
(5) For each 1-hour average, the
emissions expressed in ng/J (Ib/million
Btu) heat input are determined and used
as needed to achieve the minimum data
requirements of paragraph (f) of this
section.
(i) The following procedures are used
to conduct monitoring system
performance evaluations under
§ 60.13(c) and calibration checks under
§ 60.13(d).
(1) Reference method 6 or 7, as
applicable, is used for conducting
performance evaluations of sulfur
dioxide and nitrogen oxides continuous
monitoring systems.
(2) Sulfur dioxide or nitrogen oxides,
as applicable, is used for preparing
calibration gas mixtures under
performance specification Z of appendix
B to this part.
(3) For affected facilities burning only.
fossil fuel, the span value for a
continuous monitoring system for
measuring opacity is between 60 and 80
percent and for a continuous monitoring
system measuring nitrogen oxides is
determined as follows:
faaitual
Span vaJua for
nitrogen oxides (ppffi)
Gu.
SoM
Combination...
soo
500
1,000
500(x+y) + 1.000z
where:
x is the fraction of total heat input derived
from gaseous fossil fuel,
y is the fraction of total heat input derived
. from liquid fossil fuel and
z is the fraction of total heat input derived
from solid fossil fuel.
(4) All span values computed under
paragraph (b)(3) of this section for
burning combinations of fossil fuels are
rounded to the nearest 500 ppm.
(5) For affected facilities burning fossil
fuel, alone or in combination with non-
fossil fuel, the span value of the sulfur
dioxide continuous monitoring system at
the inlet to the sulfur dioxide control
11-14
device is 125 percent of the maximum
estimated hourly potential emissions of
the fuel fired, and the outlet of the sulfur
dioxide control device is 50 percent of
maximum estimated hourly potential
emissions of the fuel fired.
(Sec. 114. Clean Air Act as amended (42
U.S.C. 7414).)
j 60.48a Compliance determination
procedures and methods.
(a) The following procedures and
reference methods are used to determine
compliance with the standards for
particulate matter under § 60.42a.
(1) Method 3 is used for gas analysis
when applying method 5 or method 17.
(2) Method 5 is used for determining
participate matter emissions and
associated moisture content. Method 17
may be used for stack gas temperatures
less than 160 C (320 F).
(3) For Methods 5 or 17, Method 1 is
used to select the sampling site and the
number of traverse sampling points. The
sampling time for each run is at least 120
minutes and the minimum sampling
volume is 1.7 dscm (60 dscf) except that
smaller sampling times or volumes,
when necessitated by process variables
or other factors, may be approved by the
Administrator.
' (4) For Method 5, the probe and filter
holder heating system in the sampling
train is set to provide a gas temperature- -
no greater than 160'C t32°F).
(5) For determination of particulate
• emissions, the oxygen or carbon-dioxide
sample is obtained simultaneously with
each run of Methods 5 or 17 by
traversing the duct at the same sampling
location. Method 1 is used for selection
of the number of traverse points except
that no more than 12 sample points are
required.
(6) For each run using Methods 5 or 17,
the emission rate expressed in ng/J heat
input is determined using the oxygen or
carbon-dioxide measurements and
particulate matter measurements
obtained under this section, the dry
basis'Fc-factor and the dry basis
emission rate calculation procedure
contained in Method 19 (Appendix A).
(7) Prior to the Administrator's
issuance of a particulate matter
reference method that does not
experience sulfuric acid mist
interference problems, particulate
matter emissions may be sampled prior
to a wet flue gas desulfurization system.
(b) The following procedures and
methods are used to determine
compliance with the sulfur dioxide
standards under § 60.43a.
(1) Determine the percent of potential
combustion concentration (percent PCC)
emitted to the atmosphere as follows:
-------
(i) Fuel Pretreatment (% Rf):
Determine the percent reduction
achieved by any fuel pretreatraent using
the procedures in Method 19 (Appendix
A). Calculate the average percent
reduction for fuel pretreatment on a
quarterly basis using fuel analysis data.
The determination of percent R( to.
calculate the percent of potential
combustion concentration emitted to the
atmosphere is optional. For purposes of
determining compliance with any
percent reduction requirements under
S 60.43a, any reduction in potential SO>
emissions resulting from the following
processes may be credited:
(A) Fuel pretreatment (physical coal
cleaning, hydrodesulfurization of fuel
oil, etc.),
(B) Coal pulverizers, and
(C) Bottom and flyash interactions.
(ii) Sulfur Dioxide Contrbl System (%
ft,): Determine the percent sulfur
dioxide reduction achieved by any
sulfur dioxide control system using
emission rates measured before and
after the control system, following the
procedures in Method 19 (Appendix A);
or, a combination of an "as fired" fuel
• monitor and emission rates measured
after the control system, following the
procedures in Method 19 (Appendix A].
When the "as fired" fuel monitor is
used, the percent reduction is calculated
using the average emission rate from the
sulfur dioxide control device and the
average SO» input rate from the "as
fired" fuel analysis for 30 successive
boiler operating days.
(iii) Overall percent reduction (% Re):
Determine the overall percent reduction
using the results obtained in paragraphs
(b)(l) (i) and (ii) of this section following
the procedures in Method 19 (Appendix
A). Results are calculated for each 30-
day period using the quarterly average
percent sulfur reduction determined for
fuel pretreatment from the previous
quarter and the sulfur dioxide reduction
achieved by a sulfur dioxide control
system for each 30-day period in the
current quarter.
(iv) Percent emitted (% FCC):
Calculate the percent of potential
combustion concentration emitted to the
atmosphere using the following
equation: Percent PCC=100-Percent R,
(2) Determine the sulfur dioxide
emission rates following the procedures
in Method 19 (Appendix A).
(c) The procedures and methods
outlined in Method 19 (Appendix A) are
used in conjunction with the 30-day
nitrogen-oxides emission data collected
under \ 60.47a to determine compliance
with the applicable nitrogen oxides
standard under § 60.44.
(d) Electric utility combined cycle gas
turbines are performance tested for
participate matter, sulfur dioxide, and
nitrogen oxides using the procedures of
Method 19 (Appendix A). The sulfur
dioxide and nitrogen oxides emission
rates from the gas turbine used in
Method 19 (Appendix A) calculations
are determined when the gas turbine is
performance tested under subpart GG.
The potential uncontrolled participate
matter emission rate from a gas turbine
is defined as 17 ng/J (0.04 Ib/million Btu)
heat-input
{ 60.49a Reporting requirements.
(a) For sulfur dioxide, nitrogen oxides,
and particulate matter emissions, the
performance test data from the initial
performance test and from the
performance evaluation of the
continuous monitors (including the
transmissometer) are submitted to the
Administrator.
(b) For sulfur dioxide and nitrogen
oxides the following information is
reported to the Administrator for each
24-hour j>eriod.
(1) Calendar date.
(2) The average sulfur dioxide and
nitrogen oxide emission rates (ng/J or
Ib/million Btu) for each 30 successive
boiler operating days, ending with the
last 30-day period in the quarter
reasons for non-compliance with the
emission standards; and, description of
corrective actions taken.
(3) Percent reduction of the potential
combustion concentration of sulfur
dioxide for each 30 successive boiler
operating days, ending with the last 30-
day period in the quarter; reasons for
non-compliance with the standard; and,
description of corrective actions taken.
(4) Identification of the boiler
operating days for which pollutant or •
dilutent data have not been obtained by
an approved method for at least 18
hours of operation of the facility;
justification for not obtaining sufficient
data; and description of corrective
actions taken.
(5) Identification of the times when
emissions data have been excluded from
the calculation of average emission
rates because of startup, shutdown,
malfunction (NO, only), emergency
conditions (SOi only), or other reasons,
and justification for excluding data for
reasons other than startup, shutdown,
malfunction, or emergency conditions.
(6) Identification of "F1 factor used for
calculations, method of determination,
and type of fuel combusted.
(7) Identification of times when hourly
averages have been obtained based on
manual sampling methods.
(8) Identification of the times wnen
the pollutant concentration exceeded
full span of the continuous monitoring
system.
(9) Description of any modifications to
the continuous monitoring system which
could affect the ability of the continuous
monitoring system to comply with
- Performance Specifications 2 or 3.
(c) If the minimum quantity of
emission data as required by § 60.47a is
not obtained for any 30 successive
boiler operating days, the following
information obtained under the
requirements of § 80.46a(h) is reported
to the Administrator for that 30-day
period:
(1) The number of hourly averages
available for outlet emission rates (n,)
and inlet emission rates (nj as
applicable.
(2) The standard deviation of hourly
averages for outlet emission rates (s0)
and inlet emission rates (sj as
applicable.
(3) The lower confidence limit for the
mean outlet emission rate (E,*) and the
upper confidence limit for the mean inlet
emission rate (E,*) as applicable.
(4) The applicable potential
combustion concentration.
(5) The ratio of the upper confidence
limit for the mean outlet emission rate
(E,,*) and the allowable emission rate
(£«,,) as applicable.
(d) If any standards under § 60,43a are
exceeded during emergency conditions
because of control system malfunction.
the owner or operator of the affected
facility shall submit a signed statement:
(1) Indicating if emergency conditions
existed and requirements under
§ 60.46a(d) were met during each period,
and
(2) Listing the following information:
(i) Time periods the emergency
condition existed;
(ii) Electrical output and demand on
the owner or operator's electric utility •
system and the affected facility:
(iii) Amount of power purchased from
interconnected neighboring utility
companies during the emergency period:
(iv) Percent reduction in emissions
achieved;
Iv) Atmospheric emission rate (ng/J)
of the pollutant discharged; and
(vi) Actions taken to correct control
system malfunction.
(e) If fuel pretreatment credit toward
the sulfur dioxide emission standard
under § 80.43a is claimed, the owner or
operator of the affected facility shall
submit a signed statement
' (1) Indicating what percentage
cleaning credit was taken for the
calendar quarter, and whether the credit
was determined in accordance with the
-------
provisions of § 60.48a and Metnod 1!
(Appendix A): and
(2) Listing the quantity, heat content
and date each pretreated fuel shipment
was received during the previous
quarter; the name and location of the
fuel pretrealment facility; and the total
quantity and total heat content of all
fuels received at the affected facility
during the previous quarter.
(f) For any periods for which opacity,
sulfur dioxide or nitrogen oxides
emissions data are not available, the
owner or operator of the affected facility
shall submit a signed statement
indicating if any changes were made in
operation of the emission control system
during the period of data unavailability.
Operations of the control system and
affected facility during periods of data
unavailability are to be compared with
operation of the control system and
affected facility before and following the
period of data unavailability.
(g) The owner or operator of the
affected facility shall submit a signed
statement indicating whether:
(1) The required continuous
monitoring system calibration, span, and
drift checks or other periodic audits
have or have not been performed as
specified.
(2} The data used to show compliance
was or was not obtained in accordance
with approved methods and procedures
of this part and is representative of
plant performance.
(3) The minimum data requirements
have or have not been met; or, the
minimum data requirements have not
been met for errors that were
unavoidable. ,
(4) Compliance with the standards has
or has not been achieved during the
reporting period. "
(h) For the purposes of the reports
required under § 60.7, periods of excess
emissions are defined as all 6-minute
periods during which the average
opacity exceeds the applicable opacity
standards under § 60.42a(b). Opacity
levels in excess of the applicable
opacity standard and the date of such
excesses are to be submitted to the
Administrator each calendar quarter.
(i) The owner or operator of an
affected facility shall submit the written
reports required under this section and
subpart A to the Administrator for every
calendar quarter. AJ1 quarterly reports
shall be postmarked by the 30th day
following the end of each calendar
quarter.
(Sec. 114. Clean Air Act 38 amended (42
U.S.C 7414).)
11-16
-------
ft— -Standards of Performance for
Nitric Add Plant*
6 60.70 Applicability and designation of
affected facility.
<•) The provisions of this subpart are
applicable to each nitric acid production
unit, which is the affected facility.
cea«Kld<».
(a) On and after the date on which
the performance test required to be con-
ducted by | 60.8 Is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
into the atmosphere from any affected
facility any gases which:
(1) Contain nitrogen oxides, ex-
pressed as NO,, in excess of 1.5 kg per
metric ton of add produced (3.0 Ib per
ton), the production being expressed as
100 percent nitric acid,
(2) Exhibit 10 percent opacity, or
greater.
| 60.73 Emiation monitoring.
(a) A continuous monitoring system
for the measurement of nitrogen oxides
tftan be installed, calibrated, maintained,
and operated by the owner or operator.
The pollutant gas used to prepare cali-
bration gas mixtures under paragraph
2 1 Performance Specification 2 and for
calibration checks under 1 60.13(d) to
this part, s>»*n be nitrogen dioxide (NO.) .
The span shall be set at 500 ppm of nitro-
gen dioxide. Reference Method 7 shall
be used for conducting monitoring sy«-
tem performance evaluations nrifitx I 60.-
(c. t . „ . .
(D) The owner or operator shall estab-
lish a conversion factor for the purpose
of converting monitoring data Into units
of the applicable standard (kg/metric
ton Ib/short ton) . The conversion factor
•hail be established by measuring emls-
aions with the continuous monitoring
iystem concurrent with measuring emls-
cions with the applicable reference meth-
od tests Using only that portion of the
continuous monitoring emission data
that represents emission measurements
concurrent with the reference method
test periods, the conversion factor than
References:
60.2
60.7
60.8
60.11
60.13
Reference Method 7
Specification 2
11-17
-------
•ubpart H—Standard* of PtrfornMnc* for
Sulfuric Add Plants
| 60.80 Applicability and deaicnation of
affected facility.
(a) The provisions of this subpart are
applicable to each sulfuric acid produc-
tion unit, which Is the affected facility. .
converter. Ap-
propriate correction* must be made
for air Injection plant* subject to tbe
Administrator's approval.
a = percentage of sulfur dioxide by vol-
ume In tbe emission* to tbe atmoi-
pbere determined by tbe continuous
monitoring lyitem required under
paragraph (a) of this section.
(c) The owner or operator shall re-
cord all conversion factors and values un-
der paragraph (b) of this section from
which they were computed (Le., CF. r,
and »)•
(d) [Reserved]
(e1 For the purpose of reports under
I 60.7 (c), periods of excess emissions
ah&ll be all three-hour periods (or the
arithmetic average of three consecutive
oue-hour periods) during which the in-
tegrated average sulfur dioxide emissions
exceed the applicable standards under
I 60.82.
(See. 114 at the Oeaa Air Act aa
(43 VAC. l«7e-«).).
§ 60.84 Emission monitoring.
(a) A continuous monitoring system
for the measurement of sulfur dioxide
shall be installed, calibrated, maintained,
and operated by the owner or operator.
The pollutant gas used to prepare cali-
bration gas mixtures under paragraph
2.1, Performance Specification 2 and for
calibration checks under |60.13(d),
shall be sulfur dioxide (SO>). Reference
Method 8 shall be used for conducting
monitoring system performance evalua-
tions under J 60.13(0 except that only
the sulfur dioxide portion of the Method
8 results shall be used. The span shall be
set at 1000 ppm of sulfur dioxide.
(b) The owner or operator shall estab-
lish a conversion factor for the purpose
of converting monitoring data into units
of the applicable standard (kg/metric
ton, Ib/ahort ton). The conversion lae-
11-18
References:
60.2
60.7
60.8
60.11
60.13
Reference Method 8
Specification 2
-------
$60.100 Applicability and designation of
.affected facility.
(a) The provisions of this subpart
are applicable to the following affect-
ed facilities in petroleum refineries:
fluid catalytic cracking unit catalyst
regenerators, fuel gas combustion de-
vices, and all Claus sulfur recovery
plants except Claus plants of 20 long
tons per day (LTD) or less associated
with a small petroleum refinery. The
Claus sulfur recovery plant need not
be physically located within the
boundaries of a petroleum refinery to
be an affected facility, provided it pro-
cesses gases produced within a petro-
leum refinery.
(b) Any fluid catalytic cracking unit
catalyst regenerator of fuel gas com-
bustion device under paragraph (a) of
this section which commences con-
struction or modification after June
11, 1973, or any Claus sulfur recovery
plant under paragraph (a) of this sec-
tion which commences construction or
modification after October 4. 1976, is
subject to the requirements of this
part.
(h) "Coke burn-off" means the coke
removed from the surface of the fluid
catalytic cracking unit catalyst by com-
bustion In the catalyst regenerator. The
rate of coke burn-off Is calculated by the
formula specified In f 60.106.
(1) "Claus sulfur recovery plant"
means a process unit which recovers
sulfur from hydrogen sulflde by a
vapor-phase catalytic reaction of
sulfur dioxide and hydrogen sulflde.
(j) "Oxidation control system"
means an emission control system
which reduces emissions from sulfur
recovery plants by converting these
emissions to sulfur dioxide.
(k) "Reduction control system"
means an emission control system
which reduces emissions from sulfur
recovery plants by converting these
emissions to hydrogen sulflde.
(1) "Reduced sulfur compounds"
mean hydrogen sulflde (E>S), carbonyl
sulfide (COS) and carbon dlsulfide
(CS,).
(m) "Small petroleum refinery"
means a petroleum refinery which has
a crude oil processing capacity of
50,000 barrels per stream day or less.
and which is owned or controlled by a
refinery with a total combined crude
•11 processing capacity of 137,500 bar-
Mis per stream day or less.
140.101 Definition*.
As used In this subpart, all terms not
defined herein shall have the meaning
given them In the Act and In Subpart A.
(a) "Petroleum refinery" means any
facility engaged In producing gasoline,
kerosene, distillate fuel oils, residual fuel
oils, lubricants, or other products
through distillation of petroleum or
through redistillation, cracking or re-
forming of unfinished petroleum
derivatives.
(b) "Petroleum" means the crude ofl
removed from the earth and the oils de-
rived from tar sands, shale, and coal.
(c) "Process gas" means any gas gen-
erated by a petroleum refinery process
unit, except fuel gas and process upset
gas as defined In this section.
(d) "fuel gas" means any gas which
is generated by a petroleum refinery
process unit and which Is combusted. In-
cluding any gaseous mixture of natural
gas and fuel gas which Is combusted.
(e) "Process upset gas" means any gas
generated by a petroleum refinery process
unit as a result of start-up, shut-down.
upset or malfunction.
(f) "Refinery process unit" means any
segment of the petroleum refinery In
which a specific processing operation to
conducted.
(g) "Fuel gas combustion device"
means any equipment, such as process
beaters, boilers and flares used to com-
bust fuel gas, but does not Include fluid
coking unit and fluid catalytic cracking
unit incinerator-waste heat boilers or fa-
cilities in which gases are combusted to
produce sulfur or sulfurlc acid.
J 60.102 Standard for particulate matter.
(a) On and after the date on which
the performance test required to be
conducted by } 60.8 is completed, no
owner or operator subject to the provi-
sions of this subpart shall discharge or
cause the discharge Into the atmos-
phere from any fluid catalytic crack-
ing unit catalyst regenerator:
*****
(S) One* exhibiting greater than 10
percent opacity, except for one six-mln-
ote average opacity reading in any one
hour period.
S 60.104 Standard for sulfur dioxide.
(a) On and after the date on which
the performance test required to be
conducted by §60.8 is completed, no
owner or operator subject to the provi-
sions of this subpart shall:
(1) Burn in any fuel gas combustion
device any fuel gas which contains hy-
drogen sulfide in excess of 230 mg/
dscm (0.10 gr/dscf), except that the
gases resulting from the combustion of
fuel gas may be treated to control
sulfur dioxide emissions provided the
owner or operator demonstrates to the
satisfaction of the Administrator that
this is as effective in preventing sulfur
dioxide emissions to the atmosphere
as restricting the H, concentration in
the fuel gas to 230 mg/dscm or less.
The combustion in a flare of process
upset gas, or fuel gas which is released
to the flare as a result of relief valve
leakage, is exempt from this para-
graph.
(2) Discharge or cause the discharge
of any gases into the atmosphere from
any Claus sulfur recovery plant con-
taining in excess of:
(i) 0.025 percent by volume of sulfur
dioxide at zero percent oxygen on a
-dry basis if emissions are controlled by
an oxidation control system, or a re-
duction control system Jollowed by in-
cineration, or
(11) 0.030 percent by volume of re-
•duced sulfur compounds and 0.0010
percent by volume of hydrogen sulfide
calculated as sulfur dioxide at zero
percent oxygen on a dry basis if emis-
sions are controlled by a reduction
control system not followed by incin-
eration.
(b) [Reserved]
* 60.105 F,mi»»lon monitoring,
(a) Continuous monitoring systems
shall be installed, calibrated, maintained,
and operated by the owner or operator as
follows:
(1) A continuous monitoring system
for the measurement of the opacity of
emissions discharged into the atmosphere
from the fluid catalytic cracking unit cat-
alyst regenerator. The continuous moni-
toring system shall be spanned at 60. 70.
or 80 percent opacity.
(2) An instrument for continuously
monitoring and recording the concen-
tration of carbon monoxide in gases
discharged into the atmosphere from
fluid catalytic cracking unit catalyst
regenerators. The span of this con-
tinuous monitoring system shall be
1,000 ppm.
(3) A continuous monitoring system
for the measurement of sulfur dioxide in
the gases discharged into the atmosphere
from the combustion of fuel gases (ex-
cept where a continuous monitoring sys-
tem for the measurement of hydrogen
sulfide Is installed under paragraph (a)
(4) of this section). The pollutant gas
used to prepare calibration gas mixtures
under paragraph 2.1, Performance Speci-
fication 2 and for calibration checks un-
der | 60.13 (d), shall be sulfur dioxide
(SO,). The span shall be set at 100 ppm.
For conducting monitoring system per-
formance evaluations under I 60.13(c),
Reference Method 6 shall be used.
(4) An instrument for continuously
monitoring and recording concentra-
tions of hydrogen sulfide in fuel gases
j burned in any fuel gas combustion
device. if compliance with
] §60.104(a)(l) is achieved by removing
H,S from the fuel gas before it is
burned; fuel gas combustion devices
having a common source of "fuel gas
may be monitored at one location, if
1 monitoring at this location accurately
represents the concentration of H,S in
i the fuel gas burned. The span of this
continuous monitoring system shall be
300 ppm.
(5) An instrument for continuously
monitoring and recording concentra-
tions of SO, in the gases discharged
into the atmosphere from any Claus
, sulfur recovery plant if compliance
with § 60.104(a)(2) Is achieved through
11-19
-------
tbe use of an oxidation control system
or a reduction control system followed
by ir.cLientior.. The span of this con-
tinuous monitoring system shall be
sent at 500 ppm.
(6) An instrument^) for continuous-
ly monitoring and recording the con-
centration of HaS and reduced sulfur
compounds in the gases discharged''
into tr><» atmosphere from any Claus
sulfur recovery plant If compliance
with § 60.104(aX2) Is achieved through
the use of a reduction control system
not followed by incineration. The
..span(s) of this continuous monitoring
system(s) shall be-set at 20 ppm for
monitoring and recording the concen-
tration of H,S and 600 ppm for moni-
toring and recording the concentration
',of reduced sulfur compounds.
(c) The average coke burn-off rate
(thousands of Ulogram/hr) and hours of
operation for any fluid catalytic crack-
Ing unit catalyst regenerator subject to
180.102 or 160.103 shall be recorded
daily.
For any fluid catalytic cracking
unit catalyst regenerator which Is subject
to I 60.102 and which utilizes an inciner-
ator-waste heat boiler to combust the
exhaust gases from the catalyst regen-
erator, the owner or operator shall re-
cord dally the rate of combustion of
liquid or solid fossil fuels (llters/hr or
kilograms/hr) and the hours of opera-
tion during which liquid or solid fossil
fuels are combusted in the Incinerator-
waste heat boiler.
(e) For the purpose of reports under
I 80.7 (c), periods of excess emissions that
shall be reported are defined as follows:
(1) Opacity.
All one- hour periods which
contain two or more six-minute periods
during which the average opacity as
measured by the continuous monitoring
system exceeds 30 percent.
(2) Carbon monoxide. All hourly pe-
riods during which the average carbon
monoxide concentration in the gases
discharged into the atmosphere from
any fluid catalytic cracking unit cata-
lyst regenerator subject to § 80.103 ex-
ceeds 0.050 percent by volume.
(3) Sulfur dioxide, (i) Any three-
hour period during which the average
concentration of H»S in any fuel gas
combusted in any fuel gas combustion
device subject to §60.104(a)Q) exceeds
230 mg/dscm (0.10 gr/dscf). if compli-
ance is achieved by removing H,S from
the fuel gas before it is burned; or any
three-hour period during which the
average concentration of SO, In the
gases discharged into the atmosphere
from any fuel gas combustion device
subject to §60.104(a)(l) exceeds the
level specified in § 60.104(a)(l). if com-
pliance is achieved by removing SO,
from the combusted fuel gases.
(11) Any twelve-hour period during
which the average concentration of
SO, in the gases discharged into the
atmosphere from any Claus sulfur re-
covery plant subject to §60.104(a)<2).
exceeds 250 ppm at zero percent
oxygen on a dry basis if compliance
with 560.104(b) is achieved through
the use of an oxidation control system
or a reduction control system followed
by incineration; or any twelve-hour
period during which the average con-
centration of H.S, or reduced sulfur
compounds in the gases discharged
into the atmosphere of any Claus
sulfur plant subject to §60.104(a)(2)
(b) exceeds 10 ppm or 300 ppm. respec-
tively, at zero percent oxygen and on a
dry basis if compliance is achieved
through the use of a reduction control
system not followed by incineration.
11-20
References:
60.2
60.7
60.8
60.11
60.13
Reference Methods 6,
Specifications 1. 2
-------
«**part H Standard* of Pwfomuum lor
Primary Copper Smelters
160.160 Applicability mxt •r»irn«tion
ef affected facility.
(»> The provisions of tnls subpart arc
•Pllcable to the following affected facili-
ties in primary copper smelters: dryer,
Toaster, melting furnace, **"* copper
converter.
"Smelting" means processing
techniques for the melting of a copper
suifide ore concentrate or calcine charge
leading to the formation of separate lay-
ers of molten slag, molten copper, and/or
copper matte.
(f) "Smelting furnace" means any
vessel in which the smelting of copper
sulflde ore concentrates or calcines is
performed and In which the heat neces-
sary for smelting Is provided by an elec-
tric current, rapid oxidation of a portion
of the sulfur contained in the concen-
trate as it passes through an oxidizing
atmosphere, or the combustion of a fossil
fuel. •
(g) "Copper converter^ means any
vessel to which copper matte is charged
and oxidized to copper.
(h) "Sulfurlc acid plant" means any
facility producing sulfuric acid by the
contact process.
d) "Fossil fuel" means natural gas,
petroleum, coal, and any form of solid.
liquid, or gaseous fuel derived from such
materials for the purpose of creating
useful heat.
(j) "Reverberatory smelting furnace"
means any vessel In which the smelting
of copper sulflde ore concentrates or cal-
cines is performed and in which the heat
necessary for smelting is provided pri-
marily by combustion of a fossil fuel.
(k) "Total smelter charge" means the
weight (dry basis) of all copper sulflde
ore concentrates processed at a primary
copper smelter, plus the weight of all
other solid materials introduced Into the
roasters and smelting furnaces at a pri-
mary copper smelter, except calcine, over
a one-month period.
(1) "High level of volatile impurities"
means a total smelter charge containing
more than 0.2 weight percent arsenic, 0.1
weight percent antimony, 4.5 weight per-
cent lead or 5.5 weight percent zinc, on
a dry basis.
f 60.163 Standard for wlfur dioxide.
(a) On and after the date on which
the performance test required to be con-
ducted by { 60.8 is completed, no owner
or operator subject to the provisions
of this subpart shall cause to be dis-
charged into the atmosphere from any
roaster, smelting furnace, or copper con-
verter any gases which contain sulfur
dioxide in excess of 0.065 percent by
volume, except as provided in para-
graphs (b) and (c) of this section.
(b) Reverberatory smelting furnaces
shall be exempted from paragraph (a)
of-this section during periods when the
total smelter charge at the primary cop-
per smelter contains a high level of
volatile Impurities.
(c) A change in the fuel combusted
In a reverberatory smelting furnace shall
not be considered a modification under
this part.
(60.164 Standard for ruible rmiMinn*.
(a) On and after the date on which
the performance test required to be con-
ducted by ! 60.8 is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
into the atmosphere from any dryer any
visible emissions which exhibit greater
than 20 percent opacity.
(b) On and after the date on which
the performance test required to be con-
ducted by i 60.8 is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
into the atmosphere from any affected
facility that uses a sulfuric acid plant to
comply with the standard set forth in
I 60.163, any visible emissions which ex-
hibit greater than 20 percent opacity.
8 60.165 Monitoring of operation*.
(a) The owner or operator of any pri-
mary copper smelter subject to i 60.163
(b) shall keep a monthly record of the
total smelter charge and the weight per-
cent (dry basis) of arsenic, antimony.
lead and zinc contained in this charge.
The analytical methods and procedures
employed to determine the weight of the
total smelter charge and the weight
percent of arsenic, antimony, lead and
zinc shall be approved by the Adminis-
trator and shall be accurate to within
plus or minus ten percent.
(b) The owner or operator of any pri-
mary copper smelter subject to the pro-
visions of this subpart shall in«ta.ft
operate: 11-21
(1) A continuous monitoring system
to monitor and record the opacity of
gases discharged into the atmosphere
from any dryer. The span of this system
shall be set at 80 to 100 percent opacity.
(2) A continuous monitoring system
to monitor and record sulfur dioxide
emissions discharged Into the atmos-
phere from any roaster, smelting furnace
or copper converter subject to 5 60.163
(a). The span of this system shall be
set at a sulfur dioxide concentration of
0.20 percent by volume.
(i) The continuous monitoring system
performance evaluation required under
I 60.13 (c) shall be completed prior to the
initial performance test required under
I 60.8. During the performance evalua-
tion, the span of the continuous moni-
toring system may be set at a sulfur
dioxide concentration of 0.15 percent by
volume if necessary to maintain the sys-
tem output between 20 percent and 90
percent of full scale. Upon completion
of the continuous monitoring system
performance evaluation, the span of the
continuous monitoring system shall be
set at a sulfur dioxide concentration of
0 JO percent by volume.
(11) For the purpose of the continuous
monitoring system performance evalua-
tion required under I 60.13(c) the ref-
erence method referred to under the
Field Test for Accuracy (Relative) in
Performance Specification 2 of Appendix
B to this part shall be Reference Method
6. For the performance evaluation, eacn
concentration measurement shall be of
one hour duration. The pollutant gas
used to prepare the calibration gas mix-
tures required under paragraph 2.1, Per-
formance Specification 2 of Appendix B,
and for calibration checks under } 60.13
(d), shall be sulfur dioxide.
(c) Six-hour average sulfur dioxide
concentrations shall be calculated and
recorded dally for the four consecutive 6-
hour periods of each operating day. Each
six-hour average shall be determined as
the arithmetic mean of the appropriate
six contiguous one-hour average sulfur
dioxide concentrations provided by the
continuous monitoring system installed
under paragraph (b) of this section.
(d) For the purpose of reports required
under 5 60.7(c). periods of excess emis-
sions that shall be reported are defined
as follows:
(1) Opacity. Any six-minute period
during which the average opacity, as
measured by the continuous monitoring
system Installed under paragraph (b) of
this section, exceeds the standard under
|60.164(a).
(2) Sulfur dioxide. All six-hour periods
during which the average emissions of
sulfur dioxide, as measured by the con-
tinuous monitoring system installed
under f 60.163, exceed the level of the
standard. The Administrator will not
consider emissions In excess of the level
of the standard for less than or equal to
1.5 percent of the six-hour periods dur-
ing the quarter as Indicative of a poten-
tial violation of i 60.11 provided the
affected facility, including air pollution
control equipment, is maintained and
operated in a manner consistent with
-------
good air pollution control practice for
minimizing emissions during these pe-
riods. Emissions in excess of the level of
the standard during periods of startup.
shutdown, and malfunction are not to be
Included within the 1.5 percent*
(Sees. 111. 114. and 301 (a) of tbe Clean Air
Act as amended (42 U.S.C. 1SS7C-6, 18S7C-B,
l«S7g(a)).)
References:
60.2
60.7
60.8
60.11
60.13
Reference Methods 6,
Specifications 1, 2
11-22
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SubpertQ—Standard* of Performance for
Primary Zinc Smarter*
160.170 Applicability and Alienation
•f affected facility.
(a) The provision* of this subpart are
applicable to the following affected facili-
ties ID primary tine smelters: roaater and
•Interior machine.
. Any facility under paragraph (a)
of this lection that commences construc-
tion or modification after October 18,
1074. is subject to the requirements of
this subpart.
i 60.171 Definition*.
As used In this subpart, all terms not
defined herein shall have the meaning
given them In the Act and In Bubpart A
of this part.
(a) "Primary zinc smelter" means any
Installation engaged in the production, or
any intermediate process in the produc-
tion, of zinc or zinc oxide from **"" sul-
flde ore concentrates through the use
of pyrometallurgical techniques.
(b) "Roaster" means any facility In
which a zinc sulflde ore concentrate
charge is heated in the presence of au-
to eliminate a significant portion (more
than 10 percent) of the sulfur contained
in the charge.
(c) "Sintering machine" means any
furnace in which calcines are heated in
the presence of air to agglomerate the
calcines into a hard porous mass called
"sinter."
(d) "Sulfuric acid plant" means any
facility producing sulfurie acid by the
contact process.
| 60.173 Standard for folfnr dioxide.
(a) On and after the date on which
the performance test required to be con-
ducted by { 60.8 is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
into the atmosphere from any roaster
any gases which contain sulfur dioxide In
excess of 0.065 percent by volume.
(b) Any sintering machine which
eliminates more than 10 percent of the
sulfur initially contained in the zinc
sulflde ore concentrates will be consid-
ered as a roaster under paragraph (a)
of this section.
| 60.174 Standard for visible emiuion*.
(a) On and after the date on which the
performance test required to be con-
ducted by I 60.8 is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
into the atmosphere from any sintering
machine any visible emissions which ex-
hibit greater than 20 percent opacity.
(b) On and after the date on which
the performance test required to be con-
ducted by f 60.8 Is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
into the atmosphere from any affected
facility that uses a sulfuric acid plant to
comply with the standard set forth in
i 60.173, any visible emissions which ex-
hibit greater than 20 percent opacity.
| 60.175 Monitoring of operation*.
(2) Sulfur dioxide. Any two-hour pe-
riod, as described in paragraph (b) of
this section, during which the average
emissions of sulfur dioxide, as measured
by the continuous monitoring system In-
stalled under paragraph (a) of this sec-
tion, exceeds the standard under { 60.173.
(a) The owner or operator of any pri-
mary zinc smelter subject to the provi-
sions of this subpart shall Install and
operate:
(1) A continuous monitoring system to
monitor and record the opacity of gases * *
discharged Into the atmosphere from any
sintering machine. The span of this sys-
tem shall.be set at 80 to 100 percent
opacity.
(2) A continuous monitoring system to
monitor and record sulfur dioxide emis-
sions discharged Into the atmosphere
from any roaster subject to I 60.173. The
span of this system shall be set at a
sulfur dioxide concentration of 0.20 per-
cent by volume.
(1) The continuous monitoring system
performance evaluation required under
I 60.13(c) shall be completed prior to the
initial performance test required under
I 60.8. During the performance evalua-
tion, the span of the continuous monitor-
ing system may be set at a sulfur dioxide
concentration of 0.15 percent by volume
if necessary to maintain the system out-
put between 20 percent and 90 percent
of full scale. Upon completion of the con-
tinuous monitoring system performance
evaluation, the span of the continuous
monitoring system shall be set at a sulfur
dioxide concentration of 0.20 percent by
volume.
(11) For the purpose of the continuous
monitoring system performance evalua-
tion required under I 60.13(c), the ref-
erence method referred to under the
Field Test for Accuracy (Relative) in
Performance Specification 2 of Appendix
3 to this part shall be Reference Method
6. For the performance evaluation, each
concentration measurement shall be of
one hour duration. The pollutant gas
used to prepare the calibration gas mix-
tures required under paragraph 2.1, Per-
formance Specification 2 of Appendix B.
and for calibration checks under I 60.13
(d). shall be sulfur dioxide.
(b) Two-hour average sulfur dioxide
concentrations shall be calculated and
recorded dally for the twelve consecutive
2-hour periods of each operating day.
Each two-hour average shall be deter-
mined as the arithmetic mean of the ap-
propriate two contiguous one-hour aver-
age sulfur dioxide concentrations pro-
vided by the continuous monitoring sys-
tem Installed under paragraph (a) of
this section.
-------
Subpart R—Standards of ParformanM tar
Primary Lead Smelten
160.180 Applicability
•f affected
<«) The provislona of this fobpart are
applicable to the following affected
facilities In primary lead amelters: sin-
tering machine, wintering machine dis-
charge end. blast furnace, dross rever-
beratory furnace, electric imelting fur-
nace, and converter.
(b) Any facility under paragraph (a)
of this section that commences con-
struction or modification after October
16, 1914. ia subject to the requirements
of this cubpart.
160.1*1 Definition..
As used in this subpart, all terms not
denned herein shall have the meaning
given them In the Act and In Subpart A
of this part.
(a) "Primary lead smelter" means any
Installation or any intermediate process
engaged in the production of lead from
lead sulflde ore concentrates through
the use of pyrometallurglcal techniques.
(b) "Sintering machine" means any
furnace In which a lead sulflde ore con-
centrate charge Is heated in the presence
of air to eliminate sulfur contained in
the charge and to agglomerate the
charge into a hard porous mass called
"sinter."
(c) "Sinter bed" means the lead sulflde
ore concentrate charge within a atnter-
' "Sintering machine discharge end"
means any apparatus which receives sin*
ter as it Is discharged from the conveying
grate of a sintering machine.
(e) "Blast furnace" means any reduc-
tion furnace to which sinter is charged
and which forms separate layers of
molten slag and lead bullion.
(f) "Dross reverberatory furnace"
means any furnace used for the removal
or refining of Impurities from lead
bullion.
(g) "Electric smelting furnace" means
any furnace in which the heat necessary
for smelting of the lead sulflde ore con-
centrate charge is generated by passing
an electric current through a portion of
the molten mass in the furnace.
(h) "Converter" means any vessel to
which lead concentrate or bullion la
charged and refined.
(i) "Sulfuric acid plant" means any
facility producing sulfuric acid by the
contact process.
| 60.183 Sundard for tolfor dioxide.
(a) On and after the date on which
the performance test required to be con-
ducted by I 60.8 Is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
into the atmosphere from any sintering
machine, electric smelting furnace, or
converter gasea which contain sulfur di-
oxide in excess of 0.065 percent by
volume.
| 60.184 Standard for riaible emiiaiona.
(a) On and after the date on which
the performance test required to be con-
ducted by {60.8 is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
into the atmosphere from any blast fur-
nace, dross reverberatory furnace, or
aintering machine discharge end any
visible emissions which exhibit greater
than 20 percent opacity.
(b) On and after the date on which
the performance test required to be con-
ducted by { 60.8 is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
Into the atmosphere from any affected
facility that uses a sulfuric acid plant to
comply with the standard set forth in
f 60.183, any visible emissions which
exhibit greater than 20 percent opacity.
| 60.185 Monitoring, of operation*.
(a) The owner or operator of any
primary lead smelter subject to the pro-
visions of this subpart shall Install and
operate:
(1) A continuous monitoring system
to monitor and record the opacity of
gases discharged Into the atmosphere
from any blast furnace, dross rever-
beratory furnace, or sintering machine
discharge end. The span of this system
•hall be set at 80 to 100 percent opacity.
(2) A continuous monitoring system
to monitor and record sulfur dioxide
emissions discharged into the atmos-
phere from any sintering machine,
electric furnace or converter subject to
} 60.183. The span of this system shall
be set at a sulfur dioxide concentration
of 0.20 percent by volume.
(1) The continuous monitoring system
performance evaluation required under
f 60.13 (c) shall be completed prior to the
Initial performance test required under
I 60.8. During the performance evalua-
tion, the span of the continuous moni-
toring system may be set at a sulfur
dioxide concentration of 0.15 percent by
volume If necessary to maintain the sys-
tem output between 20 percent and 90
percent of full scale. Upon completion
of the continuous monitoring system
performance evaluation, the span of the
continuous monitoring system shall be
set at a sulfur dioxide concentration of
0.20 percent by volume.
(li> For the purpose of the continuous
monitoring system performance evalua-
tion required under { 60.13 (c), the refer-
ence method referred to under the Field
Test for Accuracy (Relative) in Per-
formance Specification 2 of Appendix B
to this part shall be Reference Method
6. For the performance evaluation, each
concentration measurement shall be of
one hour duration. The pollutant gasea
used to prepare the calibration gas mix-
tures required under paragraph 2.1, Per-
formance Specification 2 of Appendix B,
and for calibration checks under I 60.13
(d). shall be sulfur dioxide.
(b) Two-hour average sulfur dioxide
concentrations «h»" be calculated and
recorded daily for the twelve consecu*
ttve two-hour periods of each operating
day. Each two-hour average shall be de-
termined as the arithmetic mean of the
appropriate two contiguous one-hour
average sulfur dioxide concentrations
provided by the continuous monitoring
system installed under paragraph (a) of
this section.
(c) For the purpose of reports re-
quired under i 60.7(c). periods of excen
emissions that shall be reported are de-
nned as follows:
(1) Opacity. Any six-minute period
during which the average opacity, as
measured by the continuous monitoring
system installed under paragraph (a) of
this section, exceeds the standard under
|60.184(a).
(2) Sulfur dioxide. Any two-hour pe-
riod, as described in paragraph (b) of
this section, during which the average
emissions of sulfur dioxide, as measured
by the continuous monitoring system in-
stalled under paragraph (a) of this sec-
tion, exceeds the standard under I 60.183.
<8«c 114 of tn» OMB Air Act a*
(43 OJ.C. l«5To-«).).
References:
60.2
60.7
60.8
60.11
60.13
Reference Methods 6,
Specifications 1, 2
11-24
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Sutopart Z—Standards of Performance- for
Ferroalloy Production Faculties
§60.260 Applicability tad firllgnfl"rn
of affected facility.
<») The provision* of this subpart are
•ppBcatole to the following affected fa-
culties: electric submerged arc furnaces
which produce silicon metal, f orrosilicon,
eaJclum silicon, tUlcomcnguneae slroon-
ium. ferrocbrome silicon, allvery
Iron, high-carton ferrochrome, charge
chrome, standard ferromanganese, sfll-
eomanganeae, ferromancaneee silicon, or
calcium carbide; and dust-handling
equipment.
(to) Any facility under paragraph (a)
of this section that commences construc-
tion or modification after October 21,
1074, Is subject to the requirements of
this subpart.
160.261 Definition*.
As used in this subpart. all terms not
defined herein *ha.n have the tti«mi¥ig
given them in the Act and in Subpart A
of this part.
(a) "Electric submerged arc furnace"
means any furnace wherein electrical
energy Is converted to heat energy by
transmission of current between elec-
trodes partially submerged in the furnace
charge.
(b) "Furnace charge" means any ma-
terial introduced into the electric sub-
merged arc furnace and may consist of.
but Is not limited to. ores, slag, carbo-
naceous material, and limestone.
(c) "Product change" means any
change in the composition of the furnace
charge that would cause the electric sub-
merged arc furnace to become subject
to a different mass standard applicable
under t"'-« subpart
"Silicon metal" means any silicon
alloy containing more *>»*" 96 percent
silicon by weight.
(y) "Ferromanganese silicon" means
that alloy containing 63 to 66 percent by
weight manganese, 28 to 32 percent by
weight silicon, and a maximum of 0.08
percent by weight carbon.
g 60.262 SUncUrd for particulate mat-
ter.
(a) On and after the date on which the
performance test required to be con-
ducted by i 60.8 is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
Into the atmosphere from any electric
submerged arc furnace any gases which:
*****
(3) Exit from a control device and ex-
hibit 15 percent opacity or greater.
(b) On and after the date on which
the performance test required to be con-
ducted by i 60.8 is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
into the atmosphere from any dust-han-
dling equipment any gases which exhibit
10 percent opacity or greater.
§ 60.264 EnuMion monitoring.
(a) The owner or operator subject to
the provisions of this subpart shall In-
stall, calibrate, maintain and operate a
continuous monitoring system for meas-
urement of the opacity of emissions dis-
charged into the atmosphere from the
control devlce(s).
(b) For the purpose of reports re-
quired under i 60.7Cc), the owner or op-
erator shall report as excess emissions
all six-minute periods In which the av-
erage opacity is 15 percent or greater.
g 60.263 Monitoring of operation*.
(b) The owner or operator subject to
the provisions of this subpart shall in-
stall, calibrate, maintain, and operate a
device to measure and continuously re-
cord the furnace power input. The fur-
nace power input may be measured at the
output or input side of the transformer.
The device must have an accuracy of ±5
percent over its operating range.
(c) The owner or operator subject to
the provisions of this subpart shall in-
stall, calibrate, and maintain a monitor-
ing device that continuously measures
and records the volumetric flow rate
through each separately ducted hood of
the capture system, except as provided
under paragraph (e) of this section. The
owner or operator of an electric sub-
merged arc furnace that Is equipped with
a water cooled cover which is designed
to contain and prevent escape of the
generated gas and particulate matter
shall monitor only the volumetric flow
rate through the capture system for con-
trol of emissions from the tapping sta-
tion. The owner or operator may install
the monitoring device (s) in any appro-
priate location in the exhaust duct such
that reproducible flow rate monitoring
will result. The flow rate monitoring de-
vice must have an accuracy of ±10 per-
cent over its normal operating range and
must be calibrated according to the
manufacturer's instructions. The Ad-
ministrator may require the owner or
11-25
-------
operator to demonstrate the accuracy of
the monitoring device relative to Meth-
ods 1 and 2 of Appendix A to this part
-------
Subpart AA—Standards of torformanc*
for Stael Plants: Etoctric Are Furnaces
160.270 Applicability tmi
•f affected f •ditty.
(a) The provisions of this subpart are
applicable to tfae foUowlng affected fa-
cilities In steel plants: electric arc fur-
naces and dust-handling equipment.
(b) Any facility under paragraph (»)
of this section that commences construc-
tion or modification after October 21.
1974, is subject to the requirements of
160-271 Definition*.
As used in this subpart, all terms not
denned herein shall have the meaning
given them in the Act and In Subpart A
of this part.
(a) "Electric arc furnace" (EAF)
means any furnace that produces molten
steel and beats the charge materials
with electric arcs from carbon electrodes.
Furnaces from which the molten steel la
cast into the shape of finished products.
such as hi a foundry, are not affected fa-
cilities included within the scope of this
definition. Furnaces which, as the pri-
mary source of iron, continuously feed
prereduced ore pellets are not affected
facilities within the scope of this
definition.
(b) "Dust-handling equipment" means
any equipment used to handle particu-
late matter collected by the control de-
vice and located at or near the control
device for an EAF subject to this sub-
part.
(c) "Control device" means the air
pollution control equipment used to re-
move particulate matter generated by
an EAP(s) from the effluent gas stream.
(d) "Capture system" means the
equipment (including ducts, hoods, fans,
dampers, etc.) used to capture or trans-
port particulate matter generated by an
EAF to the air pollution control device.
(e) "Charge" means the addition of
Iron and steel scrap or other materials
into the top of an electric arc furnace.
(f) "Charging period" means the time
period commencing at the moment an
EAF starts to open and ending either
three minutes after the EAF roof is
returned to its closed position or six
minutes after commencement of open-
ing of the roof, whichever Is longer.
(g) "Tap" means the pouring of
molten steel from an EAF.
(h) "Tapping period" means the time
period commencing at the moment an
EAF begins to tilt to pour and ending
either three minutes after an EAF re-
turns to an upright position or six
minutes after commencing to tilt, which-
ever is longer.
I 60.272 Standard for a*rtieul«le nut-
ter.
(a) On and after the date on which
the performance test required to be con-
ducted by i 60.8 Is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
into the atmosphere from an electric arc
furnace any gases which:
(2) Exit from a control device and ex-
hibit three percent opacity or greater.
(3) Exit from a shop and, due solely
to operations of any EAF(s), exhibit
greater than zero percent shop opacity
except:
(1) Shop opacity greater than zero per-
cent, but less than 20 percent, may occur
during charging periods.
(11) Shop opacity greater than zero
percent, but less than 40 percent, may
occur during tapping periods.
(ill) Opacity standards under para-
graph (a) (3) of this section shall apply
only during periods when flow rates and
pressures are being established under
i 60.274 (c) and (f).
(iv) Where the capture system is op-
erated such that the roof of the shop is
closed during the charge and the tap,
and emissions to the atmosphere are pre-
vented until the roof is opened after
completion of the charge or tap, the shop
opacity standards under paragraph (a)
(3) of this section shall apply when the
roof is opened and shall continue to ap-
ply for the length of time denned by the
charging and/or tapping periods.
(b) On and after the date on which the
performance test required to be con-
ducted by I 60.8 is completed, no owner
or operator subject to the provisions of
this subpart shall cause to be discharged
into the atmosphere from dust-handling
equipment any gases which exhibit 10
percent opacity or greater.
8 60.273 Emiuion monitoring.
(a) A continuous monitoring system
for the measurement of the opacity of
emissions discharged Into the atmosphere
from the control device(s) shall be in-
stalled, calibrated, maintained, and op-
erated by the owner or operator subject
to the provisions of this subpart.
(b) For the purpose of reports under
I 60.7 (c), periods of excess emissions that
shall be reported are denned as all six-
minute periods during which the aver-
age opacity is three percent or greater.
(8*c. 114 of Uu d«*a Air Aev M
(41 0.8.C. lMlc-9).).
References:
60.2
60.7
60.8
60.11
60.13
11-27
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Svbport BA—Standards of farfofnMne* for
Kraft Pulp Millt
60.280 Applicability and designation of af-
fected facility.
(a) The provisions of this subpart
are applicable to the following affect-
ed facilities In kraft pulp mills: digest-
er system, brown stock washer system,
multiple-effect evaporator system,
black liquor oxidation system, recov-
ery furnace, smelt dissolving tank,
Ume fcHn, and condensate stripper
system. In pulp mma where kraft
pulping is combined with neutral sul-
fite semlchemical pulping, the provi-
sions of this subpart are applicable
when any portion of the material
charged to an affected facility is pro-
duced by the kraft pulping operation.
(b) Any faculty under paragraph (a)
of this section that commences con-
struction or modification after Sep-
tember 24, 1976, is subject to the re-
quirements of this subpart.
§ 60.281 Definitions.
As used in this subpart, all terms not
defined herein shall have the same
meaning given them in the Act and in
Subpart A.
(a) "Kraft pulp mill" means any sta-
tionary source which produces pulp
from wood by cooking (digesting)
wood chips in a water solution of
sodium hydroxide and sodium sulfide
'(white liquor) at high temperature
and pressure. Regeneration of the
cooking chemicals through a recovery
process is also considered part of the
kraft pulp mill.
(b) "Neutral sulfite semlchemical
pulping operation" means any oper-
ation in which pulp is produced from
wood by cooking (digesting) wood
chips in a solution of sodium sulfite
and sodium bicarbonate, followed by
mechanical defibrating (grinding).
(c) "Total reduced sulfur (TRS)"
means the sum of the sulfur com-
pounds hydrogen sulfide, methyl mer-
captan, dimethyl sulfide, and dimethyl
disulfide, that are released during the
kraft pulping operation and measured
by Reference Method 16.
(d) "Digester system" means each
continuous digester or each batch di-
gester used for the cooking of wood in
white liquor, and associated flash
tank(s). below tank(s), chip steamer(s),
and condenser(s).
(e) "Brown stock washer system"
means brown stock washers and associ-
ated knotters, vacuum pumps, and fil-
trate tanks used to wash the pulp fol-
lowing the digester system.
(f) "Multiple-effect evaporator
system" means the multiple-effect
evaporators and associated
condensers) and hotwell(s) used to
concentrate the spent cooking liquid
that is separated from the pulp (black
liquor).
(g) "Black liquor oxidation system"
means the vessels used to oxidize, with
air or oxygen, the black liquor, and as-
sociated storage tank(s).
(h) "Recovery furnace" means either
a straight kraft recovery furnace or a
cross recovery furnace, and includes
the direct-contact evaporator for a
direct-contact furnace.
(1) "Straight kraft recovery furnace"
means a furnace used to recover
chemicals consisting primarily of
sodium and sulfur compounds by
burning black liquor which on a quar-
terly basis contains 7 weight percent
or less of the total pulp solids from
the neutral sulfite semichemical pro-
cess or has green liquor sulf idlty of 28
percent or less.
(j) "Cross recovery furnace" means a
furnace used to recover chemicals con-
sisting primarily of sodium and sulfur
compounds by burning black liquor
which on a quarterly basis contains
more than 7 weight percent of the
total pulp solids from the neutral sul-
fite semlchemical process and has a
green liquor sulfidity of more than 28
percent.
(k) "Black liquor solids" means the
dry weight of the solids which enter
the recovery furnace in the black
liquor.
(1) "Green liquor sulfidity" means
the sulfidity of the liquor which leaves
the smelt dissolving tank.
(m) "Smelt dissolving tank" means a
vessel used for dissolving the smelt
collected from the recovery furnace.
(n) "Lime kiln" means a unit used to
calcine lime mud, which consists pri-
marily of calcium carbonate, into
quicklime, which is calcium oxide.
(o) "Condensate stripper system"
means a column, and associated con-
densers, used to strip, with air or
steam, TRS compounds from conden-
sate streams from various processes
within a kraft pulp mm.
J 60.282 Standard foiUiarticulate matter.
(a) On and after the date on which
the performance test required to be
conducted by §60.8 is completed, no
owner or operator subject to the prov^
sions of this subpart shall cause to be
discharged Into the atmosphere: — — .
(1) From any recovery furnace any
gases which: - -
(1) Contain participate matter in
excess of 0.10 g/dscm (0.044 gr/dscf)
corrected to 8 percent oxygen.
(11) Exhibit 35 percent opacity or
greater.
(2) From any smelt dissolving tank
any gases which contain paniculate
11-28
matter In excess of 0.1 g/kg black
liquor solids (dry weight)[0.2 Ib/ton
black liquor solids (dry weight)].
(3) From any lime kiln any gases
which contain particulate matter in
excess of:
(i) 0.15 g/dscm (0.06*7 gr/dscf) cor-
rected to 10 percent oxygen, when gas-
eous fossil fuel is burned.
(11) 0.30 g/dscm (0^13 gr/dscf) cor-
rected to 10 percent oxygen, when
liquid fossil fuel is burned.
$60.283 Standard for total reduced sulfur
(TBS).
(a) On and after the date on which
the performance test required to be
conducted by §60.8 is completed, no
owner or operator subject to the provi-
sions of this subpart shall cause to be
discharged into the atmosphere:
(1) From any digester system, brown
stock washer system, multiple-effect
evaporator system, black liquor oxida-
tion system, or condensate stripper
system any gases which contain TRS
in excess
-------
S 60.284 MoaUarinc of emiwioiu and op-
eration*.
(a) Any owner or operator subject to
the provisions of this subpart shall In-
stall, calibrate, maintain, and operate
the following continuous monitoring
systems:
(DA continuous monitoring system
to monitor and record the opacity of
the gases discharged into the atmos-
phere from any recovery furnace. The
span of this system shall be set at 70
percent opacity.
(2) Continuous monitoring systems
to monitor and record the concentra-
tion of TRS emissions on a dry basis
and the percent of oxygen by volume
on a dry basis in the gases discharged
into the atmosphere from any lime
kJln, recovery furnace, digester
system, brown stock washer system.
multiple-effect evaporator system,
black liquor oxidation system, or con-
densate stripper system, except where
the provisions of § 60.283(a)(l) (lii) or
(iv) apply. These systems shall be lo-
cated downstream of the control
device(s) and the span(s) of these con-
tinuous monitoring system(s) shall be
set:
(i) At a TRS concentration of 30
ppm for the TRS continuous monitor-
ing system, except that for any cross
recovery furnace the span shall be set
at 50 ppm.
(11) At 20 percent oxygen for the
continuous oxygen monitoring system.
(b) Any owner or operator subject to
the provisions of this subpart shall in-
stall, calibrate, maintain, and operate
the following continuous monitoring
devices:
(DA monitoring device which mea-
sures the combustion temperature at
the point of incineration of effluent
gases which are emitted from any di-
gester system, brown stock washer
system, multiple-effect evaporator
system, black liquor oxidation system,
or condensate stripper system where
the provisions of §60.283(aXD(iii)
apply. The monitoring device is to be
certified by the manufacturer to be ac-
curate within ±1 percent of the tem-
perature being measured.
(2) For any lime kiln or smelt dis-
solving tank using a scrubber emission
control device:
(DA monitoring device for the con-
tinuous measurement of the pressure
loss of the gas stream through the
control equipment. The monitoring
device is to be certified by the manu-
facturer to be accurate to within a
gage pressure of ±500 pascals (ca. ±2
inches water gage pressure).
(11) A monitoring device for the con-
tinuous measurement of the scrubbing
liquid supply pressure to the control
equipment. The monitoring device is
to be certified by the manufacturer to
be accurate within ±15 percent of
design scrubbing liquid supply pres-
sure. The pressure sensor or tap is to
be located close to the scrubber liquid
discharge point. The Administrator
may be consulted for approval of alter-
native locations.
(c) Any owner or operator subject to
the provisions of this subpart shall,
except where the provisions of
§60.283(a)(l)(lv) or § 60.283UX4)
apply.
(1) Calculate and record on a dailv
basis 12-hour average TRS concentra-
tions for the two consecutive periods
of each operating day. Each 12-hour
average shall be determined as the
arithmetic mean of the appropriate 12
contiguous 1-hour average total re-
duced sulfur concentrations provided
by each continuous monitoring system
installed under paragraph (a)(2) of
this section.
(2) Calculate and record on a daily
basis 12- hour average oxygen concen-
trations for the two consecutive peri-
ods of each operating day for the re-
covery furnace and lime kiln. These
12-hour averages shall correspond to
the 12-hour average TRS concentra-
tions under paragraph (cXl) of this
section and shall be determined as an
arithmetic mean of the appropriate 12
contiguous 1-hour average oxygen con-
centrations provided by each continu-
ous monitoring system installed under
paragraph (a)(2) of this section.
(3) Correct all 12-hour average TRS
concentrations to 10 volume percent
oxygen, except that all 12-hour aver-
age TRS concentration from a recov-
ery furnace shall be corrected to 8
volume percent using the following
equation:
where:
CTO=the concentration corrected for
oxygen.
C»».=the concentration unconnected for
oxygen.
X=lhe volumetric oxygen concentration In
percentage to be corrected to (8 percent
(or recovery furnaces and 10 percent for
lime kilns, incinerators, or other de-
vices).
y^the measured 12-hour average volumet-
ric oxygen concentration.
(d) For the purpose of reports re-
quired under § 60.7(c), any owner or
operator subject to the provisions of
this subpart shall report periods of
excess emissions as follows:
(1) For emissions from any recovery
furnace periods of excess emissions
are:
(1) All 12-hour averages of TRS con-
centrations above 5 ppm by volume for
straight kraft recovery furnaces and
above 25 ppm by volume for cross re-
covery furnaces.
(11) All 6-minute average opacities
that exceed 35 percent.
(2) For emissions from any lime kiln,
periods of excess emissions are all 12-
hour average TRS concentration
above 8 ppm by volume.
(3) For emissions from any digester
system, brown stock washer system,
11-29
multiple-effect evaporator system,
black liquor oxidation system, or con-
densate stripper system periods of
excess emissions are:
(i) All 12-hour average TRS concen-
trations above 5 ppm by volume unless
the provisions of §60.283(a)(l) (i), (ii).
or (iv) apply; or
(ii) All periods In excess of 5 minutes
and their duration during which the
combustion temperature at the point
of incineration is less than 1200° F.
where the provisions of
§60.283(a)Q)(il) apply.
(e) The Administrator will not con-
sider periods of excess emissions re-
ported under paragraph (d) of this sec-
tion to be indicative of a violation of
J 60.11(d) provided that:
(1) The percent of the total number
of possible contiguous periods of
excess emissions in a quarter (exclud-
ing periods of startup, shutdown, or
malfunction and periods when the fa-
cility is not operating) during which
excess emissions occur does not
exceed:
(i) One percent for TRS emissions
from recovery furnaces.
(ii) Six percent for average opacities
from recovery furnaces.
(2) The Administrator determines
that the affected facility, including air
pollution control equipment, is main-
tained and operated in a manner
which is consistent with good air pol-
lution control practice for minimizing
emissions during periods of excess
emissions.
§ 60.285 Test methods and procedures.
(a) Reference methods in Appendix
A of this part, except as provided
under §60.8(b), shall be used to deter-
mine compliance with § 60.282(a) as
follows:
(1) Method 5 for the concentration
of particulate matter and the associat-
ed moisture content,
(2) Method 1 for sample and velocity
. traverses,
(3) When determining compliance
with § 60.282(a)(2), Method 2 for veloc-
ity and volumetric flow rate, t
(4) Method 3 for gas analysis, and
(5) Method 9 for visible emissions.
(b) For Method 5, the sampling time
for each run shall be at least 60 min-
utes and the sampling rate shall be at
least 0.85 dscm/hr (0.53 dscf/min)
except that shorter sampling times,
when necessitated by process variables
or other factors, may be approved by
the Administrator. Water shall be
used as the cleanup solvent instead of
acetone in the sample recovery proce-
dure outlined in Method 5.
(c) Method 17 (in-stack filtration)
may be used as an alternate method
for Method 5 for determining compli-
ance with §60.282(a)(l)(i): Provided,
That a constant value of 0.009 g/dscm
(0.004 gr/dscf) is added to the results
of Method 17 and the stack tempera-
-------
ture Is no greater than 205* C (ca. 400°
F). Water shall be used as the cleanup
solvent iiijtead of acetone in the
sample recovery procedure outlined in
Method 17.
(d) For the purpose of determining
compliance with J60.283(a) (1), (2),
(3), (4), and (5), the following refer-
ence methods shall be used:
(1) Method 16 for the concentration
of TRS,
(2) Method 3 for gas analysis, and
(3) When determining compliance
with §60.283(a)<4), use the results of
Method 2, Method 16. and the black
liquor solids feed rate in the following
equation to determine the TRS emis-
sion rate.
MaMQjdJ/BJ-S
Where:
E = mass of TRS emitted per unity of black
liquor solids (g/kg) (Ib/ton)
Cn = average concentration or hydrogen
sulfide (H.S) during the test period,
PPM.
dun = average concentration of methyl
mereaptan (MeSH) during the test
period. PPM.
COM, = average concentration of dimethyl
sulfide (DMS» during the test period,
PPM.
CBIOJS = average concentration of dimethyl
dlsulfide (DMDS) during the test period,
PPM.
Fm = 0.001417 g/m' PPM for metric units
- 0.08844 lb/ft' PPM for English units
Fwaa = 0.00200 g/m1 PPM for metric units
= 0.1248 lb/ft• PPM for English units
Faia = 0.002583 g/m* PPM for metric units
- 0.1612 lb/ft' PPK for English units
FBU» = 0.003917 g/m' PPM for metric units
= 0.2445 lb/ft' PPM for English units
QM = dry volumetric stack gas flow rate cor-
rected to standard conditions, dscra/hr
(dscf/hr)
BLS = black liquor solids feed rate, kg/hr
(Ib/hr)
(4) When determining whether a
furnace is straight kraft recovery fur-
nace or a cross recovery furnace,
TAPFI Method T.624 shall be used to
determine sodium sulfide, sodium hy-
droxide and sodium carbonate. These
determinations shall be made three
times daily from the green liquor and
the daily average values shall be con-
verted to sodium oxide (Na»O) and
substituted into the following equa-
tion to determine the green liquor sul-
fidity:
I.J.J OtMervatlon for Clocstac of Probe.
If reduction* In cample concentration* are
observed durinc a sample run that cannot
be explained by process conditions, the sam-
ex-
GLS = 100
Where:
GLS = percent green liquor sulfldity
1 average concentration of No*
pressed as Na,O (mg/1) ~~
average concentration of NaOH
expressed as Na,O
-------
Subpart HH—Standards of Perfor-
mance for Lime Manufacturing
Plants
Sec.
60.340 Applicability and designation of af-
fected fadlity.
60.341 Definitions. -
60.342 Standard for particvUate matter.
60.343 Monitoring of emissions and oper-
ations.
60.344 Test methods and procedures.
AOTHORTTT: S«c. Ill and 301(a) of the
Clean Air Act, as amended (42 U.S.C. 7411.
7601). and additional authority as noted
below.
§60.340 Applicability and designation of
affected facility.
(a) The provisions of this subpart
are applicable to the following affect-
ed facilities used in the manufacture
of lime: rotary lime kilns and lime hy-
drators.
(b) The provisions of this subpart
are not applicable to facilities used in
the manufacture of lime at kraft pulp
mills.
(c) Any facility under paragraph (a)
of this section that commences con-
struction or modification after May 3,
1977, is subject to the requirements of
this part.
§ 60.341 Definitions.' ~
As used in this subpart, all terms not
defined herein shall have the same
meaning given them in the Act and in
subpart A of this part.
(a) "Lime manufacturing plant" in-
cludes any plant which produces a,
lime product from limestone by calci-
nation. Hydration of. the lime product
is also considered to be part of the
source. : •
(b) ''Lime product" means the prod-
uct of the calcination process includ-
ing, but not limited to, calcitic lime,
dolomitic lime, and dead-burned dolo-
mite. -.'-.,' .
(c) "Rotary lime kiln" means a unit
with an inclined rotating drum which
is used to produce a lime product from
limestone by calcination. i
(d) "Lime hydrator" means a unit
used to produce hydrated lime prod-
uct.
{ 60.342 Standard for partieuUtl nutter.
(a) On and after the date on which
the performance test required to be
conducted by §60.8 is completed.-no
owner or operator subject to the provi-
•sions of this -subpart shall cause to be
discharged into the atmosphere:
(1) Prom any rotary lime kiln any
gases which:
(i) Contain participate matter In
excess of 0.15 kilogram per megagram
of limestone feed (0.30 Ib/ton).
(ii) Exhibit 10 percent opacity or
greater.
(2) From any lime hydrator any
gases which contain participate matter
in excess of 0.075 kilogram per mega-
gram of lime feed (0.15 Ib/ton).
§ 60.343 Monitoring of emissions and op-
erations.
kiln and the mass rate of lime feed to
any affected lime hydrator. The mea-
suring device used must be accurate to
within ±5 percent of the mass rate
over its operating range.
(e) For the purpose of reports re-
quired under §60.7(c), periods of
excess emissions that shall be reported
are defined as all six-minute periods
during which the average opacity of
the plume from any lime kiln subject
to paragraph (a) of this subpart is 10
percent or greater.
(a) The- owner or operator subject to
the provisions of this subpart shall in- <** »« °* "??,a " lunended
stall, calibrate, maintain, and operate **^ UJ*-C- <414JJ
a continuous monitoring system,
except as provided in paragraph (b) of
this section, to monitor and record the
opacity of a representative portion of
the gases discharged into the atmos-
phere from any rotary lime kiln. The
span of this system shall be set at 40
percent opacity.
(b) The owner or operator of any,
rotary lime mn using a wet scrubbing
emission control device subject to the
provisions of this subpart shall not be
required to monitor the opacity of the
gases discharged as required in para-
graph (a) of this section, but shall in-
stall, calibrate, maintain, and operate
the following continuous monitoring
devices:
(DA monitoring device for the con-
tinuous measurement of the pressure
loss of the gas stream through the
scrubber. The monitoring device must
be accurate within ±250 pascals (one
inch of water).
(2) A monitoring device for the con-
tinuous measurement of the scrubbing
liquid supply pressure to the control
device. The monitoring device must be
accurate within ±5 percent of design
scrubbing liquid supply pressure.
(c) The owner or operator of any
lime hydrator using a wet scrubbing
emission control device subject to the
provisions of this subpart shall install,
calibrate, maintain, and operate the
following continuous monitoring de-
vices: . - . . - * - _
(DA monitoring device for the con-
tinuous measuring of the scrubbing
liquid flow rate. The monitoring
device must be accurate within ±5 per-,
cent of design scrubbing liquid flow
rate. . • -^.. .
(2) A monitoring device for the con-
tinuous measurement of the electric
current, in amperes, used by the scrub-
ber. The monitoring device must be ac-
curate, within ±10 percent over "its
normal operating range.
(d) For the purpose'of conducting a
performance test under $60.6, the
owner or operator of any lime manu-
facturing plant subject to the provi-
sions of this subpart shall install, cali-
brate, maintain, and operate a device
for measuring the mass rate of lime-
stone feed to any affected rotary lime
11-31
-------
METHOD 1—Baunx AKB Vrt-ocrrr T».»Tri<.«Ej ro*
-x 6TiTION4»T SODECK
1. Princifilt ind ApplicabaUi
1.1 Principle. To aid In the-representative nieasure-
jneot of pollutant emissions tod/or total volumetric flow
rale from a stationary source, > measurement site where
the effluent stream u flowing In a known direction la
selected, and the cross-section of tbe stack la divided Into
a number of equal areas. A traverse point it then located
within each of these equal anas.
'1.2 Applicability. This method la applicable to flow-
Inf (as streams In ducts, stacks, and flues. Tbe metfcod
cannot be used when: (1) flow Is cyclonic or swirling (fee
Section 2.4), (2) a stack i» smaller than about 0.30 meter
<12 In.) In diameter, or O.O71 m> (113 In-1) In croea-eec-
tJonal area, or (1) tbe measurement si(e u less tban two
suck or duet diameter: downstream or less than a bait
diameter upstteam from a flow disturbance.
Tbe requirements of Ibis method must be considered
before r.onstnjctf on of a new facility from whicb emissions
will be measured; failure to do so may require subsequent
alterations to Ihe (tack or deviation from the standard
procedure. Cases involving variants are subject to ap-
proval by tbe Administrator, U.S. Environmental
Protection Agency.
2. Proetiurt
2.1 Selection of Measurement Site. Sampling or
velocity measurement is performed at a site located at
least eight stack: or duct diameters downstream and two
diameters upstream from any flow disturbance sucb as
a bend, eipaosion, or contraction In tbe slack, or tram a
visible flame. If ne<«sary, an alternative location may
b* selected, at a position at least two stack or duet di-
ameters downstream and a ball diameter oruttream from
any flow disturbance. For a rectangular cross section,
an equivalent diameter (£>.) shall be calculated from tb*
fallowing equation, to determine tie upstream and
downstream distances: • •
D.'
where i-lenglh and ""-width.
2.S Delernuning the Number of Traverse Points.
2.2.1 Paniculate. Traverses. When the eight- and
two-diameter criterion can be met, tbe minimum number
. of traverse points shall be: (1) twelve, (or circular or
rectangular stacks with diameters (or*: equivalent di-
ameters) greater than 0.81 meter (24 in.); (2) eight, for
circular stacks with diameters between 0.80 and 0.61
meter (13-24 in.); (3) nine, tor rectangular stacks with
equivalent diameters between 0.30 and 0.61 meter (13-24
in.). . . v
When tbe eight- and two-diameter criterion cannot b*
met, the minimum number of traverse v°ints Is deter-
mined from Figure 1-1. Before referring to tbe figure,
however, determine the distances from tbechovn meas-
urement site U> the nearest upstream and downstream
• disturbances, and divide each distance by the stack
diameter or equivalent diameter, to determine tbe
distance in terms of tbe number of duct diameters. Then,
determine from Figure 1*1 the minimum number of
traverse points that corresponds: (1) to the number of
duct diameters upstream; and (2) to the number of
diameters downstream. Select tbe bigber of the two
minimum numbers of traverse points, or a greater value,
ao that for circular stacks tbe number is a multiple of 4,
and for rectangular flacks, tbe number Is one of thos*
sbown In Table 1-L
TABU 1-1. OoM-wcjioiial Itftut far trcmtolar tfmckj
Are>
Ml
A'umbrr of trmrrrH potato
9..
12.
16.
20.
25..
..
42..
49..
4X3
4x4
Sl4
4lS
6x5
tit
lit
7x7
Figure 1-1. Minimum number of traverse points for particulate traverses.
DUCT DIAMETERS UPSTREAM FROM FLOW DISTURBANCE (DISTANCE A)
1.0 1.5 2.0
£ 10
2
* FROM POINT OF ANY TYPE OF
DISTURBANCE (BEND, EXPANSION, CONTRACTION, ETC.)
8
*
DUCT DIAMETERS DOWNSTREAM FROM FLOW DISTURBANCET(DISTANCE B)
11-32
10
-------
50
DUCT DIAMETERS UPSTREAM FROM FLOW DISTURBANCE (DISTANCE A)
0.5 1.0 1.5 2.0
2.5
I
I
I
CO
O
a.
LU
u.
O
30
20
DISTURBANCE
MEASUREMENT
?- ' SITE
10
DISTURBANCE
I
3 45 67 8 9
DUCT DIAMETERS DOWNSTREAM FROM FLOW DISTURBANCE (DISTANCE R)
10
Figure 1-2. Minimum number of traverse points for velocity (nonparticulate) traverses.
2.2.2 Velocity (Non-Partlculate) Traverses. When
velocity or volumetric Bow nit Is to be determined (but
not particolaU matter), the same procedure as that for
paniculate Inverses (Section 2.2.1) la followed, except
that Figure 1-2 may be osexj instead of Fiirure 1-1.
2.3 Cross-Sectional Layout aod Location of.Travers*
Points.
2.3.1 Circular Stacks. Locate the traverse points on
two perpendicular diameters adcordjng to Table 1-2 and
Uie example shown in Figure 1-3. Any equation (for
eiamplcs, see Citation: 2 and 3 in [he Bibliography) that
gives the same values as those in Table I--2 may be used
in lieu of Table 1-2.
For particulate traverse*, one of the diameter* must b«
in a plane containing Uie greatest eipccled concentration
variation, e.g., after brnds, one diameter shall be in the
pl&ne of the bend. This requirement becomes less critical
as the distance from the disturbance increases; therefore.
other diameter locations may be used, subji-ct la approval
of the Administrator.
jn addition, for stacks having diorDcters greater than
O.G1 ID (24 in.) no traverse points ihall be located within
2-5 ecuUmo.lers (1.00 tn.) of the stack vails; and for stack
diamcUTS equal to or less than 0.81 m (24 In.), no traverse
points shall be located wit hin 1.3 cm (O.iO in.) of the slack
walls. To meet these criteria', observe the procedures
given below.
2.3.1.1 Slacks With Diameters Greater Than 0.41 m
(34 In.), When any of the traverse points as located In
eVctlon 2.3.1 toll within 2.5 cm (1.00 In.) of the slack walla,
relocate them away from tha stack walls to: (1) a distance
of 2J em (1.00 In.); or (2) a distance equal to the aoiile
Inside diameter, whichever is larger. These relocated
(nvers* points (on each end of a diameter) (hall be to*
"adjusted" traverse polnu.
Whenever two successive traverse points are combined
to form a single >d|usl«d traverse point, treat the ad-
justed point as two separate traverse points, both In tb«
campling (or velocity nivasurcment) procedure, and In
recording the dala.
11-33
-------
TRAVERSE
POINT
1
2
3
4
t
Figure 1-3. Example showing circular stack cross section divided into
12 equal areas, with location of traverse points indicated.
filln rta/l< having U-rcntiftl InlUj nr °U"-' d"ct ron-
flrureUom »nirh t/Td lo induce ivi viliiig: In Ui«'s»
Iiutwints. the pre.vvice or anwnfr of ryclunl<- flow at
the tamnliTit loration mufl bedcU'rmii"-d The following
techniques arc acceptable (or Ibis determination.
1 1
° i °, >
T - '"
!'J i
i —
i
0 | 0 1
1 1
1
0 1 0
1
-1
o '1 o
1
1
— 1
1
o e
1
1
Figure 1-4. Example snowing rectangular stack crott
lection divided into 12 equal areas, with • traverse
point at cemroid of each area.
Table 1-2 LOCATION OF TRAVERSE POINTS IN CIRCULAR STACKS
(Percent of stack diameter from inside wall to traverse point)
Tr» verse
point
number
on ( .
diameter
1
2
3
4|
5'
6
7
8
9
10
11
12J
13
14
15
16
J7
18
19
20:
21
22
23
24
• Number of traverse points on i diameter
2
14.6
85.4
i
'
.
4
6.7
25.0
75.0
•93.3
'
6
4.4
14.6
29.6
70.4
85.4
95.6
•
8
3.2
10. S
19.4
32.3
67.7
80.6
89.5
96.8
'
.
y
10
2.6
8.2
14.6
22.6
34.2
65.8
77.4
85.4
91.8
97.4
•
12
2.1
6.7
11.8
17.7
2S.O
35.6
64.4
75.0
82.3
88.2
93.3
97.9
14
1.8
5.7
9.9
14.6
20.1
26.9
36.6
63.4
73.1
79.9
85.4
90.1
94.3
98.2
16
1.6
4.9
8.5
12.5
16.9
Z2.0
28.3
37.5
62.5
71.7
78.0
83 .'1
87.5
91.5
95'. 1
98.4
18
1.4
4.4
7.5
10.9
14.6
18.8
23.6
29.6
38.2
61.8
70.4
76.4
31.2
85.4
89.1
92.5
95.6
98.6
20
K3
3.9
•6.7
. 9.7
12.9
16.5
20.4
25.0
30.6
38.8
61. '2
69.4
75.0
79.6
83.5
87.1
90.3
93.3
96.1
98.7
22
1.1
3.5
6.0
8.7
11.6
14.6
18.0
21.8
26.2
31.5
39.3
60.7
68.5
73.8
78.2
82.0
85.4
88.4
91.3
94.0
96.5
98.9
24
1.1
3.2
' 5.5
7.9
10.5
13.2
16.1
19.4
23.0
27.2
32.3
39.8 '
60.2
67.7
72.8 '
77.0
80.6
83.9
86.8
89.5
92.1
94.5
96.8
98.9
JJ.1-3 Blacks With Diamrten Equal to or Loss Tb«n
0.61 m O4 In.), follow the procedure In Section 2J.1.1.
noting only that any "adjusted" polnu should be
relocated away from the flack walls to: (1) • distance at
1J em (OJO In. 1: or C) a dtslance equal to Ibe DouJ*
Inside diameter, whichever li larger.
1JJ Rectangular Slacks Determine tbe number
of lnv«ne points as uplalned In Sections 2.1 and JJ of
Uui mttbod. From T»ble 1-1. drtrrmliM UM (rid too-
flfuraUon. DMd« the »tvi crtm-tefllon Into u many
•qua! r«ctjuiful&r fclenieouU areas u trtrene poLota,
»nd Item local* a invent point at the rtntiold of each
•quaj are* anwdJnc to tbe eutnple In Fi(urt 1-4-
Tbc lituaUoo of trm»erM pomu beliuj too clow lo tb«
nx'k wall! b not upect«d to arur »dth rcctanciilai-
•Ucia. If thh problam ihoold e»cr arise, the Adimnls-
tntlor must b« contacted for ruolatlbn of UM oiati«r.
2.4 Varioration ol Ab^nct ol Cyclonic flow. In most
fUtlonarr aourraa, Ibr direction of rtack cu Scnr H
MSontiallir ptraJlel to the >tack valb. UowtTer,
erdonic flo<» may eilA 0) a/t*r nich dt»M-« u ryrlonea
aod inertlal deml5t«n following venturi acnjbbexa, or
L«T«] and iero the mnnoin^ter. Connect a Type 8
pilot tub< to the manometer. Position th« Type 8 pilot
tube at each inverse point, lo cuecession, ao thai ih*
planes of the fac* openiru;? of tbe pilot tube are perpendio-
ulo.- to tbe itack eross-wctionaj plane: when the Type 8
pilot robe b In this position, it I: at "0° reference." Note
the differtmiaJ pressure (Ap) reading at each traverse
point. If a nuH (tero) pilot readjng is obtained at 0*
reference ai a riven trarcrse poini. an acceptable flo»
eondJiioD ciiiuai that point. If tbe pilot reading 1> not
xaro at 0* reference, rotate the pilot lube (DP lo ±fXT yaw
an* ]«). on til a null nsdjne is obtained. Carefully detemtine
tod record lb« value of the roiation angle (o) u> Ibe
nearest decree. After tbe null technique has been applied
at each irmrrse point, calculate tbe averare of the abso-
lute values of «-. assign a values of 0° to those poinu for
vnich no roiauoo «K required, and include Ibese In tbe
overall average. If Ihe average value of a is greater than
10°. the overall flov condition in tbe slack Is unacceptable
ana alternative methodology, sul>iu:i to Ihe approval of
tbe Administrator, mart be usod to perform aecuraU
aample and velocity traverses.
1. Determining Dust Concentration In a Gu Stream.
ASME. Performance Test Code No. 27. New York.
U57.
2. Devorklu, Howard, et aL All Pollution Source
Testing Manual Air Pollution Control District. Loi
Angeles, CA. November 1963
a. Methods fcr Oelermlnatlon of Velocity, Volume,
Dust and Misi Content of Oases. Western Precipitation
Division of Joy ManuIacturiDg Co. Los Angeles, CA,
Bulletin VtT^iO. 1968.
4. Standard Method for SampUng Slacks for Paniculate
Waller. In: 1971 Book of ASTM Standards, Pin 23.
ASTM Designation D-2928-71. Philadelphia. Pa. 1971.
i. Hanwri, 11. A., el al. Paniculate Sampling Strategies
for Large Power Planis Inchjding Nonuniform Flow.
USEPA, ORD. ESRL, Research Triangle Park, N.C.
EPA-600/2-76-170. June 1978.
6. Eniropy EnrironnjentaUsu. Inc. Deierminatlon of
the Oplimum Number of Sampling Poinls: An Analysis
of Method 1 Criteria. Environmental Proleclion Agency.
Re««arch Trianfle Park, N.C. EPA Conlracl No. 48-01-
»ir2, Task 7.
MITHOB J— DtTSiinniTioN OT STIC« OAS VILOOTT
AJTD VOLCMITUC FtOW RiTI (TTPI S PlTOT TUB!)
1. Principlr end AppltmbUUl
U Principle. Tbe average gas velocity In a stack Is
determined from the gas density and from measurement
of Ihe average velocity head wiih a Type S (Siausscheibe
or reverse tyr*i pilot tube.
U Applicability. Thl.i method Is applicable lor
me-asurcmem of the average velocity of a gas stream and
for quantifying gas now.
This procedure is not applicable at measure-merit sites
which fail to meet Ihe criteria of Method I, Section 2.1.
Also, the method cannot be used for direct measurement
In cyclonic or swirling gas streams; Section 2.4 of Method
1 shows how 10 determine cyclonic or swirling flow con-
ditions. Wben nnacceptable conditions eusl, alternative
procedures, sub)ect to the approval of the Administrator,
U.S. Environmental Protection Agency, must be em-
ployed to make accurate flow rale determinations:
examples of sucb alternative procedures are: (1) to install
ftraigntening vanes: (2) lo calculate the tolal rolumelrlo
now rate noichiomelrically, or (3) lo move to another
measurement die al which the Dow Is acceptable.
Z. Apparatut
11-34-
-------
1.90.2.54cm'
(0.75-1.0 in.)
i
T~Vl'-'.'.'fr"TJ
...... ^^'..
= T •'Ht'.'fA.V.W.f.T., *ur
^ T , 7.62 cm (3 in.}'
TEMPERATURE SENSOR
LEAK-FREE
CONNECTIONS
•SUGGESTED (INTERFERENCE FREE)
PITOT TUBE • THERMOCOUPLE SPACING
Figure 2-1. Type S pitot tube manometer assembly.
2.1 Type 8 Pilot Tub*. Th« Typ« 8 pilot tub*
(Figure 2-1) thai] be made of m«Ul tubing (e.g., niin-
I«3 tteel). It ii recommended that the titenul tubing
,, Figure 2-2b) b« betwtco 0.48
and. 0.96 ceatlmoten (ffi tad H Ineli). There sb&ll b«
An equal distaoce from the b&se o/ each leg of th« pilot
labe to III lace-opening place (dimension] Pi and Pi,
Figure 2-2b); jt la recommended that thli disLaoce b*
b«twe«n 1.05 and IJOtimei the Bitenul tubiox diameter.
. The (act op«aJng3 of tne pilot tutx iball, pn/erably. b«
aligned u sbown lo Figure 2*2; however, slight rolsahgn-
menu of the opening! are permissible (M< Figure 2-3).
Tn« Type 8 pitot tube thai] bare a ioow-o coefflclent,
d«t«rtalned as outlined In Section <. An IdentlAcailon
number snail be ai^goed to the pitot tube; this number
•hall be permanently marked or engrarril ou the body
of tne lube.
11-35
-------
TRANSVERSE
TUBE AXIS
\
FACE
'OPENING
PLANES
(a)
A SIDE PLANE
I • "• " V /
LONGITUDINAL '* Dt
TUBE AXIS ^ *
A _X
B "\
PA
PB
: *"Y^
B-SIDE PLANE
NOTE:
1.05Dt
-------
TRANSVERSE-
TUBE AXIS '
I w I
LONGITUDINAL
TUBE AXIS—
J, ft t+or-)
—M » ^ !• •
Figure 2-3. Types of face-opening misalignment that can result from field use or im-
proper construction of Type S pilot tubes. These will not affect the baseline value
of.Cpfs) so long as ai and 0.2 < 10°, /?1 and 02 < 5°. 2 < 0.32 cm (1/8 in.) and w <
0.08 cm (1/32 in.) (citation 11 in Section 6).
11-37-
-------
A standard pilot tul-e iv.aT I* n"-d Instead of a Type. P,
prnvid'-O thai 11 me«-l3 II"" n»Tificallniis of Sections J.7
»nd <.2: nnte, Imwrvrr. thfti II" smile and Impact
lirrssiirc holes of jimidurd pilot tube* arc susceptible to
pliituinir tn p.-uticul3tf-ladrn eas streams. Therefore,
whenever « standard plu>l lube i.' n"d to perform >
traverse, aderiu-.te prwi must be fnrni.«licd that the
nricninrs of the pilot mix- have not plurci-d up during the
traverse twrji^j; this ean be done by taking ft velocity
•wad (Ap) reading at the final Iraverv point, eleaiiing out
tlie Impart and natic boles of the standard pitnt tube by
"bark-purling" with pressurized air. and thfn taking
another Ap mdjng. If the Ap readme? mad' before and
•fter the air poire are the same (tS percent), the Invent
Is acceptable. Otherwise, reject the run. Note that If Ap
at Uio final traverse point Is unsuitably low, another
point may be selected. II "back-purging" at regular
Inlrrrali If port of the procedure, then comparative Ap
readings (halHM taken, as above, tor th« last two bade
purfe* at which suitably bigh Ap readings are observed-
S.I Differential Prewure Gauce. An Inclined manom-
«ler or equivalent device is used. Most sampling trains
are equipped with a 10-in. (water column) Inclined'
vertical manometer, having 0.01-ln. HrO divisions OD the
•0- to 1-ln. Inclined scale, and 0.1-ln. HiO divisions on tb«
1- to 10-ln. vertical Kale. This type of manometer (or
other gauge of equivalent sensltlTlty) Is satisfactory for
the measurement of Ap values as low as 1J mm (0.05 In.)
HrO. However, a dinerential pressure gauge of greater
(ensjllvtiy thai) b« used (subjecl to the approval of the
Administrator). If any of toe following Is (bond to be
tine: (1) the arithmetic avenge of all Ap readings at toe
traverse points In the slack Is leas than 1.3 mm (0 OS to.)
HiO; (2) for traverses of 12 or more points, more than 10
percanl of the individual Ap readings are below 1J nun
(0.05 In.) HiO: (3) lor traverses of fewer than 12 points,
more than one Ap reading Is below 1J mm (0.06 In.) HiO.
Citation IX In Section « describes commercially available
EnstrumentalloQ far tbe measurement of low-range gas
velocities.
As an alternative to criteria (1) through (3) above, UM
(ollowini calculatioa mav be prrformed to determine Uw
of using a more sensitive differentia) presaur*
rxiitiirf cnnjc nwd not 1*- al!»rli"(5 tn fhi> pit"', tnl^;
this aJl^riiauve is subject w the approve] of Uia
AdniuJ^'raiur.
t.t I'T^'urr rrol-»»nd Or.u;f. A pic7omr:i-r lul>« and
rncri-ur\- or »uier-;ijlwj l'-iuim inamtnu-ifr ca|«»t.-lr of
mriiurinr jLarlt prc^urp to within 2.6 mm (0.1 in.) lie
is u«*d. The italic top of a suiidnrd type pilot tube or
one li'C of a Type X pilot lulie with'the farr O|x-tiin|t
plants positioned paralU-J lo llif giis flow may also Ue
U-vd a« the pressure probe.
2.i Barometer. A mercury, ttncroM, or other barom-
eter capable of measuring atmospheric pressure to
wlthlo 2J mm UK (0.1 In. HE) may be used. In many
eases, the barometric reading may lx obtained from a
nearby national weather wrvlrc station. In which case
UM nation value (which Is tbe absolute barometric
pressure) (hall be requested and an adjustment for
elevation differences between the weather station and
the sampling point shall be applied at a rate of mlnua
2.5 """ (0.1 In.) H( per SOmeler (100 foot) elevation
Increase, or vice-verso for elevation decrease.
2.9 Gas Density Determination Equipment. Method
3 equipment, if needed (see Section 3.6), to determine^
tbe (lack gas Ary molecular weight, and Reference
Method 4 or Method S equipment lor moisture content
determination; other methods may be used subject to
approval of tbe Administrator.
2.7 Calibration Pilot Tube. When calibration of the
Type E pilot tube Is necessary (sea Section 4), a standard
pilot tube I* used as a reference. Tbe standard pilot
tut* shall, preferably, have a known coefficient, obtained
either (1) dlrrctly from the National Bureau of Stand-
ards, Route 270, Quince Orchard Road, Qaitbersburt.
Mn-jlrvnd. or (2"i l»y i..'.n»rr.!lnn nr Ji.rt anoHm* Ftlnil.in]
pilot tube with »!] NHS-tijceu'-li. owlliiiciit. Allcr.
nnttvi-ly. a yla-ujmU pltul tuU- o Citations 7. 8, and IT in
R'Ttion C) rn.ny W U-. cl. IMUit tuU-> (l<-«ipliod lUTyldnip
to these s|«•v.-ifR-aiiou will have baseline coi-U.iient.< of
about O.W'irO.Ol.
2.7.1 Hemispherical (sliowu In Ficure2-4).elliiJ6nhlal,
or conical Up.
2.72 A rainlaiurn ot s\i rllamelrrs straichl nin (liawd
ui«n D. tbe external 4ii^rnetcr of the tul>e) between Ilia
tip and tbe (title pressure boles.
2.7.3 A minimum of eight diameters rtralght run
between UxrituUc preisuro hole* anil the cenlerUnc of
the external tube, follcwinc tlie 90 drcrec bend.
2.7.4 Static prmurr holes olrrjual tlte (approilronlely
0.1 D), equally spaced in a piezometer ring conftcurctlorL
2-7.5 Ninety degree bend, with curved or mluurd
Junction.
2.8 Differential Pressure Gouge for Type S Pilot
Tube Calibration. An inclined manometer or equivalent
Is used. If the tingle-velocity calibration technique U
employed (sec Section 4.1.2.3), the calibration dlacren-
tlal pressure range (liall be readable to the nearest 0.13
nun HrO (O.OOS in. liiO). For mulUvelocity callbraOons,
tbe gauge shall be readable to the nearest 0.13 mm HiO
(0.005 In BiO) for Ap values between 1.3 and 25 mm IIlO
(0.05 and 1.0 In. BtO), and to the Dearest U mm HiO
(0.05 In. HiO) for Ap values above 25 mm HrO (1.0 tn.
HjO). A speciaJ, more grnsltlve raoce will be required
to read Ap njnee below 1.3 """ HrO |0.05 lo. HrO]
(ae« Citation 18 in Section 8).
vhera:
Api-Indlvid.ua! velocity bead reading at a travena
point, mm H,O (in. H.O).
n-Total nnmbor of traverse points.
i."-0.13 nun IIiO when metric units are nsed and
0.005 in HiO when English units are used.
If T Is greater than 1.05, the velorlty head data an
unacceptable and a more sensitive differential pressure
gauge must be U5ed.
NOTT..—If differential pressure gauges other than
Inclined manometers are used (e.g., macnehelic gauges),
their calibration must be checked after each lesi series.
To check Hie calibration of a differential pressure gauge,
compare Ap readings of the taupe with those of a gauge-
on manometer at a minimum of three points, approxi-
mately representing the ranee of Ap values In the slack.
If, at each point, the values of Ap as read by the differen-
tial pressure gauge and gauge-oil manometer agree lo
wilhin 5 percent, Ihe differential pressure gauge shall be
considered to be in projier calibration. Otherwise, the
test series shall either b? voided, or procedures lo adjust
the measured Ap values and linal rrsullj shall be used,
subject to the approval of the Administrator.
2^ Temperature Gauge. A thermocouple, Uquid-
fUled bulb thermometer, bimcuillic thermometer, mer-
cury-in-glass thermometer, or other gaucc eanable of
measuring lempcraiure to within 1.5 prrci-ni of the mini-
mum absolute slack trin|irralurr Rliall he used. The
temperature gauge shall Ix1 attached to the pilot lube
such that the sensor tip dors not touch any mcial; the
cause shall be in an Inlerfcreiite-fr.-e arrangement with
resiM£t lo Ihc pilot lube face openings (see Kigure 2~1
and abo Figure 2-7 in Section 4). Alicruatr positions may
b« used If the pilot -tube-temperature gauge system la
calibrated according to the procedure of Section 4. Pro-
vided that a difference of not more than 1 pcrccni In the
averaga vclocily measurement u; Introduced, the tea-
CURVED OR
MITEBED JUNCTION
STATIC
HOLES
(-0.1D)
HEMISPHERICAL
TIP
Figure 2-4.~Standard pitot tube design specifications.
1. Praadurt
I.I Set np the apparatus as shown In Figure 2-1.
Capillary tubing or surge tanks installed between the
mauometer and pitot tube mny be used lo dampen Ap
fluctuations. It is recommended, but not required, that
a pretest leak-check be conducted, as follows: (1) blow
through the pilot Impact opening until at least 7.6 cm
(3 in.) HiO velocity presMire registers on the manometer;
then, close oS the impact opening. The pressure shall
remain stable for at least 15 seconds; (2) do Ihe same for
the static pressure side, except using suction to obtain
the minimum of 7.6 cm (3 in.) HiO. Other leak-check
procedures, subject to tbe approval of the Administrator,
may be used. . :
3.2 Level and tero Ihe manometer. Because the ma
nometer level and zero may drift due to vibrations and
temperature changes, make periodic checks during the
traverse. Record all ncx-essary data as shown In the
example data sheet O'tcure 2-5).
3.3 Measure the velocity hend nn<5 lemperalure at the
traverse points specified by Method 1. Ensure that the
proper differential pressure gutice is l»eing used for tha
range of Ap values encountered (see Section 2.2). If It Ll
necessary to clia^e to a more sensuive gouge, do so, and
rcmeasure the Ap and n mperauire readings at each tra-
verse poini. Conduct a post-tost leak-check (mandatory),
as described in Section 3.1 above, lo validale Ihe traverse
run.
3.4 Measure the static pressure In tbe tUck. On»
reading Is usually adequate.
3.5 Determine the atmospheric pressure.
11-38'
-------
PLANT.
DATE.
RUN NO.
STACK DIAMETER OR DIMENSIONS, m{in.)
BAROMETRIC PRESSURE, mm Hg (in. Hg}
CROSS SECTIONAL AREA,
OPERATORS
PIT.OTTUBEI.D.NO.
AVG. COEFFICIENT, Cp = .
LAST DATE CALIBRATED.
SCHEMATIC OF STACK
CROSS SECTION
Traverse
PuNo.
mm (inj H20
Stack Temperature
mm Hg (in.Hj)
Averag*
Figure 2-5. Velocity traverse data.
11-39:
-------
3.1 Dcterrnlnt (he rtark gas dry molivular welpht.
For remt'Uilion pror&uat or pror&ssci ttut unit essen-
tially COi, Oi. CO, and Ni, ose Metbod X For procr.-wa
emlitlnc essentially tlr. in analysis neud not be con-
duct**d; use a dry molucular weight of 29.0. For other
processes. other methods. subject to the approval of Un
A dr. I-1-.: .''••. -:•;•">•<• 'i and H In.) wid U ^j and /'i are
equal and between 1 .<& and l.£D R,, there are two poulble
options: (1) the, pilot tube maj be ealibratod acrordini;
to the procedure outlined In Sections 4 1.2 through
4.1 J> below, or (2) a baseline (Isolated tube) coefficient
nlue at 0.84 mar be assi(ned to the pilot tube. Note,
bowerer, that U the pilot tube b pan of an assembly,
calibration may itlll be required, desplu knowledge
of the baseline coefficient ralue (ae* Section 4.1.1).
If Di, Ft, and Pi are outside the specified limits, the
pilot tube muit be calibrated as outlined In 4.1-2 through
, 4.1 £ below.
4.1.1 Type 8 Pilot Tube Assemblies. During umple
ud relocltT traTenea, tbe Isolated Type 8 pilot tub* to
Dot alwayi osed: la man; uulaneea, tbe pilot tube I*
uedlneooiblnauoo with other soorwtampllnf oompoo-
eots (tbennocouple, aampllng probe, noitle) as part of
an "assembly." The presence of other aamplin? compo-
nents can tometlmei aflecl the baseline ralne of the Type
S pilot tube coefficient (Citation < In Section «); thrrelor*
aa assigned (or otherwise known) baseline coefficient
i-L
TYPE SPITOT TUBE
T«lu« oi"T cr my not be rnlld for » rtvon ««-.•.'iibly. Tin
busline u:id «i. ^i)>ly corQickot vaiu'i ulU L>c idtiiliuil
only when Hie riU'.nt placrmrnt ol tlie cul>i|i
-------
THERMOCOUPLE
-ti-
TYPE S PITOT TUW
SAMPLE PROBE
THERMOCOUPLE
2>S.O«tm j
Ui«J
f
-&-
TYPE SPITOT TUBE
SAMPLE PROBE
Figure 2-7. Proper thermocouple placement to prevent interference;
Dt between 0.48 and 0.95 cm (3/16 and 3/8 in.).
TYPE SPITOT TUBE
SAMPLE PROBE
Y>7.62cm(3inJ
Figure 2-8. Minimum pitot-sample probe separation needed to prevent interference;
D between 0.48 and 0.95 cm (3/16 and 3/8 in.).
4.1.2.1 The flowing gas strum most be manned to a
duct of definite cross-sectional area, either circular or
rectangular. For circular cross-sections, tbe minimum
diirt diameter shall b« 30J cm (12 In.); tor rectangular
rroaveectiona, the width (shorter tide) shall b« it leut
25 4 cm (JOIn.).
4.U.I Tbe eroo-seftlonal area of tbe ralibration duct
must be constant over a distance of 10 or mar* duct
diameters. For a rectangular crosa-section, use An equlva-
Irnt diameter, calculated from the following equation,
to determine the number o/ duct diameters,:
D,-
21. IT
where:
/>.-Equivalent diameter
£-Length
To ensure th« presence of stable, fully developed flow
patterns at th« calibration site, or "test section." tbe
ou must b« located at le*st eiftlil diameters downstream
and two diameters upstrfam Irom Lh« ocarwt disturb-
—The debt- and two-diaai«trr criUria arc not
absolute- o(h*r test *eclloo locailons m«r b« o»d (rob-
)Kt to approTal o/ the Administrator), prortded that the
flow at th« i«n i"< >> siable and d«moutnblr p^nlld
to tb« duet uia.
4J J 3' Th« flow ryylmi shafl hare tha capacltr t«
(fii«roia a lpst-5«Uon vtlocity around 91} ffl/min 13,000
ft/rain). This velocity mart be constant with time U
guarantee steady flow during calibration. Note that
Type 8 pitot tube coefficients obtained by single-velocity
calibration at 915 m/min (5,000 ft/mln) will generally be
valid to within ±3 percent for tbe measurement of
velocities above 306 m/min (1,000 ft/min} and to within
±5 to 6 percent for the measurement of velocities be*
tween 180 and 3O& m/min (600 aod 1,000 ft/mln). If a
more precise correlation between C, and velocity b
de^irea, the flow system shall have tbe capacity to
generate at least four distinct, time-invariant test-section
velocities covering the velocity range from ISO to 1.525
rnAnin (600 to 5,000 ft/mln), and calibration data shall
be taken at regular velocity Intervals over this range
(sea Citations 9 and 14 in Section t for details).
4.1.2.4 Two entry ports, one each for the standard
Equation ''-I and Type 8 pilot tubes, shall be cut In the tast section;
1 the standard pitot entry port shall be located slightly
downstream of tbe Typa 8 port,
-------
PIT'OTTUBE IDENTIFICATION NUMBER:
CALIBRATED BYr.
.DATE:.
RUN NO.
1
2
3
"A"SIDE CALIBRATION
' A pad
em HjO
(in. HaO)
APM
em H20
-tin. H20)
Cp(SIDEA)
Cp(s)
•
DEVIATION
cpW ' Cp-Type 8 pilot tube coefficient '
C, (mi • Standard pilot tube coefficient; DM 0.99 If tb«
coefficient is unknown and the tut* is designed
according to tbe criteria of Sections 2.7.1 to
2.7.5 of this method.
A J>.u—Velocity head measured by the standard pltot
tube, cm HiO (uv H|O)
Ap.-Velodty bead measured by the Type S pltot
tube, cm H,O (In. HiO)
4.1.4J Calculate C, (dde A), the mean A-side coef-
ficient, and £, (side B), the mean B-side coefficient'
calculate the difference between these tvo average
values.
4.1.4.3 Cat -.iblc llio <1 .\;.ii;n:i ofpschofllit llin-c A-
(side 1J). l!.«c Hie fo|.
lowing equation:
CP...! — 0.01
and 11 thr absolute value of the difference between C,
CA) and "c, (B) Is 0.01 or Irss.
4.1.5 Special considerations.
4.1 Al SfJrctloo of calibration point.
4.1.i.l.l When an isolnled Type S pilot tube \t cali-
brated, select a calibration point at or near tbe center of
the duct, and foUow the prorrdurrs outlined in Sections
4.1.S and 4.1.4_aboTe- The T)-p« 6 pilot coefficieno n
obtained, I.e., C, (side A) and C, (sideB), Till be TaJld
ao long as either: (1) the isolated pilot tube is used' or
(2) tbe pltot tube Is used witli other components (noitle,
thermocouple, sample prolip) In an arrangement thai 5
free from aerodynamic interference eflecu (see Figures
2-6 through 2-«).
4.1J.U For Type S pilot tube-thermocouple com-
binations (without sample probe), select a calibration
point at or near the centrr of the duct, and follow the
procedures outlined In Sections 4.1.3 and 4.1.4 above.
The coefficients so obtained » III be valid so long as the
pilot tube-thermocouple combination is used by Itself
or withother components In an interference-free arraofp.
ment (Figures 2-« and 2-*).
4.1.5.1.3 For assemblies with sample probes, the
calibration point should be located at or near the center
of the duct; however, insoriion of a probe sheath into a
small duct may cause siguiiicant cross-sectional area
blockade and yield incorrect rr*effirient values (Citations
In Section 6). Therefore, lo minimize Ihe blockage effect,
the calibration point may In- a few inches off-center If
necessary. The actual blocknpe effect will be negligible
when the theoretical blocVacc, as determined by a
projected-arca model of tlie probe sheath, Is 2 percent u
less of the duct cross-sectiorml area for assemblies without
external shear hs (Figure 2-lttO, and 3 percent or less for
assemblies with eiternal shcatus (Figure 2-10b).
4.U.2 For tho«e probe assemblies in which pltot
tube-nonle Interference is a luctor (i.e., those in which
the pitoi-notiel separation distance fails to meet the
specification illustrated in Ficure 2-6«), the value of
C.<.) depends upon the amount of free-space between
the tube and nozrle, and therefore is a function of noztls
size. In these instances. sojvuoLe calibrations shall bo
performed wiih each of the commonly osed notzle sites
in place. Note that the uncle-velocity ealjbralion l«b-
nlque is acceptable for Uili purpose, even though th«
larger noizle'sizes OO.OSScm or \i in.) are not ordinarily
used for isotinetic sampbiic at velocities around 915
m/min (3,000 ft/nun), which is tli« calibration velocity:
note also that it is not ntvessary to draw an isokmetio
sample dunnj calibration (see Citation 15 in Section 6).
4.1. S.3 For a probe awmlily constructed such that
Itj pltot tube is always used in the same orientation, only
one side of the pilot tube nred be calibrates (the ad«
vhich will lace the flow). The pilot tubt must still meet
Ibe alignment specifications of Ficure J-J or 2-3, however,
and must have an average de\ ulion («) value of 0.01 or
less (see Section 4.1.4.4).
-------
ESTIMATED
SHEATH
BLOCKAGE
F lxw 1
[pUCTAREAj
x 100
Figure 2-10. Projected-area m.odels for typical pitot tube assemblies.
4.1 J Field Use and Recalibration.
4.1.6.1 Field Use.
4.1.6.1.1 When a Type S pitot tube (Isolated tube or
assembly) Is used in the field, the appropriate coefficient
value (whether assigned or obtained by calibration)shall
be used to perform velocity calculations. For calibrated
Type 8 pitot tubes, the A side coefficient shall be used
when the A side of the tube faces the flow, and the B side
coefficient shall be used when the B side faces the flow;
alternatively, the arithmetic average of the A and B side
coefficient values may be used, Irrespective of which side
tacce the flow.
4.1.6.1.2 When a probe assembly Is used to sample a
frn.ii duct (12 to 36 in. in diameter), the probe sheath
sometimes blocks a significant part of the duct cross-
section, causing a reduction in the elective value ol
7»(.i- Consult Citation t In Section 6 for details. Con-
ventional pilot-sampling probe assemblies are not
recommended for use In ducts baring inside diameters
smaller than 12 Inches (Citation 16 in Section 6).
4.1.6.2 Recalibration.
4.1.6.2.1 Isolated Pitot Tubes. After each acid use, the
pitot tube shall be carefully reeiamined In lop, side, and
«cd views. If the pitot face openings are still aligned
within the specifications illustrated in Fiji ire 2-2 or 2-3,
tt can be assumed that the baseline coefficient of the pilot
tube has not changed. If, however, Ibe tube has been
damaged lo the estcnl that It no longer meet! the specifi-
cations of Figure 2-2 or 2-3, the dam act shall either be
repaired to restore proper alignment of the face openings
or the tube shall be discarded.
4 j g_2_j Pitot Tube Assemblies. After each field use,
check the lace opening alignment of the pitot tube, as
m Section 4.1.6.2.1; also, remeasure the intcrcomponent
spacing! of tho assembly. If the Intercomponent spaclius
bave not changed and the face opening alignment is
acceptable. It can b« assumed that the coefficient of the
assembly has not changed. If the face opening alignment
is no longer within the specifications of Figures 2-2 or
j-3 either repair the damage or replace the pitot tub*
(calibrating the new assembly, if necessary). If the inter-
•omnonont spacinfs have changed, restore the original
apacings or recalibrate the assembly.
4 J Standard pilot tube (I/ applicable). II a standard
Diiut lube is used for the Telocity traverse the tob« shall
be constructed according to the criteria of Section 2.7 and
thall be or-slgned a baseline coefficient value of 0.90. If
lh< jtandtrd nltot tube Is u.*d as part of an a,vembly.
the tobe shall be In an Interference-free arrangement
(subject to the approval of tile Administrator).
4.3 Temperature Gauges. Aft«r each field use, cali-
brate dial thermometers, liquid-filled bulb thermom-
eters, thermocouple-potentiometer systems, and other
gauges at a temperature within 10 percent of the average
absolute stock temperature. For temperatures up to
405* C (761° F), use an ASTM mercury-in-glass reference
thermometer, or equivalent, as a reference; alternatively,
either a reference thermocouple and potentiometer
(calibrated by NBS) or thermometric fiied points, e.g..
Ice bath and boiling wator (corrected for barometric
pressure) may be used. For temperatures above 405* O
(761* f), use an NBS-calibrated reference tbermocouple-
polenliomeler system or an alternate reference, subject
to the approval of the Administrator.
If. during calibration, the absolute temperatures meas-
ured with the gauge being calibrated and the reference
gauge agree within 1.5 percent, the temperature data
taken in the field shall be considered valid. Otherwise,
the pollutant emission test shall either bo considered
invalid or adjustments (If appropriate) of the test results
shall be made, subject to the approval of the Administra-
tor.
4.4 Barometer. Calibrate the barometer used against
a mercury barometer.
S. Calnitlima
Carry out calculations, retaining at least one extra
decimal figure beyond that of the acquired data. Round
of! figures after final calculation.
6.1 Nomenclature.
A — Cross-sectional area of stack, m' (If).
B,.-Water vapor In the gas stream (from Method J or
Reference Method 4). proportion by volume.
C, —Pitot tub* coeffleleni»41menslonle«s.
K,r Pitot tube constant.
,, 0_ ™_ r(g/g-molc)(mm Hg)"]m
J EccL ("KKmmHjO) J
far the metric system and
_ft_ r(lh/ll)-mole)(in. Ha)"]"*
"^eccL (°K)(m.H,0) J
11-43-
lor the English system.
Af<-Molecular weight of stock gas, dry basis (M
Section 3.6) g/g-mole (IbAb-mole).
I/.—Molecular weight of stack fas, wet basis, ifg-
mole Qb/lb-mole).
— A/rf (1—B,,)+18.0 BM Equation 2-5
/"»«.- Barometric pressure at measurement site, """
Hg (in. Hg).
Pa—Stack static pressure, rn'Tn Hg (In. Hg).
P.*-Absolute Hack gas pressure, mm Hg (in. Hg)j
"Pi^+P, Equation 3-6
/*.ij«Standard absolute pressure, 7GO mm Hg (29.93
in. Hg).
C^-Drr volumetric stack gas flow rat* corrected to
standard conditions, dscm/br (dscZ/hr).
I,-Stock temperature, *C CF).
T,—Absolute stack temperature, *K (*R).
—J73+(. for metric
-«0+J. for English
Equation 2-7
Equation 2-1
r«d - Standard sbwlute temperature, »3 *K (S28* R)
>,-Averace stock gas velocity, m/see (ft/sec).
Ap-Velocity head of stack goa, mm HiO (io. HiO).
3,6fJO~Conversion factor, sec/or.
18.0-.Molemlar weight of water, g^g-mole (Ib-Tb-
mole).
6.2 Average slock gas velocity.
PM.
^ Equation 2-9
Avtrago stock gas dry volumetric flow rate.
Equation 2-10
I. Mark, L. 8. MT-hnnical Encinrcrs' Ilandbook. New
orr HcGrjw-Hill Hook Co., Ir.e. 1041.
2. Perry. J. IT. Cliemicnl Enirineers' Tfnndbook. New
York. Jlctjraw-lliU Uoiit Co., Inc. 1060.
-------
3. Flilrrliora, R T.. W T. Todd. and W. S. Smith.
Signihrnnrr of Errors In Pluck Snmiillns Mi-!i.«umncnls.
U.S. Knvironnieninl 1'roier-lion Afrncy. Research
Triansle I'ark, N.C. (Presented at tlic Aimu:il Mi-ollnc o(
the Air Pollution Control Association, Si. Louis, Mo.,
June 14-1H. l'J70.)
4 Standard Method for Sampling Slacks for Paniculate
Matter. In: 1971 Book of AST.M Standards, Part 23.
PhiladeJpliia, Pa. 1971. ASTM Designation D-2928-71.
6. Vcniiard, J. K. Eluiucntury Fluid Mechanics. New
York. John Wiley and Sons, Inc. 1047.
6. Fluid Meters—Their Theory and Application.
American Society of Mechanical Engineer], New York,
N.Y. 1950.
7. ASH HAS Handbook of Fundamental*. 1072. p. 208.
8. Annual Book of ASTM Standards, Port 26. 1974. p.
MS.
». VoDaro, H. F. Guidelines for Type S Pilot Tub*
Calibration. U.S. Environmental Protection Agency.
Research Tiangle Park, N.C. (Presented at 1st Annual
Mt«Ung, Source Evaluation Society, Dayton, Ohio,
September 18,1975.)
10. Volluro, R. F. A Type S Pilot Tub* Calibration
Study. U.S. Environmental Protection Agency. Emts-
oon Mcasurejnent Broach, Research Triangle Pork,
N.C. July 1974.
11. VoUaro, R. 7. The Effects of Irnp*ct Opening
Misalignment on the Value of the Type S Pilot Tube
Coefficient. U.S. Environmental Protection Agency,
Emission Measurement Branch, Research Triangle
Park, N.C. October 1976.
12. Vollaro, R. F. Establishment of a Baseline Coeffi-
cient Value for Properly Constructed Type S Pjtot
Tubes. U.S. Environmental Protection Agency, Emis-
sion Measurement Branch, Research Triangle Park,
N.C. November 1974.
IS. VoUaro^ R. F. An Evaluation of Single-Velocity
Calibration Techniques as a Means of Determining Type
, 8 Pilot Tube Coefficients. U.S. Environment*! Protec-
tion Agency, Emission Measurement Branch, Research
Triangle Park N.C. August 1975.
14. vollaro, R. F. The Ose of Type S Pilot Tubes for
the Measurement of Low Velocities. U.S. Environmental
Protection Agency, Emission Measurement Branch,
Research Triangle Park, N.C. November 1974.
15. Smith, Marvin L. Velocity Calibration ol EPA.
Type Source Sampling Probe. United Technologies
Corporation, Pratt and Whitney Aircraft Division,
East Hartford Conn. 1975.
16. Vollaro, R. F. Recommended Procedure lor Sample
Traverses In Ducts Smaller than 1? Inches in Diameter.
U.S. Environmental Protection Agency Emission
Measurement Branch, Research Triangle Park, N.C.
November 1976.
17. Ower, E. and R. C. Pankhurst. The Measurement
of AiT Flow, 4th Ed., London, Pcrgamou Press. 19M.
18. Vollaro, R. T. A survey of Commercially Available
Instrumentation lor the Measurement of Low-Range
Oas Velocities. U.S. Environmental Protection Agency,
Emission Measurement Branch, Research Triangle
Park, N.C. November 1978. (Unpublished Paper)
19. Onyp, A. W., C. C. Si. Pierre. D. 8. Smith. D.
VOLIOD. and J. Sieiner. An Experimental Investigation
of the Effect of Pilot Tube-Sampling Probe Configura-
tions on the Magnitude of the S Type Pilot Tube Cc-
ftfficienl for Commercially Available Source Sampling
rrobr«. rrrpan-d Iiy the VnivrrMi> olttnulor for the
Ministry o( Hie Environment, To:o:.lo, Caiijdo. Feb-
ruary 1975.
METHOD 3 — GAS ANALYSIS FOK CARIIOS PIOIIKE,
OXTOEN, ElCEM AIB.AND L>E7 MOLECULAR Wtlfiin
1. Prineiplr and Appiictbtiiil
1.1 Principle. A gas sample Is extracted from a stack,
by one of Uic following methods: (1) single-point, grab
tampling; (2) single-point, iDlrgntrd sampling; or (3)
multi-point. Integrated sampling. Tlie nu- sample li
anaJyu-d for percent carbon dloiide (COj), percent oxy-
gen (O7), and, If necessary, ppreent carbon monoxldt
(CO). If ft dry molecular weight determination Is to be
made, either an Orsat or a Fyrite ' anilyier may be nsed
for the analysis; for excess air or emission rale correction
factor determination, an Orsol analyjer must be uwd.
1.2 Applicability. This method Is applicable for de-
termining C0> and Oi concentration*, eicru air, and
dry molecular weight of a sample from a gas ftrram of a
Josdl-fueJ combustian process. The method may also b»
applicable toother processes where it hasl^endfLennlned
that compounds other than COi, O:. CO, and nltmcca
(Ni) are not present In concentrations sufficient to
alert the results.
Other methods, as well as modifications to the proce-
dure described herein, are also applicable for ?omc or til
ol the above determinations. Examples of sjwlfic meth-
ods and modifications include: (1) a multi-[ioint samp-
ling method using an Orsat anoJyier to analvre Indi-
vidual grab samples obtained ai each point; (2) a melhod
using COj or Oi and stoichiometric calculations to deter-
mine dry molecular weight and excess air; (3) assigning a
value of 30.0 lor dry molecular weight. In lieu of actual
measurements, for processes burning natural gas, coat, or
oil. These methods and modifications may be uvd, but
are subject to the approval of the Administrator.
As an alternative tp the sampling apparatus and >yt-
tems described herein, other sampling systems (e.g.,
liquid displacement) may be used provided such svsums
are capable of obtaining a representative sample and
maintaining a constant sampling rate, and are otherwise
capable of yielding acceptable results. Use of such
vvstems is subject to the approval of the Administrator.
2.1 Grab Sampling (Figure J-l).
2.1.1 Probe. The probe should be made of stainless
•teeJ or borosilicale glass tubing and should be equipped
with an in-stock or oui-siacE niter lo remove paniculate
matter (a plug of glass wool is satisfactory for this pur-
pose). Any other material Inert to Oi. COi, CO, ana Ni
and resistant to temperature at sampling conditions may
be used for the probe; examples of such material are
aluminum, copper, quant glass and Teflon.
2.1. J Pump. A one-way squeeze bulb, or equivalent,
Is used lo transport Ihe gas sample lo the analytor.
2.2 Integrated Sampling (Figure 1-2).
2.2.1 Probe. A probe such as Uiat described in Section
2.1.1 is suitable.
i .Mention of trade names or specific products docs not
constitute endorsement by the Environmental Protec-
tion Agency.
11-44
-------
.PROBE
FLEXIBLETUBING
\
FILTER (GLASS WOOL)
TO ANALYZER
SQUEEZE BULB
Figure 3-1. Grab-sampling train.
RATE METER
AIR-COOLED
CONDENSER
PROBE
\
\
FILTER
(GLASS WOOL)
RIGID CONTAINER
Figure 3-2. IntegratecPgas-sampling train.
11-45
-------
; ; 3 Conderner. An air-cooled or water-eooird coo-
derivr. or olbw condenser that wilt Dot remove Oi.
CO,. CO, and Ni. may be used to remove- tiers.* moisture
»-M,-h wnuld Interfere with Ibe operation of Ibe pump
ana no* nici (less than 4.0 percent) or high Ch greater than
14.0 percent) coneentrations,-lbe measuring burette of
tbe Orsat must bav« at least 0.1 percent subdivlsions.
S. Dry Uolmltr ViifU DOtrmimUm
Any of the three sampling and analytical procedures
described below may be used for determining the dry
molecular weight.
I.I Single-Point, Qrab Sampling and Analytical
Proeedure-
1.1.1 Tbe sampling point In the duct ibaD either be
at tbe centroid of the cross senior or at a point no claw
to the wails than 1.00m (33 ft), unless otherwise specified
by the Administrator.-
1.1-2 Set up tbe equipment as shown In Figure 3-1,
making cure ail connections ahead of tbe analyzer are
tight and leak-tree. If an Orsat analyrer Is used. It fa
recommended that the analyzer be leaked-cbecked by
following the procedure In Section £, however, tbe leak-
dMck U optional.
1.1 J pbKe the probe In th> stack, with the Up of the
probe positioned at the sampling point; purge the sampl-
ing one. Draw a sample into the analyzes and Imme-
diately analyze It for percent COiand percent Oa. Deter-
mine the percentage of tbe gas that Is Ni and CO by
subtracting the sura of the percent COi and percent Oi
from 100 percent. Calculate the dry molecular weight ai
indicated In Section 6.3.
a. 1.4 Repeat the sampling, analysis, and calculation
procedures, until the dry molecular weights of any three
grab samples differ from their me.an by oo more than
0.3 g/g-mole (0.3 Ib/lb-mole). Average these three molec-
ular weights, and report tbe results to the nearest
0.1 g/g-mole Ob/lb-mole).
1.2 Single-Point, Integrated Sampling and Analytical
Procedure.
8.2.1 Tbe sampling poiot In the duct sball be located
as specified In Section 3.1.1.
3.2.2 Leak-check (optional) the fleiible bog as In
Section 2.1-6 Set up tlie equipment as shown in Figure
1-2- Just prior to sampling, leak-check (optional) tbe
train by placing a vacuum gauge at tbe condenser inlet,
polling a vacuum of at least 250 mm Ilg (10 in. Bg),
plugging the outlet at the quick disconnect, and then
turning off the pump. Tbe vacuum should remain stable
for at least 0.5 minute. Evacuate tbe flexible ba£. Connect
the probe and pl«e It in the stack, with the tip of the
probe positioned at the sampling point; purge the sampl-
ing line. Nut. connect the ban and make lure that ail
connections art tight and leat tree.
UJ Sample at a constant rale. Tbe sampling run
•bould be simultaneous wilb, and for the same total
length of time as. tbe pollutant emission rate determina-
tion. Collection of at least 30 liters (1.00 ft') of sample gas
li rerommended: however, smaller volumes may be
coUectad.U desired.
1.2.4 Obtain one Integrated flue gu sample during
each pollutant emission rate determination. Within i
hours after tbe sample Is uken, analyze It (or percent
COi and percent Ot using either an Orsat aruJyLcr or a
Fyrite-type combustion gu analyzer. If an Orsat ana-
lyzer Is naed. It Is recommended that the Orsat leek-
ececk de&cribed In Section S be performed before this
determination; bowsver, UH check Is optional. Deter-
mine the percentage of the gu that Is NI and CO by sub-
tracting the aum o/ the percent CO. and percent Oi
from ](X' percent. Calculate the dry molecular weight as
Indicated In Section «J.
1.2.5 Repeat the analysis and calculation procedures
onlU Ibe Individual dry molecular weights for any three
analyses dlfler from their mean by no more than 0.3
tyg-mole (OJ Ib/lb-mole). Average these three molecular
weights, and report the results la the nearest 0.1 c/g-mole
(0.1 Ib/lb-mole).
U Multi-Point, Integrated Sampling and Analytical
Procedure.
3-3J Unless otherwise specified by tbe Adminis-
trator, a minimum of eight traverse points shall be used
for circular stackk -baving diameters less then 0.61 D
(24 In.), a minimum of nine shall be uivd for rectangular
stacks having equivalent diameters less than 0.61 m
(34 In.), and a minimum of twelve traverse point* shall
be osed for all other cases. Tbe traverse point* shall b*
located according lo Method 1. The use of fewer point*
li subject to approval of tbe Administrator.
X3.2 Follow the procedures outlined in Sections 3.2.2
through 3.2.1, eicept for the following: traverse all sam-
pling points and sample at each point lor an equal length
of time. Record sampling data as shown In Figure 3-3.
4. EnUrioa fiatt Cur,,dim r*ctvi m Ljini Ai, Mn.
mino/ioB
NOT*.—A Fyrite-type mmbujiion rw analyio It not
acceptable lor eiwis air or erui.vsiou rate eornt'tmn luclor
determination, unless approved by the Adntinisirstoi
If both percent CO, and poreent Oi are mcwured th,
analnical results ol any of the three prorrdura e'mn
below nuy also U used (or calculating the dry moloculv
wriCbt-
E«h of the three procedures below ihall be used onlr
when spec lied In an applicable suhnan of Ibe sUndsrdi
Tb« nse of these procedures for other purnojes must bin
specific prior approval of the Administrator.
4.1 Single-Point, Qrab lu^piing Uj Analytical
Procedure.
4.1.1 Tbe sampling point In tbe tact shill tlther bi
at the centroid of the cross-section or at a point no closer •
to the walls than 1.00m (3.3ft), onlesotherwisespecUlid
by the Administrator.
4.1.2 Bet op tbe equipment as shown In Flran M,
making sort all connections ahead ol the analyzer in
tight and leek-tree. Leak-cheek the Oral analyze: se-
eording to tbe procedure described lo Section i. TUi
leak-check Is mandatory.
TIME
TRAVERSE
PT.
-
f
AVERAGE
Q
1pm
X DEV.8
i
DEV=
Q • Q avg
(MUSTBE<10%)
Figure 3-3. Sampling rate data.
4.1.3 Place tbe probe In the stack, with the Up ol tbe
probe positioned at the sampling point; purge the sam-
pling line. Draw a sample Into tbe analyzer. For emission
rate correction factor determination, immediately ana-
lyze the sample, as outlined In Sections 4.1.4 and 4 1 6
lor percent CO, or percenl O,. If eicess air Is desired'
proceed as follows: (1) Immedlalely analyie Ibe sample'
as In Sections 4.1.4 and 4.1J, lor percent CO,. 0,. and
CO: (2) determine the percentage ol the gas tbat is N,
by subtracting the sua> of the percenl CO,, percent O,
and percenl CO from 100 percent: and (3) calculate
percent excess air as outlined In Section 6 2.
4.1.4 To ensure complete absorption of the CO, Ov
or U applicable, CO. make repealed passes throuch each
absorbing solution until iwo consocutive readings are.
tbe same. Several passes (three or four) should be made
between readings. (If constant readings cannot be
obtained aflor tnrce consccutiva readings reolace th«
absorbing solution.)
4.1.5 After the analysis Is completed, leak-check
(mandatory) the Orsat analyser once aealn as described
In Section 5. For the results at the analysis lo be valid
the Orsil ansryzer must pass this leak test be/ore and
after the analysis. NOTE.—Since this single-point grab
sampling and analytical procedure Is normally conducted
In conjunction with a single-point, grab sampling and
analytical procedure for a pollutant, only one analysis
li ordinarily conducted. Therefore, real care must be
taken to obtain a valid sample and analysis. Although
in most cases only CO, or 0, Is required. It U recom-
mended tbat both CO, and CT, be measured and that
Citation 5 In the Bibliography be used to validate X.
analytical data.
4 J Single-Point, Integrated Sampling and Analytical
Procedure. *
4.22 Leak-check: (mandatory) the fleilble bat as In
/Section 2.2.6. Set up the equipment u shown UiFirur.
1-2. Jnit pnor to umpung, leak-check (mandslorv) the
train by placing a vacuum gsuce at tbe condenser Inlet,
pulling a vacuum of at least 150 mm Dg (10 in. Hg)
proving tbe outlet at tbe quick disconnect and then
' 11-46 •
tumioj? off the purnp. The vacuum shall remain stablt
lor at lca,;i 0.5 minute. Evamale the Bozlble bag. Coo-
n»ct the prnbeand place It in the stack, with tbe tip of the
probe portioned at the sampling point; purge the sam-
pling line. Neil, connect the bag and make sure that
all onnni-cuons ore light and leak free.
4.2.3 Eaznplc at a coiuiont rale, or as specified by th«
Adminj.'iraior TUe sampling run niust be simuliaoeous
»nth, and for the same louil Icngih of time as, the pollut-
ant emi-vion raie determination. Collect-at least 30
liters (1.00 ft1) of sample cas. Smaller volumes may be
ooUfcied. subject to approval of the AdminiMjalor.
4.2.4 Obtain one intrprated flue gas sample during
eacb j»ollutani emission rule determination. For emission
rate corrfrnon factor dctrnninatiOQ, analyze the sample
within 4 hours oiler it is Inken for percent C0?or percent
O? (ai outlined in S*,-clion3 4.2.5 throurb 4.2.7). The
Orsat ar^Jj-zcr must be leak-checked (see Section 6)
before tbe analysis. U czcess air is desired, proceed as
follows: (l) wuhin 4 hours after tbe sample is taken,
analyze it las in Sections 4.2.5 through 4.2.7| lor percent
COi. O>. and CO: (2) determine tbe percentage of the
gas that is N, by subtracting thr mm of the pcrcenl COh
percent O,. and percent CO from 100 licrcrnl; (3) cal-
culate ixTLtnl excess air, as outlined in Section 6.2.
4.2.5 To ensure complete absorption of the CO,, O».
or If ap;>Lrab)e. CO. make reiwalrd passe5 Ihroueb eacfl
absorbing solution until two consecutive readings aro tbe
same. Several passes (three or four) should be made be-
tween readings. (If constant readings cannot be obtained
alter three oonsecutlTt readings, riplace the absorbing
solution.)
4.2.6 Keprat tbe analysis until the folio* Ing criteria
are met:
4.2.6.1 For percent COi. repeat the analytical pro-
cedure until the rtjulu ofany three analyse* differ by no
more than (a) 0.3 percent by volume » ben CO, Is greater
than 4.0 percent or (b) 0.2 iierccnl by volume when CO»
Is less thaa or e«ina! to 4.0 percent. A»er»ee the three ao-
ceptable values of percent CO, and report tbe feral U U>
Ibe Dea-*e£t 0.1 percent.
4.2.8.2 For percent Oi. repeat the analytical procedon
ontil tbe re?ulls of any lnre« uialyscs difler by no more
-------
than (a) 0.3 pvrvMit by volume when O, Is Irsa thtn 15 0
percent or tb) 0.2 prrci-nt by volume when Oi la greater
than 15.0 prri-rnt. Average the three acceptable values o(
percent Oi and report tl<« result! to the oeartit 0.1
percent.
4.2.6.3 For percent CO, repeat the analytical proce-
dure until the results of tny three icalj*n differ by no
man than O.I percent. Average th« throe acceptable,
values ol percent CO »nd repurl the results to the nearest
0.1 percent.
4.2.7 After the analysis Is completed, leak-check
(mandatory) Hie Orsat analyzer once wain, as described
In Section i. For the results of the analysis to be valid, th*
Onat analyter roust pas this leak test before and after
the analysis. Note: Although in most Instances only COi
•r Oi Is required. It Is recommended that both COi and
Oi be measured, and that Citation 5 in the Bibliography
be used to validate the analyllral data.
4J Multi-Point, Integrated Sampling and Analytical
Procedure.
4.XI Doth the minimum number of sampling points
and the sampling point location shall be as specified ID
Section 3.11 o( this met hod. The use of fewer poi nts than
•pecJied M jubjcct to Ibe approval of the Administrator.
4.3.2 Follow the procedures outlined In Sections 4.2.2
throurh 4.2.7, eicepl lor the following: Traverse ail
sampling points and sample at each point for an equal
length of time. Record sampling data as sliovrn in Figure
3-3,
5. Zrfal-CVct Pttetfart for Oriat Anal^:rrt
Moving an Orsat analyter frequently causes it to leak.
Therefore, an Orsat analyzer should be thoroughly Ink-
checked on site before the Hue «as sample is introduced
Into it. The procedure for taik-cbecking an Onat aiulyter
5.1.1 Brine the liquid level In each pip»tte up to the
reference mark on the capillary tubing and then close the
pipette stopcock.
5.1.2 Raise the leveling bulb sufficiently to bring the-
eonfining liquid meniscus onto the graduated portion of
the burette and then close the manifold sto|».-ock.
5.1.3 Record the meniscus position.
5.1.4 Observe the meniscus in the burette and the
liquid level In the pipette for movement over Uie neit 4
minutes.
5.1.5 For the Orsat analyter to pass the leak-check,
two conditions most be met.
5.1.5.1 The liquid level In each pipette must not fall
below the bottom of the capillary tuUng during Ibis
4-mlnuteinterval.
5.1.5.2 Tbe meniscus In the burette must not change
by more than 0.2 ml during this 4-minutelnterval.
5.1.0 If the analyter fails the leak-check procedure, all
rubber connections and stopcocks should be checked
until the cause of the leak is Identified. Leaking stopcocks
must be disassembled, cleaned, and regrfosed. Leaking
rubber connections must be replaced. After the analyter
Is reassembled, the leak-chock procedure must be
repeated.
(. Calnttaiotu
a.1 Nomenclature.
Mi" Dry molecular weight, f.'g-mole (Ib/lb-mole).
r.EA-Purcflt eicess air.
%COi-Pereent COi by volume (drr basis).
"Oi-Percent Oi by volume (dry basis).
-O-Pereent CO by volume (dry bails).
_Ni-Percent Ni by volume (dry basis).
0.204- Ratio of Oi to N, In air, v/v.
0.280-Molecular weight of Ni or CO, divided by 100.
0.320-Molecular welsht of Oj divided by 100.
0.440-Molecular weight of CO, divided by 100.
6.2 Percent Eiccss Air. Calculate the percent eic**a
air (If applicable), by substituting the appropriate
values of percent Oi, CO, and Ni (obtained from Svctlon
4.1 J or 4.2.4) Into Equation J-l.
bEA =
%0,-0.5%CO
).264 %N,( %0,-O.S %CO)
100
Equation 3-1
NOTE.— The equation above assume that ambient
air is used as the source of Oi and that the fuel does not
contain appreciable amounts of NI (as do coke oven or
blast furnace gases). For tho*e cases when appreciable
amounts of Ni are present (coal, oil, and natural gas
do not contain appreciable amounts of Ni) or when
oiygen enrichment Is used, alternate methods, subject
to approval of the Administrator, are required.
6.1 Dry Molecular Weight. Use Equation 3-2 to
calculate the dry :nolecular weight of the slack gas
Equation 3-2
NOTE, — The above equation docs not consider argon
In aJr (about 0.1) percent, molecular weight of 17.7).
A negative error of about 0.4 percent Is Introduced.
The tester may opt to include argon to the analysis using
procedures subject to approval of the Administrator.
7. BWiovTjpA,
1. Altshuller. A. P. Storage of Oases and Vapors in
Plastic Begs. International Journal of Air and Water
Pollution. 6:76-81. 1963.
2. Conner, William D. and J. 8. Nader. Air Sampling
Plastic Bags. Journal of the American Industrial Hy-
giene Association. W291-J97. 11)64.
3. Burrell Manual lor (las Analysts, Seventh edition.
Burrell Corporation, 2223 Fifth Aveuue, Pittsburgh,
Pa. 15219. 1)51.
4. Mitchell. W. J. and M. R. Midfctt. Field Reliability
of the Orsat Analyter. Journal of Air Pollution Control
Association W:4'JI-4'J5. May 1976.
5. Shigehora, R. T., R. M. Neulichl, and W. S. Smith.
Validating Orsat Analysis Data from Fossil Fuel-Fired
Units. Stack Sampling Newt. 4(2)21-26. August, 1976.
MITOOD t—DtTtJmrNATiov or Moi*tu»t CONTENT
m STICI GASU
L Principal and Xpp'inoftfr
1.1 Principle. A gas sample Is uUacted at a constant
rala from the source; moisture is removed from the sam-
ple stream and determined either voltuneirtcally or
fravuoetrinUy.
1.2 AppllcabOAy. This method Is applicable lor
determining the moisture content of slack got,
Two procedure* are given. The first is a rrfereoca
method, for accurate determinations of moisture content
(such as ore needed to calculate emission data). The
second U an approsimatioa method, which provides
Mtimati of percent moisture to aid In setting isoklnetlo
sampling rates prior to a pollutant emission measure-
ment run. The approximation method described herein
is only a suggested approach; alternative means for
apprniinuting ilie moisture content, e.g., drying tubes,
wet bulb-dry bulb techniques, condonation techniques,
gtoichiofnclric calculations, previous eipericnce, etc.,
are also acoptabl*.
Tbe reference method Is often conducted simultane-
ously with a pollutant emission measurement run; when
It h, calculation of percent isoltinetlc, pollutant emission
rate, etc., for the run shall be oa?*d upon the results of
the reference method or its equivalent; tbcse calculations
shall not be based upon the results of the approximation
method, unless the approximation ruribod is shown, to
the satisfaction of th« Administrator, U.S. Environmen-
tal Protection Agency, to be capable of yielding results
within 1 percent HiO of the reference mi'thod.
NOTE.—The reference method may yield questionable
results when applied to saturated gas streams or to
stri-ams that contain water droplets Therefore when
these conditions exist or are snsperUd, a second deter-
mination of the moisture content shall be made simul-
taneously with the reference method, as follows: Assume
that the gas stream is saturated. Attach a temperature
aensor (capable of measuring to -1° C (2* F)| to the
reference method probe. Measure the stack gas tempera-
tun at each traverse point (we Section 2.2.1) during the
reference method traverse: calculate the average stack
(as temperature. Neit, determine the moisture percent-
age either by: (1) using a psychromethc chart and
making appropriate corrections il stark pressure it
different from that of the chart, or (2) using saturation
vapor pressure tables. In cases where the Dsychrometrie
chart or the saturation vapor pressure tables an not
applicable (based on evaluation of the process), alternate
methods, subj
-------
FILTER
(EITHER IN STACK
OR OUT Of STACK)
STACK
WALL
CONDENSER-ICE BATH SYSTEM INCLUDING
SILICA GEL TUBE —-7
Figure 4-1. Moisture sampling train-reference method.
Z.l.1 Probe. The prob* Is constructed of stainless
ntf\ or class tubing, sufficiently heated to prevent
water condensation, and is equipped with a filter, either
ln-ctack (• f. . a plug of plass wool Inserted into the end
ol th< probe) or heated out-slack (e.g., as described in
Method 5), 10 remove paniculate matter.
H'ben nack conditions permit, other metals or plastic
tubing may be used lor the probe, subject to the approval
ol the Administrator.
2.1.2 Condenser. The condenser consists of four
tapinrers coojioctcd in scries trith rround class, leak-
Irw Iiltines or any similarly leak-tree non-contaminating
fittings. The first, third, and fourth impinc.c/3 shall be
of the Grrenrnjrg-Smilh desicn. modified by replacing
Ihe tip wilb a 1.3 centimeter (H inch) ID class tube
axtenoine to about 1.3 cm (M in.) from the bottom of
the fta^k. The second impinger shall b« of th» Greenburg-
Bmitb delicti with the standard tip. Modifications (e.g.,
nslne flriible connections between the implngers, using
material* other than class, or usins flexible vacuum lines
to coonect the filler holder to the condenser) may b«
roe-d, subject to the approval of the Administrator.
The first two Impinccrs slmll contain known volumes
of water, the third shall be empty, and the fourth shall
contain a known weight of ft- to 16-mosh Indicating type
(iUea {el, or »crolvalent desiccanl. If lh« silica gel has
been previously used, dry ai 175* C (350° F) for 2 hours.
New silica jel may be used as received. A thermometer,
eapnble of measurin; temperature to within 1* C 12° F),
shall be placed at the outlet of tbe fourtb Impinges, fir
monitoring purposes.
Alternatively, any system may b« used (subject to
the approval of the Administrator) that cools the sample
fas stream and allows neasurement of both the water
that has been condensed and the moisture leaving th«
condenser, each to within 1 ml or 1 f. Acceptable means
mrt lo .measure tbe condensed water, either gravi-
metrically or volumetrically. and lo measure the mots-
ton leaving the condenser by: (1) monitoring tb«
temperature and pressure at the eilt of the condenser
and " prevent
moisture condensaiion In the pump and metering
devices and to avoid the nejMJ to make corrections for
moisture io the mrtcrcd volume
2.1.3 Cooling System An Ice bath container and
crushed ice (or equivalent) are usrd to aid in condf rising
moisture.
2.1.4 Metering System. This system Includes a vac-
uum gauge, leak-free pump, thermometers capable of
measuring temperature to within 3* C (S.<° F), dr> gas
met«r capable of measuring volume to within 2 percent,
and related equipment as shown io Figure 4-1. Other
metering systems, capable of maintaining a constant
sampling rale and determining sample gas volume, may
be u.««d, subject to tbe approval of the Administrator.
2.1-5 Barometer. Mercury, aneroid, or other barom-
eter capable of measuring atmospheric pressure lo within
2.4 mm Hg (0.1 In. Hg) may br used. In many uses, ttie
barometric reading may be obtained from a nearby
national weather sendee station, in wblcb case the sta-
tion value (which is the absolute barometric pressure)
ihall b< requested and a/i adjustment for elevation
differences between the wrather'SLaiion and tbe sam-
pling pnlnt shall be applied at a rate of mlnu< 2J rr-m Hg
(0.1 In. Bg) per 30 ra (100 ft) elevation lucrcase or vice
versa lor elevation decrease.
2.1.8 Graduated Cylinder and/or BaUnet. These
Items are used to measure condensed water and moL-tur»
caught In the silica gel to within 1 ml or OJ j Graduated
cylinders sbaU have subdivisions no greater than 2 znL
tlcei laboratory balances are capable of weighing to the
nearest CU j or les. Tbcse balances art suitable lor
use bert. ^
2.3 Procedure. The foDowJng procedure Is written for
a eoodenser tr^fta (such as tbe Unpinfer fyslezn de-
11-48 •.
•cribed in Section 2.1.2) Incorporating volumetric analy-
sis to measure tbe condensed moisture, and silica gel and
fravimetnc aoalrsi* to measure tbe moisture leaving tht
condenser
2.2.1 U nJo.<3 otherwise specified by tbe Administrator,
a minimum of eigbt traverse points shall be used (or
circular stacks having diameters less than O.C1 ID (24 in.),
a minimum of nine point? shall be UM.-d for rectangular
stacks bav.ng equivalent diameters lcs« than 0.61 m
(24 in.), and a mi;iirjium of twelve tmvcrs points 5hall
be used in all otber cavs. The traverse points shall be
located according io Method 1. The use ol fower pomls
Is suhjrci to the approval of the Administrator. Solrel i
suilaMr pr«jl'f anil probe Irncth such that all traverse
points can >-e uui|ilvd. Consider sampling Irom opiwsiw
sides of tbe sli'-k (four total sampling ports) for larca
itacks. to permit u.=e of shorter pn.bc lengths. Mark tbe
probe with heat resistant tape or by conic otbcr Dicthod
to denote the proper distance into tbe stack or duct (or
each sampling point. ?lace known volumes of watrr in
the first Im-o linpjngcrs. Welch antl record the weiplit cf
tbe silica pel to the nearest O.S c. and transfer the silica
•gel to the lounh impinper; alternatively, the silica gul
may UTS* b* traiufcrrod to the Imiiingcr, and thr wriglit
of the silica pel plus impinger n^-orded.
2.2.J £rl»ei a total samiiling lime suci that a mini-
mum lol^l gas volume of U.Oli sera (21 seO »'H be col-
lecud, at a rale no greater tban 0.021 m'/min (0.75 dm).
Wben both moist ui« content and pollutant emission r»U
arc to b< d«teroijned. tbe moisture determinatioo iball
be limuJtaneous with, and for tbe same total length of
'lime as, the pollutant emission rate run, unless olhcrwiat
(pecl.Vd In an applicable subpan ol the standards.
2-SJ Ekt op tbe sampling train as shown in Figun
4-1. Turn on tbe probe healer and (if applicable) tb«
nll*r besting sysum to temperatures of about 120* 0
(248* F), to prevent mater condensation ahead of tb«
condenser-, allow time for the teraporaluru to stabUii*.
Place erusbed Ice in tbe lee batb container. It U recoov
mended, bat not required, that a leak check be done, ai
fellows: Discoacecl the probe, from tbe unt Impimtf or
-------
(If applicable) from the Utter holder. Plug the Inlet ta tbe
first tinpingar (or uJtrr lioMer) and pull a3SO mm (15 in )
n» vacuum;«lower vacuum may be used, provided tbat
it is not etri-rdcd durinc the test. A leakage nle in
eicc&i oi •* percent of Uic svv rare saraplinz rate or (1,00057
mVmm (O.W cfm), whichever Is less, is unacceptable.'
Following the eak clicck, reconnect the prob* to the
aampling train.
2J.4 During the sampling run, maintain a sampling
raU within 10 percent o( constant rate, or u specified br
the Admiiuitrmtor. For rarb run. record Ibe data rt-
SHired on Ux uampla data sheet shown in Figure 4-2.
e lure to record th« dry fis meter reading at tie begin-
ning and end ole*cb sampling time Increment and vheo-
t OCATION
OfERATOR
DATE
HUM NO
AMBIENT TEMPERATURE.
•AROMETRIC PRESSURE.
MOSE LENGTH m(ft)
erer amptlng Is balt«d. Take otbor approprlaU
at eacb sample point, at \aui ooca during each tima
Increment.
2.2.3 To beftn sampling, position tbe probe tip at tba
first traverse point. Immediately ct&rt the pump and
adjust tbe flow to tbe desired rate. Traverse the crosi
lection, sampling at each traverse point (or an equal
length of time. Add more Ice and, If necessary, salt to
maintain a temperature of leu than 20* C (GS* F) at tbe
tillca gel outlet.
12.1 Aftar collecting the sample, disconnect the probe
from the filter holder (or from tbe first lmpinger)and con-
duct a leak check (mandatory) ai described In Section
*3. J. Record tbe leak rate. I/ the Vtfaje rate f irreds the
allowable rate, the l&ster itiall other relrcl the test n-
fuJts or shall correct tbe sample volume as In Section 6.3
of Method A.Neit, measure the volume of th« moisture
conderued to the near&il mi. Determine the increase in
weight of the silica gel (or silica gxl pirn ImpinCT) u> tbe
nearest 0^ g. Record this inform*Uoa (see eiftmple data
ib«t. Figure 4-3) and calculate tbe moisture percentage,
u described In 2J below.
2.3 Calculations. Carry out tb»toOowiiig calculations,
retaining at least one eitra deciraal figure beyond that of
tbe acquired data. Round ofl ajura afur liaal calcula-
JCHEMATIC OF STACK CROSS SECTION
TRAVERSE POINT
NUMBER
•
TOTAL
SAMPLING
TIME
(9), mia.
!
-
AVERAGE
STACK
TEMPERATURE
•C(°F)
'
•
PRESSURE
DIFFERENTIAL
ACROSS
ORIFICE METER
(AH).
mmr»j HJO
METER
READING
GAS SAMPLE
VOLUME
•3 (h3)
•
AV«
«3(hJ)
'.
GAS SAMPLE TEMPERATURE
AT DRY GAS METER
INLET
fT»iJ. »C Crl
"
-
A.*.
Av»..
OUTLET
fT«,ut). »C («F1
'
.
A*
TEMPERATURE
OF GAS
LEAVING
CONDENSER OR
LASTIMPINGER.
•CPF)
-
Figure 4-2. Field moisture determination-reference method.
11-49
-------
HUM.
INFTIAL
DimrtHCi
WINCH
VOLUUE.
•M
jncAca.
«IGHT.
f
Figure 4-1 Antlytkjl d»u • reference m«thod
2.8.1 Nomenclature.
B,.- Proportion of water Taper, by volume, In
the gas stream.
JU»-Molecu)ar weight ol water. 18.0 rt-mol«
'or Enclish unit*.
T«,«Absolute temperature at meter, K (*R).
T.n—Standard absolute temperature, 293* K
• (MS" K).
V«—Dry gas Tolome measured by dry gas meter,
dem (dcfl.
AV.- Incremental dry gas Tolume measured by
dry gas meter at each traTcrse point, dem
(del).
V.f.u)—Dry gas rolorae measured by tbe dry gal
meter, corrected to standard conditions,
dscm (dscf).
V»«l.u) — Volume of water vapor collected In aflloa •
fel corrected to ftandard conditions, aexn
(sen.
Vj—Tina] Tolame of condenser water, ml.
Vt^lnitial Tolume, I/ any, of condenser water,
ml.
W," Final weight of silica gel or aQica gel plus
Iropinger, g.
JT.-lnltlal weight of tfllca gel or iffic* gel plus
Imping tr. g.
y-Dry gu meter calibration factor.
F.-Density of water, 0.9982 g/ml (0.002201
Ib/ml).
S.3.2 Volume of wsler vapor condensed.
Equation 4-1
where:
iTi-0 001333 ni'i'ml for metric units
-0.CM/07 (I'/ml for English units
2.3.3 Volume of water vapor collected In silica gel.
when:
A'i-0.001336 m'/IT for metric nnlts
-O.CH71J ft>/g for English nnlli
3.1.4 Sample gas Tolum*.
Eqaatlon 4-9
=A-,y IrZ!=
K'luatlou 4-3
where:
A*>-0.3ȣ8 'K/inrn Ug for metric nulls
-17.M "RKD. Ug lor English anils
NOTZ.—If the post-test leak rate (Section 2.2.0) ex-
ceeds Ui4 allowable rate, correct the value -of V. In
Equation 4-3, as described In Section 6.3 of Method i.
2.3.6 Moisture Content.
*j
• *rt ( ~T » f
'• re {
Equation 4—4
XOTE. — In saturated or moisture droplet-laden gas
streams, two calculations of tbe moisture content of tbe
stack raj shall be made, one usin^ a ralue bacrd upon
the saturated conditions (see Section 1.2), and another
based upon the results of the impinfer analysis. The
lower of tbeM two values of B*. sball be considered cor-
rect.
J-3.0 Verification of constant sampling rate. For each
time increment, determine the il'.. CaJculate tbe
average. If the value for any time Increment differs from
the average by more than 1U percent, reject the results
and repeal tbe run.
3. Approj, motion A/rfW
The approTtniation method descn>«ed below Is pre-
Knted only as a suggested method (set Section 121.
3.1 Apparatus.
• 3.1 .1 Probe. Stainless steel or glass tubing, sufficiently
heated to prevent water condensation and equipped
with a filter (either In-staci or heated out-stack) to re-
move paniculate matter. A plug of glass wool, inserted
tnlo tbe end of tbe probe, Is a satisfactory filter.
3.1.2 Impingen. Two midget impingers, each with
30 ml rapacity, or equivalent.
3.1.3 Ice Bath. Container and ice, to aid in condens-
ing moisture In impingers.
3.1.4 Drying Tube. Tube packed with pew or re-
generated A- to 16-mesh indicatin?-tvpe silica gel (or
equivalent dcsicrant), to dry tlie sample ga; and to pro-
tect the meter and pump.
3.1.4 Valve. Needle valve, to regulate the sample gas
flow rate.
3.1.6 Pump. Leak-free, diaphragm type, or equiva-
lent, to pull, tbf gas sample through the train.
3.1.7 Volume meter. Dry gas meicr, sufCcienUy ac-
rurate to measure tbe sample volume within 2%. and
calibrated over the range of now rales and conditions
actually encountered during itamplinf.
3.1.8 Bate Meter. Roiameter, to measure the flow
range from Oto3 I pm (0 to 0.11 crni).
3.1.9 Graduated Cylinder. 25 ml.
3.1.10 Barometer. Mercury, aneroid, or other barom-
eter, as described in Section 2.1.5 above.
3.1.11 Vacuum Gauge. At least 760 mm Eg (30 In.
Bg) gauge, to be used for the sampling leak check.
3.2 Procedure.
3.2.1 Place exactly 5 ml distilled water in e*ch Im-
pinger. Assemble the apparatus without tbe probe as
shown in Figure 4-4. Leak check tbe train by placing a
vacuum gauge at the Inlet to the nrst impingcr and
drawing a vacuum of at least 250 mm Bg (10 In. Bg),
plugging the outlet of the roiametcr, and then turning
on* the pump. Tbe vacuum shall remain constant for at
Mst one minute. Carefully release the vacuum gauge
Ibefbre unplugging tbe rotameter end.
11-50-
-------
HEATED PROBE
SILICA GEL TUBE
RATE METER,
VALVE
~v
MIDGET IMPINGERS
PUMP
Figure 4-4. Moisture-sampling train - approximation method.
LOCATION.
TEST
COMMENTS
DATE
OPERATOR
BAROMETRIC PRESSURE
CLOCK TIME
•
GAS VOLUME THROUGH
METER, (Vm)",
m3 (ft3)
-
RATE METER SETTING
nrVmin. (fvVmin.)
•
j
METER TEMPERATURE.
°C (°F)
•
Figure 4-5. Field moisture determ.ination - approximation method.
II-5T
-------
3.;.; (Vinr.'rt lh» prob*. Invrt It Into the stick. and
Kimi.lo at > cnr:.-..iT.t rue of 21pm (0.071 dio). Comlnu*
ff.lnpline cnul tlie dry fn« mr'.tl rrz:r!en al>out 30
liler? (I.I ft') or until vi>;iile liquid dropim are carried
ore/ from tlif fuvl Impineer lo the »rooud. Kecoid
tr.-rn. ranife, prf.vurr. ar.d dry g=s Dicier readings u
required by Fjjrjre 4-J.
3.2.1 After ci-lleciing the sample, corntlnt the con-
tent j of the t»'o ij5pir.;trj and rorisure Ibe volume to tb«
^l(^rr«T 0.5 ml.
3.3 Calculations. TL^dcul.-.tflon method prfwntedls
dr.ci^npd to r5tirra(e tbe moisture in Ibe nick cu:
th«r/ore, other d>!i, irblch ire only npcc«ary for «a-
cumtF moisture dctrnnlnatipns, »re not -collwrtcd. Tb«
foltovlng f^uaUon* id^qu«l^7 e^limate Tb* mobJuri
eentcnt, tar the pu-'poie ol detennjnlns boUnetic MJH-
plinc rate »ttinf j.
3.3.1 Nomrrr!a!nrt.
B ••" Approxirztte proportion, bT volume, at
vater vapor In the ru strum luring U>«
second Implnpir, 0.025.
B.."-W»i(r rapor tn the {ti slrram, proportion by
A/.
P*
.P,iv
T".i/
(sa- R)
V/ — Final volume of Lmpinper oontfnU. ml,
Vi-«»lruti&J volume of impinper oontenu, ml.
V.-Dry pas Toiume mexmred by dry gw m«t«,
dcm (dcO.
lr«(t(4)HDrr pas volume measured by dry gu meter,
• corrected lo lundard condiuons, dxm
(dscfl.
Vwgc.iwj^Volume ofvater Tapor condensed, corrected
to standard conditions, son (s«f).
..-Density of water. O.WS2 g/ml (0.002201 I
3.3.2 Volume of water vapor collected.
ci.nlrnl.
/—;+<°-025)
Equation i-7
4.1 For the reference method, calibrate equipment as-
fpvcffird iu tbe following sections of Method 5: Ei-CUon 5.1
(mMerinp lysleni); Section 5.5 (tcmff-ratare gauges);
and Section 5.7 fbaro.nr.cr). Tbo rrcoaunrndt-dlfftk
cJbfck of the metering lystezn (Srrtfon 5.8 of Method i)
also applies to thf refcrfnce mclhod. For ibc »pproiiiii»-
tlon method, use the proc^durrs outlined in Srcuon 5.1.1
Of Method 6 to calibrate tbe mrtrrinr 5>strm, a:id Ibe
procedure of Mclbod 5, Section 5.7 10 cnhbrate the
bajomcler.
•Molecular Tffpht of waltr, 13.0'g/s-iDoU 5-
(18.0'b.1b-mole)
• Absolute pressure (for this mctbod, same u
baiomnric pressure) at Ibe dry pas meter.
• StAJidird ah&olule pressure, 760 mm Hg
(29.P2 in. Hg).
• Idfol taa corjrtAnt, O.OC234 (mm Hp) (m1)/
(j-molf) f°K) for metric units a/id 21J15
(in. Ht) (fi^/lb-iDole) <"K) tor English
uniu.
• Absolute Uimpcrature at meter, *K (*R)
' Standard absolute tempcraiur«, 293* K
1. Air Pollution Enifineeriii|t Manual (Si cond Edition).
Danie}son, J. A. (ed.). U.S. EnrtronireJilal Protection
Agency, Office of Air Quality Plaiiniup and Standards.
RewArcb Triangle Pa/*, K.C. 1'ublicanon No. Al'-lO.
1973.
2. Devorkin, Howard, elal. Air Pollution Source Test-
In? Manual. Air Pollution Control Disuia, Lo- Angelea,
Calif. November, 1963.
3. Methods for Determination of Velocity, Volume.
Dust and Mist Content of Gav.v We5iem Precipitation
Division of ;oy Manufacturing Co., Lo! Angeles, Calif.
Bulletin WP-iO. 1968.
Equation 4-5
where:
K,-0.0011T3 nii.'inl for metric units
-O.W
-------
WETBon e—t>tn«mv»T>ON or St'tn i liioin-t
Ziiiaaioxa Fmoai StJUio.Mai Eoi m LS
1- fritfivlt sue1 A rtWicatam
1.1 Principle A fas sample Is eilrvird from the
mmplinj pomi In the stack. Tbe lulluric acid misi
(including sulfur trioiidr) and tbe sulfur dioxide arr
•aparaied. Tbe sulfur dioxide tracuoo u measured by
tbe barium-thorm ntratton method.
1.2 Applicability. Thu method U applicable tor UM
•termination of sulfur dinnde erumons from sutlonary
sources. The minimum detectable limit of toe method
he* been determined to be 3.4 milligrams (ru«i of SOi'm'-
(2,12X10~; 4i>1i>). Although no upper limit has been
t»tablube
Ufh as 10.000 mg'nj' o( bOt can be roUecieO trnclrntlj
in iwo mideet Impingcn, each containing 15 milluiierV
o(3 peroenrhydrogen wronje. al a rale ol 1.0 Ipm for
20 minute;. Based on ibeorrucal calculations Uw upper
•onoeniraiian limit in a JO-Uiei aample is about M tut
BC 'Tli'.
Possible interlvrenu are free ammonia, waler-eoluble
eaiions. and fluoride;. Tbe cations and fluorides are
rtmoveJ br glais cool fillrrs and ac iaopropanol bubbler
•nd hence do not afleci the SOianaUjij. M hen sample
ore being lasrn from a tas stream wnb UiRli conctnira-
ttons o( vary line metallic fumes (such ti In Inlets to
eonirol dericeei, a hich-efncirocy glass nlxr filler mu.*i
be used in plavr ol the gla.v wool plug ti.e.. the one ID
the prol*1 to remove the cation intctleieni?.
Tree anunonia interleirs by rvarting »ith SOj lo form
paniculate sutnie and by re*vtin« with the indicator
If free ammonia u prewnl (this can be determined by
knowledge of the process and noticing white parucuiau
sootier ID tbe probe and leoproi^enol bubble:), alterna-
tive melliods. sul>|m lo the approval '
tor, !].£. Enrironnu-ntal J'rotef-ti
required.
11.10 Volome Metar. Dry n> BMUr, •offidently
atoorat* to measure the aunple Totume within 2 percent,
calibrated at tbe aelwled flow rate and condJtiom
actual) > encountered durint aunpllnf. and equipped
with a temperature faucr (Ola) thermometer, or eqult-
alant) capable ol meuurinf temperature to within
fC (*.«•/).
11.11 Barometer. Mercury, ameroid, or other baron>-
•tar oapabU of measuring atmoiphertc preaaure to within
It mro Bf (0 1 In. HI ). In many ou»s, the baromelrlt:
iwadinf ma>- be obtained from i nearby national w«ainer
•rrioe nation. In which oaw the nation ralue (which
» the absolute barometric pmsure) ihall be rrquejlM
and an adjustment for elevation dlflerenrts between
the weather tutloo and Mmpllni point in all be applixi
aiaraUofmlnusJ.imm Hf (0.1 In. Hi) per JO m (100ft)
aa>T»tlon tncree* or riot Teraa for deration decreaac
11.12 Vacuum Oauf«. At least 760 mm HI (10 In.
H«) ttutr, to be need lor leak check of the aampllnf
train.
12 Sample Raco»«ry.
12.1 Waab bottlea. Polyethylene or flaat, HO ml,
two
12.1 Btoract Bottles Polyethylene, 100 ml, to store
Implnfer aamplei (one per sample).
S.I Analysis.
U.I Pipettes Volumetric type, Mnl, JO-mJ (one per
aunple), and 2Sml ati«9
11.3 Volumetric T laaka. 100-ml lUe (one per aample)
IBd 100-ml tlae.
i-I.I BureUea 5- and SO-ml dies.
14. ( Xrlenmeyer Tlaiks. IbO ml^iu (ooe far each
aampk, blank, and rtarrdard).
U.i Dropping Bottle lli-ml tlte, to add Indicator.
JJ.e Oraduatad Cyllado. lOO-ml die.
11.7 Bpectropbotomvtar . TV meavure abaorbance a.
MI Danameten
11 ftampUm Tb* avmpUoe train U abovn la
*-l, and eomponent paru an dlioiBed below. Toe
ta«ui hu tbi optkio of rotatltatlm auoplint «qup-
m d«cnb*d Ic Method 8 in place ol tbe nud«ei 1m-
ter fqoipmem ol Method 6. Hovrrer. tbe Method 8
ln muT be modin«4 to Include k heated fljier b«twaea
the probe and Isopropanol Lmpuifer, and tbe operation
tt tbe mnpUot tmo and ample inilyms toad be at
Ux flov ma arid aoluuon Tolus«9 defined in Method 8
The tester also n&s the option ol d«tcrmjnjoc 8Oi
Mmult&neou&lv vlth paniculate matur and moisture
4elennjnaiion£ by (1) replacing the vaier In a Method 5
impinfer iTTum «1th I peraat perioiide tolatioQ, or
(f) by repUcun the, Method i water impinctr lyneTT.
with a Method i l*opropaBo!-nlUr-peroilde iytt«m. The
ftoaJyiifl lor SOi mufl n coniistent wILh the prooedore
in Method 8.
LI.] Probe. Borosilicate tlaas, or itainlM »K*1 (gtber
•Mtnnili of oonttruetloo may bt owd, nb)«ct to Ihe
ftpproTal ol tbe A&mininraiar), approiimaiely o-mrn
tndde diamei«r, wltb a b«aan« lystem lo preTem water
eeedeoaatlon aad a filler (either Ln-ttack or boated out-
•teck) to remove panicalate matter, l&dudinc lullunc
•dd mi5t. A plot of (Use wool li a latuiairtory filur.
J.U Bubbler and impintfn. Ooe midget bubbler,
with medliun-coane lias Ml and borotllicau or qoani
Ckus wool packed In top (x* Flfun 4-1) lo pre'ent
add mi*t cajryo'er, and torae Sf>roJ midget
The bubbler and mid«rt lmpln«en moil be
In Kriea with leak -Cm (Us coruxcton. Btli-
aon< trout may be tued. If ou laiary. U prt'tnt le*ka>e.
At tbe option of tbe IsrUr. > mJdf et Implofer may be
IMd In clace of tbe mldcet bubbler.
Othar ccUertloc abxrrben and flow rates may be UMO,
fcot an fub)ect to tb« approra] of tbe Administrator.
A^o, oolierlloo efficiency mu« be ibown to be at leaft
M percent for ea£b left run and mujt b« documented In
tbe report. If tbe efficiency U found to be acceptable after
a teriee of three tesu, further documentation ij not
Twauij»d To conduct the efficiency te«t, an extra ab-
acrber muft be added and analyzed Mparately. Toll
aartn abeorber mur. net ooctaln more than 1 percent el
tki total 80i.
J.1J Qiao Wool. BorwllleaU or qoartt.
1.1 4 Stopcock Oreaje Autone-lnwlubk, kaat-
•table lUloone r«a*e may be u»ed If n«c«aar».
XI i Temperature O»uft Dial tb*rmom«Ur. •
•oolralent to meuure temperatun of fa» Imrtat UB-
mLftr train to within 1* C if 7.)
Drrlnt Tub*. Tub* packed wtth*- to l«-m«ah
tn* «"!«» «''. » wjalTaJeat, to dry tbe n«
T7nlee9 otherwiae Indicated, all raafrnt* muat conform
to tbe ipecinratioru established by tbe Commirtee on
Analytical Reagents of the American Chemical Eociet)
Where such specifications are not available, use the best
arallable grade.
«-l BampUoi.
1.1.1 Water7l>ionlJ«d,a^tmed to conform Ui A STM
apeclnration Dl 195-74, Type >. At tbe option ol the
analyst, the KMjiO. test for oii&iable organic mattfr
may be omitted when high concentrations of orfarui
natter are not elpected to bf present.
1.1.2 laopropanol, 90 perofnt. Mil 80ml of isopropanol
•with 30m) of deiomied djsUUed water. Check each lot of
Itopropanol for peroildf impuriun as follows tbakr 10
ml of isopropanol wltb 10 ml of freshly prepared 10
percent pouj*ium Iodide solution Prepare a blank by
similarly treating 10ml of distilled water After 1 minute,
read the aosorhence al l&j nanometers on a rpectro-
pcolomeler If abaorbance exceeds 0.1, reject alcohol lor
oar
Peroxides may be removed trom isopropanol by redis-
tilling or by panage through a column of activated
ahiirana; however, reagent grade ianpropano! with
Kliably low peroxide level; may be obtained from com-
mercial sources. Rejection of contaminated lots may,
therefore, be a more efficient procedure
1.1.1 fi>droffn Peroxide, 1 Percent. Dilute K percent
hydrogen peroxide 1:» (v/v) with deiomied. distilled
water (M ml Is nwded per aample). Prepare trrjh dally
1.1.4 Potassium Iodide Solution, 10 Percent. PissoKe
10.0 grams XI in deionited, distilled water and dllule to
100 ml. Prepare when needed
1.2 Sample Recovery
1.2.1 Water. Deioniied, distilled, u In 11.1.
1.2.2 Ijopropanol. 80 Percent MJI 80 ml of isopropano!
with 2(1 ml of delonlud. dlsdu>d water
IJ Analysis
Ml Waler. Delonlted, distilled, as In 3.1.1.
UJ Isopropanol, 100 percent
1.1.1 Thortn Indicator l-(o-ar»nopbenylazo)-:-
napblbo)-3,6-dJ5ul(onic acid, disodium salt, or equjva-
sant Dissolve OJO g In 100 ml of dekmited, dl5tiUed
mtar
IJ4 Barium ParchloraU Solution, 00100 K. Dis-
a»rvi 1 »S f of barium percnloraw trlhTdrate IBairiO.li
IHiOl In 200 ml djstilied water and dlluu to 1 liur wlih
topropanol Alternatively. I 22 g of |B«Clr2H,01 ma>
be osed insleed of tee parcbiorate Standardue w In
•ample and to protect tie meter and pump. U Uw dliac
JJl bai been uA prevloujlj. dry « Hi* C («OT 7) Jor
J houn. Ne* iUi=» jeJ maj be used as received. AJlema-
BTely other type* of desircanu (MUiralejit or better)
maTbeoaeiJ fuolect lo approTalof Ihe Administrator.
1.1.7 Value, Keedle ralue, to reattl»!« aampk fai flow
**li.8 Pnmp. l^ak-lree diiphrafm pomp, or equiT-
al«t to poll C»» tbroufb tbe train. ln«*U i unal) tank
between the pump and rale metei to eliminate the
notation ^e^ °' l" *»Por>«™ P<"OP »° th« rotameter.
^t\» Rate Meter. Rotajueier, or eqol»al«nt, capable
ft meaaurlnf flor rate to within J percent et UK aelected
low rale of about 1000 oe/mln.
11-5 Sulrurlc Acid Standard, 0 0100 N. Purchase or
itandardlie lo «0 0005 N a»*ln« 0.0100 N NaOH which
has previously been standardlted against potassium
add phthalate (primary standard grade).
4. Pnctiw
4.1 Sampling.
4.1.1 Preparation of collection train. Measure 15 ml o<
M percent uopropanol Into the rn^ltet bubbler and li
ml of 3 percent hydrogen perotlde into each of the first
two m)d«ft Implngerj Leave the final midget implrwer
dry Assemble the train as jho»-n In Figure 6-1 Adjust
probe healer to a temperature nuTicient to prevent veter
oonderjatloa. Pkca cruibed ice and water around UM
imping en.
4 1 1 Leak-cbeck procedure A leak chert prior to the
sampUnf run it optional however, a leak rherk a/ler the
aampllng run l> mandatory Tbe teak-check procedure is
as follows
Wltb the probe divonnerted. place a vacuum rattfe at
tbe Inlet to Ihe bubbler and pull i vacuum ol 230 mm
(10 In ) Hg. plug or pinch off Ihe outlet of tbe flow meter,
and then turn oft the pump The vacuum shall remain
stable lor at least K seconds Carefully release the
vacuum game before-releasing tbe flow meter end to
prevent bark flow of lift Impinge/ fluid
Other leak check procedures may be used, subject to
tbe approval of tbe Administrator. U 8 Environmental
Protection Atencj The procedure used In Method 5 is
not suitable lor diaohcagm pump>
4 1 3 Sample collecHon Record the Initial dry gw
meter reading and barometric pressure To begin sam-
pling, position the tip o' the probe al the sampling point,
connect the probe to the bubbler, and start the piimp
Adjust the aample flow to a constant rate of ap*
proiimately 1 0 hter'mln ei Indicated by tbe rotameter
Maintain this constant rate («10 percent) during the
entire sampling run Take reading? (dry gas meter.
temperatures at dry gas meter and at Implnxer outlet
and rale meter) at Vast every i minutes Add more loe
during the run to keep the temperature of tbe gases
leaving the last Implnger at 20* C if T) or less At the
conclusion of each run. turn off the pump, remove probe
from tbe
-------
5.2 Ttormomeun. Calibrate
flaji thermometers.
t.l Rotameter. The rotaiaeler n»d not be calibrated
but ibould be cleaned and malataloed acooniUx to UM
aanuiactunr'i innrucUon.
1.4 Barometer Calibrate afainit a mercury barom-
eter.
tJ Barium Percblorate Solution. Standard! i» UM
barium perehlonte lolction afiioJt Z3 ml of nandard
nlfuric acid to vhlcb 100 ml at 100 pvoeat laopropanol
hat beau added.
Carry oat calculation!, retaining it lean one extra
decimal flmnJxrond ibal of the »c^uir»d du&. Kaacd
4.1 NoiD«)claturi.
eomeud to
06/dscn.
of nUur dJaildc. drr bMii
oondltlotu, mc/d«an
of tmrlarn p»rctilor»« Utrvit,
it tb« exit ortfloe of U»
dry ru meter, nun U| (In. Hf).
/•, j - 8lind»rd «b«oluie preuun, 7W mm Hf
(S.Kin. HI).
T.-ATenft dry r»» m«>«r «b«oluu umpentan,
•K CR).
T«j-8l»ndxrd tbaolatt tcapennm, «O* X
«a' R).
V,- Volume of ample ill q not turned, ml.
V.»Drr 01 Tolnme u sauand br tb* dry (••
. dem (drf».
fat Tolume meamnrl by the dry tai
grrected to rtandard condition!,
_ I volume of BloUon In which tb« foUar
dioxide aunple li contained. 100 ml.
Vi-Volume of barium perchlor»i» tltrant oaed
tor the lample, ml (arenfe of replicate
Utrmttoni).
V,.-Volume of barium parehlorau Utrant nted
for the blank, ml.
y-Dry tu meter callbrallon factor.
B.03- Equi'iJent writ hi of fullur dioxide.
a i Dry eample (at Tolume, oorrected to
condition!.
Tm
JT,-0 «M 'frnjE Bf fcr iMtrtc nnJu.
.17.WR/ln. H« lor EndUb on
M Suitor dioxide eonotctntlon.
•Kt
(V,-V,t)
'mtu41
Xqattlon «-l
uvi r
ITi-E 03 mc/meq. far metric unlu
-7.0»lX10-« Ib/meq. lor Xotllili uniu.
7.
1. Atmnpherte Etnlmlora from Solfurlc Add Mann-
hetortnf rroma*. U.B. DHEW. PH8. Dlrlalon of Air
Pollution Public Health fterrlot Publleatlon No.
m-AP-13. Cincinnati, Ohio. IMi.
J. Corbett, P. T. The Domination of SOi and 8Oi
In Plat Oatea. Journal of th* IrutlluUof rnel.AC ZP-
MJ. 1M1.
J. Malty, R. E. and E. K Dlehl. Meuurint Flue-Oai
BOt and 9Ov POTO. 101: M-CT. NoTembrr IM7.
4. Patton, W. p. and J. A. Brink. Jr. Nrv Equipment
aad Tecbnlqon lor 8«jbpUnt Chemical Proem Gaaes
J. Air Pollution Control-AjtociatIon 13: 182. 1963.
V Rom. J. J. Maintenance. Calibration, and Oprntlon
t< I«okinctie Source-Stapling E.nulpment. OfBot of
Air Prommi, EnrliiMimental Protection Afrney.
linircb TrUnfle Parr, N.C. APTD-Q6?t. Marcb \vn.
1 Hamll, H. P. and D. K. Camann. ColUborvIre
Stndy of Method for the Determination of Sulfur Dloilde
Xmteloru (rom Stationary Sourca (Fomll-Fuel Plred
Blrmm Oeneralorj). EnTlronrrjental Proteerlor Afency,
Keaearcb Trtanxk Park. N.C. I PA-&SO/4-74-034.
D«OBmber 1973.
7. Annual Book of A8TM Standard*. Part 31, Watar.
Almaphenc Analyrli. Amencan Society lor TesUai
aud Maunali. Philadelphia. Pi. 1V74. pp. 40-U
I. Knoll, J. E. and M. R. Midiett. The Application of
CPA Method 6 to Hub Sulfur Dlonde Conaemnuoni.
Enrlronmanul Protection Afeacy. ReMarcb Tnaofle
Park, N.C. EPA-400/t-Tt-OH. July 1978.
THERMOMETER
PROBE (END PACKED'
WITH QUARTZ OR
PYREX WOOL)
J*\
STACK WALL
MIDGET IMPINGERS
MIDGET BUBBLER
GLASS WOOL
SILICA GEL
DRYING TUBE
ICE BATH
THERMOMETER
NEEDLE VALVE
PUMP
Figure 6-1. SOj sampling-train.
SURGE TANK
11-54
-------
Mrr»oB r—DmucDunoif or Nmoor* Orn>i
'"••OKI 7ao« (jTinoKiiT BotradJ
1. frteapk .W ^ppli—i.ai.r
_L? -pl'iBclpl«. A n»b "unple l» collected In an ev»eo-
<•««»»» ooo t«J nine a dilute BiUuric aci<»-bydrof«o
iwrr«» 1>M bean determined
to b» 3 M400mllllcT»mi NO, (a» NO.) per dry rtandari
«*>* , Without harlDf to dllaU tijT—mpL.
EE£
J.I B*.Tt>!'-.| (t* rirure 7-1). Other p»b aunpUnf
rf»Umi or equipment, capable of measurtni sampie
volume to w4thin ±AO peraot and ooUeeUnt > sufficient
maple Torame to allow analytic*! reproduclblllty to
»1Uun ±4 p«reent, wll) b» coaHderxJ acnpublt alter-
B«IT«, »ub>ct to appr»T»l of tb« Admlniivralor, U.S.
KaTUnamenUI ProttcUoo AjraacT. Tb«
•qolpm*ot U oaed In lampUuf:
tl.l Probe. Boro*llic*l* (!&• tabUic. luctor
M»t«a to preTact vater corvdftoaaUoo and vquipped
»1tb an U>-«tack or ooujt»ck OJtar to remore partlciuaU
unor (a plu« of flus wool U »tli(actor7 fw tail
porpoK). StAuOca iu«l or TiOoo ' tubioj ma? also be
oa»d lor the probe BaaOot U Dot Daoaavr U th. prob*
remain* dry doriof U» pdrrinj period.
> Uaotloii of trvl< namei or ipaeifle pradoetj d«a oo4
aodonunant br th« XoTiroaa>aat*J Pn-
tlJ CaUKtloe rtaak Tvo-lltv boratlicau. roasd
bettom (huk, with ihon ncrk and 24/40 rundard Uper
•pnUot, protfrtrd acaiiut Implosion or broaiwe.
1.1.3 Fluk Val'r T-bon iMpcoct oonoecKd to a
M/40 lUndjird Uptr lolnt
1.1.4 Temprratun Oauft. Dtal-type tbermoniftcr, or
olbfr umppniurv ptttff. capable of Tnramrlnt 1* C
ITT) interrals from -i to WTC (26 to I2i° F). .
S.1.S Vacuum Lint Tub Ira capeblr of wltbnandinc
» TVCUUID of 76 mm Hj (3 ID Be) abtolutt pnaiurt, with
*^" ooQnecuoo and T-bort itopcock.
3.1.6 Vacuud Oauff. U-tub« manometer. 1 mei«r
(X In-), with 1-mm (0.1-ln.) dirulou. at olher
• pablr of nMaiurioi prenun to wltblD ±J.S mni
(8.10 in. Hjl
' 1.1.T Pump Capable of • radiating the eoUectioo
fluk to a PTOBUIT aqoal to or lev <^»" 75 "^^ He (3 In.
Bt) absolute.
2.1.8 Squfctf Bulb. Ooe-Tay.
11.9 Volumetric Plpetu. is ml
LI.10 Stopcock and Ground Joint Qreaw A bifh-
vacuum, tuin-umperatore chlorofluorccarboc prwr li
raqnired. HijocarbonZW6 hat b»»nfound lobe«flectl»e.
1.1.11 Barometer. Mercury, aneroid, or other barom-
•to- capable ot measurLnf atmcepheric pressure to wltbln
2.5 mm Hf (0.1 In. U;). ID man> cawj. tne barometric
ratdiof may be obtained Irorc t oca/by oaUonaJ weaibcr
•arrice su'.ion. In which cue tbe nation value (wbJcti Ij
the absolute barometnc prenurp) ihall be requested and
ac adJustmeDt for elevation dlfTerencea betvKD tbe
weather station and sampling point Bhall be applied at a
rate of minus 2.5 mm He 10.1 in. Hgj per M DI (100 ft)
•levatioD increase, or vice vena for elevation decrease
2.2 £vnpl> Recovery. Tbe folloTioc equipment b
rwaolred for »ample recovery
1-21 Oradu»t»d Cylinder. 40 ml with l-ml dlrUlonj.
2JU Sloraft Cootalners. Leak tne polyetbvlene
bottles.
t.2.1 Wa«h Bottle Polv«tby)eB» or flav
1.24 Ola«5 gurrirn Rod.
L2.5 Ten Piper (or Indjoatlof pB. To eovar Lbe pB
ute of 7 tn 14.
JJ Analviit. Tor the. anaJntj. the Mtow1n( eqolp-
t-1.1 Volumetrtf PlpetM* Two 1 ml, two 2 ml. one
t ml, one 4 ml. two 10 ml. aod one 2ft ml tor each «ampl'
and tuodvd
U.2 Poratalo Znporadnt Dlaba 176- to 2&0-mj
•apacltf with lip for Dourto«. one foi each «ample and
•acb »t»ndard. the Coon No. 4i006 (ihallow-fonE . 194
Bl) hat been feond fartor> Xllernattvely,
polyniethyl pentene bemien (Nail- No. 1203. 150 ml), or
(U« beakm (150 ml) jnay be tued. Wben |lau beaken
•re used, elchjni of tbe beakers may cause solid matter
to be present In tbe arfHyUcal (Uo. tbe tolldj ibould be
maoved byflltrailon (Mt Section 4.3).
2.^ -1 Steam Bath. Low-temperature ovens or tbermo-
ataucally fontrolled bot plates kept below 70* C (1«0° T)
air accepubl.1 alternatives.
U 4 Dropping Pipette or Dropper. Three required
2J 5 Polyethylene PoUorrnan. One for eacb aunple
aod each itandard
2.J 6 Or»duated CrUnder. 100ml with 1-mldivljlonj.
2.3.7 Volumetric Flaskt. 50 mJ (one foi each »anipl»).
KM ml (one for each sample and earb itandard. >nd one
tar tbe workinc standard KNOi aolutlonj, and 1000 ml
(one)
2.a.g Spec&opbotoEDete?. To maaffure abaorbance at
410 run.
2.1.0 Graduated Plprtu 10 ml with 0.1-tnl divisions.
2.1.10 Ten Paper (or IndloatirK pH To cover iht
pE rant e o( 7 to M
?J.1J Analytical BaJaooe. To meann U within 0.1
me
EVACUATE
PROBE
\
PURGE
x_x
FLASK VALVE\ ff} SAMPLE
r
FILTER
GftOUND-GLASS SOCWTT.
§ NO- 12/6
110 nm
STOPCCX:ilr
T-BORE. i PTREX.
2-mm BOR£. 8-mm OO
FLASK
FLASK SHIELD^.\
SQUEEZE BULB
IMP VALVE
PUMP
THERMOMETER
CONE
GROUND-GLASS
STANDARD TAPER.
SLEEVE NO. 24/40
210 mm
GftOUND-GLASS
SOCKET. § NO. U/5
PYREX
•FOAM ENCASEMENT
BOILING FLASK •
2-LITER. ROUND-BOTTOM. SHORT NECK.
WITH | SLEEVE. NO. 24/40
Figure 7-1. Sampling train, flask valve, and flask.
11-55
-------
Unless otherwts* Indicated. It Is Intended that all
nejfnu conforni to tbe specifications established by the
Committee on Analytical Raajentj of tbe American
Chemical Society, where such specifications are avail
able, otherm-tie. use the b»l ivallablf (rede.
1*1 Sampling To prepare tbr absorbing solution,
•aotlously add 2.S ml concentrated HiSO. d 1 liter of
waloniied, distilled water. Mil well and add « ml of I
percent hydrogen peroxld'. freshly prepared from K
parent hydrogen peroildc solution The absorbing
solution ibould bf u»Ki wiihln 1 »'eek of lu preparation.
Do not eipose u> extreme heat or dirert sunlight
t-2 Bamplr Recovery. Two raag&nu are raqulnd fat
avmple recovery:
ail Scaium Hydroxide ON). DKeoIvs 40 g NaOH
IB delotuaea, distilled water and cSluu to 1 liter
aJ.2 Wiier Delonlaed. distilled to conform u AETM
ayaclDeatloo OU0-74. Type i. At tbe option ol the
analyst. th« rXNO. U*t for oxldiiable orraolc matur
nay be aalru>d when tilth eoDccntraUotu of er|*alc
matte are not upecttd U> be praenl.
1.3 Aoalysii. for the aoalyus, tbe following raafenu
an raquired
HI Fumlnf BtiUuric Acid. IS to 18 percent by w«l|ht
Cnr sulfur trionde HANDLE WITH CAUTION.
14.3 Phenol Whiu Kbd
14.J Bulrunc Acid Concentrated. V> percent mini.
•ma assay. HANDLE WITH CAUTION.
» J 4 Potassium Nitrate Dned at IDS to 110° C (T3C
U 230C F) for t minimum of 2 hours lust prior u prepart
tton of nandard solution.
1-J.5 Standard KNOi Bolutloo Ditsoln aiactly
L196 ( of dried potassium nitrate (KNOi) in deionited.
diitllle^ Tater and dilute to 1 liter with deiomud.
diibllL^ -rater in a 1,000-ail Tolumeirie flask
1.S8 Wortinz Staodard ENOi Solution Dilate 10
•H of w t standard solution to 100 mJ with deioniud
dlstilW ir»tei One mllliliter of the wortiot ilandard
•oluuon U equivalent to 100 «f nitrogen dloiide (N Oil
1.3.7 Water. Deionited, distilled as to Section J.:.:
» JJ Phenoldi5Ulforuc Acid Solution. Dissolve U |
af pure wait* phenol In 150 ml concentrated suUuric
add on a neam bath Cool, add 75 ml fuminc sulfuric
•eld, aod beat at 100° C (217° F) for 2 boon Sure In
• dart, stoppered botUe.
4. Pnctdura
4.1 Sampling.
4.1.1 Pipette 25 ml of absorbing solution Into a aimple
flask, retaining • sufficient quantity for ii» in prepartnf
tbe calibration standards Insert tbe flask rllrf stopper
mto tbe flask witb the TaJre In the "purfe" position
Assemble tbe aimpltnc train as shovri In Figure 7'1
and place the probe at the sampling point Ualcf sure
that all ntunrs are ti(bt and leak-free, and thai all
(round flas Jcinu have been properly freased with a
klth-raruum, hlth-lernperature chlorofliiorocarbon-
ttopcock (reax Turn -tbe fiask nlve and tbe
Pomp nice to their "•nruatr" positions TTacuate
the flask to 75 mm Hj (3 in HI) absolute pnsurf. or
laav £racuation to a praaurt apprriarhinc the Tapor
pr«sure of water at tbe ousting temperature is desirable
Turn the pump ralve to Its "vent" position and turn
aC th« pump Check for latkatr by obMrrint tbe ma-
aoouUr far aoy prusure fluctuation (**y Taruti^n
greater than 10 mm R| (0.4 lo Hi) orar a p&nod of
1 minute U not araeptab^, and the fla and-nlve (V/), the nask Umpenture (T,),
and the barometric pressure Turn the flask -ralte
ooonterdockwue to Its "purge" position and do the
aame with the pump ralve. Purre the probe and tbe
Tteuum tube uslnc tbe aqueete bulb If conderuation
occurs In the probe and the flask valve area, beat the
probe and purfe until tbe condensation disappears
Nart, turn tbe pump »al»e to lu "tent" position Turn
tbe nask rvl^f dottrrue to lu "eTaruate position and
record the difference in the mercury levels in tbe znanoro-
•ter. Tbe absolute internal pressure In the flask (P.)
b equal to tbe barometric pre&sure leis tbe manometer
readlni Ircmedialely turn tbe flask valve to tb< "aam-
ple" position and prmit the (as to enter the flask until
pressures in the flaoiide (1 N), dropwue
(about 25 to IS drops) Check the pH by dipping a
•tlrrinx rod into the aolutlon and then touching tbe rod
to the pR t&st paper. Ramove as Uttle maurlal as possible
tfurlnf this tup Uark the height of the liquid level K
that tbe container can be checked for leakage after
traojpon Label the container to clearly Identify lu
contents Seal tbe container for ihlpptcg
4J Analrsls Note the level of tbe liquid In container
acd confirm vbether or not any aample was loel during
afclpment; note this on the analytical data sheet. II a
noticeable amount of leakagr has occurred, either void
tbe sample or use methods, »un)ect to tbe approval of
tbe Administrator, to correct tbe final mulls. Immedi-
ately prior to analysis, transfer the contents of tbe
ablpping container to a £O-ml volumetric flask, and
rinae tbe container twice with 4-ml portions of deionittd,
distuied water. Add tbe rime water to tbe flask and
dilute to tbe mark with deionited. distilled water; mil
thoroughly. Pipette • ZVmJ aliquot into tbe procelaln
mporating dish. Return any unused portion of the
•ample to the polyethylene itorafe bottle Evaporate
the 25>ml aliquot to dryneas on a tuaro bath and allow
to aool Add 2 ml pheooldisulfooic acid aolution lo the
dried residue and tnturale thoroughly with a povlethyl-
ao« policeman. Make lure the solution contacts all the
racdut. Add. 1 ml deionited. distilled water and four
drops of concentrated sulfunc acid. Heat the aolution
oc a rteam batb for 3 minutes with occasional stirrtni
Allow the solution to cool, add X ml deiotuud. distilled
water, mil well by nirring, and add concentrated am-
Booium bydroriae, dropwise, with constant itlrrtng,
ontil the pH U 10 (at determined by pH paper). If the
aample contains aolids, these musl be ramoved by
nhnrjoo (centnfugation U an acceptable alternative,
•object to the approval of tbe Administrator), as follows
filter through Whatman No. 41 filter paper Into a 10t>ml
volumetric flask, nnv the evaporating dish with three
*-m) portions of deioaited, distilled water, filter these
three rinses. Wafh the filter with at least three IVml
portions of deionited. distilled water Add the filter
washing! to the contents of the volumetric flask and
dilute to the mark with deionited, distilled water. If
•olids are absent, tbe solution can be transferred directly
to tbe 100.ml volumetric flask and diluted to the mark
wiib deionited. distilled water. XUj the contents of the
Balk thoroughly and measure tbe abaorbance at the
optimum wavelength ua*d for tbe standards (Section
5.2. 1), using the blank solution as a ttro reference. Dilute
the sample and the blank with equal volumes of dcion-
laed, distilled water If the absorbance exceeds /C. the
abaorbance of tbe 400 *« N Oi nandard (aee Section i-2-2) .
11 Flask Volume Tbe volume of the collection flasl-
•aak valve combination musl be known prior v> aun-
pling Aatemble tbe flask and flask valve and fill will
water, lo the tlopoock Measure the volume of water to
±10 ml Record this volume on tbe flask.
1.2 Speclropbolometcr Calibration.
ft.2.1 Optimum Wavelength Determination. For both
fised and variable wavelength ipectrophotoiDeters.
calibrate against standard certified wavelength of 410
nm. every 8 months Alternatively, for variable wave
length tpeclropbotomeirrs. aran the ipectrum between
400 and 412 nm using a 20Ti *g NOi standard aolution (aee
Section 4.J.2). If a peak does not occur, tbe ipectropho-
tomeler ls probably malfunctioning, and should be re-
paired. When a peak Is obtained within the 400 to 416 nm
nuige, the w»7elen?th at which this peak occurs shall be
the optimum wavelength for the measurement ot ab-
sorbance for both the standards and samples.
12.2 Determination of Ep-ctrophotomelei Callbn
Bon Factor K,. Add 0.0. 1.0. 2.0, J.O. aod 4.0 ml of tbe
ENOi working standard solution (I ml -100 «t NOi) to
• aeries of five porcelain evaporating dishes. To each, add
M ml ft/ absorbing notation. 10 ml deionited, distilled
water, and sodium bydroiide (IN), dropwise, until the
pB Is belween t and 12 (about~2S to 15 drops each)
BepinninK with the evaporation step, follow the analy-
sis procedure of Section 4.S. until the lolution has be»n
fransfexred to the 100 ml volumetric flask and diluted lo
tbe mark Measure the absorbancr of «ec b solu lion . at the
optimum wtvtlength, as determined In Section >2.1.
This calibration procedure must be repeated on each day
that samples ar» analy ted Calculate the spectrophotom-
eler calibraUon factor as follow].
K ion i
' w
' Equation 7-1
wfeart:
JT. -Call bradoB factor
Xi-Absorbance of the lOO-* NOi ttaadard
Xi-Abwrbance of the 200-)« NOi itandard
X^Absorbanceoftht KOvC NOi itandard
X.-AUorbance of the 400-ng NOi standard
i.l Barometer. Callbrau acalnst a mercury barom-
eter.
»4 Tamperature Oaugr Calibrate dial thermam< -er»
ajaJrul mercury-ia-f taat thensomeun.
11-56
».S Veemini Oeugr Calibrate mechanical gauges, II
oaed, against t mercury manometer web M that speci-
fied lo 2.1.«.
4.8 Analytical Balance. Calibrate against itandard
•alfbts.
Carry rat thf calculations. retaining it least onr ertra
decimal figure beyond tbti of tb« acquired data. Round
00 figures after fin*] calculations.
e.1 Nomenclature ,
X-AbMrbanc" of sample
C"Concentra'iorfOf NO( as HOi, dry basis. cor-
net^ to standard conditions, ing/djcm
(Ib/dscf)
/••Dilution factor (I e., B/i, 2110, etc., required
only II serDplfdllullon vas needed to redoce
the absorbanre^lnio thf rarne of calibration)
Jif, — 8p*rtropholomeier calibration factor
• •Hiss of NO, as NOi In (as sample. »t
/•/"Final absolute pressure of flask. mm Hf (in HI)
^-Initial absolute pressure of flask, mm Hi (In
He)
/•«<- Standard ibeolotf pnawre, 780 ram Hg (29 97 in
He)
TV-Final absolute temperature of flask ,'K PR)
Ti- Initial absolute temperature o( flask °K <°R).
r.u- Standard absolute temperature. 293° E (128* R)
t'.,- Sample volume at ilandard conditions (dry
basis). ml
V/»Volume or flask and Wve. ml
Vt«Volume of absorbing solution. 26 ml
2-60 24 the auquol factor. (If other than a 2&-inl
eliouol wa* used for analysi-, Ibf correspond-
Ins factor roust he substituted)
t.2 Sample volume, dry bajis, corrected to ctandard
conditions
where-
A", = 0.3858
-17.W
°K
mm Hg
•R
Equation 7-2
for metric units
in. Hg
6.1 Total ft NOi per ample.
for English units
Equation 7-3
HoTX.—Mother than a 24-ml aliquot is used for enely-
ali, tbe factor 2 must be replaced by a oorrMponding
tector.
1.4 Sample concentration, Arj bull, eometed to
standard conditions.
C-K,
Equation 7-4
,-IV —8/^ for metric unite
jig/ml
-6.243X10-
for English units
7.
1. Standard Methods of Chemical Analysis. 6th ad
Naw York, D. Vna Nostraad Co., Inc. 1862. Vol. 1,
p. I2»-330.
1. Standard Method of Test for Oildes of Nitrogen In
Gaseous Combustion Products (PhenoidisuUonic Arid
Procedure). In. 196S Book of ASTM Standards, PartSC
Philadelphia, Pa. 1S«. ASTM Designation D-1W6-M.
p. Tli-72«.
1. Jacob, U. B. Tbe Chemical Analysis of Air Pollut-
ants. New York. Lnlenclence Publishers, Inc. I960.
Vol. 10, p. 151-156.
4. Beany, R. L-, L. B, Berger, and H. H. Schrenk.
Determination of Oildes of Nltrof f n by tbe Phenoldusul-
(onlc Acid Method Bureau of Mines, U.S. Dept. of
Interior. R. I. J6S7. February W3.
». Hamll. H. F. and D. K. Camann. Collaborative
Btudy of Method for the Determination of Nitrogen
Oxide Emissions from Stationary Sources (Fossil Fuel-
Tired Steam Generators). Southwest Research Institute
report for Environmental Protection Agency. Research
Triangle Park. N.C. October i, 1S73.
«. Hamll. H. F. and R. E. Thomas. Collaborative
Btudy of Method for the Dnermlnation of Nitrogen
Oxide Emission* from Stationary Sources (Nitric Acid
Plants). Southwest Research Institute report lor En-
vironmental Protection Agrocv. Research Triangle
Park. N.C. May a. 1»74.
-------
MlTHOD »— DtTHMIMiTIOh Of BTJUTUC AOD Mill
AND SuLnil DlOIlDl IHUBIOMI TICK 8tiT10Ni«T
&OUICU
I. Principle «
1.1 Piiucipir A ;u sample- 11 titrated boklne/ltolly
IroiE ihe >iaci.. The sulfunc acid mist (Including nillur
trioiidc) and the sulfur diotide ire separated. mil boib
tractioru are measured separately by lb« bariiuu-lhano.
Utntion method.
1.2 Applicability. This method is applicable. (or tbe
determination ol sulfuric acid nuit (indudJnf niltur
trtoncje, and in th< absence, of other paniculate matter)
and sulfur diotlde emissions Irom stationary sourne *
Cotlaborvtvt tests have shown that the minimum
delectable hyiiu of thf meihcxj are 0 OS miluimmvcubK
meter (003> 10-' noundvcubic toot) (or lullur irloiid*
»nd l.J mt/ti^ (0.74 10-' ll> ll'l tor sullur dioildt. No
upprr limiu-h«»« b«n fl»bli-hod Ui»d on ihcorttlcal
calcuUnoru lur 'AX) miUilncrs ol 3 percent hydrocca
ptroude «o^uion, th« upper concenmtion limit lor
lullur dicnde HI > 1 u m' (36 1 (t>) (u iunple u tboul
1J.400 mr'm' (7.7X10-1 llrlii). The upper limit c»n be
eitf ndf d by MicrfSdinc th« iiu«ntily a/ pvroiide solulioc
to trie impu^en.
Possiblf intcrfvnnc t(ents of this method ir« fluondu,
free fcmmomt. ftnd dimethyl tniUne. If tny of th»e
interfering »^pi.i.3 ire prfsrnt (this cmn be determined by
knowledge of the process), tlterriAliTe methods, subject
to the. approve ot the AdoiliUitrtiw, wt required.
Filler.ble ptnlcuUte matter nur r« determined tlnitt
with SOi >nd 30t Uublei't lo Ihe ippro»il ol the Aa-
nJnliinttor): hovever, toe procedure tued lor purlculAU
Butter must be coiuintnt with the ipnlArt>Uoni uid
procedures fl»eD In Utlhod 5
2.1 Sampllnf. A ichem«Uc of the suopUnf mln
turd la this m.'thod li ihovn In Tiriire S-l. It 13 ilmjuu
to the Method 5 Irnlti cirrpt that the. fllier rx^lQon b
dUforenl tnd Ihe niter holdi T da-5 not have lo be hulexi.
Comrnprrlal ni^Jels of this train are available For tboae.
who desire lo build their own. however, complete, con-
' Itrtli'llon drlallj a/r Ji-krllx-O In A1'T[)A>I Chanid
from the AI'TU^i'iHI dmunifnt inj allowAl-U* modi-
Acailoiu to Fliiurt I- 1 art dixutonl In the followlnf
'i U Pilot Tube Sane ai Method S. SocUon 2.1.3.
11.4 Dlfl«r»nU«l Prtssiart 0«nf S»n>« M M el bod 8.
Tlir orjernlhif and maintenance procrdurej for lh«
iuii|illn( train uu«r la lni(Kjrtant In obliUidnK valid results, ait user*
ihouM ii-ud Ihu ArTP4r,7« ilwurr., in and adupl Ibe
opcrailnit and mainiriuincr pruL'i-Uurcs outlined In It,
unless otlierwlb^ s^'rified hcri-in Funhu JeLalb and
ruhlrllnr^ on OIMTUIIOII And niainli'nance arc riven In
M-thod 5 and should ta read and lolluwrd whenever
they aru ap|)lirahle.
; 1 1 ProU Nuulc. Same as Method i. Section 3.1.1.
2 I..1 l'rolM^ l^nrr. UoroaJllcklrt or i|uanj f lax>, vllh a
heatlnjt syslcro to iirevtnt vl»ll>lf cond**iu*uon durtn(
smmpUng. Do not uae mclai probe linen.
Holdsr Boro«lllc«l» flrna, »lth » «la*
bit tUter support and a illlcone rubber (islet Otber
•wket mat/ilals, «.«., Teflon or Vlton, may be n»d iub-
tl t« the appro»al of the Admlnlsu»tor. The holder
Stilt) iball proTlda a po>IU» a-al acalnit leataie from
tbe ouulde or wound In Tliuir t-\. The
tnt and third ihall be-of tbe OrMnhurt-Smlih rlealfn
with lundftrd Upi Ta» ncond and fourth in»U be. of
(be Or»enban-8mlth dWl^n, modlAed by replarlni the
Insert with an approilmately II mllllmeier (OJ IrL) ID
flaw lube harlnt an uncorurlrlried tip located 13 mm
(O.S In ) from the, bottom ol the fuul Similar collection
ryvtema, which oa^« b«en approved by the Adjulolj.
trator. nur be wed
J 1.7 Wetenoi BrrUm. Same u Metbcx] i. Section
tl.t.
1.1 i Barometer. Same M Method i Section 3.1.9.
US Oa.< Density Dettrmloalloo Equipment. Bane
M Method 5. Bwtlon 2.1.10.
1.1.10 Te,mp«r«turt Oauce. Thermometer or «qulT»-
ktnt, to met.uLr« tbe lemperaturf o< Uie f u icarlnc tbe
iBploter tnJn to wlthlc 1* C (7 T}.
1.2 temple Recovery.
PROBE
7
REVERSE TYPE
PITOT TUBE
TEMPERATURE SENSOR
PROBE
HTOTTUBE
TEMPERATURE SENSOR
THERMOMETtR
FILTER HOLDER
,CHECK
VALVE
ICE BATH IMPINGERS
BY-PASS VAWt
VACUUM
LINE
VACUUM
GAUGE
MAIN VALVE
DRY TEST METER
Figure 8-1. Sulfuric acid mist sampling train.
11-57
-------
Nor*.—II moisture oooUol Is Vc b« determined by
Imping tr analysis, weigh tech of the Am three Implnfcn
(plus absorblngsolutlon) to the nearest 0.5 | and record
these weights. The weight of the silica col (or silica gel
plus container) mult also be determined U> U» merest
0_i | »au iwoixled.
4.1.4 Pretest Leek-Check Procedure. Fallow the
basic procedure outlined In Method 6. Section 4.1.4.1.
noting that th* probe heater shell be adjusted to the
•ninlnvir" temperature required to prevent condensa-
tion, end also lh»t verbege >uch as. pliurmi to*
Inlet to toe Alter bolder • • V shell be replaced by,
"• • • plugtlng the Inlet to the first Impinger • • V"
Tfce pretest leal-check is optional.
4.1J Trelrr^OpentloD. Follow the basic procedures
eotlioed In Method 5. Section 4.1-5, In oorUunction with
UM sallowing special Instructions. Data shell be raeorded
•a a sbeet similar Co lb« one In Tigurs *-l- The sampling
rale shall not noted 0.090 m'/mln (1.0 ctm) during the
ran. Periodically during th« test, observe toe coor»ecting
Una between The probe end Ant Implnger foe signs at
condensation. If It does occur. adjust the probe bun*
•siting upward to the minimum temperature required
to prevent condensation. If component changes become
Maeaary durlni > run, e leak-check shell bt done Im-
mediately before each change, According to the procedure
outlined In Section 4.1.4J of Method 5 (with appropriate
BodtAcalloos. u mentioned la Section 4.1.4 of tali
method); record ill leek rales. If the leakage rele<»)
exceed the specified rate, tbt tester thill either Told the
ran or shell plan to correct the sample volume u out-
lined in Section 83 ol Method 5. Immediately after com-
ponent changes, leek-checks an optional. U then
leak-check) an done, the procedure outlined la Section
4.1.4.1 of Method 5 (with appropriate modifications)
•ball be used.
AAer turning off the pomp aod recording the final
readings at the conclusion of each ran, remove the probe
from the stack. Conduct t pott-test (mandatory) leak-
check BJ ir. Section 4.1.4.3 of Method 5 (with appropriate
modification) and record the leak rate. If the post-test
leakage rate eiceeds the specified acceptable rate, the
tester shall either correct the sample volume, as outlined
la Section 6 J of Method 5. or shall void the run.
Drain the ice bath and. with the probe disconnected.
purge the remaining part of the train, by drawing clean
ambient air through the system for li minutes at the
average flow rate used for sampUng.
NOTI—Clean ambient air can be provided by pesstns;
air through a charcoal Alter. At the optioa of the tester,
mmbient air (without cleaning) may be used.
4.1.t Calculation of Percent Isotinetic. Follow the
procedure outlined in Method 5, Section 4.1.8.
4-2 Sample Recovery.
4-1.1 Container No. 1. If a moisture content analysli
to to be done, weigh the first uopinfcr plot cooUnti to
toe oeamt 0.51 and record thii weight.
Trauler the contents of the Ant implncer to a ISO-mi
graduated cylinder. Rinse the probe. Ant Implnger, all
oonnecting glassware before the Alter, and the front bal/
of the Alter oolder with 80 perc«nt lsoprope.iol. Add the
ruue solution to the cylinder. Dilute to 250 ml with M
percent isopropanol. Add the Alter to the aolutlon, mix,
and transfer to the storage container. Protect the solution
a«aln*i evaporation. Mark the level of liquid on bet
container and identirv the sample container.
4-2.3 Container No. 2. II a moisture content analyau
to to be done, weigh tb« second and third impingen
(plui contents) to the nearest OJ, g and record these
weighu. Also, weigh the spent itllca (el (or silica gel
plus implnger) to the nearest 0.5 g.
Traas/er the solution! from the second aod third
impingers to • 1000-mJ graduated crllnder. Rirue all
aaanecUAg glasfware (Including back half of Alter holder)
between the Alter aod silica gel implnger with delonlred,
distilled water, and add this rinse water to the erllMer.
Dlluu to t volume of 1000 ml with delonlied, distilled
water Transfer the solution to i ttoragt container. Mark
the level of liquid on the container. Seal and Identify tb«
ample container.
4J A
Analyiii.
Note the level of liquid In containers 1 and 2, aad eoo-
fina whether or not any sample wu lost during ship-
Bent; note this on the analytical diu sbect. If a notice-
able amount of leakage has occurred, eitHer void UM
sample or use methods, subject to the approval of the
Administrator, to correct the Anal results.
4-1.1 Container No. 1. Shake the container boldlnf
tbe Isopropanot solution and the Alter. If the Alter
breaks up, allow the fragments to settle lor a few minutes
beXon removing a sample. Pipette a 100-mJ aliquot of
this solution into a 2SC-ml Erlenmeyer flaak. add J to 4
drops of thortn Indicator, and UtraU lo a plxu\ end point
using 0.0100 N barium perchlorale. Repeat the tltratlon
with • second aliquot c/sample and average the tlcraUoo
T*inJ*- KepUcaU atrslions mart agree within I parent
sj-OJ ml, whichever Is greater.
4JJ Container No. 2. TborooghJy mil the ntattoc
KB the container holding the contents of the seeood aod
third tmpiogen. Pipette s 10-ml allqoot of sample into s
tSO-mJ Erleooieyv cul. Add ml of laopropanol. 2 to
4 drops of thorin Indicator, and titrate t« a pint eodpoint
•Log 0.0100 N barium psrebJcrete. Repeat the trtratioo
wtti a seoocd aliquol of sample aod avenge the UtreOon
YtjuM Replicate titrstioos moat afret within 1 peroeot
«r U ml, whichever Is greater.
4JJ Blanks. Prepare blanks by adding 2 to 4 drops
•* thorin Indicetor to 100 ml of H percent tsopropanol.
TBrate the blanks In tee sam« manner u the sample*
(.1 Calibrate equipment using the procedures spec)-
led In the lollowing sections of Method I Section 6J
CPMtedog ryrum); Section U (temperature ranges),
•eetlon 1.7 (barometer). Note that lie recommended
' leak -check of the metering symtrn, described in Section
iJ of Method i, also applies to this method.
U Standardise the barium perchlorale solution vrith
V ml of standard tuliurlc acid, to which 100 ml of 100
at leopropenol has bean added.
Note.—Carry oat aakalatloai retaining at kut OB*
ntr» decimal fig-tin beyond that of the acquired data.
Boond ofl ogiirera/ter final calculation.
(J Nomenclature.
X.-Crosa-seetlooal area of nctilt, m> (ft').
JB^^Water vapor In the gas stream, proportion
by volume
CHsSOt-Bumirk acid (Indoding SOi) eoeeeBtntloc,
l/dscm Ob/dscf).
CSOi'Sulfor dioxide oonoentrattoo, g/dscm (IV
dsc/1.
7-Percent of IsokineOc sampling.
rV-NormalitT of barium parchlorate titrant, g
•qulvalents/llter.
n»t~Barometric prMSurt at the sampling site,
mm Bg (In. Eg).
P.-Absolute stack gaa pressnrt, mm Hg da.
Bg).
''•td-Btandard absolute pnswra, TV mm Etg
(29.92m. Eg).
T«-Avaraf e abeomte dry ras meter temperature
(•eeTlfure 8-2). • K (• R).
r.ojlvarage absolute ctack (as t&mparaton (sse
Figure S-2), • K f B).
T^td" Standard absolate Umperatun, fff I
(42T E).
V.»Volome of sample allqaot titrated, 100 ml
tar BiSO, and 10 ml for SO:.
Vi.-Total volume of liould ooUecled In tmptngen
and silica gel. ml.
V*mVolume of gas sample as unsimiisil by dry
«ns»U the moartun conteat of the pptMi to this method. Note that U the affluent rei
can be considered dry, the volume of water vapor
ad moisture content need not be calculated.
e-6 BuUurtc acid mist (including SOi) concentration.
_ _
Cm,»0," AI
V.
t
Equation 8-2
JC.-0.049CX (AnUIiaqul-ralmt tor metric units
-l.oeixio-'lb/miq lor English units.
Sulfur dioxide concentration.
Equation 8-3
jr;, -0.02303 r/meq (or metric onlta.
-7.061 xlO-Mb/ineq for Inflish tmrts.
C.7 IsokJoetic Variation.
a.7.1 Cakoiation from raw data.
j 100 T.IK, V..+ ( V,/T,) P>., + AH/13.6)]
Equation 8-4
where:
Xi-0.0034«4 ma Hg-m'/ml-'a" lor metric nnlts.
-O.OCO676 In. Hf-h'/mJ-'E lor Zngliih tmlu.
«.7J Calculation tram InUrmedlaU nines.
T V
~K> P.».A*i(l-B..)
EquAtion 8-5
Xi-4^aO lor metric tmlts.
-O.OWiO for English units.
(4 Acceptable Resuru. U 90 percent « tester i&alj tltbw correct the value of t'. (n Equation
*-l (ei described In Section U el Method i), or shall
Invalidate the test run.
M Volume of Water Vapor and Jtourcun Content.
CeJeniaU the volume of water vapor using Equation
t-i oT Method 4: the weight of water collected In the
J? ?**" *"d *llc* (el can be dlrectlv eooTerted to
mmiUten (the sped He parity of water is 1 i/ml). Cal-
1. Atmospheric Zmisriou from SuUuric Acid Manu-
•asturlng rnxusats. D.B. DEEW, PBS. Division of
Air Palfution. Public Health Serrlc* PnbueaUon No.
HV-AP-13. Cincinnati. Ohio. 19*i.
1. Corbett, P. T. The Determination of SOi and BO,
m riue OSMS. Journal ol th« Institute of fuel. 14.-237-M9.
im.
t. Martin, Robert M Construrtioti Details of Isokrinetic
Soorc* Sampling Equipment. Environmental Protection
Agency. Research Triangle Park, N.C. AH Pollution
Control Office Publication No. APTD-QM1. April, 1971.
4. Panon, W. T. and 1. A. Briak, Jr. New Equipment
sod Techniques for Sampling Chemical Process Oases
Journal of Air Pollution Control Association. IS 142.1963
6. Rom, J. J. Maintenance Calibration, and Operation
«° Isotloetlc Source-Sampling Equipment Office of
Jalr Programs, Environmental Protection Agency.
lavearch Triangle Park, N.C. APTD-OS74. March, 1«72.
«. Hamil. H. T. and D. I. Camaan. Collaborative
Study of Method lor Determination of Sulfur Dloude
Emissions from Stationary Sources (7osall fuel-Fired
Steam Oen&raton). Environmental Protection Agency.
sUaeareh Triangle Park, N.C. EPA-450/4-74-034.
Dioember, 1973.
7. Annual Book of A8TU Standards. Fart II: Water.
Atmospheric Analysis pp 40-42. American Society
lor Tasting and Matartais. Philadelphia, Pa. 1974.
11-58
-------
Wath BctUa*. PolyiUrteae « |La», too ml.
Sow)
1.9 Analyst.
oom*ot »n»Jysii !
2.1.4 Ortduaud Cylinder. 100 ml.
, to
Botik. To *dit, Ihf KMnO, ust lor ozldiimble orimlc mitwj
»•) b« omltud »hen bltb ocmoenL-aLloni o( omoJc
•wtur in not eipectnj to tw prannt.
t.1.4 topropanal. K Parant. Mil wn ml of laopro-
»uo! with *» ml ofdeionlted, distilled rater.
NoTI.—Experience has abovn that only A.C.8. trade
hepropanol Is ftatlafartory Tests b»»e shown that
laopropaool obtained from oomjnerrjaj sources occav
eauloDally has peroilds Imparities tbal will csuiat ej.
ptroildts In aach lot cJ
Shake 10 ml of toe Isopropenol with 10 ml
f freshly prepared 10 percent potassium loUlde aolatloo.
rnpare a bUrU by similarly trutlnf 10 ml of distilled
water. After 1 minute, read the ftbaorbanc* on ft spectro-
pbotometer ftt &S2 naoocneten. II the absorba^ce eiceeds
'0.1. the Isopropanol iball not be used Paroiides may be
removed from laopropanol by redl5tilltnx. or by pajeege
Uvouch a column of actlTst>d alumina Bovever. r*>
•(ant-ffrade Isopropanol vlth suitably low perollde levels
li reaullly ftrallabre from oonunercial sources; tbereJon,
r%>«rUon of eoDtamlnated lots may be more emcleot
than loUowlrut the peroilde rtrooTal procedure.
Hi Byorofpn Fvotide I Perrrnt. DUate 100 ml
•I to peircent hydrogen peroxide to 1 Ut«r Tlth datoalsMd,
dlcUlled vaLer. Prepan fnah dally.
I.I » Craabedlce.
1.3 Sample RerOTrry.
U.I Water. Same al S.t.l.
1.3.2 Isopropanol, 10 Percent. B*>me u 1.1.4.
1.1 Analysts.
U.I Water. Same all.1.9.
112 laopropanol. 100 Peretrjl.
1.1.3 Thortn Indicator l-(o-ano l§opTt)f»r«ol. 1.22 | of bulum ehlorlrtf dJhrdrmte
(BftTIf SH rO) m»y b» o»«J lrul«d of the b»r1nm p»r-
«tlk>nl> BlAndftrdlM vKJ> •aUurlc ftcld M In ftocUon 5.2
Thli io)utkxi mut t» preuoud tnjait mponUon >t
rnllUma
1.3 5 Sulfurtc Acid 8it/id*nj (00100 N) Purrhve or
itandtrdlu to ±0 9XC N ftfunjl 00100 N NiOH thftt
hM prrTiotuly been -itandftrdiud ftc&init primary
itandird pouoluni acid phthaUu.
4. Procedure
4.1 SunpUnt
4.1.1 Pruest Preparation. Folio* the procerfun out-
lined in Mflhod i, f—Hion 4.1 1. nilrn should be In-
•pfcied. but nr*d not b» dMiccaipd «fi(hed, or Identl-
lird. Iflhefffluentfasranbe coruidfriNd dry , I.e., mois-
ture free, the silica |fl n"d not be weighrd
4.1.2 Prelimmar) H'lfrminalionj Folio* tb« pro-
CTdure outlined in Mclhod 5, S^cnon 4 1.2.
4.1.3 Preparation of Tollecuon Tnln Follow the pro-
cedure outlined in Mel hod 5. S«riinn 4 I 3 (eifept for
the tecood paragraph and other obTiouiiy mapplicabte
p»n«) and u» Fifure 8-1 instead of Fiirure S-l Replace
the aecond partfraph «1lb Place 100 ml of 80 percent
toopropanol in the ftnt Impin^er. 100 ml of 3 percent
bydxocen peroxide in both the second and trurd Im-
pln^en, relAlo ft portion of each rtefeot for uae M ft
blank solution. Placx about KOI of atlioa [tl In tb« k>ont>
K.ANT.
LOCATION.
OMRATOR.
DATE
MUM NO. _
SAMPLE SOX NO..
METER »OXNO._
METER 4Hf
CFACTOR
«TOTTUBE COEFFICIENT,^.
STATIC PRESSURE. •• H| (•. H|)
AMBIENT TEMPERATURE
BAROMETRIC PRESSURE
ASUMEO MOISTURE,*
PROBE LENGTH. m|h)
SCHEMATIC Of STACK CROSS SECTION
NOZZLE IDENTIFICATION NO
AVERAGE CALIBRATED NOZZLE DIAMETER, on(mj.
PROBE HEATER SETTING
LEAK RATE. m3/mi«,(cfm)
PROBE LINER MATERIAL
FILTERED.
TRAVERSE POINT
NUMSEF.
TOTAL
SAMPUXC
TIME
(«), mia.
AVERAGE
VACUUM
••H|
0».Hi)
HACK
TEMPERATURE
(Tsl,
•C(»F)
VELOCtTY
MEAD
(APj),
a«rl;0
OfcrljO)
PRESSURE
DIFFERENTIAL
ACROSS
ORIFICE
METER.
•mHjO
(n.H;0)
CAS SAMPLE
VOLUME.
.3 (ft))
J
EAS SAMPLE TEMPERATURE
AT DRY GAS METER
INLET,
»C(»F)
Avg
oirnn,
*C(»F)
Av«
Av«
TEMPERATURE
Of GAS
LEAVING
CONDENSER OR
LAST IMPINGER
»C («F)
Flgur» §-2.
dau.
11-59
-------
^ji »'UfjB j TBPAL UiiliumfATTOH C* TKX
or ucaaxomi r»OM
stationary sources discharge visible
j Into th* atmosphere-, the** •mis-
sions are usually in toe chap* of » plum*.
This method involve* th* determination of
plum* opacity by qualified observers- Th*
method Include* procedure* for th* training
and certification of ob*erv«rs, and procedure* .
to b* u**d_ln th* field tor determination of
plum* opacity. The appearance of a plum* as
Tlewed byran observer depend* upon a num-
ber of vartmblsa, sou of which may b* con-
IroiUil* and MB* of which may Dot b*
eontroUabl* la tb* Odd. Variable* wnlch can
b« eootrollirt to an «rt»nt to which tU*y no
longer exert a significant Influence upon
plum* appearance Include: Angle of the ob-
server with reapect to the plume; angle of the
observer with respect to the *un; point of
observation of attached and detached steam
plume; and angle of the observer with re-
spect to a plume emitted from a rectangular
Made with a Large length to width ratio. The
TTHrftirxl Includes specific criteria applicable
to the** variable*.
Other vartabk which may not b« control-
lable In the fleiu are luminescence and color
contrast betwei the plume and the back-
ground against vilch the plume it viewed.
These variables exert an Influence upon the
mpp«arance of a plume a* viewed by an ob-
server, and can affect the ability of th* ob-
server to accurately assign opacity value*
to the observed plume. Studies of the theory
of plume opacity and field studies have dem-
onstrated that a plume if moat risible and
presents the greatest apparent opacity when
viewed against a contrasting background. It
follows from this, and is confirmed by field
trial*, that the opacity of a plume, viewed
under conditions where a contrasting back-
ground is present can b« assigned with the
greatest degree of accuracy. However, the po-
•*tential for a positive error is alao the greatest
when a plume l£ viewed under such contrast-
ing conditions. Undrr conditions presenting
a less contrasting background, the apparent
opacity of a plume Is lees and approaches
eero as the color and luminescence contrast
decree** toward zero. As a result, significant
negative blag and negative errors can b*
mad* when a plume U viewed under less
contrasting condition*. A negative bias de-
creases rather than Increases the possibility
that a plant operator will be cited for a vio-
lation of opacity standards dne to observer
•rror.
Studies have been undertaken to determine
the magnitude of positive errors which can
be man> by qualified observers while read-
Ing plumes under contrasting condition* and
•using the procedures set forth in this
method. The results of these studies (field
trials) which Involve a total of 709 set* of
25 reading* each are as follows:
(I) For black plumes (133 sets at a rmoke
generator), 100 percent of the a«u wsr»
read with a positive error' of less tbAn 7.6
percent_opaclty; 99 percent were read with
a positive error of leas than 5 percent opacity.
(3) For white plumes (170 sets at a imoke
generator, 168 if It at a coal-fired power plant,
398 sets at a ruifurtc acid plant). 99 percent
of the Mts were read with a positive error of
leas than 7 J percent opacity, 95 percent were.
read with a poaltiv* error oTleas than 5 per-
cent opacity.
Tn* positive observation*! error associated
•with an average of twenty-five reading! Is
therefor* established. Th* accuracy of th*
method muat be taken Into account-when
determining possible violations of appli-
cant* opacity standaid*..
t far a art, poatUr* *rrar=av»rag» opacity
«J*termiQsd b- observes' 35 observation*—
Average opacity d«t*rmln*d .from tranxmJc-
•omstert U recordings.
1. Principle and appltcoMllfy.
l.f Principle. Tb* opacity of •mission*
from stationary source* is determined rts-
tusUy by a qualified observer. -
1.2 Applicability. This method is appll-
eabl* for the determination oi th* opacity
of emissions from stationary source* pur-
suant to I 60.11 (b) and for qualifying ob-
server* for visually determining opacity of
^•missions.
2. froetdufti. The obaerrw q-uallfled m
accordance with paragraph S of this method
ahau ns* the following procedural for vis-
ually detarmlnlng th* opacity of •mleslons:
1.1 fosltlon - Th* qualified obeerver »*^"
Itand at a distant* sufficUnt to provld* a
clear view of the emissions with th* sun
oriented in th* 140* sector to hi* back. Con-
sistent with maintaining thi above require-
ment, the obeerrer shall, as much as possible.
make his obeervatlonj from a poaltion such
that his line of vision Is approximately
perpendicular to th* plum* direction, and
when observing opacity of emissions from
rectangular outlets (e.g. roof monitors, open
beghousea, nonclrcular stacks), approxi-
mately perpendicular to th* longer axis of
the outlet. The observer's line of sight should
not Include more t.h«n one plume at a time
when multiple stacks are Involved, «"fi In
any case the observer should make his ob-
servations with his line of sight perpendicu-
lar to the longer »**» of such a set of multi-
ple (tacks (e.g. stub stacks on beghouaes).
3J2 Field records. Th* observer ahall re-
cord the name of the plant, emission loca-
tion, type facility, observer's -name and
affiliation, and the dat« on a field data sheet
(Figure 9—1). The time, estimated distance
to the emission location, appro limits wind
direction, estimated wind speed, description
of the sky condition (preaence and color of
clouds), and plume background art recorded
on a field data sheet at the time opacity read-
ings are Initiated and completed.
2.3 Observations. Opacity observations
ahall bo made at the point of greatest opacity
In that portion of the plume where con-
densed watet vapor 1* not present. Tb* ob-
server sh&U not look continuously at the
plume, but Instead shall observe Uv* plume
momentarily at l£-second Interval*.
3.3.1 Attached steam plume*. When con-
densed water vapor 1* present within the
plume as It emerges from the emission out-
let, opacity observation* ahall be made be-
yond the point In the plume at which con-
densed water vapor is no longer visible. The
observer shall record the approximate dis>
tanc* from the emission outlet to the point
in the plume at which the observations are
made.
2.3.2 Detached steazn plume. When water
vapor In the plume eoodenaee and becomes
visible at a distinct distance from the emis-
sion outlet, the opacity of emissions should
be evaluated at the emission outlet prior to
the condensation of water vapor and the for-
mation of the steam plume.
2.4 Recording observations. Opacity ob-
servations shall be recorded to the nearest 5
percent at l&^&eoond Intervals on an ob-
servational record sheet. (See Figure 9-3 for
an example.) A minimum of 34 observations
shall be recorded. Each momentary observa-
tion recorded ahull bo deemed to represent
the average opacity of smU&lon* for > 15-
•econd period.
3.5 Data Reduction. Opacfty shall be de-
termined as an average of 34 consecutive
observations recorded at 15-eecond Intervals.
Divide th* observations recorded on the rec-
ord sheet Into seta of 24 consecutive obser-
vations. A set Is compoeed of any 24 con-
secutive observations. Bets need not b* con-
secutive in time and in no case shall two
Mts overlap. For e*ch set of 34 observations,
calculate the average by summing th* opacity
of th* 34 observations and dividing -this sum
by 34. If an applicable standard specifies an
averaging time requiring more th.r) 34 ob-
servations, calculate the average for all ob-
servations mad* during th* specified time
period. Record the average opacity on a record
sheet. (Bee Figure 9-1 for an example.)
8.
8.1 CertlficaUoa requirements. To receive
wrtlfleatloo as • qualified observer, a can*
dldat* must b* tasted and demonstrate the
ability to assUgn opacity readings la 5 percent
Increments to 35 different black plum** »"*1
M different whit* plum**, with an error
not to *»f**d It perant opacity en any one
m*i11nE and an average error -not to exceed
1J6 percent opacity in each category. Candi-
dates shall be tested according to the pro-
cedure* described In paragraph 3.3. Smoke
generator! used pureuant to paragraph 32
«**" be equipped with a smoke meter which
meet* the requirements of paragraph 33.
The certification shall be valid for a period
of 6 months, at which time the qualification
procedure must be repeated by any observer
In order to retain certification.
• SJ Certification procedure. The certifica-
tion teet consists of showing the candidate a
complete run of 50 plumes— 26 biack plume*
»<-"l 26 wtilte plumes— generated by a smoke
generator. Plume* within each set of 26 buck
and 26 white runs shall be presented in ran-
dom order. The candidate assigns an opacity
value to each plume and records his obser-
vation on a suitable form. At the completion
of each run of 60 readings, the score of the
candidate is determined. If a candidate falls
to qualify, the complete run of 50 readings
must be repeated in any retest. The smoke
test may be administered as part of a smoke
school or training program, and may be pre-
ceded by training or familiarization runs of
the smoke generator during which candidates
are shows black and white plumes of knows.
opacity.
- 33 Smoke generator spectfloatlons. Any
amoke generator used for the purposes of
paragraph S 2 &hall be equipped with » amoks
meter Installed to measure opacity across
the dfavmeter of the smoke generator stack.
The- cznoke meter output shall display in-
vtack opacity ba&ed upon a pathjength equal
to the atack exit diameter, on a full 0 to 100
percent ch&rt recorder scale. The amoks
meter optical design and performance shall
meet the specifications shown In Table 9-1.
The sxnolte me&er shall be calibrated as pre-
scribed In paragraph 8.3.1 prior to the con-
duct of each amolte reading teet. At the
completion of each test, the zero and span
drift «*»Ji be checked and If the drift ex-
ceeds iJ percent opacity, the condition ahsJl
be eorreoted prior to conducting any subse-
quent teat runs. Th« smoke meter «><«ii be
Demonstrated, at the time of installation, to
m«rt the specifications listed In Table 9-1.
This demonstration ahall bo repeated fol-
lowing a£y subsequent repair or replacement
ol th* photocell or associated electronic cir-
cuitry Including the chart recorder or output
me-ter, or *»ry 6 months, whichever occur*
firvt.
».SJ Calibration. Tn* smoke met*? is
calibrated after allowing « minimum of >0
.mlnutee wannup by alternately producing
simulated opacity of 0 percent and 100 per-
cent. When st&ble response at 0 percent or
100 percent Is noted,- the amoke meter Is ad-
justed to produce an output of 0 percent of
100 percent, a* appropriate. Tnl* calibration
ahall b* repeated ante stable 0 percent and
100 percent reading* are produced without
adjustment. Simulated 0 percent and 100
percent opacity values may be produced by
alternately switching th* power to the light
source oa and off while th* amoks generator
if cot producing smok*.
11-60
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••BOOT JJTD
Speotfleatton
*- t^»V. SMirce. Incandeeoent
operated at
t%ted roltage.
»x apeetral response. Pbotopio (daylight
«f photocell. •pectral nepoaM of
tbe human
. refereix>e *J).
c. Angle c^Tlew 15-
*- Angle of projec- 15' m^TtmiiT^ total
Uon-r angle.
•. Calibration error. -±a% opacity, maxl-
X. Zero and span ±a% opacity, 30
•drift minutes,
f. Beer cms* Ume._ S3 t*TVlii.
Smoke meter evaluation. The smoke
meter design and performance are to be
erraluated a£ tolJoa-s:
3.3.2.1 light source. Verify truui manu-
facturer's data and froir rolt*g« matsujfr-
meuts mmd« at the lamp, aa InstaUed. tbat
the Ump ia operated irttiiji :±J percent of
tte nominal rated voltage.
8J^^ SpectpaJ recponae of photocell.
Verify from manufacturer'* d«,t« t33»t tbe
photocell b«j a photople response; 1*, tie
•pectra! aensltlrlty of tbe cell thai! closely
approximate the ft&ndard spectral-luminos-
ity curre for photoplc rtston which Is refer-
enced la (D) of Table 9-1.
SJJ2J Angle of rl«™r. Check coortnictlon
geometry to enrure tbkt the total angle of
new of the cmolce plume. tJ ceen. by tbe
photocell. <3oe< not exceed 1C*. Tbe total
angle of Tlev m&y be calculated frccn: /=S
tan-1 d/ZL, where 1 = total angle of -rl»r,
d=the rum of the photocell dlameter+Che
ter of tne limiting aperture; and
l>=tbe dlrtaHce from the photoceU to th*
limiting aperture. The limiting aperture K
the point In th« pate between tbe pbotooeQ
and tbe amoke plum* where tiie angle at
rl*w U mart restricted. In nnok» f«nerator
•mokj metcn tbJ« it normally -an orifice
plate.
3.3.3.4 Angle of projection. Obeck oon-
f»ometry to enrure tbat 'lt>» total
•agle of projection of tb« lamp en the
•not* plume doe* not aic«d IB*. Tb* total
angle of projection may be calculated from:
t=3 tan-' d/2L, where «= total angle of pro-
jection; d= tbe lum of tbe length of the
lamp filament + tbe diameter of tbe *i*r\it)T^
aperture; and L= the dlstanoe from tb« Ump
to tbe limiting aperture.
l£3£ Calibration error. Udng neutral-
denalty niter* of known opacity, obeck tbe
error between tbe actual re«pon*e arul tbe
theoretical linear reeponse of tbe unoke
awter. Tbli check li aooompUabed by firrt
calibrating tbe emote meter according to
84.1 and then Inserting a aerie* of three
neutnl-dentlty filters of T>nrr* 100 percent opacity
ralues and observing tbe time required to
reach stable reepom*. Opacity ralue*) of 0
percent and 100 percent may be simulated
by alternately twitching tbe power to tbe
light source OS and on while tbe smoke
generator Is not operating.
4. Etjcrcncts.
4.1 Air Pollution Control District Rules
and Regulations, Los Angeles County Air
Pollution Control District, Regulation IV,
Prohibitions, Rule 50.
4.Z WeUburd, Melrln t, Field Operations
and Enforcement Manual for Air, UJ3. Envi-
ronmental Protection Agency, Boeeircb Tri-
angle Park, N.O, APTD-1100. Aufuct 1B72.
pp. 4.1-4.38.
4-S Condon, E. U., «TM< Odlshaw, H. Band -
boot of Physics, McOrmw-HUl Co, K.T, N.T,
KM, Table 3.1, p. 6-42.
11-61
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RECORD OF VISUAL DETERMINATION OF OPACITY
PAGE of
COMPANY
LOCATION
TEST NUMBER
DATE
TYPE FACILITY^
CONTROL DEVICE
HOURS OF OBSERVATION.
OBSERVER
OBSERVER CERTIFICATION DATE_
OBSERVER AFFILIATION
POINT OF EMISSIONS
HEIGKT OP DISCHARGE POINT
CLOCK TIME
OBSERVER LOCATION
Distance to Discharge
Direction from Discharge
Height of Observation Point
BACKGROUND DESCRIPTION
WEATHER CONDITIONS
Hind Direction
Wind Speed
Ambient Temperature
SKY CONDITIONS (clear.
overcast. % clouds, etc.) .
PLUME DESCRIPTION
Color
Distance Visible
071IER
Initial
Final
K
1
t
SUMMARY OF AVERAGE OPACITY
Set
Number
-
limp
Start— End
Opacity • .
Sum
> r ' - •• •
eadlngs ranged from ^ to X opac
he source was/was not in compliance wit
he time evaluation was made.
Average
ity
h .at
-------
FIGURE 9-2 OBSERVATION RECORD
PAGE
COMPANY
LOCATION
TEST NUMBtT
IWTE
OBSERVER
TYPE FACILITY" '
POINT OF EMlSSlOTir
Hr.
H1n.
0
1
2
3
4
5
6
/
B
9
10
|l
12
13
14
15
Ib
I/
1H
19
20
21
22
23
24
2S
26
27
28
29
0
Seconds
15
JO
'.._.'
TYPE FACILITY """"
POINT OF EMissTMT
Hr.
Mln.
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
4;
48
49
50
51
52
53
54
55
56
57
58
59
Seconds
0
15
30
45
STEAM PLUME
(check If «poHcable)
Attached
Detached
COWENTS
i
|FR Doc.74-38160 Filed 11-11-74;B:1S am)
-------
Method 19. Determination of Sulfur
Dioxide Removal Efficiency and
Paniculate, Sulfur Dioxide and Nitrogen
Oxides Emission-Rates From Electric
~ Utility Steam Generators
1. Principle and Applicability
1.1 Principle.
1.1.1 Fuel samples from before and
after fuel pretreatment systems are
collected and analyzed for sulfur and
heat content, and the percent sulfur
dJoxide (ng/joule, Ib/million Bru)
reduction is calculated on'a dry basis.
(Optional Procedure.)
1.1.2 Sulfur dioxide and oxygen or
carbon dioxide concentration data
obtained from sampling emissions
upstream and downstream of sulfur
dioxide control devices are used to"
calculate sulfur dioxide removal
efficiencies. {Minimum Requirement.) As
an alternative to sulfur dioxide
monitoring upstream of sulfur dioxide
control devices, fuel samples may be
collected in an as-fired condition and
analyzed for sulfur and heat content
(Optional Procedure.)
1.1.3 An overall sulfur dioxide
emission reduction efficiency is
calculated from the efficiency of fuel
pretreatment systems and the efficiency
of sulfur dioxide control devices.
1.1.4 Participate, sulfur dioxide,
nitrogen oxides, and oxygen or carbon
dioxide concentration data obtained
from sampling emissions downstream
from sulfur dioxide control devices are
used along with F factors to calculate
participate, sulfur dioxide, and nitrogen
oxides emission rates. F factors are
values relating combustion gas volume
to the heat content of fuels.
1.2 Applicability. This method is
applicable for determining sulfur
removal efficiencies of fuel pretreatment
and sulfur dioxide control devices and
the overall reduction of potential sulfur.
dioxide emissions from electric utility
steam generators. This method is also
applicable for the determination of
participate, sulfur dioxide, and nitrogen
oxides emission rates.
2. Determination of Sulfur Dioxide
Removal Efficiency of Fuel
Pretreatment Systems
2.1 Solid Fossil Fuel.
2.1.1 Sample Increment Collection.
Use ASTM D 2234 '. Type I, conditions
A. B, or C, and systematic spacing.
Determine the number and weight of
increments required per gross sample
representing each coal lot according to
Table 2 or Paragraph 7.1.5.2 of ASTM D
2234 '. Collect one gross sample for-*ach
raw coal lot and one gross sample for
each product coal lot.
2.1.2 ASTM Lot Size. For the pujpose
of Section 2.1.1, the product coal lot size
is defined as the weight of product coal
produced from one type of raw coal. The
raw coal lot size is the weight of raw
coal used to produce one product coal
lot. Typically, the lot size is the weight
of coal processsed in a 1-day (24 hours)
period. If more than one type of coal is
treated and produced in 1 day, then
gross samples must be collected and
analyzed for each type of coal. A coal
lot size equaling the 90-day quarterly
fuel quantity for a specific power plant
may be used if representative sampling
can be conducted for the raw coal and
product coal.
Note.—Alternate definition* of fuel lot
sizes may be specified subject to prior
approval of lie Administrator.
2.1.3 Gross Sample Analysis.
Determine the percent sulfur content
(%S) and gross calorific value (GCV) of
the solid fuel on a dry basis for each
gross sample. Use ASTM 2013 ' for
sample preparation, ASTM D 3177 ' for
sulfur analysis, and ASTM D 3173 ' for
moisture analysis. Use ASTM D 3176 '
for gross calorific value determination.
2.2 Liquid Fossil FueL
2.2.1 Sample Collection. Use .ASTM
D 270 * following the practices outlined
for continuous sampling for each gross
sample representing each fuel lot
2-2.2 Lot Size. For the purposes of
Section 2.2.1, the weight of product fuel
from one pretreatment facility and
intended as one shipment (ship load,
barge load, etc.) is defined as one
product fuel lot. The weight of each
: crude liquid fuel type used to produce
one product fuel lot is defined as one
inlet fuel lot
Note.— Alternate definitions of fuel lot
sizes may be specified subject to prior
approval of the Administrator.
Note.— For the purposes of this method,
raw or inlet fuel (coal or oil) is defined as the
fuel delivered to the desulfuriialion
pretreatment facility or to the steam
generating plant. For pretreated oil the input
oil to the oil desulfurization process (e.g.
hydrotrealraent emitted) i« sampled.
2.2.3 Sample Analysis. Determine
the percent sulfur content (%S) and
gross calorific value (GCV]. Use ASTMD
240 ' for the sample analysis. This value
can be assumed to be on a dry basis.
'U»e tie mo»l recent revision or designation of
the ASTM procedure ip«d£ed •
1 U«e the mail recent revision or designs tioo of
the ASTM procedure ipecified.
11-64
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1.3 Calculation of Sulfur Dioxide Remov-
al Efficiency Due to Fuel Pretreatment. Cal-
culate the percent sulfur dioxide reduction
due to fuel pretreatment using the follow-
ing equation:
•c 100
-VGCVo
SS./GCV,
Where:
Sulfur dioxide removal efficiency due
pretreatment: percent.
%S0 = Sulfur content of the product fuel lot
on a dry ba-sis; weight percent.
%S, = Sulfur content of the inlet fuel lot on
a dry basis; weight percent.
GCV. = Gross calorific value for the outlet
fuel lot on a dry basis: kJ/kg (Btu/lb). '
GCV, = Gross calorific value for the inlet
fuel lot on a dry basis; kJ/kg (Btu/lb),
Norr.— If more than one fuel type is used
to produce the product fuel, use the follow-
ing equation to calculate the sulfur contents
per unit of heat content of the total fuel lot,
%S/GCV:
Where:
%R. =Sulfur dioxide removal efficiency of
the sulfur dioxide control system using
inlet and outlet monitoring data; per-
cent.
E»o , = Sulfur dioxide emission rate from the
outlet of the sulfur dioxide control
system; ng/J (Ib/million Btu).
E«, , = Sulfur d.oxide emission rate to the
outlet of the sulfur dioxide control
system; ng/J Ob/million Btu).
3.3 As-fired Fuel Analysis (Optional Pro-
cedure). If the owner or operator of an elec-
tric utility steam generator chooses to deter-
mine the sulfur dioxide imput rate at the
inlet to the sulfur dioxide control device
through an as-fired fuel analysis in lieu of
data from a sulfur dioxide control system
inlet gas monitor, fuel samples must be col-
lected in arrorriance with applicable para-
graph In Section 2. The sampling can b«
conducted upstream of any fuel processing.
;.g., plant coal pulverization. For the pur-
poses of this section, a fuel lot size Is de-
fined as tries-weight of fuel consumed In 1
day (2< hour*) and is directly related to the
exhaust gas monitoring data at the outlet of
thf sulfur dioxide control system. .
V
3.3.1 Fuel Analysis. Fuel samples must bo
uialyzed for sulfur content and gross calo-
rific value. The ASTM procedures for deter-
mining sulfur content are defined In the ap-
plicable paragraphs of Section 2.
3.3.2 Calculation ofSdlfur Dioxide Input
Rite. The sulfur dioxide imput rate deter-
mined from fuel analysis is calculated bv:
2.0(Kf)
~~GCV
2.0(SS(
GCV
10 for S. I. units.
x 10 for Englisti uni ts.
Where:
'.S/GCV
k = l
Where:
Yk = The fraction of total mass Input derived
from each type, k, of fuel.
%S>-Sulfur content of each fuel type, k. on
a dry basis; weight percent.
GCV, = Gross calorific value for each fuel
type. k. on a dry basis; kJ/kg (Btu/lb).
n = The number of different types of fuels.
I * Sulfur dioxide input rate from as-fired fuel analysis,
ng/J (1 fa/million Btu).
?S, • Sulfur content of as-fired fuel, on a dry basis; weight
percent.
GCV « Gross calorific value for as-fired fuel, on a dry basis;
•kJ/kg {Btu/lb).
3. Determination of Sulfur Remove! Efficien-
cy of the Sulfur Dioxide Control Device
3 1 Sampling. Determine SO, emission
rates at the inlet and outlet of the sulfur
dioxide control system according to meth-
ods specified in the applicable subpart of
the regulations and the procedures specified
in Section 5. The inlet sulfur dioxide emis-
sion rate may be determined through fuel
analysis (Optional, see Section 3.3.)
''32 Calculation. Calculate the percent
removal efficiency using the following equa-
tion:
3.3.3 Calculation of Sulfur Dioxide Emit-
jion Reduction Using As-fired Fuel Analysis.
The sulfur dioxide emission reduction effi-
ciency is calculated using the sulfur imput
rate from paragraph 3.3.2 and the sulfur
Where:
dioxide emission rate, £*„. determined In
the applicable paragraph of Section 5.3. The
equation for sulfur dioxide emission reduc-
tion efficiency is:
IS ,f, » Sulfur dioxide removal efficiency of the sulfur
dioxide control system using as-fired fuel analysis
data; percent.
j
ESO * Su1fuC- di°xide emission rate from .sulfur dioxide control
2
system; ng/J (Ib/million Btu).
I
Sulfur dioxide input rate from as-f1red fuel analysis;
ng/J (1b/million Btu).
11-65
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4. Calculation of Overall Reduction in
Potential Sulfur Dioxide Emission
4.1 The overall percent sulfur
dioxide reduction calculation uses the
sulfur dioxide concentration at the inlet
to the sulfur dioxide control device as
the base value. Any sulfur reduction
realized through fuel cleaning is
introduced into the equation as an
average percent reduction, %R<.
4.2 Calculate the overall percent
sulfur reduction as:
JR
5R
W
o *
100C1.0. 0.0-T-g) 0.0 -
Where:
or CO. - based calculation or calculated
1H » Overall sulfur dioxide reduction; percent.
SR- • Sulfur dioxide removal efficiency of fuel pretreatanent
froia Section 2; percent. Refer to applicable subpart
for definition of applicable averaging period.
IR • Sulfur dioxide removal efficiency of sulfur dioxide control
-> device either
froo fuel analysis and emission data, from Section 3;
percent. Refer to applicable subpart for definition of
applicable averaging period.
5. Calculation of Particulate, Sulfur
Dioxide,jind Nitrogen Oxides Emission
Rates
5.1 Sampling. Use the outlet SO» or For SI Units:
Ot or COi concentrations data obtained
In Section 3.1. Determine the participate,
NO,, and O> or CO» concentrations
according to methods specified in an
applicable subpart of the regulations.
5.2 Determination of an F Factor.
Select an average F factor (Section 5.2.1)
or calculate an applicable F factor
(Section 5^2.). If combined fuels are
fired the selected or calculated^ factors
are prorated using the procedures in
Section 5-2.3. F factors are ratios of the
gas volume released during combustion
of a fuel divided by the heat content of
the fuel. A dry F factor (FJ is the ratio of
the volume of dry flue gases generated
to the calorific value of the fuel
combusted a wet F factor (F,) is the
ratio of the volume of wet Due gases
generated to the calorific value of the
fuel combusted and the carbon F factor
(FJ is the ratio of the volume of carbon
dioxide generated to tfie calorific value **The
of the fuel combusted When pollutant hydrogen
and oxygen concentrations have been
determined in Section 5.1, wet or dry F
factors are used. (Fw) factors and
associated emission calculation
procedures are not applicable and may
not be used after wet scrubbers; (Fe) or
(FJ factors and associated emission
calculation procedures are used after
wet scrubbers.) When pollutant and
carbon dioxide concentrations have
been determined in Section 5.1. F,
factors are used
5.2.1 A verage F Factors. Table 1
shows average Fd, F,, and Fe factors
(scrn/J, scf/milJion Bru) determined for
commonly used fuels. For fuels not
listed in Table 1. the F factors are
calculated according to the procedures
outlined in Section 5.2.2 of this section.
5.2.2 Calculating an F Factor. If the
fuel burned is not listed in Table 1 or if
the owner or operator chooses to
determine an F factor rather than use
the tabulated data, F factors are
calculated using the equations below.
The sampling and analysis procedures
followed in obtaining data for these
calculations are subject to the approval
of the Administrator and the
Administrator should be consulted prior
, to data collection.
227.0(M) * 9S.7(tQ + 35.4(«) + 8.6(SN) - 28.5(tO)
SCV
347.4{W)+95.7(SC)+35.4(I5)+8.6(l«)-23.5{iOH3.0(IH20)»
Tgj=y- :
For English Units:
106[5.57(tH) i- l.S3(IC) * 0.57(tS) * 0.14(«Q - 0.46(10)]
GCV
106[5.57(W)+l.S3(IC)+0.57(lS)+0.14(IN)-0.46(tO)+0.21(lH,0)**]
SCV
106C0.3Z1(IC)]
GCV
tern nay be oaltted
»nd oxygen In the
1f IH and 10 Include the unavailable
fora of H-0.
11-66-
-------
Where:
F«, F,, and Fe have the units of scm/J, or scf/
million Btu; %H. %C, %S, *N. %O, and
*H,O are the concentrations by weight
(expressed in percent) of hydrogen,
carbon, sulfuj, nitrogen, oxygen, and
water from an ultimate analysis of the
fuel; and GCV is the gross calorific value
of the fuel in kj/kg or Btu/lb and
consistent with the ultimate analysis.
Follow ASTM D 2015* for solid fuels, D
240' forliquid fuels, and D 1826* for
gaseou»3ruelg as applicable In
determining GCV.
5.2.3 Combined Fuel Firing F Factor.
for affected facilities firing
combinations of fossil fuels or fossil
fuels and wood residue, the Fd, F,, or F.
factors determined by Sections 5.2.1 or
5-2.2 of this section shall be prorated in
accordance with applicable formula as
follows:
n
*f,x>
n
I x.
dk
or
or
n
I x
k-1
kFck
"Where:
x« = Tbe fraction of total heat input derived
from each type of fuel K.
n=The number of fuels being burned in
combination.
5.3 Calculation of Emission Rate.
Select from the following paragraphs the
applicable calculation procedure and
calculate the particulate, SOj, and NOX
emission rate. The values in the
equations are defined as:
E = Pollutant emission rate, ng/J pb/million
Btu).
C«= Pollutant concentration, ng/scm (lb/scf).
Note, — It is necessary in some cases to
convert measured concentration units to *
other units for these calculations.
Use the following table for such
conversions:
Conv«r*kxi Factor* tor Concentration
from— To— Mtrtply trf—
10"
10*
i.eozxio"
2.860x10'
1.»12x10«
1^60x10-'
1.194X10-'
5.3.1 Oxygen-Based F Factor
Procedure.
5.3.1.1 Dry Basis. When both percent
oxygen (%O,I) and the pollutant
concentration (CJ are measured in the
flue gas on B dry basis, the following
equation is applicable:
Cd'Fd
20.9
20.9 - 10
2d
5.3.1.2 " Wet Basis. When both the
percent oxygen (%0,.) and the pollutant
concentration (C.) are measured in the
flue gas on a wet basis, the following
equations are applicable: (Note: Fw
^factors are not applicable after wet
scrubbers.)
/.> r - r r r 20-9 1
\mt ' *•« rw L2u.4(l - a )-lo. J
Where: -
B., = Proportion by volume of water vapor in
the ambient air.
In lieu of actual measurement, B,,
may be estimated as follows:
Note.—The following estimating factors are
selected to assure that any negative error
introduced in the term:
/ 20.9 ,
V20.9(l -~
'2ws
will not be larger than —1.5 percent.
However, positive errors, or over-
'estimation of emissions, of as much as 5
percent may be introduced depending
upon the geographic location of the
facility and the associated range of
ambient mositure.
(i) B»,=0.027. This factor may be used
as a constant value at any location.
(ii) E»,=Highest monthly average of
Bw, which occurred within a calendar
year at the nearest Weather Service
Station.
(iii] 8,,,:= Highest daily average of B^
which occurred within a calendar month
at the nearest Weather Service Station,
calculated from the data for the past 3
years. This factor shall be calculated for
each month and may be used as an
estimating factor for the respective
calendar month.
(b)
20.9
20.9
M,
Where:
B^ = Proportion by volume of water vapor in
the stack gas.
5.3.1.3 Dry/Wet Basis. When the
pollutant concentration (C,) is measured
on a wet basis and the oxygen
concentration (%O>J or measured on a
dry basis, the following equation is
applicable: x.
CwFd
20,9
L20.9 - SO
2d
When the pollutant concentration (CJ
Is measured on a dry basis and the
oxygen concentration (%O^J is
measured on a wet basis, the following
equation is applicable:
11-67-
cdFd
20.9
20.9 -
5.3.2 Carbon Dioxide-Based F Factor
Procedure.
5.3.2.1 Dry Basis. When both the
percent carbon dioxide (%COa
d c -co2d
5.3.2.2 Wet Basis. When both the
percent carbon dioxide (SCO*,) and the
pollutant concentration (C,) are
measured on a wet basis, the following
equation is applicable:
5.3.2.3 Dry/Wet Basis. When the
pollutant concentration (C») is measured
on a wet basis and the percent carbon
dioxide (%COi(J is measured on a dry
basis, the following equation is
applicable:
^Fc
' wv
100
D2d
When the pollutant concentration (CJ
is measured on a dry basis and the
precent carbon dioxide (%CO»w) is
measured on a wet basis, the foDowing
.equation is applicable:
,100
'd'1
5.4 Calculation of Emission Rate
from Combined Cycle-Gas Turbine
Systems. For gas turbine-steam
generator combined cycle systems, the
emissions from supplemental fuel fired
to the steam generator or the percentage
reduction in potential (SOi) emissions
cannot be determined directly. Using
measurements from the gas turbine
exhaust (performance test, subpart GG)
and the combined exhaust gases from
the steam generator, calculate the
emission rates for these two points „
following the appropriate paragraphs In
Section 5.3.
Note.—F. factors shall not be used to
j determine emission rates from gas turbines
because of the Injection of steam nor to
calculate emission rates after wet scrubbers;
Ft or Fe factor and associated calculation
procedures are used to combine effluent
emissions according to the procedure in
Paragraph 5i3.
The emission rate from the steam generator
it calculated as:
-------
'
Where:
EM = Pollutant emission rate from steam
generator effluent, ng/J (Ib/million Bru).
E,=Pollutant emission rate in combined
cycle effluent; ng/J (Ib/million Btu).
Ew = PoIlutant emission rate from gas turbine
effluent^ns/J (Ib/million Btu).
X,. = Fraction of total heat input from
supplemental fuel fired to the steam
generator.
X^=Fractio& of total heat input from gas
turbine exhaust gases.
Note. — The total heat input to the steam
generator is the sum of the heat input from
tupplemental fuel fired to the steam
generator and the heat input to the steam
generator from the exhaust gases from the
gat turbine.
5.5 Effect of Wet Scrubber Exhaust.
Direct-Fired Reheat Fuel Burning. Some
wet scrubber systems require that the
temperature of the exhaust gas be raised
above the moisture dew-point prior to
the gas entering the stack. One method
used to accomplish this is directfiring of
an auxiliary burner into the exhaust gas.
The heat required for such burners is
from 1 to 2 percent of total heat input of
the steam generating plant. The effect of •
this fuel burning on the exhaust gas
components will be less than ±1.0
percent and will have a similar effect on
emission rate-calculations. Because of
this small effect a determination of
effluent gas constituents from direct-
fired reheat burners for correction of
stack gas concentrations is not
necessary.
Where:
sc=Standard deviation of the average outlet
hourly average emission rales for the
reporting period; ng/J (Ib/million Bru).
», = Standard deviation of the average inlet
hourly average emission rates for the
reporting period; ng/J (Ib/million Btu).
6.3 Confidence Limits. Calculate the
lower confidencelimit for the mean
outlet emission rates for SOt and NO,
and, if applicable'the upper confidence
limit for the mean inlet emission rate for
SO, using the following equations:
T»b)« 19-1.—FFactors for Various fuels'
F.
F.
ft**.
CD*
ffcttmm* •
Lv*1*
n|b
G*c
l^fenl
Aiten«
M/i^in-'
2 ifly 10"'
10'Blu
(10100)
(9780)
(9660)
(9190)
(8710)
(8710)
(8710)
(9240)
(9600)
•son
J ,
2J3X10-'
2.86X10-'
S^1X10-'
2.77X10-'
174x10-'
2.79X10-'
md
10'Btu
(10S40)
(10640)
(11950)
(10320)
(10610)
<10200)
(10390)
•cm
J
0^30x10-'
0.484X10-'
0.513x10-'
OJ«3x10-'
0^87X10-'
0.321X10-'
OJ37X10-'
0.492X10-'
0.4S7X10-'
•d
10'Blu
(1970)
(1800)
(1910)
(1420)
(1040)
(1190)
(12SO)
(1830)
(1850)
£,* = £, -(- V-8,
Where:
E.*=The lower confidence limit for the mean
outlet emission rates: ng/J (Ib/million
Bru).
Ei* = The upper confidence limit for the mean
inlet emission rate; ng/J (Ib/million Btu).
V«.=Values shown below for the indicated
number of available data points (n):
(r.
6.31
2.42
2.35
2.13
2.02
• Aj dusfed (Cccnfng to ASTM D 388-66.
k OjOe, residual, or dsUlat*.
• Dotvmned tt EttttJarf condftcns. 2
available for reporting period.
PCC
The values of this table are corrected for
n-1 degrees of. freedom. Use n equal to
the number of hourly average data
points.
7. Calculation to Demonstrate
Compliance When Available
Monitoring Data Are Less Than the
Required Minimum
7.1 Determine Potential Combustion
Concentration (PCC) for SO,.
7.1.1 When the removal efficiency
due to fuel pretreatnaent (% R,) is
included in the overall reduction in
potential sulfur dioxfde emissions (% RO)
and the "as-fired" fuel analysis is not
used, the potential combustion
concentration (PCCJ is determined as
follows:
10'; ng/J
01 10*; Ib/m-mion Btu.
Potential emissions removed by the pretreatnent
process, using the fuel parameters defined In
section 2.3; ng/J (Ib/mllllon Btu).
11-68 '
4- 2
-------
7.1.2 When the "as-fired" fuel
analysis is used and the removal
efficiency due to fuel pretreatment (% RJ
is not included in the overall reduction
in potential ru!fur droxide emissions (%
RO), the potential combustion
concentration (PCCJ is determined aa
follows:
PCC = I.
Where:
I, = The sulfur dioxide input rate as defined
in aection 3.3
7.1.3 When the "as-fired" fuel
analysis is used and the removal
efficiency due to fuel pretreatment (% RJ
is included in the overall reduction (%
RJ, the potential combustion
concentration (PCC) is determined as
-follows:
PCC
PCC
7.1.4 When inlet monitoring data are
used and the removal efficiency due to
fuel pretreatment (% RJ is not included
in the overall reduction in potential
aulfur dioxide emissions (% RJ, the
potential combustion concentration
(PCC) is determined as follows:
Where:
EI* = The upper confidence limit of the mean
inlet emission rate, as determined in
iection 6.3.
7.2 Determine Allowable Emission
Rates [Eat].
72.1 NO*. Use the allowable v
emission rates for NO, as directly
defined by the applicable standard in '
terms of ng/J (Ib/million Btu).
7.22 SO,. Use the potential
combustion concentration (PCC) for SOi
as determined in section 7.1, to
determine the applicable emission
standard. If the applicable standard is
an allowable emission rate in ng/J (lb/
million Btu), the allowable emission rate
10'; ng/J
1b/mmion 8tu.
is" used as E^. If the applicable standard
is an allowable percent emission,
calculate the allowable emission rate
(Eua) using the following equation:
E«, = % PCC/100
Where:
S PCC = Allowable percent emissipn as
defined by the applicable standard;
percent —
7.3 Calculate EC"/Eon. To determine
compliance for the reporting period
calculate the ratio:
E.*/E«,
Where:
E.*-=The lower confidence limit for the
mean outlet emission rates, as defined in
section 6.3; ng/J (Ib/million Btu).
E^ = Allowable emission rate as defined in
section 7.2; ng/J (Ib/million Bru).
If Eo'/E,,,, is equal to or less than 1.0, the
facility is in compliance; if E.'/E^,, is greater
than 1.0, the facility is not in compliance for
the reporting period.
[FR Doc. 79-17W77 RW »-8-7B: 8:48 tm]
WLUNO COO€ (MO-OV-M
11-69-
-------
Method 20—Determination of Nitrogen
Oxides, Sulfur Dioxide, and Oxygen
Emissions from Stationary Gas Turbines
1. Applicability and Principle
1.1 Applicability. This method is
applicable for the determination of nitrogen
oxides (NO,), sulfur dioxide (SO2). and
oxygen (O:) emissions from stationary gas
turbines. For the NO, and O, determinations.
this method includes: (1) measurement
system design criteria. (2) analyzer
performance specifications and performance
test procedures: and (3) procedures for
emission testing.
1.2 Principle. A gas sample is
continuously extracted from the exhaust
stream of a stationary gas turbine; a portion
of the sample stream is conveyed to
instrumental analyzers for determination of
NO, and O, content. During each NO, and
OOi determination, a separate measurement
of SO, emissions ts made, using Method 6, or
it equivalent. The O, determination is used to
adjust the NO, and SO* concentrations to a
reference condition.
2. Definitions
2.1 Measurement System. The total
equipment required for the determination of a
gas concentration or a gas emission rate. The
system consists of tie following major
«u bsys terns:
2.1.1 Sample Inlerface. That portion of a
system that is used for one or more of the
following: sample acquisition, sample
transportation, sample conditioning, or
prelection of the analyzers from the effects of
the stack effluent.
2.1.2 NO, Analyzer. That portion of the
system that senses NO, and generates an
output proportional to the gas concentration.
2.1.3 Oi Analyzer. That portion of the
system that tenses O, and generates an
output proportional to the gas concentration,
2.2 Spen Value. The upper limit of a gas
concentration measurement range that is
specified for affected source categories in the
applicable part of the regulations.
2-3 Calibration Gas. A known
concentration of a gas in an appropriate
diluent gas.
2.4 Calibration Error. The difference
between the gas concentration indicated by
the measurement system and the known
concentration of the calibration gas.
2.5 Zero Drift. The difference in Ihe
measurement system output readings before
and after a stated period of operation during
. .M'hich no unscheduled maintenance, repair,
or adjustment took place and the input
concentration at the time of the
measurements was zero.
2.6 Calibration Drift. The difference in the
measurement system output readings before
and after a stated period of operation during
which no unscheduled maintenance, repair,
or adjustment took place and the input at the
time of the measurements was a high-level
value.
2.7 Residence Time. The elapsed time
from the moment the gas sample enters the
probe tip to the moment the same gas sample
reaches the analyzer inlet.
Z8 Response Time. The amount of time
required for the continuous monitoring
system to display on the data output 95
percent of a step change in pollutant
concentration.
2.9 Interference Response. The output
response of the measurement system to a
component in the sample gas, other than the
gas component being measured.
3. Measurement System Performance
Specifications
3.1 NO, to NO Converter. Greater than 90
percent conversion efficiency of NO, to NO.
3.2 Interference Response. Less than ± 2
percent of the span value.
3.3 Residence Time. No greater than 30
seconds.
3.4 Response Time. No greater than 3
minutes.
3.5 Zero Drift. Less than ± 2 percent of
the span value.
3.6 Calibration Drift. Less than ± 2
percent of the spsn value.
4. Apparatus and Reagents
4.1 Measurement System. Use any
measurement system for NO, and O3 that is
expected to meet the specifications in this
method. A schematic of en acceptable
measurement system is shown in Figure 20-1.
The essential components of the
measurement system are described below:
Figure 20 1. Measurement system design lor settorwy 9*5 turbines.
EXCESS
SAMPLE TO VENT
4.1.1 Sample Probe. Heated stainless
steel, or equivalent, open-ended, straight rube
of sufficient length to traverse the sample
points.
4.1.2 Sample Line. Heated (>95'C)
stainless steel or Teflon* bing to transport
the sample gas to the sample conditioners
and analyzers.
4.1.3 Calibration Valve Assembly. A
three-way valve assembly to direct the ie~Q
and calibration gases to the sample
conditioners and to the analyzers. The
calibration valve assembly shall be capable
of blocking the sample gas flow ;ind of
introducing calibration gasts to the
measurement system when in the calibration
mode.
4.1.4 NO, to NO Converter. That portion
of the system that converts the nitrogen
dioxide (NO,) in Ihe sample gas to nitrogen
oxide (NO). Some analyzers are designed to
measure NO, as NOi on a wet basis and can
be used without an NO, to NO converter or a
moisture removal trap provided the sample
line to the analyzer is heated (>95°C) to the
inlet of the analyzer. In addjlion, an NO, to
NO converter is not necessary if the NO,
portion of the exhaust gas is less than 5
percent of the total NO, concentration. As a
guideline, an NO, to NO converter is not
necessary if the gas turbine i£ operated at 90
percent or more of peak load capacity. A
converter is necessary under lower load
conditions.
4.1.5 Moislure Removal Trap. A
refrigerator-type condenser designed to
continuously remove condt;rs;jte from the
sample gas. The moisture n-mcval trap is not
necessary for analyzers thbt can measure
NO, concentrations on a wet basis: for these
analyzers, (a) heat the sample line up to the
inlet of the analyzers, (b) determine the
moisture content using methods subject to th<
approval of the Administrator, and (c) correcl
the NO, and Oi concentrations to a dry basis
4.1.8 Particulale Filter. An in-slack or an
out-of-steck glass fiber filter, of the type
specified in EPA Refrrencf MMhnd 5;
however, an out-of-stack liller is
recommended when the stark gas
temperature exceeds 250 to 300'C.
4.1.7 Sample Pump. A nonreactive leak-
free sample pump to pull the sample gas
through the system at a flow rate sufficient tc
minimize transport delay. The pump shall be
made from stainless steel or coated with
Teflon or equivalent.
4.1.8 Sample Gas Manifold. A sample gas
manifold to divert portions of the sample gas
stream to the analyzers. The manifold may be
constructed of glass, Teflon, type 316
stainless steel, or equivalent
4.1.9 Oxygen and Analyzer. An analyzer
to determine the percent O, concentration of
the sample gas stream.
4.1.10 Nitrogen Oxides Analyzer. An
analyzer to determine the ppm NO, i
concentration in the sample gas stream.'
4.1.11 Data Output. A strip-chart recorder,
analog computer, or digital recorder for 1
recording measurement data.
4.2 Sulfur Dioxide Analysis. EPA
Reference Method 6 apparatus and reagents,
4.3 NO, Caliberation Gases. The
calibration gases for the NO, analyzer may
be NO in N,. NO, in air or N,, or NO and NO,
11-70
-------
in N;. For NO, measurement analyzers lhat
require oxidation of NO to NO3. the
calibration gases must be in the form of NO
in N,. Use four calibration gas mixtures as
specified below:
. 4.3.1 High-level Gas. A gas concentration
that is equivalent to 80 to 90 percent of the
span value.
t 4.X2 Mid-level Gas. A gas concentration
tnat is equivalent to 45 to 55 percent of the
span value.
4.3.3 Low-level Gas. A gas concentration
that i, equivalent to 20 to 30 percent of the
spnn value.
4.3.4 Zero Gas. A gas concentration of
less than 0.25 percent of the span value.
Ambient air may be used for the NO, zero
g;.3.
4.4 Oj Calibration Gases. Use ambient air
at 20.9 percent as the high-level Oi gas. Use a
g.is concentration that is equivalent to 11-14
percent Oi for the mid-level gas. Use purified
nitrpuen for the zero gas.
4.5 NO,/NO Gas Mixture. For
determining the conversion efficiency of the
NO, to NO c.mverter. use a calibration gas
m:\Ujr- of NO. nnd NO in N,. The mixture
i\. .1 \;z kr.imn concenirnnons of 40 to bo ppru
NO, and Average must be 45 to 55% of span value.
c Average must be 80 to 90% of span value.
d Must be < ± 10% of applicable average or 10 ppm,
whichever is greater.
Figure 20-2. Analysis of calibration gases.
11-71
-------
S.3 Calibration Check. Conduct the
calibration checks for both the NO, and the
O, analyzers as follows:
5.3.1 After the measurement system has
been prepared for use (Section 5-2), introduce
zero gases end ihe mid-level calibration
gases; set the analyzer output responses to
the appropriate levels. Then introduce each
of the remainder of the calibration gases
described in Sections 4.3 or 4.4, one at a time,
(o the measurement system. Record the
responses on a form similar to Figure 20-3.
5.3J: If the linear curve determined from
the zero and mid-level calibration gas
Tesponses does not predict the actual
response of the low-level (not applicable for
the Oj analyzer] and high-level gases within
±2 percent of the span value, the calibration
shall be considered invalid. Take corrective
measures on the measurement system before
proceeding with the test.
5.4 Interference Response. Introduce Ihc
gaseous components listed in Table 20-1 into
the measurement system separately, or as gas
mixtures. Determine the total interference
output response of the lystem to these
components in concentration units; record the
values on a form similar to Figure 20-4. If the
sum of the interference responses of the lest
gases for either the NO, or O, analyzers is
greater than 2 percent of the applicable span
value, take corrective measure on the
measurement system.
T«W« 20-1.— Interference Test Gas Concentration
CO-
SO,.
CCs-
Cs-
500 -M ppm.
?00-SOppm.
10± I percent.
........ ___ ......... K 9 ± 1
percent
Ari.H,/--i i«ui|*«l
Turbine type:,
Date:
Identification number.
Test number
Analyzer type:.
Identification number.
Cylinder Initial analyzer Final analyzer Difference:
value, response, responses, initial-final,
ppm or % ppm or % ppm or % ppm or %
Zero gas
Low - level gas
Mid - level gas
High • level gas
Percent drift =
Figure 20-3.
Absolute difference
X 100.
Span value
Zero and calibration data.
Conduct an interference response test of
each analyzer prior to its initial use in the
field. Thereafter, recheck the measurement
system if changes are made in the
instrumentation that could alter the
Interference response, e.g., changes in the
type of gas detector.
In lieu of conducting the interference
response test, instrument vendor data, which
demonstrate that for the tesl gases of Table
20-1 the interference performance
specification is nol exceeded, are acceptable.
5.5 Residence and Response Time.
5,5.1 Calculate the residence time of the
sample interface portion of the measurement
system using volume and pump flow rate
information. Alternatively, if the response
time determined as defined in Section 5.5.2 is
less than 30 seconds, the calculations are not
necessary.
5-5.2 To determine response time, first
introduce zero gas into the system at the
11-72
-------
calibration valve until all readings are stable;
then, switch to monitor the stack effluent
until a stable reading can be obtained.
Record the upscale response time. Next.
introduce high-level calibration gas into the
system. Once (he system has stabilized at the
high-level concentration, switch to monitor
the stack effluent and wait until a stable
value is reached. Record the duwnscale
response time. Repeat the procedure three
times. A stable value is equivalent to a
change of less than 1 percent of span value
for 30 seconds or less than 5 percent of the
measured average concentration for 2
minutes. Record the response time data on a
form similar to Figure 20-5, the readings of
the upscale or downscale reponse time, and
report the greater time as the "response time"
for the analyzer. Conduct a response time
test prior to the initial field use of the
measurement system, and repeat if changes
are made in the measurement system.
Date of test.
Analyzer type.
S/N
Span gas concentration.
Analyzer span setting_
Upscale
1.
2
3.
. ppm
.seconds
.seconds
.seconds
Average upscale response.
1
Downscale 2.
3
.seconds
.seconds
.seconds
.seconds
Average downscale response.
seconds
System response time = slower average time = seconds.
Figure 20-5. Response time
5.6 NO, NO Conversion Efficiency. '
Introduce to fhe system, at the calibration
valve assembly, the NO=/NO gas mixture
[Section 4 5). Record the response of the NO,
an.,|\ ™- If thf instrument response indices
less li.jn «) l'-TC«nt N0= to NO cnm-pion.
make correctums to the Masuremenl system
and repeat the check. Alternatively, the NO,
to NO converter rheck described in Title 40
Part 80- Certification and TVs/ Procedure* for
Heavy-Duty Engines for 19& and Later
Model Years may be used. Other alternate
procedures may be used with approval of the
Administrator.
6. Emission Measurement Test Procedure
6.1 Preliminaries.
6.1.1 Selection of a Sampling Site. Select a
sampling site as close as practical to the
exhaust of the turbine. Turbine geometry,
stack configuration, internal baffling, and
point of introduction of dilution-air will vary
for different turbine designs. Thus, each of
these factors must be given special
consideration in order to obtain a
representative sample. Whenever possible,
the sampling site shall be located upstream of
the point of introduction of dilution air into
the duct. Sample ports may be located before
or after the upturn elbow, in order to
accommodate the configuration of the turning
varies and baffles and to permit a complete,
unobstructed traverse of the stack. The
sample ports shall not be located within 5
feet or 2 diameters (whichever is less) of the
gas discharge to atmosphere. For
supplementary-fired, combined-cycle plants,
the sampling site shall be located berween
the gas turbine and the boiler. The diameter
of the sample ports shall be sufficient to
allow entry of the sample probe1.
6.1.2 A preliminary Oi traverse is made
for the purpose of selecting low O3 values.
Conduct this test at the turbine condition that
is the lowest percentage of peak load
operation included in the program. Follow the
procedure below or alternative procedures
subject to the approval of the Administrator
may be used:
6.1.2.1 Minimum Number of Points. Select
a minimum number of points as follows: (1)
eight, for stacks having cross-sectional areas
less than 1.5 m: (16.1 ft1): (2) one sample point
for each 0.2 m-(2.2 ft*of areas, for stacks of
l.S m' to 10.0 m1 [16.1-107.6 ft*) in cross-
sectional area; ar.d (3) one sample point for
each 0.4 m" (4.4 ft-") of area, for stacks greater
than 10.0 m * (107.6 ft ^ in cross-sectional
area. Note that for circular ducts, the number
of sample points must be a multiple of 4. and
for rectangular ducts, the number of points
must be one of those listed in Table 20-2;
therefore, round off the number of points
(upward), when appropriate.
6.1.2.2 Cross-sectional Layout and
Location of Traverse Points. After the number
of traverse points for the preliminary OJ
sampling has been determined, use Method 1
to located the traverse points.
8.1.2.3 Preliminary OJ Measurement.
While the gas turbine is operating at the
lowest percent of peak load, conduct a
preliminary O1 measurement as follows:
Position the probe at the Erst traverse point
and begin sampling. The minimum sampling
time at each point shall be 1 minute plus the
average system response time. Determine the
average steady-state concentration of O2 at
each point and record the data on Figure 20-
6.
6.1.2.4 Selection of Emission Test
Sampling Points. Select the eight sampling
points at which the lowest O' concentration
were obtained. Use these same points for all
the test runs at the different turbine load
conditions. More than eight points may be
used, if desired.
Tabl« 2Q-2.—Crcss-s&:tx>f>al Lerovt tor
tecxs
No
Ot traverse pctfrti;
<>
1j
IS
M
25.
30 _
36
42
O
MM-
tarn.
3
4
*
S
K
K
7
7
II--73
-------
Date.
Pljnt
City, State
Turbine identification:
Manufacturer
Model, serial number.
Sample point
Oxygen concentration, ppm
Figure 20-6. Preliminary oxygen traverse.
6.2 NO, and O» Xfeasurement. This lest is
to be conducted at each of the specified load
conditions. Three tfistruas at each load
condition constitute a complete test.
6.2.1 At the beginning of each NO, test
run and, as applicable, during the run, record
turbine data as indicated in Figure 20-7. Also,
record the location and number of the
traverse poinU on a diagram.
SLLLINC CODE « 560-01-W
6.2.2 Position the probe at the tirst point
determined in the preceding section and
begin sampling. The minimum sampling time
at each point shall be at least 1 minute plus
the average system response time. Determine
the average steady-state concenlralion of O,
end ,N'O, at each point and record the data on
Figure 20-8.
IIr-74
-------
Test operator
I
Turbine identification:
Tyfie
Serial No
Location:
Plant
City
TURBINE OPERATION RECORD
Date-
Ultimate fuel
Analysis C
H
N
Ambient temperature.
Ambient humidity
Test time start
Ash
H2O
Trace Metals
IMa
Test time finish.
Fuel flcxv ratea_
Va
etcu
Water or steam.
Flow rate3
Ambient Pressure.
Operating load.
aDescribe measurement method, i.e., continuous flow meter,
Start finish volumes, etc.
bi.e.. additional elements added for smoke suppression.
Figure 20-7. Stationary gas turbine data.
Turbine identification:
Manufacturer . _
Test operator name.
Model, serial No.
Location:
Plant
City, State
Ambient temperature
Ambient pressure
Date _
Test time • start
Test time finish
O2 instrument type _
Serial No
NOX instrument type.
Serial No
Sample
point
•
^tMf-p
"
Time,
min.
j
of-
%
NO;.
ppm
3Average steady-state value from recorder
instrument readout
or
BILLING CODE 6550-01-C
Figure 20-8. Stationary gas turbine sample point record.
11-75
-------
6.2.3 After sampling the last point,
conclude the test run by recording the final
turban; operating parameters and by
detenr.ining the zero and calibration drift, as
follows:
Immediately following the test ran at each
load condition, or if adjustments are
necessary for the measurement system during
the tests, (^introduce the zero and mid-level
cahbrd::on ^ases as described in Sections 4.3,
and 4.4. orts at a time, to the measurement
system alThe calibration valve assembly.
(Ma*e .notdjustments to the measurement
system ur.til after the drift checks are made].
Record the analyzers' responses on a form
similar to Figure 20-3. If the drift values
exceed the specified limits, the test run
preceding the check is considered invalid and
will be repeated following conections to the
measurement system. Alternatively, the test
results may be accepted provided the
measurement system is recalibrated and the
calibration data that result in the highest
corrected emission rate are used.
6.3 SO, Measurement. This test is
conducted only at the 100 percent peak load
condition. Determine SO, using Method 6, or
equivalent, during the lest Select a minimum
of six total points from those required for the
NO, measurement*; use two points for each
sample run. The sample time at each point
shall be at least 10 minutes. Average the O,
readings taken during the NO, test runs at
sample points corresponding to the SOj
traverse points (see Section (L2.2) and use
this average O, concentration to correct the
integrated SO> concentration obtained by
Method 6 to 15 percent O, (see Equation 20-
!)•
If the applicable regulation allows fuel
sampling and analysis for fuel sulfur content
to demonstrate compliance with sulfur
emission unit emission sampling with
Reference Mt Jjod 6 is nol required, provided
the fuel sulfur content meets the limits of the
regulation.
7. Emission Calculations
7.1 Correction to 15 Percent Oxygen.
Using Equation 20-1, calculate the NO, and
SO, concentrations (adjusted to 15 percent
, O;). The correction to 15 percent Oz is
sensitive to the accuracy of the O,
measurement. At the level of analyzer drift
specified in the method (±2 percent of full
scale], the change in the O: concentration
correction can exceed 10 percent when the O,
content of the exhaust is above 16 percent O,.
Therefore Oj analyzer stability and careful
calibration are necessary.
5_J.' (Equation 20-1)
Where:
C^u~Pollutant concentration adjusted to
15 percent O, (ppm)
C^-u = Pollutant concentration measured,
dry basis (ppm)
5.9=20.9 percent O,-15 percent O,, the
defined O, correction basis
Percent O, = Percent O, measured, dry
basis (%)
7.2 Calculate the average adjusted NO,
concentration by summing the point values
and dividing by the number of sample points.
8. Citations
8.1 Curtis, F. A Method for Analyzing NO,
Cylinder Gases-Specific Ion Electrode
Procedure, Monograph available from
Emission Measurement Laboratory, ESED,
Research Triangle Park, N.C. 27711, October
1978.
[FR Doc. 79-27933 Filed 9-7-79. 8:
-------
NCi Srtcrrrc»noNS
Performance Specification 1—Performa»ce
specifications and specification test proce-
dures for tranimisaometer systems for con-
tinuous measurement of the opacity of
•tick emissions .
1. Principle and Applicability.
1 1 Principle The op«clry of paniculate
matter In stack emissions Is measured by a
continuously operating emission measure-
ment system. These systems are based upon
the principle of transmlssometry which Is a
direct measurement of the attenuation cf
visible radiation (opacity) by paniculate
matter In a stack effluent. Light having spe-
cflc spectral characteristics If projected from
a lamp across the stack of a pollutant source
to a light sensor. The light Is attenuated due
to absorption and scatter by the paniculate
matter In the effluent The percentage of
visible light attenuated Is defined as the
opacity of the emission. Transparent stack
emissions that do not attenuate light will
have a transmlttance of 100 or an opacity of
0. Opaque stack emissions that attenuate all
Of the visible light will have a transmlttance
of 0 or sn opftclty of 100 percent. The trs,ns-
mlssometer Is evaluated by use of neutral
density niters to determine the precisian of
the continuous monitoring system. Tests of
the system are performed to determine zero
drift, calibration drift, and response time
characteristics of the system.
1.2 Applicability. This performance spe-
cification Is applicable to the continuous
monitoring systems specified In the subparts
Jor measuring op&clty cf emissions. Specifi-
cations tor continuous measurement of vis-
ible emissions are elven In terms of design.
performance, and Installation parameters.
These specification* contain test procedures.
Installation requirements, and data compu-
tation procedures .for evaluating the accept-
ability of th* continuous monitoring systems
subject to approval by the Administrator.
2. Apparatus.
2.1 Calibrated Filters. Optical filters with
neutral spectral characteristics and known
optical densities to risible U^ht or screens
toovn to produce specified optical densities.
Calibrated filters with accuracies certified by
the manufacturer to within ±3 percent
opacity chsjl be used. Filters required are
low, mid, and hlRh-range filters with nom-
inal optical densities as follows when the
transmlssometer is spanned at opacity levels
specified by applicable subparts:
Calibrated filler oDUcal densiricj
will/ «julr»ltni opiciry In
8p«n Ttluf parenthesis
60
60
TO
M
W
100
Low- M1
.1 (20)
) (20)
1 (20)
2 (ST)
» (SO)
> (SO)
4 (60)
«
Hlch-
nncr
as (so
.1 (SO)
.4 w:
.6 (Ti)
.1 <&'
.« <£7H>
It Is recommended that filter calibrations
b«. checked with a well-colllmited pbotoplc
transmlssometer of tnown linearity prior to
use. The filters shall be of sufficient size
to attenuate the entire light beam of the
transmlssometer.
3.2 Data Recorder. Analog chart recorder
or other suitable device with Input voltage
range comestible with the analyzer system
output. The resolution of the recorder's
data output shall be sufficient to allow com-
pletion of the test procedures wltiln this
»pedfl cation.
2.3 Opacity measurement System. An In-
st»ck trsnsmlssometer (folded or single
p«th) with the optical design specifications
designated balow, associated control units
and apparatus to keep optical surfaces clean.
S. Definitions.
3.1 Continuous Monitoring System. The
total equipment required for the determina-
tion of pollutant opacity In a source effluent
Continuous monitoring systems consist of
major subsystems as follc-ws:
1.1.1 Sampling Interface. The portion of a
continuous monitoring system for opacity
that protects the analyser from the effluent.
2.12 Analyzer. That portion of the con-
tinuous monitoring system which senses the
pollutant and generates a signal output thai.
Is a function of the pollutant opacity.
3.1 J Date Recorder. That portion of the
continuous monitoring system that processes
the analyzer output and provides a perma-
nent record of the output signal In terms of
pollutant opacity.
3.2 Transmtssometer. The portions of s,
continuous monitoring system 'or opacity
that Include the campling Interface end the
analyzer.
33 Span. The value of opacity at •which
the continuous monitoring system is set to
produce the maximum data display output.
Toe span shall be set at an opacity specified
In each applicable subpart.
3.4 Calibration Error. Tbe difference be-
tween the opacity reading Indicated by the
continuous monitoring system and the
known values of a •series of test standards
Por this method the test standards are a
•ertes of calibrated optical filters or screens.
3.5 Zero Drift. The change in continuous
monitoring system output over a stated pe-
riod of time of normal continuous operation
wheai tbe pollutant concentration at the
dm* of ttoe measurement* U Kro
*.« Calibration Drtrt. Tbe obange in the
continuous monitoring system output over
a stated period of time of normal continuous
operation when the pollutant concentration
at the time of the measurements Is the same
known upscale value.
3.7 System Response. The time Interval
from a step change io opacity In the stack
at the input to the continuous monitoring
system to the time at which 95 percent of
the corresponding flnal value Is reached as
displayed on tbe continuous monitoring sys-
tem data recorder.
3.8 Operational Test Period. A minimum
pertod of time over which a continuous
monitoring system it expected to operate
within certain performance specifications
without unscheduled maintenance, repair.
or adjustment.
SJ3 Transmlttance. The fraction of incident
light that it transmitted through an optical
medium of Interest.
8.10 Opacity. The fraction of Incident light
that Is attenuated by an optical medium of
Interest. Opacity (O) and transmlttance (T)
»r» related a/ follows:
• 3.11 Optical Density A logarithmic meas-
ure of the amount of light thst It attenuated
by an optical medium of Interest. Optical
density (D) is related to the transmlttance
and opacity as follows:
D=-log,0T
D= -log,, (1-0)
S.1J Peak OptlcaJ Response. The wave-
length of maximum aensltlvljy. of the Instru-
ment.
3.13 Mean Spectral Response. The wave-
length which bisects the total area under
The curve obtained pursuant to paragraph
• J.I.
J.14 Angle of View. The maximum (total)
angle of radiation detection by the photo-
detector assembly of the analyzer.
8. IS Angle of Projection. The maximum
ftotal) angle that contains 85 percent of
tbe radiation projected from the lamp assem-
bly of the analyeer.
11-77
«.!« F»thJ«nfth. The d«pth of effluent In
OM Ught to**™ between the receiver and the
transmitter of the single-pass transmlssom-
•ter, or the depth of effluent between the
transceiver and reflector of a double-pass
traosmla&ometer. Two pathlengths are refer-
«nced by this specification'
8.18.1 Monitor Pithlength. The depth of
•fluent at the Installed location of the con-
tinuous monitoring system.
3.165 Emission Outlet Pathlenjgth The
depth of effluent it the location emissions are
released to the atmosphere
4. Installation Speclflcstlon,
4.1 Location. The tranamlssometer must
be located across » section of duct or stack
that will provide a paniculate matter flow
through the optical volume of the trans-
mlosometer that Is representative of the par-
Uculate matter flow through the duct or
•tack. It Is recommended that the monitor
p*thlength or depth of effluent for the trans-
miseometer Include the entire diameter of
the duct or stack. In Installations using a
shorter pathlength, extra caution must be
u»ed In determining the measurement loca-
tion representative of the paniculate matter
flow through the duct or stack.
4.1.1 The transmlasometer location shall
be downstream from all paniculate control
equipment.
4.1.2 The transmlssometer shall be located
as far from bends and obstructions as prac-
tical.
4.1.3 A transmlssometer that Is located
In the duct or stack following a bend shall
be Installed In the place denned by the
bend where posclble.
4.1.4 .The tranamluometer should be In-
stalled In an accessible location.
4.1.5 When required by the Administrator.
the owner or operator of a source must
demonstrate that the tranamlssometer Is lo-
cated In a section of duct or stack where
a representative paniculate matter distribu-
tion exists. The determination shall be ac-
complished by examining the opacity profile
of the effluent at a series of positions across
the duct or stack while the plant Is In oper-
ation at maximum or reduced operating rates
or by other tests, acceptable to the Adminis-
trator. .
4.2 Slotted Tube. Installations that require
the UK of a slotted tube shall use a slotted
tube of sufficient size and blackness so as
not to Interfere with the free flow of effluent
through the entire optical volume of the
transmlssometer or reflect light Into the
transmlssometer photodetector. Light re-
flections may be prevented by using black-
ened baffles within the slotted tube to pre-
vent the lamp radiation from Impinging upon
the tube walls, by restricting the angle of
projection of the light and the angle of view
of the photodetector assembly to less than
the cro&s-sectlonal area of the slotted tube.
or by other methods The owner or operator
must show that the manufacturer of the
monitoring system has used appropriate
methods to minimize light reflections for
systems using slotted tubes.
4.3 Data Recorder Output. The continuous
monitoring system output shall permit ex-
panded display of the span opacity on a
»t*ndard 0 to 100 percent scale. Sine* all
opacity standards are based on the opacity
of the effluent exhausted to the atmosphere
the system output shall be based upon the
emission outlet pathlength and permanently
recorded. Por affected facilities whose moni-
tor pathlength Is different from the facility's
emission outlet pathlength, a graph shall be
provided with the Instillation.to show the
relationships between the continuous moni-
toring system recorded opacity based upon
th* emission outlet pathlength and the opac-
ity of th» effluent at the analyzer location
.(monitor pathlength). Teats for measure-
ment of opacity that are required by this
performance specification are based upon the
-------
iBonitor pathlength. The graph an 'miry to
eon nit the data r*oord«r output to the
•oojvor p»tnleneth -basis stall b* «*t»Aliah»d
M follows :
Joe (1-0,) -(U/U) k« (1-*)
vhvre:
0, = the opacity of the effluent based upon
*r
^0, = the opacity of the effluent baaed upon
lr
l, = the etnluton outlet pathlength.
l,= the monitor pathlength.
B. Optical Design Specifications.
The optical de«lgn specifications set forth
In Section 8.1 shall be met In order for *
measurement system to comply with the
requirements of this method.
6. Determination of Conformanee with De-
cifications
oenterllne of projection. Repeat the test in
the vertical direction
T. Continuous Monitoring BrTtem Per-
formance Specification!
The continuous monitoring system shall
meet the performance specifications In Table
1-1 to be considered acceptable under this
method
1-1. — PerfnTmnnrr
gn Speci
o.l Tie
.l Tie continuous monitoring system for
measurement of opacity ahall be demon-
Rrated to conform to the design speciflca-
Uons Kt forth as follows:
6.1.1 Peak Spectral Response. Tbe peak
•pectrsl response of the continuous moni-
toring systems shall occur between 500 run
and 900 nm. Response at any wavelength be-
low MO nm or above 700 nm shall be le*s
than 10 percent of the peak response of the
continuous monitoring system.
6.1.2 Mean Spectral Response. The mean
spectral response of the continuous monitor-
ing system shall occur between 600 nm and
«PO nm.
«.l J Angle of View. The total angle of Tlew
•hall be no greater than 6 degrees
1.1.4 Angle of Projection Tbe total angle
•f pro>ection shall be no greater Uxac 4 de-
gress.
6.2 Conformant* with tbe requirements
of ae'ctlon 6.1 may be demonstrated by the
owner or operator of the affected facility by
testing each analyzer or by obtaining a cer-
tificate of conformance from the Instrument
manufacturer. The certificate must certify
that at least one analyzer from each month's
production was tested and satisfactorily met
ill applicable requirements. The certificate
must state that the first analyzer randomly
sampled met all requirements of paragraph
6 of this specification If »ny of the require-
ments were not met, the certificate must
show that the entire month's auaJyzer pro-
duction was resAmpled according to the mili-
tary standard 105D sampling procedure
(VCL-STD-IOSD) Inspection level H; was re-
teeted for each of the applicable require-
ment* under paragraph 6 of this specifica-
tion; and was determined to be acceptable
under MTb-STD-lOSD procedures. The certifi-
cate of conformsnce must anew the results
of each test performed for the analyzers
sampled during the month the analyxer be-
ing installed wsj produced.
6J The general test procedures to be fqj-
lowed to demonstrate oonfonnance with Sec-
tion 8 requirements are given as follows
(These procedures will not be applicable to
all design* and will require modification In
some cases. Where analyzer and optical de-
sign Is certified by the manufacturer to con-
form with the angle of view or angle of pro-
jection specifications, the respective pro-
c»dures may be omitted.)
6.3.1 Spectral Response. Obtain spectral
data for detector, lamp, and filter components
t»«ed In the measurement system from their
respective manuf scturers. .
6.3.2 Angle of View. Bet the received up
as specified by the manufacturer. Draw an
arc with radius of 3 meters. Measure the re-
oelver response to a small (less than 3
centimeters) nac-dlre:tlona] lUht source »t
•4-centimeter Intervals on the arc for 36 centi-
meters on either side of the detector center-
line. Repeat the test In the vertical direction.
6.3 3 Angle of Projection. Set the projector
up at specified by the manufacturer. Draw
an arc with radius of 3 meters Using a small
photoelectric light detector (less than 3
centimeters), measure the light Intensity at
l-centlmeter Intervals on the arc Tor M
centimeters on either side of the Ught source
a. .Calibration «rror <3 pet opacity.1
b Zwoartli (24 h) <5 Pet opaeliv '
e.Callbrstlon drift (24 h) <2 pet oparltv i
d. Respon* Urne 10 s (maiimum)
a. Operations! tot period 1*3 h.
' Expressed as mm of absolute mean value and the
M pet confidence Interval of > series of tests.
8. Performance Specification Test Proce-
dures. The following test procedures shall be
osed to determine conformance with the re-
quirements of paragraph 7:
t.l Calibration Error and Response Time
T«st. These tests are to be performed prior to
Installation of the system on the stack and
m«y be performed at the affected facility or
at other locations provided that proper notlfl-
oation Is given. Set up and calibrate the
measurement system as specified by the
manufacturer's written Instructions for the
monitor pathlength to be used In the In-
stallation. Span the analyzer as specified In
applicable rubparts.
8.1.1 Calibration Error Test. Insert a series
of calibration filters In the transmlasometer
path at the midpoint. A minimum of three
calibration filters (low, mid, and high-
range) selected In accordance with the table
under paragraph 2.1 and calibrated -within
3 percent must be used Make a total of five
nonconsecutlve readings for e»ch filter.
Record the meas-urement system output
readings in percent opacKv. (See Figure 1-1.)
8.1.2 "System Response T?st. Insert the
high-range filter In the transmissometer
path five tiroes and record the time required
for the system to respond to 85 percent of
final zero and hign-ringe filter values. (See
Figure 1-2.)
8.2 Field- Test for Zero Drift and CeJlbra-
tion Drift. Install the continuous monitoring
syrtem on the affected facility and perform
the following alignments:
8.2.1 Preliminary Alignments. As soon as
possible after Installation and once a year
thereafter wbtn the facility Is not In opera-
tion, perform the following optical and lejc
alignments:
8.2.1.1 Optical Alignment. Align the light
beam from the trausml&someter upon the op-
tical surface-s located across the effluent (I-*,
the retroflector or pbotodflector a> applica-
ble) in accordance with the manufacturer's
instructions.
8-2.1.2 £ero Alignment. After the trancmls-
someter has been optically aligned and tbe
trsusmlisorneter mounting Is mechanically
stable (I.e.. no movement of the mounting
due to thermal contraction of the stack.
duct, etc.) and a clean stack condition has
been determined by a steady tero opacity
condition, perform the zero alignment. This
alignment is performed by balancing the con-
tinuous monitor system response so that any
simulated tero check coincides with an ac-
tual zero check performed across the moni-
tor pathlength of th» clean stack.
8-2.1.3 Spr-a. Span the continuous monitor-
Ing sy-tcm at the opacity specified In sub-
paru and ofT&el tbe tero setting at least 10
percent ol span so that negative drift can be
quantified.
8.2.2. Final Alignment*. Alter the prelimi-
nary alignments buve been completed and the
affected facility liaj been started up and
reaches normal operating temperature, r«-
checi; the optical alignment In accordance
with 8.2.1.1 of this specification" If the align-
ment has shifted, realign the optics, record
»ny detectable ahlf t In the opacity measured
by the system that can be attributed to the
optical realignment, and notify the Admin-
istrator. This condition may not be objec-
tionable If tbe a3ecte
-------
Values for t.975
2
a
•4
5
(1
7
»
n «.S7S
12 70K
4 J03
a is-
2 776
... J 571
7 *47
2.J65
2,100
n
10
11
1°
13
14
15
16
'.975
Z 242
2. 228
2 201
2. 17fl
2- 1W
2 145
2, J31
B.2 DiU Analysis and Reporting
8.2.1 Spectral Response Combine the'
tpwctra] dtu obtained ID accordance with
paragraph 6.3.1 to develop the effective spec-
tral response curve of tbe transmlssometer.
Report the wavelength at which the pe»k
response occurs, the wavelength at which the
me in responif oceun, and the maximum
response at an; wavelength below too nm
aud above 700 am expressed a* a percentage
of the peak response a* required under para-
praph 6.2.
9.13 Angle of View Using the data obtained
In accordance with paragraph 6.3.2. calculate
the response of the receiver as a function of
viewing angle ID tbe horizontal and vertical
directions (26 centimeters of arc with a
radlvu of 3 meters equal 5 degrees). Repcrt
relative angle of view curves as required un-
der paragraph 6-2.
8.2.3 Angle of Projection TJilng the data
obtained In accordance with paragraph 6.3.3,
calculate the res-sons* of the photoelectric
detector as a function of projection angle Ln
tbe horizontal and vertical directions. Report
relative angle of projection curves as required
under paragraph 6.2.
9.2.4 Calibration Error. Using the data from
paragraph 8.1 (ficure 1-1). subtract ihe
kno«-n filter opacity value from the value
shown by the measurement system for each
of the 15 readings. Calculate the mean ind
85 percent confidence interval of tbe five dif-
ferent values at each t«st filter value accord-
Low
Range I
Span Value
opacity
I opacity
Mid
Range I opacity
High
Range X opacity
I
Date of Test
Location of Test
Calibrated Filter
Analyzer Reading
I Opacity
Differences
'. Opacity
8_
9_
12.
n
15
Vean difference
Confidence Interval
Calibration error «
Low
Hid
High
Difference + C.I.
Low, nld or high range
^Calibration filter opacity - analyzer reiding
Absolute
Figure 1-1. C*litrat1or. Error Test
ing to equations 1-1 and 1-2. Report the si:tn
of tbe absolute meac dlJfrence and the 95
percent confidence Interval for each of tbe
'three t«t filters
Zero Drift Dstng the tero opacity
values measured every 2< hours during the
field test (paragraph Si), calculate the dif-
ferences between the zero point after clein-
Ing. aligning, and adjustment, and the zero
value 24 hours later Just prior to detnjng.
allfnlnp. and idjustmeot CaJculate the
mean value of these points s J the confi-
dence Interval using equations 1-3 and 1-2
Report the sum of the absoluu mean value
and the 95 percent confidence Interval.
9.2.6 Calibration Drift. Using the spin
value measured every 24 hours during the
field test. calcul&t« the differences between
the span ralue after cleaning, aligning, and
adjustment of zero aad span, and tbe spir.
value 24 hours later Just after clearjr.p
aligning, and adjustment of zero and be.'cre
adjustment of spen. Calculate the mecr.
value of these points and the wmf.dt:-.cc
Interval using equations 1-1 and 1-2. Report
the sum of the »bsolute mean value and the
confidence Interval.
921 Response Time. Using the data from
paragraph 8.1, calculate the time Interval
from filter Insertion to 95 percent of the final
stable value for all upscale and dos-nsca'ie
traverses. Report the mean of the 10 upscale
and dowrmcale test times.
92A Operational Tsst Period. During the
168-hour operational test period, the con-
tinuous monitoring system shall not require
any corrective maintenance, repair, replace-
ment, or adjustment other than that clearer
specified as required In the manufacturer's
operation and maintenance manuals as rou-
tine anci expected during a one-week period.
If the continuous monitoring system Is oper-
ated within the specified performance pa-
rameters and does not require corrective
maintenance. rtpaU. replacement, or adjust-
ment other than as specified above during
the 168-hour test period,, the operational
test period shall have been successfully con-
cluded Failure of the continuous monitor-
ing system to meet tbes< requirements shall
call for a repetition of the 16S-houj test
period Portions of the t«sts which were sat-
isfactorily completed need not be repeated.
Failure to meet any performance specifics-
tlon(s) shall call for a repetition of the
one-weelc operational test period and that
specific portion of the tests required by
parigrspb 8 related to demonstrating com-
pliance with the failed specification. All
maintenince and adjustments required shall
b« recorded Output readings sial! be re-
corded before and alter all adjustments.
10 Re f err n CM
10.1 "ExtxrimenUJ StittrUcs," Department
of Commerce. National Bureau of Standards
Handbook PI, 1963. pp. S-31, paragraphs
l6i '"Performance Specifications for Sta-
tionary-Source Monitoring Systerci for Gases
and Visible Emissions." Environmental Pro-
tection Agency. Rewarcb TTlaxiRle
NX!, £PA-6iO/2-7«-01J, January 1974.
11-79
-------
Tot
Spm
04tt Ze
and flef
Tl«c ivi
1m Drift ' (AfVr clein<»9 «"< wo
•(tZtre) but <*forc «[>4n in of a pollutant gas concentration In a
aource effluent. Continuous monitoring sys-
tems consist of major subsystems as follows:
3.1.1 Sampling Interface—That portion of
an extractive continuous monitoring system
that performs one or more of the following
operations: acquisition, transportation, and
conditioning of a sample of the source efflu-
ent or that portion of an Ln-sltu continuous
monitoring system that protects the analyzer
from the effluent.
3.1.2 Analyzer—That portion of the con-
tinuous monitoring system which senses the
pollutant gas and generates a signal output
that Is a function of the pollutant concen-
tration.
3.1.3 Data Recorder—That portion of the
continuous monitoring system that prorldes
a permanent record of the output sign*! In
terms of concentration units.
3.2 Span. The value of pollutant concen-
tration at which the continuous monitor-
Ing system Is set to produce the maximum
data display output. The span shall be set
at the concentration specified in each appli-
cable subpajt.
3.3 Accuracy (Relative). The degr«* of
correctness with which the contlnuou*
monitoring system yields the value of fa*
concentration of a sample relative to tb«
value given by a define*! reference method.
TJils accuracy U expressed in terms of error.
which k the dlffareoce between the paired
concentration measurement* expressed a* a
fwoentage of the m»an reUreno* value.
1.4 Oallbr»tl6n «rror. Tbe difference b«-
t»»en the pollutant concentration Indl-
e»ted by the continuous monitoring system
•cd the known concentration of the test
(M mixture.
1.6 Zero Drift. The change In the conttnu-
ous monitoring system output over a stated
period of time of normal continuous opera-
tion when the pollutant concentration at
tt» time for the measurements is zero.
3.8 Calibration Drift. The change in the
continuous monitoring system output over
a rteted time period of normal continuous
operations when the pollutant concentra-
tion at the time of the measurements Is the
•tone XDOWTJ upscale value ~
i.7 Response Time. Tbe time Interval
from a step change in pollutant concentra-
tion at the Input to the continuous moni-
toring system to the time at which 85 per-
cent of the corresponding final value is
reached as displayed on the continuous
monitoring system d»ta recorder.
1.8 Operational Period. A minimum period
of time over which a measurement system
I* expected to operate within certain per-
formance specifications without unsched-
uled maintenance, repair, or adjustment
3.9 Stratification. A condition identified
toy a difference In excess of 10 percent be-
tween the average concentration in the duct
or itack and the concentration at any point
more than 1.0 meter from the duct or stack
wall.
4. Installation Specifications Pollutant
continuous monitoring systems (SO, and
NO,) shall be Installed at a sampling loca-
tion where measurements ?-«" be made which
are directly representative (4.1), or which
can be corrected so as to be representative
(4.2) of the total emissions from the affected
facility Conformance with this requirement
ahall be accomplished as follows:
4.1 Effluent gases may be assiamed to be
•onstratlned If a sampling location eight or
more stack diameters (equivalent diameters)
downstream of any air in-leakage Is se-
lected. This assumption and data correction
procedures under paragraph 4.2.1 may not
be applied to sampling locations upstream
of an air preheater in a «te&m generating
facility under Subpart D of this part. For
•ampllng locations where affluent gases are
either demonstrated (4.3) or may be as-
mmed to be nonstratlfied (eight diameters).
a point (extractive systems) or path (In-sltu
•ystems) of average concentration may be
monitored.
4.3 For sampling locations where effluent
Cases cannot be assumed to be nonstratl-
flsd (less than eight diameters) or have been
ahown under paragraph 4J to be stratified,
results obtained must be consistently repre-
sentative (e.g. a point of average concentra-
tion may shift with load changes) or the
data generated by sampling at a point (ex-
tractive systems) or across a path (In-sltu
lystems) must be corrected (4.2.1 and 4.2.2)
•o as to be representative of the total emls-
aloni from the affected facility. Conform-
ance with this requirement may be «ccom-
pllahed in either of the following ways:
4.2.1 Installation of a diluent continuous
monitoring system (O. or CO. as applicable)
IB accordance with the procedures under
paragraph 4.2 of Performance Specification
I of this appendix. If the pollntant and
diluent monitoring systems are not of the
•ame type (both extractive or both In-situ),
ttn extractive system must use . multipoint
probe.
4.3.2 Installation - of extractive pollutant
monitoring systems using multipoint sam-
pling probes or lo-situ pollutant monitoring
•Totems that sample or view emissions which
ar» eonrtite-otly representative of the total
emisaaoru for the entire cross «ectlon. The
Administrator may require data to be tub-
11-80
-------
mlttad to demonstrate that the
aaxnpltd or vl»w»d art con*l»t*ntly r«pr*-
MOUClTe for aeveral typical facility procw*
operating conditions.
4-3 The owner or opermtor may perform a
traverse to characterize any atratlncatlon or
effluent gases that might exut la a stack or
duct. If no stratification Is present, sampling
procedures under paragraph 4.1 may be ap-
plied even though th* eight dLameter criteria
b not met.
4.4 When tingle point sampling probes for
•xtractlT* lyatama ire Installed within tbe
•tack or duct under paragraph! 4.1 and 4 J.I.
tb« aampl* may not be extracted it any point
lesa than 1.0 meter from the itack or duct
vail. Multipoint aainpllng probes Installed
under paragraph 4.2.2 may be located it aJiy
points necessary to.obtain consistently rep-
resentative samples.
5. Continuous Monitoring System Perform-
ance Specifications.
The continuous monitoring system shall
me«t tbe performance specifications In Table
3-1 to be considered acceptable under'tots
method.
2-1.—Performance fpeciflcatiom
Specification
I. Accoracv l ,... . <3) pet of th» mean value of tbe reference method teet
data.
?. Calibrates error > _ S 5 pel of tacb (M pel, 90 pel) calibration gas minors
value.
S. Zero drl/i (2 b) ' __ i pet of span
4. Zero drm (34 h)' Do.
i. Calibration drift (2 h) i Do.
«. Calibrmtloa drift (24 b)' _ Z-5 pet. of jpan
7. Response dme . IS mln maximum.
8. Operational p«rlod 158 h minimum.
i Expressed u sum of abaoluu mean nlat plus 94 pet
6. Performance Specification Test Proce-
dures. The following Kst procedures shall be
used to determine conformance with the
requirements of paragraph 5. For NO, an-
requiremenu of paragraph S. For NOi an-
alyzer* that oxidize nitric oxide (NO) to
nitrogen dioxide (NO.), the response time
test under paragraph 6~.3 of this method shall
be performed using nitric oxide (NO) span
gas. Other tests for NO, continuous monitor-
ing systems under paragraphs 6.1 and 6.2 and
all tests for sulfur dioxide systems shall be
performed using the pollutant span gas spe-
cified by each s~ubpart.
61 Calibration Error Test Procedure. Set
up and calibrate the complete continuous
monitoring system according to tbe manu-
facturer's wrlten Instructions. This may be
accomplished either In the laboratory or In
the field.
6.1.1 Calibration Gas Analyses. Triplicate
analyses of the gas mixtures shall be per-
formed within two weeks prior to use using
Reference Methods 6 for SO. and 7 for NOi.
Analyze each callbr-tlon gis nurture (50%,
501,} and record the results on the example
sheet shown In Figure 3-1. Each sample test
result must be within 20 percent of the aver-
aged result or the tests shall be repeated.
This step may b* omitted for non-extractive
monitors There dynamic calibration gas mix-
tures are not used (6.1.2).
6.1.2 Calibration Error Test Procedure.
Make a total of 15 nonconsecutlve measure-
ment* by alternately using zero gas and each
:ollt>eratlon gts mixture concentration (e.g..
3<-t, 50%, OT., B0%. 50%, 90%. 50%, 0%,
•tc.). For nonextractlve continuous monitor-.
lag systems, this test procedure may be per-
formed by using two or more calibration gas
cells whose concentrations are certified by
the manufacturer to be functionally equiva-
lent to these gas concentrations. Convert the
continuous monitoring system output read-
Ings to ppm and record the results on the
example sheet shown In Figure 2-2.
62 Field Teat for Accuracy (Relative),
Zero Drift, and Calibration Drift. Install and
operate the continuous monitoring tystem In
accordance with the manufacturer's written
Instruction* and drawings u follows:
8.2.1 Conditioning Period. Offset the zero
•etting at least 10 percent of the span ao
that negative zero drift can be quantified.
Operate tne sjttem lor an Initial 168-hour
conditioning period In normal operating
manner.
833 Operational T«wt Period. Crptrat* th»
continuous monitoring irrrtem for an addl-
CDOfldenct (altml of» series of.tests.
tlonal 168-hour period retaining the cero
offset. The system shall monitor the source
effluent at all times except when being
zeroed, calibrated, or bacxpurged.
6.2.2.1 Field Test for Accuracy (Relative).
For continuous monitoring systems employ-
Ing extractive sampling, the probe tip for the
continuous monitoring system ind tbe probe
tip for the Reference Method sampling train
should be placed at adjacent locations In the
duct. For NO, continuous monitoring sys-
tems. msJse 27 NOT concentration measure-
ments, divided Into nine sets, using the ap-
plicable reference method. No more than one
set of tests, consisting of three Individual
measurements, shall be performed in any
one nour. All Individual measurements of
each set shall be performed concurrently.
or within a three-minute Interval and the
results averaged For SO, continuous moni-
toring systems, make nine SO. concentration
measurements using the applicable reference
method. No more than one measurement
shall be performed In any one hour. Record
the reference method test data and the con-
tinuous monitoring system concentrations
on the example data sheet siown ID Figure
2-3.
6.2.2.2 Field Test for Zero Drift and Cali-
bration Drift. For extractive systems, deter-
mine the values given by zero and span gas
pollutant concentrations at two-hour Inter-
vals until 15 sets of data are obtained. For
nonextractlve measurement systems, tbe zero
value may be determined by mechanically
producing a zero condition that provides a
system checic of the analyzer Internal mirrors
and all electronic circuitry including the
radUtlon source and detector assembly or
by inserting three or more calibration gas
cells nnd computing tbe zero point from the
upscale measurements. If this latter tech-
nique U used, a graph(s) must be retained
by the owner or operator for each measure-
ment system that shows the relr.tlonship be-
tween the upscale measurements and the
tero point. The »pan of the »73tem ahall be
checked by using a calibration ga» cell cer-
tified by the manufacturer to be function-
ally equivalent to 50 percent of span concen-
tration. Record th» zero and span me&sure-
menta (or the computed zero drift) on the
example data sheet shown In Figure 3-4.
The two-hour periods over which measure-
ments are conducted need not be consecutive
but may not overlap. All measurements re-
quired under tixli paragraph may b* con-
ducted concumnt vltb test* undtr p*ra-
jraph 8.2.2.1.
8.3.2.3 Adjustment*. Zero aod calibration
corrections and adjustment* an allowed only
at 34-hour Intervals or at rucb ahorter In-
tervals as the manufacturer'a written In-
struction* specify. Automatic corrections
made by the- measurement system without
operator Intervention or initiation are allow-
able at any time. During the entire 163-hour
operational te»t period, record on the ex-
ample sheet abown In Figure 3-6 tbe values
given by zero and ipan gaj pollutant con-
centrations before and after adjustment, at
24-hour Intervals.
B2 Field Test for Re*pon*e Time.
6.3.1 Scope of Test. Dae the entire continu-
ous monitoring system as Installed, Including
aample transport lines If used. Flow rates.
line diameters, pumping rates, pressures (do
not allow tbe pressurized calibration gas to
change the normal operating pressure In the
sample line), etc.. shall be at tbe nominal
values for normal operation as specified l»
tbe manufacturer's written Instructions. V
the analyzer Is used to sample more than one
pollutant source (stack), repeat Uib test for
each sampling point.
6.3.2 Response Time Te*t Procedure. In-
troduce zero gas into tbe continuous moni-
toring system sampling Interface or as close
to the sampling Interface as possible. When
the system output reading has stabilized.
switch quickly to a known concentration of
pollutant gas. Record the time from concen-
tration switching to 95 percent of final stable
response. For non-extractive monitors, the
highest available calibration gas concentra-
tion shall be switched Into and out of the
sample path and response times recorded.
Perform this test sequence three (3) umas.
• Record the results of each test on the
example sheet shown In Figure 2-0.
7. Calculations. Data Analysis and Rcr>ort-
ing. •
7.1 Procedure for determination of mean
values and confidence- intervals.
7.1.1 The mean value of a data set is
calculated according to equation 2-1.
Z-^Sx
n '-I ' Equation '!.- 1
where:
X|=r absolute value of tbe measurements,
! = sum of the Individual values,
5"= mean value, and
n = number of data points,
7.1.2 The 85 percent confidence Interval
(two-sided) U calculated according to equa-
tion 2-2:
Equation 2-2
•where:
Zx,—sum of all data points,
t.rrj = t, — a/2, and
C.I.«j = 9S percent confidence interval
estimate of the average mean
value.
Values for V975
n
5:
'. 874
11
14 :..j..~
14
It
4.903
lie
S.774
1471
ivn
1364
12S2
129
1201
2. 179
Z 160
3.131
Tat value* in this table are already eor-
r*ct*d for n-1 d««r»»» of trwriom. Use n
11-81
-------
•qua! to tt» number of •ample* e* ****
point*.
12 Data AnalyaU UJd Reporting.
7J.I Accuracy (Relative). For each of the
nice .-tr^rcic-c mthotf test points, determine
the average pollutant concentration reported
by tie conUnuoui monitoring system. These
average concentration* Khali b« determined
from the continuous monitoring system data
recorded under 7.2JJ by Integrating or aver-
aging the pollutant concentrations over each
3f the time intervals concurrent with each
reference method testing period. Before pro-
ceeding to the next step, determine the basis
(wet or dry) of the continuous monitoring
system data »"* reference method test data
concentration*. If the baits trt not con-
sistent, apply a moisture correction to either
reference m«thod concentrations or the con-
tinuous monitoring system concentrations
as appropriate. Determine the correction
factor by moisture test* concurrent with the
reference method testing periods. Report the
moisture test method and the correction pro-
cedure employed. For each of the nine test
runs determine the difference for each test
run by subtracting the respective reference
method tat concentrations (ua< average of
each set of three me -urements for NOi)
from the continuous monitoring system inte-
grated or averaged c. >centratlons. Using
these data, compute the mean difference and
the 95 percent confidence Interval of the dif-
ferences (equations 2-1 and 3-2). Accuracy
Is reported a^ the rum of the absolute value
of the mean difference and the 95 percent
confidence Interval of the differences ex-
pressed u a percentage of the mem refer-
ence method value. UK the example sheet
shown In Figure 3-3
"122 Calibration Error. Using the data
from paragraph 6.1. subtract the measured
pollutant concentration determined under
paragraph 6.1.1 (Figure 3-1) from the value
shown by the continuous monitoring system
for each of the five readings at each con-
centration measured under 8.1 J (Figure 2-2).
Calculate the mean of these difference values
and the 85 percent confidence Intervals ac-
cording to equations 2-1 and 2-2. Report the
calibration error (the sum of the absolute
value of the mean difference and the 95 per-
cent confidence Interval) as a percentage of
each respective calibration gas concentra-
tion. Use example sheet shown In Figure 2-2.
7.2.3 Zero Drift (2-hour). Using the zero
concentration values measured each two
hours during the field test, calculate the dif-
ference* between oon*6cuuv» two-hour read-
lap «ipres»*d In ppm. Calculate the mem
difference and tin confidence Interval
equation* 1-1 and 3-3. He port the r»ro drift
u the sum of the absolute mean value and
U>« confidence Interval at a percentage of
•pan. Us* example sheet shown In Figure
3-4.
7.3.4 Zero Drift (24-hour). Using the rero
concentration values measured ever? 34
hours during the field test, calculate the dif-
ferences between the tero point after rero
adjustment and the iero value 24 hours later
just prior to sero adjustment. -Calculate the
mean value of these points and the confi-
dence Interval using equations 2-1 and 2-2.
Report the cero drift (the rum of the abso-
lute mean and confidence interval) as a per-
centage of span. Use example sheet abown In
Figure 3-5.
7.2.5 Calibration Drift (2-hour). Using
the calibration values obtained at two-hour
Intervale during the field test, calculate the
differences between consecutive two-hour
readings expressed as ppm. These values
should b* corrected for the corresponding
rero drift during that two-hour period. Cal-
culate the mean and confidence Interval of
these corrected difference values using equa-
tions 2-1 and 2—2. Do not use the differences
between non-consecutive readings. Report
the calibration drift a; the sum of the abso-
lute mean and confidence Interval as a per-
centage of span. Use the example sheet ahown
In Figure 2-4.
7.2.6 C-llbratlon Drift {24-hour). .Using
the calibration values measured every 24
hours durinz the field test, calculate the dif-
ferences between the calibration concentra-
tion reading after zero and calibration ad-
justment, and the calibration concentration
reading 24 hours later after zero adjustment
but before calibration adjustment. Calculate
the mean value of these differences and the
confidence Interval using equations 2-1 and
2-2. Report the calibration drift (the sum of
the absolute mean and confidence Interval)
as a percentage of span. Use the example
aheet shown in Figure 2-5.
7.2.7 Response Time. Using the charts
from paragraph 6.3, calculate the time inter-
val from concentration switching to 95 per-
cent to the nriai stable value for all upscale
and downscale tests. Report the mean of the
three upscale test tunes and the mean of the
three downscale test times. The two aver-
age times should not differ by more than 15
percent of the slower time. Report the slower
time as the system response time. Use the ex-
ample sheet shown in Figure 2-8.
7.2.8 Operational Test Period. During the
Ifr8-bour performance and operational test
period, the continuous monitoring system
ahall not require any corrective maintenance.
repair, replacement, or adjustment other **•"
that clearly specified a* required In the op-
eration and maintenance manuals as routine
end erpect*d during a one-week period. If
the continuous monitoring system operates
within the specified performance parameters
and does not require corrective maintenance,
repair, replacement or adjustment other than
as specified above during the 168-hour test.
period, th» operational period will be success-
fully concluded. Failure of the continuous
monitoring system to meet this requirement
shall call for a repetition of the 168^hour test
period. Portion* of the test which were satis-
factorily completed need not be repeated.
Failure to meet any performance specifica-
tions shall call for a repetition of the one-
weelc performance test period and that por-
tion of the testing which is related to the
failed specification All maintenance and ad-
justments required ahall be recorded. Out-
put readings shall be recorded before ana
after all adjustments.
8. References.
8.1 "Monitoring InstrumenUtlon for the
Measurement of Sulfur Dioxide In Stationary
Source Emissions," Environmental Protection
Agency, Research Triangle Park, N.C., Feb-
ruary 1873.
82 "Instrumentation for the Determina-
tion of Kitrogen Oxides Content of Station-
ary Source Emissions," Environmental Pro-
tection Aginc7, Research Triangle Park. N.C.,
Volume 1, APTD-OS47. October 1871; Vol-
ume 2, AJTD-0942, January 1973.
3.3 "Experimentil Statistics," Departm-nt
of Commerce, Handbook 91, 1863. pp. 3-31.
paragraphs 3—3.1.4.
8.4 "Performance Specifications for Sta-
tionary-Source Monitoring Systems for Gases
and Visible Emissions," Environmental Pro-
tection Agency. Research Triangle Park. N.C..
EPA-650/3-74-013, January 1974..
1-1. fcvlflH •< t*l**r*t*M IM Mnvr
-------
Calibration Gas Mixture DaU (Frm Figure 2-1)
Mid (505) ppn High (901) ppra
Cal ibration f.as
Run 1 Concentration,ppm
Measurement System
Reading, ppn
Differences,
4
5_
6
7_
8
9_
10
n
_[2_
13
15
Mean difference
onfidence interval
Calibration error
Hid High
Near Difference * C.I. ,..
Average Cal ibrat:or> Gas Concentration I f
Calibration gas concentration - measurement system reading
'Absolute value
Figure 2-2. Calibration Error Determination
Ifitrmct
hu
•M
i !
"^ "z «,
(wi
**ICf WtA»d
(».)
(",) • 1.
HMn of
IM llfftrmcti
• I ISC • I (Mj) » f
ti?l«1* Mtf report a*tJ
2-].
-------
nil
Mt
*•*!• EM! lit
•rift Son
tf."
erf ft
Zrr ^m • [heii Jerxi yrift"
CjHbritien Drift • [*te* S^*n trifi-
«*6iolutt Viluf.
S?«nj « 1C'5 •
I [SP«n) i 16
f'.Jurc 2-4. 2fro *f«: Cilierdticn Crif; (2
Date Zero Span Calibration
and Zero Drift Reading Drift
Time Reading (iZero) (After zero adjustment) (aSpan)
Zero Drift « [Mean 7ero Drift* + C.I. (Zero)
i [Instnmer.t Span] x ICO •
ation Drift « [Kean Span Drift*
+ C.I. (Spsn)
« [Instrument Span] x TOO «
* Absolute value
Figure 2-5. Zero »nd Calibration Drift (24-hour)
11-84
-------
D*t« of Ttit
Spin (Us Concentration
Aiwlyter Sp*n Sitting
Upsole
Avenge
ttownscale
-
Avenge
1
2
3
OOB.
ppn
_»»eonds
_ieeonds
_*econds
upscs.lt response seconds
1
2
3
downscile
System average response -tlite (slower
Mevlatlon from slower m \
system iverige response
_»econds
_*econds
_»econds
response seconds
t^"*) " seconds .
»vera«e upscale minus tveraqe downscale 1 _ ,nn, .
Figure 2-6. Response
— Performance
spclcauonsadspeclficton test proce-
dures (or monitors of CO, and O, from sta-
tionary sources.
1. Principle and I Applicability.
1.1 Principle. Effluent gases »re continu-
ously sampled and are analyzed for carbon
cloxlde or oxygen by » continuous monitor-
ing system. Tests of the system are performed .
during a minimum operating period to deter-
mine zero drift, calibration drift, and re-
sponse time characteristics.
1.2 Applicability. This performance speci-
fication Is applicable to evaluation of con-
tinuous monitoring systems for measurement
of carbon dioxide or oxygen. These specifica-
tions contain test procedures. Installation re-
quirements, and data computation proce-
dures for evaluating the acceptability of the
continuous monitoring systems subject to
approval by the Administrator. Sampling
may Include either extractive or non-extrac-
tive (In-sttu) procedures.
2. Apparatus.
2.1 Continuous Monitoring System for
Carbon Dioxide or Oxygen.
22 Calibration Oas Mixtures. Mixture of
known concentrations of carbon dioxide or
oxygen In nitrogen or air. Mldrange and 90
percent of span carbon dioxide or oxygen
concentrations are required. The 90 percent
of span gas mixture Is to be used to set and
check the analyzer span and Is referred to
ao span g«J. For oxygen analyzers, IT the
span Is higher than 21 percent O,. ambient
air may b« used la place of the 90 percent of
span calibration gai mixture. Triplicate
analyses of the gas mixture (except ambient
Kir) thai] be performed within two weeki
prior to us* using Reference Method 3 of
this part.
2-3 Zero Oas. A gas containing less »-h»n 100
ppm of cartoon dioxide or oxygen.
2.4 Data Recorder. Analog chart recorder
or other suitable device with Input roltage
range compatible with analyzer system out-
puc. The resolution of the recorder's data
output shall be sufficient to allow completion
of the test procedures within this specifica-
tion.
3. Dgflnlttons.
(.1 Continuous Monitoring Sjrtem. Th*
Local equipment required for the determina-
tion of carton dioxide or ozrjeQ In a flr»n
source effluent. The system consists of three
major subsystems:
3.1.1 Sampling Interface. That portion of
the continuous monitoring system that per-
forms one or more of the following opera-
tions: delineation, acquisition, transporta-
tion, and conditioning of a sample ot the
source effluent or protection of the analyzer
from the hostile aspect* of the sample or
aource environment.
3.1.2 Analyzer. That portion of the con-
tinuous monitoring system which senses the
pollutant gas and generates a signal output
that Is a function of the pcllutant concen-
tration.
3.1.3 Data Recorder. That portion of the
continuous monitoring system that provides
a permanent record of the output signal In
terms of concentration units.
3.2 Span. The value of oxygen or carbon di-
oxide coi.eentra.tl3n at which the continuous
monitoring system Is set that produces the
maximum data display output. For the pur-
poses of this method, the span shall be aet
no less than 1.S to 2.S times the normal car-.
• bon dioxide or normal oxygen concentration
in the stack gas of the affected facility.
3.3 Mldrsnge. The value ot oxygen or car-
bon dioxide concentration that Is representa-
tive of the normal conditions In the stack
gas of. the affected facility at typlcil operat-
ing rates.
3.4 Zero Drift. The change In the contin-
uous monitoring system output over a stated
period of time of normal continuous opera-
tion when the carbon dioxide or oxygen con-
centration at the time for the measurements
Is zaro.
3J Calibration Drtft. The change In the
continuous monitoring system output over a
stated time period of normal continuous op-
eration when the carbon dioxide or oxygen
continuous monitoring system Is measuring
the concentration of span gas.
8.8 Operational Test Period. A minimum
period of time over which the continuous
monitoring system Is expected to" operate
within certain performance specifications
without unscheduled maintenance,, repair, or
adjustment. . •
8.7 Response time. The ttmt Interval from
a (Up change In concentration at thj Input
to Ule continuous monitoring system to Uu
at wild 95 pcrant of th* corrwpond-
tot fln*' v*10* * dUplaywd ce tte oocttnuoos
SBOoJtorinc system data recorder.
4. Installation Specification.
Oxygen or carbon dioxide continuous mon-
itoring systems1 shall b« Installed at a loca-
tion where measurements are directly repre-
a*ntattve of the total effluent trom the
sdlect«d facility or representative of the same
•fluent sampled by a SO, or NO, continuous
monitoring STstem. This requirement shall
b* compiled, with 07 use of applicable re-
quirements Ln Performance Specification 3 of
t>M» appendix aa follows:
4.1 Installation of Oxygen or Carbon D1-
"onde Continuous Monitoring Synems Not
TJsed to Convert Pollutant D»ta. A sampling
location shall b* selected In accordance with
. toe procedures under • paragraphs 4.2.1 or
. 4.2.2. or Performance, Specification 2 of this
appendix, -
4.2 Installation of Oxygen or Carbon Di-
oxide Continuous Monitoring Systems Used
to Convert Pollutant Continuous Monitoring
System- Data to Units of Applicable Stand-
ards. The diluent continuous monitoring sys-
tem (oxygen or carbon dioxide) shall be In-
stalled at a sampling location where measure-
ments that <**" b« made are representative of
the effluent gases sampled by the pollutant
continuous monitoring system(s). Conform-
ajace with this requirement may be accom-
plished In any of the following ways:
4.2.1 The sampling location for the diluent
system shalrbe zwar the sampling location for
the pollutant continuous monitoring system
such that the same approximate point (s)
(extractive systems) or path (In-sltu sys-
tems) In the cross section Is sampled or
viewed.
4.2.2 The diluent and pollutant continuous
monitoring systems may be Installed at dif-
ferent locations If the effluent gases at both
sampling locations are noastratlfled as deter-
mined under paragraphs 4.1 or 4.3, Perform-
ance Specification 2 of *>MT appendix and
there Is no la-leakage occurring between the
two sampling locations. If the effluent gases
are stratified at either location, the proce-
dures under paragraph 4.2.2, Performance
Specification 2 of this appendix shall be used
for Installing continuous monitoring systems
at that location.
6, Continuous Monitoring System Perform-
ance Specifications.
The continuous monitoring system «>i«J'
meet the performance specifications In Tails
3-1 to be considered acceptable under t&Li
method.
6. Performance Specification Teat Proce-
dures.
The following test procedures snail be used
to determine conformance with the require-
ments of paragraph 4. Due to the wide varia-
tion existing In analyzer designs and princi-
ples of operation, these- procedures are not
applicable to all analyzers. Where this occurs.
alternative procedures, subject to the ap-
proval of the Administrator, may be em-
ployed. Any such alternative procedures must
fulfill the same purpos« (verify response,
drift, snd accuracy) as the following proce-
dures, and must clearly demonstrate oon-
fonnance with specifications In Table 8-1.
6.1 Calibration Check. Establish a cali-
bration curve for the continuous moal-
•torlng system Using zero, mldrange, and
span concentration gas mixtures. Verify
that the resultant curve of analyzer read-
Ing compared with the calibration gaf
value Is consistent with the expected re-
tponse curve ts described by the analyzer
manufacturer. If the expected response
curve la not produced, additional cali-
bration r*< measurements shall be m*d«,
or additional itepa undertaken to vertt?
11-85
-------
the accuracy ol the response curve of the
analyzer.
6.2 Field Test for Zero Drift and Ca.11-
bratic:1. Drift, lasuil and operate the
continuous monitoring system in accord-
ance with the manufacturer's written in-
structions and drawings as follows:
TABU: 3-1.—Performance ipecificalinns
Pimettr
Sped/lotion
J. Zero drift f? h)' <0.« pet Oi or COi.
2. Zen drill <0.i pet Otor CO,.
i. CiUbridoo drift (I M'.. <0.4 pet 0: or COv
i. C«llbr»non rtnfi (24 b) i. <0-S pel O: or COi.
A. Operauonal rxnod 1* b minimum.
5. Rejpontt u:ne _... JOmm. •
> £rprrss*e mem and confidence Intern! of
these corrected difference values usln? equa-
tions 3-1 and 3-2. Do not use the differences
between non-consecutive readings. Record
the sum ol the absolute mean and cot,.':-
dence interval upon the data sheet shot™
In Firure 3-1.
7-2.4 Calibration DrlU (24-hour). Using the
calibration values measured every 24 Sours
during the Qeld test, calculate the d'.fer-
ences between the calibration concentration
reading after zero and calibration adjust-
ment snd the calibration concentration read-
Ing 24 hours later after zero adjustment but
before calibration adjustment. Calculate the
mean value of these differences and the con-
fidence Interval using equations 3-1 and 3-2.
Record the eum of the absolute mean tnd
confidence interval on the data sheet abown
In Figure 3-2.
7.2.5 Operational Test Period. Dujlng the
168-hour performance and operations: test
period, the continuous monitoring sys:;m
anall not receive any corrective maintenance.
repair, replacement, or adjustment other
than that clearly specified as required In the
manufacturer's written operation and main-
tenance manual? us rojtlne and eipected
during a one-week period. If the continuous
monitoring system operates wlUiin the speci-
fied performance parameters and does net re-
quire corrective maintenance, repair, replice-
men; or adjustment o:ner than as speclS-d
above during the 168-hour test period, the
operational period will be successfully con-
cluded. Failure of the continuous monitoring
system to meet this requirement shall cz'.l
for a repetition of the 168 hour test period.
Portions of the test which were satisfactory
completed need not be repeated. Failure to
meet any performance specifications shall
call for a repetition of the one-week perform-
ance test period and that portion of the test-
ing which Is related to the failed specifica-
tion. All maintenance and adjustments re-
quired shall be recorded. Output readings
shall be recorded before and after all ad-
justments.
7.2.6 Response Time. Using tbe data devel-
oped under paragraph 6.3, calculate the time
Interval from concentration switching to 95
percent to the final stable value for all up-
scale and downscale tests. Report the mean of
the three upscale test times and the mean of
the three downicale test times. Tbe two at-
eragt time* should sot differ by more than
15 percent of the tlower time. Report the
slower time as the system response time. Re-
cord the results on Figw» 3—8-
8. References.
8.1 "Performance Specifications for Sta-
tionary Source'Monitoring Systems for Gases
and Visible Emissions," Environmental Pro-
tection Agency, Research Triangle Pars, N.C.,
EPA-650/2-74-013, January 1S74.
8.2 "Experimental Statistics," Department
of Commerce, National Bureau of Standards
Handbook 91, 1963, pp. 3-31. paragraphs
8-3.1.4.
(Sea. Ill and 114 of the Cletn Air Act, as
amended by sec. 4(a) of Pub. L. 91-604, 84
Stat 1478 (43 U.8.C. 1M7C-6, by »«e. 1*(C) (2)
of Pub. L. 91-eXH. «4 SUt. 1713 (43 O.S.C.
!U7g)>.
11-86
-------
T1«
lire
I«ro
OrUt 1pm Drift
(jjcr.) tod In,
OM«
itrs Orl ft • lf44A i^ro Of lit
ClH6r4t1w OHf. • [IHu\ S**n
"•Aeulutt Vain.
Fljurt J-l. Ztr» tnd UllSritlon Drift (2 Hour).
Jate Zero Span Calibration
and Zero Drift Reading Drift
Time Reading UZero) {After zero adjustment) (iSpan)
Zero Drift « [Kean Zero Drift*
C.I. (Zero)
Calibration Drift • [Mean Span Drift*
C.I. (Span)
Absolute value
3-2. Zero »n<3 Calibration Drift (24-hour)
11-87
-------
Datt of Test
Span Gas Concentration
A/valyzer Spin Setting
1.
Upscale ^ 2.
3.
Average
1.
Downseale 2.
3.
Average
_ PPW
ppm
seconds *
seconds
seconds *
upscale response seconds
seconds
seconds
seconds
downscale response seconds
system aversae response time (slower time) - seconds
average response slower tiire
., .,
"*
Figure 3-3. Respcnss
(B«c. 114 of tin ae>A Air Act u
(43 U.8.C. !Si7e-8).).
11-88
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NSPS OPERATIONAL MONITORING REQUIREMENTS - PROMULGATED
11-89
-------
Subpart N—Standards of Performance for
Iron and Stewl Plants *
g 60.140 Applicability and d«aicnation
of affected facility, 6 4
(a) The affected facility to which the
provisions of this subpart apply la each
basic oxygen process furnace.
(b) Any facility under paragraph (a)
of this section that commences construc-
tion or modification after June 11, 1973,
is subject to the requirements of tills
subpart.
i 60.141 Definitiona.
As used In this subpart, &Q terms not
defined herein shall have the meaning
given them In the Act and In subpart A.
(f this part.
(a.) "Basic oxygen process /umace"
a. ">FF) means any furnace producing
by charging scrap steel, hot metal,
a..a flux materials into a vessel and In-
troducing a high volume of an oxygen-
rich sas.
(K- "Steel production cycle" means
the '-"rations required to produce each
bat..h 01 steel and Includes the following
major- {unctions: Scrap charging, pre-
heating (when used), hot metal charg-
ing, primary oxygen blowing, additional
oxygen blowing (when used), and tap-
Ping.
(c) "Startup means the setting Into
operation for the first steel production
cycle of a relined BOPF or a BOPF
which has been out of production for a
minimum continuous time period of
eight hours.
§ 60.142 Standard for particnlate mat-
ter.
.(a) On and after the date on which
the performance test required to be con-
ducted by ] W.8 Is completed, no owner
or operator subject to the provisions of
tii .s subpart shall discharge or cause
iv: discharge into the atmosphere from
any affected facility any gases which.:
(1) Contain participate matter In ex-
cess of 50 mg/dscm (0.022 gr/dscf ).
(2) Exit from a control device ana
exhibit 10 percent opacity or greater,
except that an opacity of greater than
10 percent but less than 20 percent
may occur once per steel production
cycle.
f 60.143 Monitoring of operations.
(a) The owner or operator of an af-
fected facility shall maintain a single
time-measuring Instrument which
shall be used in recording daily the
time and duration of each steel pro-
duction cycle, and the time and dura-
tion of any diversion of exhaust gases
from the main stack servicing the
BOPF.
(b) The owner or operator of any af-
fected facility that uses venturl scrub-
ber emission control equipment shall
install, calibrate, maintain, and con-
tinuously operate monitoring devices
as follows:
(DA monitoring device for the con-
tinuous measurement of the pressure
loss through the venturt constriction
of the control equipment. The moni-
toring device is to be certified by the
manufacturer to be accurate within
±250 Pa (±1 inch water).
(2) A monitoring device for the con-
tinous measurement of the water
supply pressure to the control equip-
ment. The monitoring device is to be
certified by the manufacturer to be ac-
curate within ±5 percent of the design
water supply pressure. The monitoring
device's pressure sensor or pressure
tap must be located close to the water
discharge point. The Administrator
may be consulted for approval of alter-
native locations for the pressure
sensor or tap.
(3) All monitoring devices shall be
synchronized each day with the time-
measuring instrument used under
paragraph (a) of this section. The
chart recorder error directly after syn-
chronization shall not exceed 0.08 cm
(%t inch).
(4) All monitoring devices shall use
chart recorders which are operated at
a minimum chart speed of 3.8 cm/hr
(1.5 In/hr).
(5) All monitoring devices are to be
recalibreated annually, and at other
times as the Administrator may re-
quire, in accordance with the proce-
duces under § 60.13(b)(3).
(c) Any owner or operator subject to
requirements under paragraph (b) of
this section shall report for each cal-
endar quarter all measurements over
any three-hour period that average
more than 10 percent below the aver-
age levels maintained during the most
recent performance test conducted
under § 60.8 in which the affected fa-
cility demonstrated compliance with
the standard under § 60.142(aXl). The
accuracy of the respective measure-
ments, not to exceed the values speci-
fied in paragraphs
-------
Subpart T—Standards of Performance for
the Phosphate Fertilizer Industry: W«t-
Process Phosphoric Acid Plants
§ 60.200 Applicability an
of «ffee»ed facility.
(») Tbe affected facility to which the
provisions of this subpart apply to each'
wet-process phosphoric acid plant For
the purpose of this subpart the affected
facility-' Includes any combination of:
reactors, filter*, evaporators, and hot-
wells. '"•
(to) Any facility under paragraph (a)
of this section that commences con-
struction or modification after October
22, 1974, is subject to the requirements
of this cubpart
160.201 DeBnition*.
As used in this subpart, all terms not
defined herein shall have the meaning
given them In the Act and in Subpart A
of this part.
(a) "Wet-process phosphoric acid
plant" means any facility manufactur-
ing phosphoric acid by reacting phos-
phate rock and acid.
(b) "Total fluorides" means elemental
fluorine and all fluoride compounds as
measured by reference methods specified
In 5 60.204, or equivalent or alternative
methods.
(c) "Equivalent PXDi feed" means th»
quantity of phosphorus, expressed as
phosphorous pentoxide, fed to the proc-
8 60.203 Monitoring of operation*.
(c) The owner or operator of any wet-
process phosphoric acid subject to the
provisions of this part shall Install, cali-
brate, maintain, and operate a monitor-
Ing device which continuously measures
and permanently records the total pres-
sure drop across the process scrubbing
system. The monitoring device shall have
an accuracy of ±5 percent over its op-
erating range.
(S*e. 1M of Uu O«AO Ait Act M
-------
Subpart U—Standard* of Pwrformanca for
the Phosphate Fcrtllizar Industry: Supar-
phosphoric Acid Plant*
160.210 AppliuKllitj a»d deti^nmtion
•f affected
(a) Tne affected facility to which the
provision* of this subpart apply it each"
tuperphSsphoric acid plant For the
purpose, of this subpart, the affected
facility Includes any combination of:
•vaporators, hotwells, acid romps, and
poking tankrt
(b) Any facility under paragraph (a)
of this aection that commences con-
struction or modification after October
22, 1974, U subject to the requirements
of this subpart
| 60.211 Definition*.
As used in this subpart, all terms not
denned herein shall have the meaning
given them in the Act and In Subpart A
of this part.
(a) "Superphosphoric acid plant"
means any facility which concentrates
wet-process phosphoric acid to 66 per-
cent or greater P.O. content by weight
for eventual consumption as a fertilizer.
(b) "Total fluorides" means elemen-
tal fluorine and all fluoride compounds
as measured by reference methods spe-
cified in S 60.214, or equivalent or alter-
native methods.
(c) "Equivalent P.O. feed" means the
quantity of phosphorus, expressed as
phosphorous pentoxide. fe4 to the
process.
| 60.213 Monitoring of operation*.
(c) The owner or operator of any
superpnosphorlc acid plant subject to the
provisions of thu part shall Install, cali-
brate, maintain, and operate a monitor-
ing device which continuously measures
and permanently records the total pres •
sure drop across the process scrubbing
system. The monitoring device shall have
an accuracy of i 5 percent over its
operating range.
(8*e. 114 of Uu CJ««J> Ait Act at tmn
-------
•ubpart V—Standard* of P*rfonn«nc* for
th« Phosphate Fertilizer Industry. Diam-
monium Phosphate Plants
§60.220 Applicability aa«
of affected facility.
(A) The affected facility to which the
provision* of this cubp&rt apply la each,
granulat dJammonium phosphate plant.
For the purpose of this subpart, the af-
fected facility Includes any combination
of: reactors, granulatore, dryers, coolers,
screens, aod mills.
(b) Ally facility under paragraph (a)
of this section that commences construc-
tion or modification after October 22.
1974, la subject to the requirements of
this subpext.
| 60.221 Definitions.
As used in this subpart, all terms not
denned herein shall have the meaning
given them in the Act and in Subpart A
ol this part.
(a) "Granular rilammonium phos-
phate plant" means any plant manu-
facturing granular diammonlum phos-
phate by reacting phosphoric acid with
ammonia.
(b) "Total fluorides" means elemental
fluorine and all fluoride compounds as
measured by reference methods speci-
fied in ! 60.224, or equivalent or alter-
native methods.
-------
Subpart W—Standards of Performance for
the Phosphate Fertilizer Industry: Trip**
Superphosphate Plants
60.230 Applicability
of affected facility.
•ad «V«i The Affected facility to which the
provisions of this cubp&rt apply is each-
triple superphosphate plant. For the pur-
pose of this subpart, the affected facility
Includes any combination of: mixers.
curing "belts (dens), reactors, granula-
tors. dryers, cookers, screens, mills, and
facilities which store run-of-pUe triple
superphosphate.
(b) Any facility under paragraph (a)
of this section that commences construc-
tion or modification after October 22,
1974, is subject to the requlremente of
this subpart
| 60.231 Definition*.
As used in this subpart. all terms not
defined herein gh?J1 have the meaning
given them in the Act and in Subpart A
of this part.
(a) "Triple superphosphate plant"
means any facility manufacturing triple
superphosphate by reacting phosphate
rode with phosphoric acid. A run-of-plle
triple superphosphate plant include*
curing and storing.
-------
tubpart X—Standards of «»rform*nc» tor
th« Phosphate Fertilizer Industry: Gran-
ular Triple Superphosphate Storage Fa-
cilities
160.240 Applicability and dc«i«n«lu»a
•f affected tacility-
<») Ike Affected f aeflKy to which the-
prorteiotM of tills cubpart apply to each
granular triple superphosphate storage
facility .-.For ttie purpose of thia subpart,
the affected facility Includes any combi-
nation ef: storage or curing piles, con-
veyors, elevators, screens, and m1U«.
(b) Any facility under paragraph (a)
of this section that commences construc-
tion or modification after October 22,
1874. IB subject to the requirements of
thi* subpart.
160.241 Definition*.
As used in this subpart, all terms not
denned herein shall have the meaning
given them In the Act and in Subpart A
of this part.
(a) "Granular triple superphosphate
Storage facility" means any facility cur-
ing or storing granular triple superphos-
phate.
(b) "Total fluorides" means elemental
fluorine and all fluoride compounds as
measured by reference methods specified
In {60.244, or equivalent or alternative
methods.
(c) "Equivalent PiOt stored" means
the quantity of phosphorus, expressed as
phosphorus pentoxide, being cured ox
stored in the affected facility.
(d) "Fresh granular triple superphos-
phate" means granular triple superphos-
phate produced no more than 10 days
prior to the date of the performance test
£ 60.243 Monitoring of operation*.
(c) The owner or operator of any
granular triple superphosphate storage
facility subject to the provisions of this
part shall install, calibrate, maintain,
and operate a monitoring device which
continuously measures and permanently
records the total pressure drop across the
process scrubbing sytem. The monitoring
device shall have an accuracy of ±5 per-
cent over its operating range.
(Sue. IK at u>« a«*n AH Act M
(43 CAC.1U7C-9).).
References:
60.2
60.7
60.8
60.11
60.13
11-95
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Subpart Y—Standards of Performance lor
Coal Preparation Plants
160.250 Applicability a«a
•I affected facility.
(a> The provision* of thte aubpart an
applicable to any of the following af-
fected facilities in coal preparation
plants wnlr.li process more than 200 ton*
per day: .thermal dryers, pneumatic coal-
cleaning: equipment (air tables), coal
processing and conveying equipment (In-
cluding -breakers and crushers), coal
atorage systems, and coal transfer and
V-mrllnp «y«l_«1llc
(to) Any facility under paragraph (a)
of this section that commences construc-
tion or modification after October 3 *,
1974, is subject to the requirements of
160.251 Definition*.
As used in this subpart. all terms not
defined herein have the meaning given
them In the Act and in Subpart A of this
part.
(a) "Coal preparation plant" means
any facility (excluding underground
mining operations) which prepares coal
by one or more of the following proc-
esses: breaking, crushing, screening, wet
or dry cleaning, ttn^ thermal drying.
(fa) "Bituminous coal" means solid fos-
sil fuel classified as bituminous coal by
A-S.TJU. Designation D-38S-66.
, ' (c) "Coal" means all solid fossil fuels
classified as anthracite, bituminous, nib-
bltumlnouB, or lignite by A^.TJuL Des-
ignation D-388-66.
(d) "Cyclonic flow" means a splraling
movement of exhaust gases within a duct
or stack.
(e) Thermal dryer" means any fa-
cility In which the moisture content of
bituminous coal It reduced by contact
with a heated gas stream which Is ex-
hausted to the atmosphere.
(f) "Pneumatic coal-cleaning equip-
ment" means any facility which classifies
bituminous coal by size or separates bi-
tuminous coal from refuse by application
of air stream (s).
(g) "Coal processing and conveying
equipment" means any machinery used
to reduce the size of coal or to separate
coal from refuse, and the equipment used
to convey coal to or remove'coal and
refuse from the machinery. This In-
cludes, but Is not limited to, breakers,
crushers, screens, and conveyor belts.
(h) "Coal storage system" means any
facility used to store coal except for open
atorage piles.
(1) "Transfer and loading system"
means any facility used to transfer and
load coal for shipment.
| 60.253 Monitoring- of operation*.
(a) The owner or operator of any ther-
mal dryer shall install, calibrate, mam-
tain, and continuously operate monitor -
Ing devices as follows:
(DA monitoring device for the meas-
urement of the temperature of the gas
stream at the exit of the thermal dryer
on a continuous basis. The monitoring
device is to be certified by the manu-
facturer to be accurate within ±3* Fahr-
enheit.
(2) For affected facilities that use ven-
turi scrubber emission control equip-
ment:
(1) A monitoring device for the con-
tinuous measurement of the pressure loss
through the venturl constriction of the
control equipment. The monitoring de-
vice is to be certified by the manufac-
turer to be accurate within ±1 Inch
water gage.
(11) A monitoring device for the con-
tinuous measurement of the water sup-
ply pressure to the control equipment.
The monitoring device is to be certified
by the manufacturer to be accurate with-
in ±5 percent of design water supply
pressure. The pressure sensor or tap must
be located close to the water discharge
point. The Administrator may be con-
sulted for approval of alternative loca-
tions.
(b) All monitoring devices under para-
graph (a) of this section are to be recali-
brated annually in accordance with pro-
cedures under { 60.13(b) (3).
(S«c. 114 at UM CJ«*n Air Act u
(U O.S.C. l«57o-0).).
References:
60.
60.
60.
60.
2
7
8
n
60.13
11-596'
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Subpart GG—Standards of
Performance for Stationary Gas
Turbines
§ 6O330 Applicability and'd«*ignatJon of
affected facility.
The provisions of this subpart are
applicable to the following affected
facilities: ail stationary gas turbines
with a heat input at peak load equal to
or greater than 10.7 gigajoules per hour.
based on the lower heating value of the
fuel fired.
§60.331 Definitions.
As used in this subpart all terms not
defined herein shall have the meaning
given them in the Act and in subpart A
of this part.
(a) "Stationary gas turbine" means
any simple cycle gas turbine,
regenerative cycle gas turbine or any
gas turbine portion of a combined cycle
steam/electric generating system that is
not self propelled. It may, however, be
mounted on a vehicle for portability.
(b) "Simple cycle gas turbine" means
any stationary gas turbine which does
not recover heat from the gas turbine
exhaust gases to preheat the inlet
combustion air to the gas turbine, or
which does not recover heat from the
gas turbine exhaust gases to heat water
or generate steam.
(c) "Regenerative cycle gas turbine""
means any stationary gas turbine which
recovers heat from the gas turbine
11-97
-------
exhaust gases to preheat the inlet
combustion air to the gas turbine.
(d) "Combined cycle gas turbine"
means any stationary gas turbine which
recovers heat from the gas turbine
exhaust gases to heat water or generate
steam.
(e) "Emergency gas turbine" means
any stationary gas turbine which
operates as a mechanical or electrical
power source only when the primary
power source for a facility has been
rendered roopeTwhle by an emergency
situation.;
(f) "Ice fog" means an atmospheric
suspension of highly reflective ice
crystals.
(g) "ISO standard day conditions"
means 263 degrees Kelvin, 60 percent
relative humidity and 101.3 kilopascals
pressure.
(h) "Efficiency" means the gas turbine
manufacturer's rated heat rate at peak
load in terms Of heat input per unit of
power output based on the lower
heating value of the fueL
(i) "Peak load" means 100 percent of
the manufacturer's design capacity of
the gas turbine at ISO standard day
conditions.
fj) "Base load" means the load level at
which a gas turbine is normally
operated.
(k) "Fire-fighting turbine" means any
stationary gas turbine that is used solely
to pump water for extinguishing fires.
(1) "Turbines employed in oil/gas
production or oi]/gas transportation" .
means any stationary gas turbine used
to provide power to extract crude oil/
natural gas from the earth or to move
crude oil/natural gas, or products
refined from these substances through
pipelines.
(m] A "Metropolitan Statistical Area"
or "MSA" as defined by the Department
of Commerce.
(n) "Offshore platform gas turbines"
means any stationary gas turbine
located on a platform in an ocean.
(o) "Garrison facility" means any
permanent military installation.
fj>) "Gas turbine model" means a
group of gas turbines having the same
nominal air flow, combuster inlet
pressure, combuster inlet temperature.
firing temperature, turbine inlet
temperature and turbine inlet pressure.
§ 60432 Standard for nitrogen oxides.
(a) On and after the date on which the
performance test required by § 60.8 is
completed, every owner or operator
subject to the provisions of this subpart,
as specified in paragraphs (b), (c), and
(d) of this section, shall comply with one
of the following, except as provided in
paragraphs (e), {f), (gj, (h), and (i) of this
section.
(1) No owner or operator subject to
the provisions of this subpart shall
cause to be discharged into the
atmosphere from any stationary gas
turbine, any gases which contain
nitrogen oxides in excess of:
(14 4)
STD = 0.0075 Y + F
32
where:
SI L)=allowable NO, emissions (percent by
volume at 15 percent oxygen and on a
dry basis).
Y=manufacturer's rated heat rate at
manufacturer's rated load (kilojoules per
welt hour) or, actual measured heat rate
based on lower heating value of fuel as
measured at actual peak load for the
facility. The value of Y shall not exceed
14.4 kilojoules per watt hour.
F=NO, emission allowance for fuel-bound
nitrogen as defined in part (3) of this
paragraph.
(2) No owner or operator subject to the
provisions of this subpart shall cause to be
discharged into the atmosphere from any
stationary gas turbine, any gases which
con'ain nitrogen oxides in excess of:
STD = O.OT50 (-^~) + F
where:
STD=«llowable NO, emissions (percent by
volume at IS percent oxygen and on a
dry basis).
Y=manufacturer's rated heat rate at
manufacturer's rated peak load
(kilojoules per watt hour), or actual
measured heat rate based on lower
beating value of fuel as measured at
actual peak load for the facility. The
value of Y shall not exceed 14.4
kilojoules per watt hour.
F=NO, emission allowance for fuel-bound
nitrogen as defined in part (3) of this
paragraph.
(3) F shall be defined according to the
nitrogen content of the fuel as follows:
Fu*l-8oum) KHrogen f
(percent by ««ignt) (NO percent by volume)
N < 0.015
0.015 < N <_ 0.1
0.1 - N < 0.25
» > O.X
0.04(N)
0.004 * 0.0067
-------
exemptions will be allowed only while
the mandatory water restrictions are in
effect.
§ 60.333 Standard for sulfur dioxide.
On and after the date on which the
performance test required to be
conducted by § 60.8 is completed, every
owner or operator subject to the
provision of this subpart shall comply
with one or the other of the following
conditions: v
(a) No owner or operator subject to
the provisions of this subpart shall
cause-k> be discharged into the
atmosphere from any stationary gas
turbine any gases which contain sulfur
dioxide in excess of 0.015 percent by
volume at 15 percent oxygen and on a
dry basis.
(b) No owner or operator subject to
the provisions of this subpart shall burn
in any stationary gas turbine any fuel
which contains sulfur in excess of 0.8
percent by weight.
$60.334 Moriilofiiig of operations.
(a) The owner or operator of any
stationary gas turbine subject to the
provisions of this subpart and using
water injection to control NO, emissions
shall install and operate a continuous
monitoring system to monitor and record
the fuel consumption and the ratio of
water to fuel being fired in the turbine.
This system shall be accurate to within
±5.0 percent and shall be approved by
the Administrator.
(b) The owner or operator of any
stationary gas turbine subject to the
• provisions of this subpart shall monitor
sulfur content and nitrogen content of
the fuel being fired in the turbine. The
frequency of determination of these
values shall be as follows:
(1) If the turbine is supplied its fuel
from a bulk storage tank, the values
shall be determined on each occasion
that fuel is transferred to the storage
tank from any other source.
(2J If the turbine is supplied its fuel
without intermediate bulk storage the
values shall be determined and recorded
daily. Owners, operators or fuel vendors
may develop custom schedules for
determination of the values based on the
design and operation of the affected
facility and the characteristics of the
fuel supply. These custom schedules
shall be substantiated with data and
must be approved by the Administrator
before, they can be used to comply with
paragraph (b) of this section.
(c) For the purpose of reports required
under § 60.7(c), periods of excess
emissions that shall be reported are
defined as follows:
(1) Nitrogen oxides. Any one-hour
period during which the average water-
to-fuel ratio, as measured by the
continuous monitoring system, falls
below the water-tQ-fuel ratio determined
to demonstrate compliance with § 60.332
by the performance test required in
§ 60.8 or any period during which the
fuel-bound nitrogen of the fuel is greater
than the maximum nitrogen content
allowed by the fuel-bound nitrogen
allowance used during the performance
test required in § 60.8. Each report shall
Include the average water-to-fuel ratio,
average fuel consumption, ambient
conditions, gas turbine load, and
nitrogen content of the fuel during the
period of excess emissions, and the
graphs or figures developed under
§ 60.335(a).
(2) Sulfur dioxide. Any daily period
during which the sulfur content of the
fuel being fired in the gas turbine
exceeds 0.8 percent.
(3) Ice fog. Each period during which
an exemption provided in § 60.332(g) is
in effect shall be reported in writing to
the Administrator quarterly. For each
period the ambient conditions existing
during the period, the date and time the
P
air pollution control system was
deactivated, and the date and time the
air pollution control system was
reactivated shall be reported. All
quarterly reports shall be postmarked by
the 30th day following the end of each
calendar quarter.
(Sec. 114 of the Clean Air Act as amended [42
U.S.C. 1B57C-9]).
$ 60.335 Test methods and procedures.
(a) The reference methods in
Appendix A to this part, except as
provided in § 60.8(bJ. shall be used to
determine compliance with the
' standards prescribed in 5 60.332 as
follows:
(1) Reference Method 20 for the
concentration of nitrogen oxides and
oxygen. For affected facilities under this
subpart the span value shall be 300
parts- per million of nitrogen oxides.
(i) The nitrogen oxides emission level
measured by Reference Method 20 shall
be adjusted to ISO standard day
conditions by the following ambient
condition correction factor
= (N0y
y
obs
refxO.5
j I
obs
e19CH
obs
- 0.00633) (
'AMB
where:
NO. = emi3sions of NO, at 15 percent oxygen
and ISO standard ambient conditions.
NOKO«, = measured NO, emissions at 15
percent oxygen, ppmv.
Pt«<= reference combusler inlet absolute
pressure at 101.3 kilopascals ambient
pressure.
P«fc. = measured combustor inlet absolute
pressure at test ambient pressure.
Hol-= specific humidity of ambient air at test
e= transcendental constant (2.718).
Tore = temperature of ambient air at test
The adjusted NO, emission level shall
be used to determine compliance with
§ 60.332.
(ii) Manufacturers may develop
* custom ambient condition correction
factors for each gas turbine model they
manufacture in terms of combustor inlet
pressure, ambient air pressure, ambient
air humidity and ambient air
temperature to adjust the nitrogen
oxides emission level measured by the
performance test as provided for in
§ 60.8 to ISO standard day conditions.
These ambient condition correction
factors shall be substantiated with data
and must be approved for use by the
Administrator before the initial"
performance test required by § 60.8.
Notices of approval of custom ambient
condition correction factors will be
published in the Federal Register.
(iii) The water-to-fuel ratio necessary
to comply with § 60.332 will be
determined during the initial
performance test by measuring NO,
emission using Reference Method 20 and
the water-to-fuel ratio necessary to
comply with § 60.332 at 30, 50, 75, and
100 percent of peak load or at four
points in the normal operating range of
the gas turbine, including the minimum
point in the range and peak load. All
loads shall be corrected to ISO
conditions using the appropriate
equations supplied by the manufacturer.
(2) The analytical methods and
procedures employed to determine the
nitrogen content of the fuel being fired
shall be approved by the Administrator
and shall be accurate to within ±5
percent.
(b) The method for determining
compliance with § 60.333, except as
provided in § 60.8(b), shall be as _ .
-follows:
(1) Reference Method 20 for the
concentration of sulfur dioxide and
oxvgen or
(2) ASTM D2830-71 for the sulfur
content of liquid fuels and ASTM
D1072-70 for the sulfur content of
gaseous fuels. These methods shall also
be used to comply with § 60.334(b).
{c) Analysis for the purpose of
determining the sulfur content and the
nitrogen content of the fuel as required
by § 60.334(b), this subpart may be
performed by the owner/operator, a
service contractor retained by the
owner/operator, the fuel vendor, or any
other qualified agency provided that the
analytical methods employed by these
agencies comply with the applicable
paragraphs of this section.
11-99
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NSPS REGULATIONS - PROPOSED
11-100
-------
ENVIRONMENTAL PROTECTION
AGENCY
40 CFR Part 60
IFRL 12/6-4)
Standards of Performance for New
Stationary Sources; Continuous
Monitoring Performance
Specifications
AGENCY: Environmental Protection
Agency (EPA).
ACTION: Proposed Revisions.
SUMMARY: On October 6.1975 (40 FR
46250). the EPA promulgated revisions to
40 CFR Part 60. Standards of
Performance for New Stationary
Sources, to establish specific
requirements pertaining lo continuous
emission monitoring. An appendix to the
regulation contained Performance
Specifications 1 through 3, which
detailed the continuous monitoring
instrument performance and equipment
specifications, installation requirements,
and test and data computation
procedures for evaluating the
acceptability of continuous monitoring
cystems. Since the promulgation of these
performance specifications, the need for
a number of changes which would
clarify the specification test procedures,
equipment specifications, and
monitoring system installation
requirements has become apparent. The
purpose of the revisions is to
incorporate these changes into
Performance Specifications 1 through 3.
The proposed revisions would apply
to all monitoring systems currently
subject to performance specifications 1.
2. or 3, including sources subject to
Appendix P to 40 CFR Part 51.
DATES: Comments must be received on
or before December 10.1979.
ADDRESSES: Comments. Comments
should be submitted (in duplicate if
possible) to the Central Docket Section
(A-130). Attn: Docket No. OAQPS-79-^,
U.S. Environmental Protection Agency.
401 M Street. S.W.. Washington. D.C.
204GO.
Docket. Docket No. OAQPS-79-4,
containing material relevant to this
rulemaking. is located in the U.S.
Environmental Protection Agency,
Central Docket Section. Room 2903B. 401
M Street. S.W.. Washington. D.C. The
docket may be inspected between 8
A.M. and 4 P.M. on weekdays, and a
reasonable fee may be charged for
copying.
FOB FURTHER INFORMATION CONTACT:
Don R. Goodwin. Director. Emission
Standards and Engineering Division
(MD-13). Environmental Protection
Agency, Research Triangle Park. North
Carolina 27711. telephone number (919)
541-5271.
SUPPLEMENTARY INFORMATION: Changes
common to all three of the performance
specifications are the clarification of the
procedures and equipment
specifications, especially the
requirement for intalling the continuous
monitoring sample interface and of the
calculation procedure for relative
accuracy. Specific changes to the
specifications are as follows:
Performance Specification
1. The optical design specification for
mean and peak spectral responses and
for the angle of view and projection
have been changed from "500 to 600 nm"
range to "515 to 585 nm" range and from
"5"' to "3"'. respectively.
2, The following equipment
specifications have been added:
a. Optical alignment sight indicator
for readily checking alignment.
b. For instruments having automatic
compensation for dirt accumulation on
exposed optical surfaces, a
compensation indicator at the control
panel so that the permissible maximum
4 percent compensation can be
determined.
c. Easy access to exposed optical
surfaces for cleaning and maintenance.
d. A system for checking zero and
upscale calibration (previously required
in paragraph 60.13).
e. For systems with slotted tubes, a
slotted portion greater than 90 percent of
effluent pathlength (shorter slots are
permitted if shown to be equivalent).
f. An equipment specification for the
monitoring system data recorder
resolution of <5 percent of full scale.
3. A procedure for determining the
acceptability of the optical alignment
sight has been specified: the optical
alignment sight must be capable of
indicating that the instrument is
misaligned when an error of ±2 percent
opacity is caused by misalignment of the
instrument at a pathlength of 8 meters.
4. Procedures for calibrating the
attenuators used during instrument
calibrations have been added: these
procedures require the use of a
laboratory spectrophotometer operating
in the 400-700 nm range with a detector
angle view of, <10 degrees and an
accuracy of 1 percent.
5. The following changes have been
made to the procedures for the
operational test period:
a. The requirement for an analog strip
chart recorder during the performance
tests has been deleted: all data are
collected on the monitoring system data
recorder.
b. Adjustment of the zero and sp.in H(
24-hour intervals during the drift tests is
optional: adjustments are required only
when the accumulated drift exceeds the
24-hour drift specification.
c. The amount of automatic zero
compensation for dirt accumulation
must be determined during the 24-hour
zero check so that the actual zero drift
can be quantified. The automatic zero
compensation system must be operated
during the performance test.
d. The requirement for offsetting the
data recorder zero during the
operational lest period has been deleted.
e. Off the stack "zero alignment" of
the instrument prior to installation is
permitted.
Performance Specification 2
1. "Continuous monitoring system"
has been redefined to include the
diluent monitor, if applicable. The
change requires that the relative
accuracy of the system be determined in
terms of the emission standard, e.g.,
mass per unit calorific value for fossil-
fuel fired steam generators.
2. The applicability of the test
procedures excludes single-pass, in-situ
continuous monitoring systems. The
procedures for determining the
acceptability of these systems are
evaluated on a case-by-case basis.
3. For extractive systems with diluent
monitors, the pollutant and diluent
monitors are required to use the same
sample interface.
4. The procedure for determining the
acceptability of the calibration gases
has been revised, and the 20 percent
(with 95 percent confidence interval)
criterion has been changed to 5 percent
of mean value with no single value being
over 10 percent from the mean.
5. For low concentrations, a 10 percent
of the applicable standard limitation for
the relative accuracy has been added.
6. A_n equipment specification for the
system data recorder requiring that the
chart scale be readable lo within <0.50
percent of full-scale has been added.
7. Instead of spanning the instrument
at 90 percent of full-scale, a mid-level
span is required.
8. The response time test procedure
has been revised and the difference
limitation between the up-scale and
down-scale time has been deleted.
9. The relative accuracy test
procedure has been revised to allow
different tests (e.g.. pollutant, diluent,
moisture) during a 1-hour period to be
correlated.
10. A low-level drift may be
substituted for the zero drift test
11-101
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Performance Specification 3
1. The applicability of the test
procedures has been limited to those
monitors that introduce calibration
gases directly into the analyzer and are
used as diluent monitors. Alternative
procedures for other types of monitors
are evaluated on a case-by-case basis.
2, Other changes were made to be
consistent with the revisions under
Performance Specification 2.
The^proposed revised performance
specifications would apply to all sources
subject to Performance Specifications 1.
2. or 3. These include sources subject to
standards of performance that have
already been promulgated and sources
subject to Appendix-P to 40 CFR Part 51.
Since the purpose of these revisions is to
clarify the performance specifications
which were promulgated on October 6.
1975. not to establish more stringent
requirements, it is reasonable to
conclude that most continuous
monitoring instruments which met and
can continue to meet the October 6,
1975. specifications can also meet the
revised specifications.
Under Executive Order 12044. the
Environmental Protection Agency is
required to judge whether a regulation is
"significant" and therefore subject to the
procedural requirements of the Order or
whether it may follow other specialized
development procedures. EPA labels
these other regulations "specialized". I
have reviewed this regulation and
determined thai it is a specialized
regulation not subject to the procedural
requirements of Executive Order 12044.
Dated: October 1.1979.
Douglas M. Costle,
Administrator.
It is proposed to revise Appendix B.
Part 60 of Chapter 1, Title 40 of the Code
of Federal Regulations as follows:
Appendix B—Performance
Specifications
Performance Specification 1—
Specifications and Test Procedures For
Opacity Continuous Monitoring Systems
in Stationary Sources
1. Applicability and'Principle
1.1 Applicability. This Specification
contains instrument design,
performance, and installation
requirements, and teat and data
computation procedures for evaluating
the acceptability of continuous
monitoring systems for opacity. Certain
design requirements and lest procedures
established in the Specification may not
be applicable to ell instrument designs:
equivalent systems and test procedures
may be used with prior approval by the
Administrator.
1.2 Principle. The opacity of
particulale matter in stack emissions Is
continuously monitored by a
measurement system based upon the
principle of transmissometry. Light
having specific spectral characteristics
is projected from a lamp through the
effluent in the stack or duct and the
intensity of the projected light is
measured by a sensor. The projected
light is attenuated due to absorption and
scatter by the particulale matter in the
effluent; the percentage of visible light
attenuated is defined as the opacity of
the emission. Transparent stack
emissions that do not attenuate light will
have a transmittance of 100 percent or
an opacity of zero percent. Opaque
stack emissions that attenuate all of the
visible light will have a transmittance of
zero percent or an opacity of 100
percent.
This specification establishes specific
design criteria for the transmissometer
system. Any opacity continuous
.monitoring system that is expected to
meet this specification is first checked to
verify that the design specifications are
met. Then, the opacity continuous
monitoring system is calibrated,
installed, an operated fora specified
length of time. During this specified time
period, the system is evaluated to
determine conformance with the
established performance specifications.
2. Definitions
2.1 Continuous Monitoring System.
The total equipment required for the
determination of opacity. The system
consists of the following major
subsystems:
,2.1.1 Sample Interface. That portion
of the system that protects the analyzer
from the effects of the stack effluent and
aids in keeping the optical surfaces
clean.
2.1.2 Analyzer. That portion of the
system that senses the pollutant and
generates a signal otttput that is a
function of the opacity.
2.1.3 Data Recorder. That portion of
the system that processes the analyzer
output and provides a permanent record
of the output signal in terms of opacity.
The data recorder may include
automatic data reduction capabilities.
2.2 Transmissometer. That portion of
the system that includes the sample
interface and the analyzer.
2.3 Transmittance. The fraction of
incident light that is transmitted through
an optical medium.
2.4 Opacity. The fraction of incident
light that is attenuated by an optical
medium. Opacity (Op) and
transmittance (Tr) are related by:
Op=l-Tr.
2.5 Optical Density. A logarithmic
measure of the amount of incident light
attenuated. Optical density (D) is
related to the transmittance and opacity
as follows:
D= -log,. Tr= -log,. (1 -Op).
2.6 Peak Spectral Response. The
wavelength of maximum sensitivity of
(he transmissometer.
2.7 Mean Spectral Response. The
wavelength which bisects the total area
under the effective spectral response
curve of the transmissometer.
2.8 Angle of View. The angle that
contains all of the radiation detected by
the photodetector assembly of the
analyzer at a level greater than 2.5
percent of the peak detector response.
2.9 Angle of Projection. The angle
that contains all of the radiation
projected from the lamp assembly of Ihe
analyzer at a level of greater than 2.5
percent of the peak illuminate.
2.10 Span Value. The opacity value
at which the continuous monitoring
system is set to produce the maximum
data display output as specified in the
applicable subpart.
2.11 Upscale Calibration Value. The
opacity value at which a calibration
check of the monitoring system is
performed by simulating an upscale
opacity condition as viewed by the
receiver.
2.12 Calibration Error. The
difference between the opacity values
indicated by the continuous monitoring
system and the known values of a series
of calibration attenuators (fillers or
screens).
2.13 Zero Drift. The difference in
continuous monitoring system output
readings before and after a stated period
of normal continuous operation during
which no unscheduled maintenance,
repair, or adjustment took place and
when the opacity (simulated) at the time
of the measurements was zero.
2.14 CaJibralion Drift. The difference
in the continuous monitoring system
output readings* before and after a staled
period of normal continuous operation
during which no unscheduled
maintenance, repair, or adjustment look
place and when the opacity (simulated)
at Ihe time of the measurements was th*
same known upscale calibration value.
2.15 Response Time. The amount of
time it takes the continuous monitoring
system to display on the data recorder
95 percent of a step change in opacity.
2.16 Conditioning Period. A period of
time (168 hours minimum) during which
the continuous monitoring ayslem i)
operated without unscheduled
maintenance, repair, or adjustment pno'
lo initiation of the operational lest
period.
11-102
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2.17 Operational Test Period. A
period of time (168 hours) during which
the continuous monitoring system is
expected to operate within the
established performance specifications
without any unscheduled maintenance.
repair, or adjustment.
2.18 Pathlength. The depth of
effluent in the light beam between the
receiver and the transmitter of a single-
pass trar.smissometer. or the depth of
effluent between the transceiver and
reflector of a double-pass
transmissometer. Two pathlengths are
referenced by this Specification as
follows:
2.18,1 Monitor Pathlength. The
palhlength at the installed location of
the continuous monitoring system.
2.18.2 Emission Outlet Pathlength.
The pathlength at the location where
emissions are released to the
atmosphere.
4. Installation Specifications
3. Apparatus
3.1 Continuous Monitoring System.
Use any continuous monitoring system
for opacity which is expected to meet
the design specifications in Section 5
and the performance specifications in
Section 7. The data recorder may be an
analog strip chart recorder type or other
suitable device with an input signal
range compatible with the analyzer
output
3.2 Calibration Attenuators. Use
optical filters with neutral spectral
characteristics or screens known to
produce specified optical densities to
visible light. The attenuators must be of
sufficient size to attenuate the entire
light beam of the transmissomeler.
Select and calibrate a minimum of three
attenuators according to the procedures
in Sections 8.1.2. and 8.1.3.
3.3 Upscale Calibration Value
Attenuator. Use an optical filter with
neutral spectral characteristics, a
screen, or other device that produces an
opacity value (corrected for pathlength,
if necessary) that is greater than the sum
of the applicable opacity standard and
one-fourth of the difference between the
opacity standard and the instrument
span value, but less than the sum of the
opacity standard and one-half of the
difference between the opacity standard
and the instrument span value.
3.4 Calibration Spectrophotometer.
To calibrate the calibration attenuators
use a laboratory spectrophotometer
meeting the following minimum design
specification:
. 400-TOO («
. S l(T
. S OS pet »»nt/Twunc*
Install the continuous monitoring
system where the opacity measurements
are representative of the total emissions
from the affected facility. Use a
measurement path that represents the
average opacity over the cross section.
Those requirements can be met as
follows:
4.1 Measurement Location. Select a
measurement location that is (a)
downstream from all particulate control
equipment; (bj where condensed water
vapor is not present: (c) accessible in
order to permit routine maintenance;
and (d) free of interference from
ambient light (applicable only if
transmissometer is responsive to
ambient light).
4.2 Measurement Path. Select a
measurement path that passes through
the cenlroid of the cross section.
Additional requirements or
modifications must be met for certain
locations as follows:
4.2.1 If the location is in a straight
vertical section of stack or duct and is
less than 4 equivalent diameters
downstream or 1 equivalent diameter
upstream from a bend, use a path that is
in the plane defined by the bend.
4.2.2 If the location is in a vertical
section of stack or duct and is less than
4 diameters downstream and 1 diameter
upstream from a bend, use a path in the
plane defined by the bend upstream of
the transmissometer.
4.2.3 If the location is in a horizontal
section of duct and is at least 4
diameters downstream from a vertical
bend, use a path in the horizontal plane
that is one-third the distance up the
vertical axis from the bottom of the duct.
4.2.4 If the location is in a horizontal
section of duct and is less than 4
diameters downstream from a vertical
bend, use a path in the horizontal plane
that is two-thirds the distance up the
vertical axis from the bottom of the duct
for upward flow in the vertical section,
and one-third the distance up the
vertical axis from the bottom of the duct
for downward flow.
4.3 Alternate Locations and
Measurement Paths. Other locations and
measurement paths may be selected by
demonstrating to the Administrator that
the average opacity measured at the
alternate location or path is equivalent
(± 10 percent) to the opacity as
measured at a location meeting the
criteria of Sections 4.1 and 4.2. To
conduct this demonstration, measure the
opacities at the two locations or paths
for a minimum period of two hours The
opacities of the two locations or paths
may be measured at different times but
must be measured at the same process
operating conditions.
5. Design Specifications
Continuous monitoring systems for
opacity must comply with the following
design specifications:
5.1 Optics.
5.1.1 Spectral Response. The peak
and mean spectral responses will occur
between 515 nm and 585 nm. The
response at any wavelength below 400
nm or above 700 nm will be less than 10
percent of the peak spectral response.
5.1.2 Angle of View. The total angle
of view will be no greater than 4
degrees.
5.1.3 Angle of Projection. The total
angle of projection will be no greater
than 4 degrees.
5.2 Optical Alignment sight. Each
analyzer will provide some method for
visually determining that the instrument
is optically aligned. The system
provided will be capable of indicating
that the unit is misaligned when an error
of ± 2 percent opacity occurs due to
misalignment at a monitor pathlength of
eight (8) meters.
5.3 Simulated Zero and Upscale
Calibration System. Each analyzer will
include a system for simulating a zero
opacity and an upscale opacity value for
the purpose of performing periodic
checks of the transmissometer
calibration while on an operating stack
or duct. This calibration system will
provide, as a minimum, a system check
of the analyzer internal optics and all
electronic circuitry including the lamp
and photodetector assembly.
5.4 Access to External Optics. Each
analyzer will provide a means of access
to the optical surfaces exposed to the
effluent stream in order to permit the
surfaces to be cleaned without requiring
removal of the unit from the source
mounting or without requiring optical
realignment of the unit.
5.5 Automatic Zero Compensation
Indicator. If the monitoring system has a
feature which provides automatic zero
compensation for dirt accumulation on
exposed optical surfaces, the system
will also provide some means of
indicating that a compensation of
4 + 0.5 percent opacity has been
exceeded; this indicator shall be at a
location accessible to the operator (e.g..
the data output termini!). During the
operational test period, the system musl
provide some means for determining the
actual amount of zero compensation at
the .specified 24-hour intervals so that
the actual 24-hour zero drift can be
determined (see Section 8.4.1).
5.6 Slotted Tube. For
transmissometers that use slotted tubes,
the length of the slotted portion(s) must
II-103
-------
b« equal to or greater than 90 percent of
the monitor pathlength. and the slotted
tube must be of sufficient size and
orientation so as not to interfere with
the free flow of effluent through the
entire optical volume of the
Iransmissometer pholodetector. The
manufacturer must also show that the
Iransmissometer uses appropriate
methods to minimize light reflections: as
a minimum, (his demonstration shall
consist of laboratory operation of the
transmissometerboth with and without
the slotted tube in position. Should the
operator desire to use a slotted tube
design with a slotted portion equal to
less than 90 percent of the monitor
pathlength. the operator must
demonstrate to the Administrator thai
acceptable results can be obtained. As a
minimum demonstration, the effluent
opacity shall be measured using both
the slotted tube instrument and another
instrument meeting the requirement of
this specification but not of the slotted
tube design. The measurements must be
made at the same location and at the
same process operating conditions for a-
minimum period of two hours with each
instrument. The shorter slotted tube may
be used if the average opacity measured
is equivalent (± 10 percent) to the
opacity measured by the non-slotted
lube design.
6. Optical Design Specifications
Verifciation Procedure.
These procedures will not be
applicable to all designs and will require
modification in some cases; all
modifications are subject to the
approval of the Administrator.
Test each analyzer for conformance
with the design specifications of
Sections 5.1 and 5.2 or obtain a
certificate of conformance from the
analyzer manufacturer as follows:
6.1 Spectral Response. Obtain
detector response, lamp emissivity and
filter Iransmiltance data for the
components used in the measurement
system from their respective
manufacturers.
6.2 Angle of View. Set up the
receiver as specified by the
manufacturer's written instructions.
Draw an arc with radius of 3 meters in
the horizontal direction. Using a small
(less than 3 centimeters) non-directiona.1
light source, measure the receiver
response at 4-centimeter intervals on the
arc for 24 centimeters on either side of
the detector centerline. Repeat the test
in the vertical direction.
6.3 Angle of Projection. Set up the
projector as specified by the
manufacturer's written instructions.
Draw an arc with radius of 3 meters in
the horizontal direction. Using a small
(less than 3 centimeters) photoelectric
light detector, measure the light
intensity at 4-centimeter intervals on the
arc for 24 centimeters on either side of
the light source centerline of projection.
Repeat the test in the vertical direction.
8.4 Optical Alignment Sight. In the
laboratory set up the instrument as
specified by the manufacturers written
instructions for a monitor pathlength of
8 meters. Assure that the instrument has
been properly aligned and that a proper
zero and span have been obtained.
Insert an attenuator of 10 percent
(nominal) opacity into the instrument
pathlength. Slowly misalign the
projector unit until a positive or negative
shift of two percent opacity is obtained
by the data recorder. Then, following
the manufacturer's written instructions,
check the alignment and assure that the
alignment procedure does in fact
indicate that the instrument is
misaligned. Realign the instrument and
follow the same procedure for checking
misalignment of the receiver or
retroreflector unit
T»Mc 1-1.—
6.5 Manufacturer's Certificate of
Conformance (Alternative to above).
Obtain from the manufacturer a
certificate of conformance which
certifies that the first analyzer randomly
sampled from each month's production
was tested according to Sections 6.1
through 6.3 and satisfactorily met all
requirements of Section 5 of this
Specification. If any of the requirements
were not met. the certificate must state
that the entire month's analyzer-
production was resampled according to
the military standard 105D sampling
procedure (MIL-STTM05D) inspection
level II; was retested for each of the
applicable requirements under Section 5
of this Specification: and was
determined to be acceptable under MIL-
STD-105D procedures, acceptable
quality level 1.0. The certificate of
conformance must include the results of
each test performed for the analyzer(s)
sampled during the month the analyzer
being installed was produced.
7. Performance Specifications
The opacity continuous monitoring
system performance specifications are
listed in Table 1-1.
TaW« \-\.—
7. Data *vcarc*«*
. S J pet mo*
. S 0 50 pa ol M KJ,
•pan *•!•*.
maag n« eofditorwg and operational toil ptrvdi. ^
trvr^omj syHem X\ai no< »
. r«ea«. rapJ«c**ri«n|.
tful ctearty cp*ol>*d js rcgtjn* and raquvad in
8. Performance Specification
Verification Procedure
Test each continuous monitoring
system that conforms to the design
specifications (Section 5) using the
following procedures to determine
conformance with the performance
specifications of Section 7,
8.1 Preliminary Adjustments and
Tests. Prior to installation of the syslero
on the stack, perform these steps ortesli
at the affected facility or in the
manufacturer's laboratory.
8.1.1 Equipment Preparation. Set up
and calibrate the monitoring system for
the monitor pathlength to be used in the
installation as specified by the
manufacturer's written instructions. If
the monitoring system has automatic
pathlength adjustment, follow the
manufacturer's instructions to adjust (he
signal output from the analyzer to
equivalent values based on the emission
outlet pathlength. Set the span a! the
value specified in the applicable
subpart. At this time perform the zero
alignment by balancing the responseol
the continuous monitoring system so
that the simulated zero check coincide!
with the actual zero check performed
across the simulated monitor pathlenglk.
Then, assure that the upscale calibration
value is within the required opacity
range (Section 3.3).
8.1.2 Calibrated Attenuator
Selection. Based on the span value
specified in the applicable subpart,
select a minimum of three calibrated
attenuators (low, mid. and high range)
using Table 1-2. If the'system is
operating with automatic palhlenglh
compensation, calculates the attenuator
values required to obtain a system
response equivalent to the applicable
values shown in Table 1-2: use equation
1-1 for the conversion. A series of fill"1
with nominal optical density (opacity)
values of 0.1(20). 0.2(37). 0.3(50). 0.4(60),
0.5{6a). 0-6(75). 0.7(80). O^B^J. 0.9(88).
and 1.0(90) are commercially available.
Within this limitation of filter
availability, select the calibrated
11-104
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attenuators having the values given in
Table 1-2 or having values closest to
those calculated by Equation 1-1.
Tibl« 1-2.—Requred C*l!braled AltenvalotValues
(Nomnal)
C*U»t«d (87*)
D, = D, (L./U) Equation 1-1
Where:
Di = Nominal optical density value of
required mid. low. or high range
calibration attenuators.
0.= Desired attenuator optical density
output value from Table 1-2 at the span
required by the applicable subparL
Li = Monitor palhlength.
L, = Emission outlet palhlength.
8.1.3 Attenuator Calibration.
Calibrate the required filters or screens
using a laboratory spectrophotomeler
meeting the specifications of Section 3.4
to measure the transmittance in the 400
to 700 nm wavelength range; make
measurements at wavelength intervals
of 20 nm or less. As an alternate
procedure use an instrument meeting the
specifications of Section 3.4 to measure
the C.I.E. Daylightc Luminous
Transmittance of the attenuators. During
the calibration procedure assure that a
minimum of 75 percent of the total area
of the attenuator is checked. The
attenuator manufacturer must specify
the period of lime over which the
attenuator values can be considered
stable, as well as any special handling
and storing procedures required to
enhance attenuator stability. To assure
stability, attenuator values must be
rechecked at intervals less than or equal
to the period of stability guaranteed by
the manufacturer. However, values must
be rechecked at least every 3 months. If
desired, t^^-stability checks may be
performed on an instrument other than
that initially used for the attenuator
calibration (Section 3.4). However, if a
different instrument is used, the
instrument shall be a high quality
laboratory transmissometer or
spectrophotomeler and the same
instrument shall always be used for the
stability checks. If a secondary
instrument is to be used for stability
checks, the value of the calibrated
attenuator shall be measured on this
secondary instrument immediately
following calibration and prior to being
used. If over a period time an attenuator
value changes by more than ±2 percent
opacity, it shall be recalibrated or
replaced by a new attenuator.
If this procedure is conducted by the
filter or screen manufacturer or
independent laboratory, obtain a
statement certifying the values and that
the specified procedure, or equivalent,
was used.
8.1.4 -Calibration Error Test Insert
the calibrated attenuators (low, mid, and
high range) in the transmissometer path
al or as near to the midpoint as feasible.
The attenuator must be placed in the
measurement path at a point where the
effluent will be-measured: i.e.. do not
place the calibrated attenuator in the
instrument housing. While inserting the
attenuator, assure that the entire
projected beam will pass through the
attenuator and that the attenuator is
inserted in a manner which minimizes
interference from reflected light. Make a
total of five nonconsecutive readings for
each filter. Record the monitoring
system output readings in percent
opacity (see example Figure 1-1).
8.1.5 System Response Test. Insert
the high-range calibrated attenuator in
the transmissometer path five times and
record the time required for the system
to respond to 95 percent of final zero
and high-range filter values (see
example Figure 1-2).
8.2 Preliminary Field Adjustments.
Install the continuous monitoring system
on the affected facility according to the
manufacturer's written instructions and
perform the following preliminary
adjustments:
8.2.1 Optical and Zero Alignment.
When the facility is not in operation,
conduct the optical alignment by
aligning the light beam'from the
transmissometer upon the optical
surface located across the duct or stack
(i.e.. the retroflector or photodetector, as
applicable) in accordance with the
manufacturer's instructions. Under dear
stack conditions, verify the zero
alignment (performed in Section 8.1.1)
by assuring that the monitoring system
response for the simulated zero check
coincides with the actual zero measured
by the transraissometer across the dear
stack. Adjust the zero alignment, if
necessary. Then, after the affected
facility has been started up and the
effluent stream reaches normal
operating temperature, recheck the
optical alignment. If the optical
alignment has shifted realign the optics.
8.2.2 Optical and Zero Alignment
(Alternative Procedure). If the facility is
already on line and a zero stack
condition cannot practicably be
obtained, use th,e zero alignment
obtained during the preliminary
adjustments (Section 8.1.1) prior to
installation of the Iransmissometer on
the slack. After completing all the
preliminary adjustments and tests
'required in Section 8.1. install the
system at the source and align the
optics, i.e., align the light beam from the
transmissometer upon the optical
surface located across the duct or stack
in accordance with the manufacturer's
instruction. The zero alignment
conducted in this manner shall be
verified and adjusted if necessary, the
first time the facility is not in operation
after the operational test period has
been completed.
8.3 Conditioning Period. After
completing the preliminary field
adjustments (Section 8.2), operate the
system according to the manufacturer's
instructions for an initial conditioning
period of not less than 1&8 hours while
the source is operating. Except during
times of instrument zero and upscale
calibration checks, the continuous
monitoring system will analyze the
effluent gas for opacity and produce a
permanent record of the continuous
monitoring system output. During this
conditioning period there shall be no
unscheduled maintenance, repair, or
adjustment. Conduct daily zero
calibration and upscale calibration
checks, and. when accumulated drift
exceeds the daily operating limits, make
adjustments and/or clean the exposed
optical surfaces. The data recorder shall
reflect these checks and adjustments. At
the end of the operational test period.
verify that the instrument optical
alignment is correct. If the conditioning
period is interrupted because of source
breakdown (record the dates and times
of process shutdown), continue the 168-
hour period following resumption of
source operation. If the conditioning
period is interrupted because of monitor
failure, restart the 168-hour conditioning
period when the monitor becomes
operational.
8.4 Operational Test Period. After
completing the conditioning period
operate the system for an additional
168-hour period. It is not necessary that
the 168-hour operational test period
immediately follow the 168-hour
conditioning period. Except during times
of instrument zero and upscale
calibration checks. th« continuous
monitoring system will analyze the
effluent gas for opacfry and will produce
a permanent record of the continuous
monitoring system output. During this
period, there will be no unscheduled
maintenance, repair, or adjustment. Zero
and calibration adjustments, optical
surface cleaning, and optical
realignment may be performed
(optional) only at 24-hour intervals or at
11-105
-------
such shorter intervals as (he
manufacturer's written instructions
specify. Automatic zero and calibration
adjustments made by the monitoring
system without operator intervention or
initiation are followable at any time. If
the operational lest period is interrupted
because of source breakdown, continue
Ihe left-hour period following
resumption of source operation. If the
tesl jwriod is interrupted because of
monitor failure, restart the 168-hour
period when the monitor becomes
operational. During the operational test
period, perform the following test
procedures:-
8.4.1 Zero Drift Test. At the outset of
the 168-hour operational test period,
record the initial simulated zero and
upscale opacity readings (see example
Figure 1-3). After each 24-hour interval
check and record the final zero reading
before any optional or required cleaning
and adjustment. Zero and upscale
calibration adjustments, optical surface
cleaning, and optical realignment may
be performed only at 24-hour intervals
(or at such shorter intervals as the
manufacturer's written instructions
specify) but are optional. However,
adjustments and/or cleaning must be
performed when the accumulated zero
calibration or upscale calibration drift
exceeds the 24-hour drift specifications
(±2 percent opacity). If no adjustments
are made after the zero check the final
zero reading is recorded as the initial
reading for the next 24-hour period. If
adjustments are made, the zero value
after adjustment is recorded as the
initial zero value for the next 24-hour
period. If the instrument has an
automatic zero compensation feature for
dirt accumulation on exposed lens, and
the zero value cannot be measured
before compensation is entered then
record the amount of automatic zero
compensation for the final zero reading
of each 24-hour period. (List the
indicated zero values of the monitoring
system in parenthesis.)
8.4.2 Upscale Drift Test/At each 24-
hour interval, after the zero calibration
value has been checked and any
optional or required adjustments have
been made, check and record the
simulated upscale calibration value. If
no further adjustments are made to the
calibration system at this time, the final
upscale calibration value is recorded as
the initial upscale value for the next 24-
hour period. If an instrument span
adjustment is made, the upscale value
after adjustment is recorded as the
Initial upscale for the next 24-hour
period.
During the operational test period
record all adjustments, realignments and
lens cleanings.
9. Calculation, Data Analysis, and
Reporting
9.1 Arithmetic Mean. Calculate the
mean of a set of data as follows:
i ;
n i-i
2-1
Where:
~x = mean value.
n = number of data points.
Ix, = algebraic turn of the individual
measurement!, x,
9.2 Confidence Interval. Calculate
the 95 percent confidence interval (two-
sided) as follows:
l.97S
EqiMtlon ?-?
Where:
Cl.n = 95 percent confidence interval
estimate of the average mean value.
'.975 = '(lr-a/2).
Table 1-3— '375 Values
'.97S
'.975
3
3
4
s
6
12706
4303
3182
2.778
2.S71
7
a
9
to
It
2«7
2385
2306
2262
2.228
12
13
14
IS
16
2.201
2.179
2 160
2145
2131
The values in this table are already
corrected for n-1 degrees of Freedom.
Use n equal to the number of data
points.
9.3 Conversion of Opacity Values
from Monitor Pathlength to Emission
Outlet Pathlength. When the monitor
pathlength is different than the emisson
outlet pathlength. use either of the
following equations to convert from one
basis to the other (this conversion may
be automatically calculated by the
monitoring system):
log(1-Op,) = (L,/L.) Log (l-Op.) Equation 1-4
D, = (WL.) Equation 1-S
Where:
Op, = opacity of the effluent based upon L,
Op, = opacity of the effluent based upon L,
Li = monitor palhlenglh
L, = emission outlet palhlenglh
Di = optical density of the effluent based
upon U
D, = optical densily-of the effleunt based
upon U
9.4 Spectral Response. Using the
spectral data obtained in Section 6.1,
develop Ihe effective spectral response
curve of the transmissomeler. Then
determine and report the peak spectral
response wavelength, the mean spectral
response wavelength, and the maximum
response at any wavelength below 400
nm and above 700 nm expressed as a
percentage of the peak response.
9.5 Angle of View. For the horizontal
and vertical directions, using the dala.
obtained in Section 6.2, calculate the
response of the receiver as a function of
viewing angle (21 centimeters of arc
with a radius of 3 meters equal 4
degrees), report relative angle of view
curves, and determine and report the
angle of view.
9.6 Angle of Projection. For the
horizontal and vertical directions, using
the data obtained in Section 6.3,
calculate the response of the
photoelectric detector as a function of
projection angle, report relative angle of
projection curves, and determine and
report the angle of projection.
9.7 Calibration Error. See Figure 1-1,
If the pathlength is not adjusted by the
measurement system, subtract the
actual calibrated attenuator value from
the value indicated by the measurement
system recorder for each of the 15
readings obtained pursuant to Section
8.1.4. If the pathlength is adjusted by Ihe
measurement system subtract the "path
adjusted" calibrated attenuator values
from the values indecated by the
measurement system recorder the "path
adjusted" calibrated attenuator values
are calculated using equation 1-4 orl-
5). Calculate the arithmetic mean
difference and the 95 percent confidence
interval of the five tests at each
attenuator value using Equations 1-2
and 1-3. Calculate the sum of the
absolute value of the mean difference
and the 95 percent confidence interval
for each of the three test attenuators;
report these three values as the
calibration error.
9.8 Zero and Upscale Calibration
Drifts. Using the data obtained in
Sections 8.4.1 and 8.4.2 calculate the
zero and upscale calibration drifts. Then
calculate the arithmetic means and the
95 percent confidence intervals using
Equations 1-2 and 1-3. Calculate the
sum of the absolute value of the mean
and the 95 percent confidence interval
and report these values as the 24-hour
zero drift and the 24-hour calibration
drift.
9.9 "Response Time. Using the data
collected in Section 8.1.5, calculate the
mean time of the 10 upscale and
downscale tests and report this values)
the system response time.
9.10 Reporting. Report the following
[summarize in tabular form where
appropriate).
9.10.1 General Information.
a. Instrument Manufacturer.
b. Instrument Model Number.
c, Instrument Serial Number.
11-106
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d. Person(s) responsible for
operational and conditioning test
periods and affiliation.
e. Facility being monitored.
f. Schematic of monitoring system
measurement path location.
g. Monitor pathleogth. meters.
h. Emission outlet palhlength, meters.
i. System span value, percent opacity.
j. Upscale calibration value, percent
opacity.
k. Calibrated Attenuator values (low.
mid. and high range), percent opacity.
9.10.2 Design Specification Test
Results
a. Peak spectral response, nrn.
b. Mean spectral response, nm.
c. Response above 700 nm. percent of
peak.
d. Response below 400 nm, percent of
peak.
e. Total angle of view, degrees.
f. Total angle of projection, degrees.
9.10.3 Operational Test Period
Results.
a. Calibration error, high-range.
percent opacity.
b. Calibration error, mid-range.
percent opacity.
c. Calibration error, low-range.
percent opacity.
d. Response time, seconds.
e. 24-hour zero drift, percent opacity.
f. 24-hour calibration drift, percent
opacity.
g. Lens cleaning, clock time.
h. Optical alignment adjustment, clock
time.
9.10.4 Statements. Provide a
statement that the conditioning and
operational test periods were completed
according to the requirements of
Sections 8.3 and 8.4. In this statement.
include the time periods during which
the conditioning and operaUonaJ test
periods were conducted.
9.10-5 Appendix. Provide the data
tabulations and calculations for the
above tabulated results.
9.11 Retest. If the continuous
monitoring system operates within the
specified performance parameters of
Table 1-1. the operational lest period
will be successfully concluded. If the
continuous monitoring system fails to
meet any of the specified performance
parameters, repeal the operational test
period with a system that meets the
design specifications and is expected to
meet the performance specifications.
10. Bibliograpny.
10.1 "Experimental Statistics."
Department of Commerce. National
Bureau of Standards Handbook 91. 1963,
pp. 3-31. paragraphs 3-3.1.4.
10.2 "Performance Specifications For
Stationary-Source Monitoring Systems
for Cases and Visible Emissions,"
Environmental Protection Agency,
Research Triangle Park. N. C.. EPA-650/
2-74-013. January 1974.
11-107
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—-
Person Cor
Affiliation
Date —
Monitor PC
Monitoring
Calibrated
Actual <
Lov
Mic
Hig
Run
Number
1 — Low
2- Mid
3 - High
4 - Low
5 - Mid
6 - High
7 — Low
8 -Mid
9 - High
10- Low
11-Mid
12-High
13-Low
14-Mid
15-High
iducting TPIT Analyzer Manufarturpr
Model/Serial Nn
Location
thlength Li Fmi««nn Outlet Pathlervjthj 1. 3 •
System Output Pathlength Corrected? Yes No
Neutral Density Filter Values
Dptical Density (Opacity): Path Adjusted Optical Density (opacity)
A/ Rann*> ( 1 1 nuu Range " { I
1 RgprjP ( ) Mid P?"n<» {
h Rantjp ( ) W!0h Rang'o f
Calibration Filter
Value
(Pgth Adjusted Percent Opacity)
Arithmetic Mean (Equation 1 — 2): A
Confidence Interval (Equation 1 — 3): B
Calibration Error JAJ + lei
Instrument Reading
(Percent Opacity)
)
)
Arithmetic Difference
(% Opacity)
Low
—
—
—
—
—
—
—
—
—
—
X
Mid
—
—
—
—
—
—
—
—
—
—
/*\
1-
High
-
-
-
-
-
-
-
-
-
X
Figure 1 — 1. Calibration error determination
11-108
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Person Conducting Test Analyzer Manufacturer
Affiliation . Model/Serial No.
Date Location
High Range Calibration Filter Value: Actual Optical Density (Opacity).
Path Adjusted Optical Density (Opacity).
Upscale Response Value ( 0.95 x filter value) percent opacity
Downscale Response Value (0.05 x filter value) percent opacity
Upscale 1 seconds
2 seconds
3 seconds
4 -seconds
5
Downscale 1
4
5 seconds
Average response seconds
Figure 1-2. Response Time Determination
11-109
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Perso
Affili
n Conducting Te
ct , Ar
Mt
1 n
lalyzer Mar
xdel/ Serial
cation —
lufacturer
No
Date :_ — __— — ^ — —
Monitor Pathlength, L
Monitoring System Ou
Upscale Cal oration V«
Date
Time
Begin
End
F
1
tput Pathlength Correctec
lue : Actual Optical Den
Path Adjusted Opt"
mission Oi
:? Ye
sity (Opac
cal Density
/tlet Pathle
s 1
itv)
i (Opacity)
nfjth L2 - .
VJO
{ )
{ )
Percent Opacity
Zero Reading*
Initial
A
Arithmetic Mean (Eq. 1—2)
Final
B
Confidence Interval (Eq. 1-3)
Zero Drift
Zero
Drift
C = B-A
adjusted?
e
a>
N
Upscale Calibration
Reading
Initial
0
Final
E
Upscale
Drift
F = E-D
Calibration Drift
Cali-
bration
Drift
G = F-C"
adjusted?
c
(0
a
f>
| lens cleaned?
Align-
ment
checked?
adjusted?
-^
'without automatic zero compensation ~
**if zero was adjusted (manually or automatically)
prior to upscale check, then use c = 0 .
Figure 1-3. Zero Calibration Drift Determination
11-110
-------
Performance Specification 2—
Specifications and Test Procedures for
SO, and NO, Continuous Monitoring
Systems in Stationary Sources
1. Applicability and Principle
1.1 Applicability. This Specification
contains [a] installation requirements,
(b) instrument performance and
equipment specifications, and (c) test
procedures and data reduction
procedures for evaluating.the
acceptability of SOj and NO, continuous
monitoring systems, which may include.
for certain stationary sources, diluent
monitors. The,test procedures in item
(c), above, are not applicable to single-
pass, in-situ continuous monitoring
systems; these systems will be
evaluated on a case-by-case basis upon
written request to the Administrator and
alternative test procedures will be
issued separately.
1.2 Principle. Any S05 or NO,
continuous monitoring system that is
expected to meet this Specification is
installed, calibrated, and operated for a
specified length of time. During this
specified time period, the continuous
monitoring system is evaluated to
determine conformance with the
Specification.
2. Definitions
2.1 Continuous Monitoring System.
The total equipment required for the
determination of a gas concentration or
a gas emission rate. The system consists
of the following major sub-systems:
2.1.1 Sample Interface, That portion
of a system that is used for one or more
of the following: sample acquisition,
sample transportation, sample
conditioning, or protection of the
monitor from the effects of the stack
effluent.
2.1.2. Pollutant Analyzer. That
portion of the system that senses the
pollutant gas and generates an output
that is proportional to the gas
concentration.
2.1.3. Diluent Analyzer {if
applicable). That portion of the system
that senses the diluent gas (e.g.. COt or
Oi) and generates an output that is
proportional to the gas concentration.
2.1.4 Data Recorder. That portion of
the monitoring system that provides a
permanent record of the analyzer
output. The data recorder may include
automatic data reduction capabilities.
2.2 Types of Monitors. Continuous
monitors are categorized as "extractive"
or "in-situ." which are further
categorized as "point," "multipoint,"
"limited-path." and "path" type
monitors or as "single-pass" or "double-
pass" type monitors.
2.2.1 Extractive Monitor. One that
withdraws a gas sample from the slack
and transports the sample to the
analyzer.
2.2.2 In-situ Monitor. One that
senses the gas concentration in the
stack environment and does not extract
a sample for analysis.
2-2.3 Point Monitor. One that
measures the gas concentration either at
a single point or along a path which is
less than 10 percent of the length of a
specified measurement line.
2.2.4 Multipoint Monitor. One that
measures the gas concentration at 2 or
more points.
2.2.5 Limited-Path Monitor. One that
measures the gas concentration along a
path, which is 10 to 90 percent of the
length of a specified measurement line.
2-2.6 Path Monitor. One that
measures the gas concentration along a
path, which is greater-than 90 percent of
the length of a specified measurement
line.
23.7 Single-Pass Monitor. One that
has the transmitter and the detector on
opposite sides of the stack or duct.
2.2.8 Double-Pass Monitor. One that
has the transmitter and the detector on
the same side of the stack or duct.
2.3 Span Value. The upper limit of a
gas concentration measurement range
which is specified for affected source
categories in the applicable subpart of
the regulations.
2.4 Calibration Cases. A known
concentration of a gas in an appropriate
diluent gas.
2.5 Calibration Gas Cells or Filters.
A device which, when inserted between
the transmitter and detector of the
analyzer, produces the desired output
level on the data recorder.
2.6 Relative Accuracy. The degree of
correctness including analytical
variations of the gas concentration or
emission rate determined by the
continuous monitoring system, relative
to the value determined by the reference
method(s).
2.7 Calibration Error. The difference
between the gas concentration indicated
by the continuous monitoring system
and the known concentration of the
calibration gas, gas cell, or filter.
2.8 Zero Drift. The difference in the
continuous monitoring system output
readings before and after a stated period
of operation during which no
unscheduled maintenance, repair, or
adjustment took place and when the
pollutant concentration at the time of
the measurements was zero (i.e., zero
gas, or zero gas cell or filter).
2.9 Calibration Drift. The difference
in the continuous monitoring system.
output readings before and after a stated
period of operation during which no
unscheduled maintenance, repair or
adjustment took place and when the
pollutant concentration at the time of
the measurements was a high-level
value (i.e., calibration gas, gas cell or
filter).
2.10 Respons'e Time. The amount of
time it takes the continuous monitoring
system to display on the data recorder
95 percent of a step change in pollutant
concentration,
2.11 Conditioning Period. A
minimum period of time over which the
continuous monitoring system is
expected to operate with no
•unscheduled maintenance, repair, or
adjustments prior to initiation of the
operational test period.
2.12 Operational Test Period. A
minimum period of time over which the
continuous monitoring system is
expected to operate within the
established performance specifications
with no unscheduled maintenance,
repair or adjustment
3. Installation Specifications
Install the continuous monitoring
system at a location where the pollutant
concentration measurements are
representative of the total emissions
from the affected facility and are
representative of the concentration over
the cross section. Both requirements can
be met as follows:
3.1 Measurement Location. Select an
accessible measurement location in the
stack or ductwork that is at least 2
equivalent diameters downstream from
the nearest control device or other point
at which a change in the pollutant
concentration may occur and at least 0-5
equivalent diameters upstream from the
effluent exhaust. Individual subparts of
the regulations may contain additional
requirements. For example, for steam
generating facilities, the location must
be downstream of the air preheater.
3.2 Measurement Points or Paths.
There are two alternatives. The tester
may choose either (a) to conduct the
stratification check procedure given in
Section 3.3 to select the point, points, or
path of average gas concentration, or (b)
to use the options listed below without a
stratification check.
Note.—For the purpose of thij lection, the
"centroidal area" is defined as a concentric
area thai is geometrically similar to the stack
cross section and is no greater than 1 percent
of the alack crosi-»ec1iootl area.
3.2.1 SO, and NO. Path Monitoring
Systems. The tester may choose to
centrally locate the sample interface
(path) of the monitoring system on a
measurement line thai passes through
the "centroidal area" of the cross
section.
11-111
-------
3.2.2 SOi and NO, Multipoint
Monitoring Systems. The tester may
choose to space 3 measurement points
along a measurement line that passes
through the "centroidal area" of the
stack cross sectinn, at distances of 16.7.
50.0, and 83.3 percent of the way across
it (see Figure 2-1).
11-112
-------
"CENTROIDAL
AREA"
POINT
NO.
1
2
3
DISTANCE
(%OF L)
16.7
50.0
833
"CENTROIDAL
AREA"
2-1. Location of an example measurement line (L) and measurement points.
11-113
-------
The following sampling strategies, or
equivalent, for measuring the
concentrations at the 3 points are
acceptable: (a) The use of a 3-probe or a
3-hole single probe arrangment.
provided that the sampling rate in each
of the 3 probes or holes is maintained
within 10 percent of their average rate
(This option requires a procedure.
subject to the approval of the
Administrator, to demonstrate that the
proper sampling rate is maintained): or
(b) the use of a traversing probe
arrangement, provided that a
measurement at each point is made at
least once every 15 minutes and all 3
points are traversed and sampled for
equal lengths of time within 15 minutes.
3.2.3 SO, Single-Point and Limited-
Path Monitoring Systems. Provided that
(a) no "dissimilar" gas streams (i.e,
having greater than 10 percent
difference in pollutant concentration
from the average) are combined
upstream of the measurement location.
and (b) for steam generating facilities, a
CO, or O, cotinuous monitor is installed
in addition to the SOj monitor.
according to the guidelines given in
Section 3.1 or 3.2 of Performance
Specification 3, the tester may choose to
monitor SO, at a single point or over a
limited path. Locate the point in or
centrally locate the limited path over the
"centroidal area." Any other location
within the inner 50 percent of the stack
cross-sectional area that has been
demonstrated (see Section 3.4) to have a
concentration within 5 percent of the
concentration at a point within the
"centroidal area" may be used.
3.2.4 NO. Single-Point and Limited-
Path Monitoring Systems. For NO,
monitors, the tester may choose the
single-point or limited-path option
described in Section 3.2.3 only in coal-
buming steam generators (does not
include oil and gas-fired units) and nitric
acid plants, which have no dissimilar
gas streams combining upstream of the
measurement location.
3.3 Stratification Check Procedure.
Unless specifically approved in Section
3.2.. conduct a stratification check and
select the measurement point points, or
path as follows:
3.3.1 Locate 9 sample points, as
shown in Figure 2-2, a or b. The tester
may choose to use more than 9 points,
provided that the sample points are
located in a similar fashion as in Feure
2-2.
3.3.2 Measure at least twice the
pollutant and. if applicable (as in the
case of steam generators). CO, or O,
concentrations at each of the sample
points. Moisture need not be determined
for this s.tep. The following methods are
acceptable for the measurements: (a)
Reference Methods 3 (grab-sample), 6 or
7 of this part; (b) appropriate
instrumental methods which give
relative responses to the pollutant (i.e..
the methods need not be absolutely
correct), subject to the approval of the
Administrator or (c) alternative
methods subject to the approval of the
Administrator. Express all
measurements, if applicable, in the units
of the applicable standard.
3.3.3 Calculate the mean value and
select a point points, limited-path, or
path which gives an equivalent value to
the mean. The point or points must be
within, and the limited-path or path
must pass through, the inner 50 percent
of the stack cross-sectional area. All
other locations must be approved by the
Administrator.
11-114
-------
POINT
NO.
DISTANCE
I* OF D)
1.9
2.8
C
3.7
4.6
10.0
30.0
50.0
70.0
90.0
Ul
•
2
•
9
(b)
Figure 2-2. Location of 9 sampling points for stratification check.
11-115
-------
3.4 Acceptability of Single Poinl or
Limited Path Alternative Location. Any
of the applicable measurement methods
mentioned in Section 3.3.2. above, may
be used. Measure -the pollutant and, if
applicable. Cd or d concentrations at
both the centroidal area and the
alternative locations. Moisture need not
be measured for this test. Collect a 21-
minute integrated sample or 3 grab-
samples, either at evenly spaced (7 ± 2
min.) intervals over 21 minutes or all
within 3 minutes, at each location. Run
the comparative.tests either
concurrently or within 10 minutes of
each other. Average the results of the 3
grab-samples.
Repeat the measurements until a
minimum of 3 paired measurements
spanning a minimum of 1.hour of
process operation are obtained.
Determine the average pollutant
concentrations at the centroidal area
and the alternative locations. If
applicable, convert the data in terms of
the standard for each paired set before
taking the average. The alternative
sampling location is acceptable if each
alternative location value is within ± 10
percent of the corresponding centroidal
area value and if the average at the
alternative location is within 5 percent
of the average of the centroidal area.
4. Performance and Equipment
Specifications
The continuous monitoring system
performance and equipment
specifications are listed in Table 2-1. To
be considered acceptable, the
continuous monitoring system must
demonstrate compliance with these
specifications using the test procedures
of Section 6.
5. Apparatus
5.1 Continuous Monitoring System.
Use any continuous monitoring system
of SOt or NO, which is expected to meet
the specifications in Table 2-1. For
sources which are required to convert
the pollutant concentrations to other
emission units using diluent gas
measurements, the diluent gas
continuous monitor, as described in
Performance Specification 3 of this
Appendix, is considered part of the
continuous monitoring system. The data
recorder may be an analog strip chart
recorder type or other suitable device
with an input signal range compatible
with the analyzer output.
5.2 Calibration Cases. For
continuous monitoring systems that
allow the introduction of calibration
gases to the analyzer, the calibration
gases may be SO» in air or N,. NO in N».
and NOt in air or N,. Two or more
calibration gases may be combined in
the same gas cylinder, except do not
combine the NO and air. For NO,
monitoring systems that oxidize NO to
NOj, the calibration gases must be in the
form of NO. Use three calibration gas
mixtures as specified below:
5.2.1 High-Level Gas. A gas
concentration that is equivalent to 80 to
90 percent of the span value.
T»ble 2-1.—Continuous Monitoring System
Performance and Equipment Specifications
Parameter
Specrftcauon
I. CuriditJurWIQ
penod*.
2. Operaeonel l«sl
period'.
3. Cattratjon error •.
4. Response lime
1 Zero dnfl la-
bour)".
6. Zero OWl (24-
hour) •-•.
7. CilCrjboo drifl
(2-hour)'.
9
(24-hour) >.
9. Belalrve
accuracy*.
10 Calibration 911
censor Wterv
11. Data reorder
cfta/i resolution.
12. Extractive
rrwnrtors.
< S pet ol each mid-1*.«l and f~jn-
tovel caMvamn value.
< 15 mirmjtn (5 mwmtes tor 3-point
lrav«rvng probe arrangement).
< 2 pet ol span vaJue.
< 2 pet of span value.
< 2 pet ol span value.
«• 2.5 pet ol span value,
e; 20 pet ol ttie mean value ol
reference metnod(s) lest dau in
terns Of errvsSJOn standard or 10
percent ol rhe applicable
standard. wtKhever o greater.
Must provide a cftech ol a* analyzer
nlemal nwrors and lenses and afl
electroric orcutry ncluckng Ine
radiation source and detector
assemtory wrwcf) are normally use
in sampling and analysis.
CTiart scales must be readable to
•xrrm « 0 50 pet ol lull-scale.
Must use jfie seme sample nterlaee
to sample botn rne pollutant and
dJuent gases. Place in series
frMuent alter poHutant analyzer) or
use a T.-* Oumg me
o>ndi»on«v >nd operational test
penods. the continuous mrXMlormg
system sftal not requ*s any
repiecemenc or adjustment olrter
loan Wit clearly specified a*
routine and regured in Vie
operabon and maMilenanc*
manuals. ' Evessed as Ine sum
ol trie absolute mean value plus
the 95 percent conhdence interval
ol a senes ol tests dmded by a
relerenca value. • A low-level IS-
IS percent ol span value) *iti lest
may be substituted lor the zero
Onfl leiti.
5.2.2 Mid-Level Gas. A gas
concentration that is equivalent to 45 to
55 percent of the span value.
5.2.3 Zero Gas. A gas concentration
of less than 0.25 percent of the span
value. Ambient air may be used forth
zero gas.
5.3 Calibration Gas Cells or Filters,
For continuous monitoring systems
which use calibration gas cells or filler
use three certified calibration gas cell]
or filters as specified below:
5.3.1 High-Level Gas Cell or Filter,
One that produces an output equivalent
to 80 to 90 percent of the span value
5.3.2 Mid-Level Gas Cell or Filter.
One that produces an output equivalent
to 45 to 55 percent of the span value.
" 5.3.3 Zero Gas Cell or Filter. One
that produces an output equivalent lo
zero. Alternatively, an analyzer may
produce a zero value check by
mechanical means, such as a movable
mirror.
5.4 Calibration Gas—Gas Cell or
Filter Combination. Combinations of llii|
above may be used.
6. Performance Specification Test
Procedures.
6.1 Pretest Preparation.
6.1.1 Calibration Gas Certification,
The tester may select one of the
following alternatives: (a) The tester
may use calibration gases prepared
according to the protocol defined in
Citation 10.5. i.e. These gases may be
used as received without reference
method analysis (obtain a statement
from the gas cylinder supplier certifying
that the calibration gases have been
prepared according to the protocol); or
(b) the tester may use calibration gase!
not prepared according to the protocol
In case (b). he must perform triplicate
analyses of each calibration gas (mid-
level and high-level, only) within 2
weeks prior to the operational test
period using the appropriate reference
methods. Acceptable procedures are
described in Citations 10.6 and 10.7.
Record the results on a data sheet
(example is shown in Figure 2-3). Hack
of the individual analytical results mail
be within 10 percent (or 15 ppm,
whichever is greater) of the average;
otherwise, discard the entire set and
repeat the triplicate analyses. If the
average of the triplicate reference
method test results is, within 5 percenl«|
the calibration gas manufacturer's taj
value, use the tag vafiie: otherwise,
conduct at least 3 additional reference
method lest analysesnintil the resullso!
6 individual runs (the 3 original plusS
additional) agree within 10 percent of"
ppm. whichever is greater, of the
average. Then use this average for In*
cylinder value.
11-116
-------
Figure 2-3. Analysis of Calibration Gases
Date (Must be within 2 weeks prior to the
operational test period)
Reference Method Used
Sample Run
1
2
3
Average
Maximum % Deviation
Mid-levelb
pom
High-level0
PP">
Not necessary if the protocol in Citation 10.5 is used
to prepare the gas cylinders.
Average must be 45 to 55 percent of span value.
c Average must be 80 to 90 percent of span value.
Must be £ + 10 percent of applicable average or 15 ppm,
whichever Ts greater.
6.1.2 Calibration Gas Cell or Filter
Certification. Obtain (a) a statement
from the manufacturer certifying that the
calibration gas cells or filters (zero, mid-
level, and high-level) will produce the
stated instrument responses for the
continuous monitoring system, and (b) a
description of the lest procedure and
equipment used to calibrate the cells or
filters. At a minimum, the manufacturer
must have calibrated the gas cells or
filters against a simulated source of
known concentration.
6.2 Conditioning Period. Prepare the
monitoring system for operation
according to the manufacturer's written
instructions. At the outset of the
conditioning period, zero and span the
system. Use the mid-level calibration
gas (or gas cell or filter) to set the span
at 50 percent of recorder full-scale. If
necessary to determine negative zero
drift, offset the scale by 10 percent. (Do
not forget to account for this when using
the calibration curve.) If a zero offset is
not possible or is impractical, a low-
level drift may be substituted for the
zero drift, by using a low-level (5 to 15
percent of span value) calibration gas
(or gas cell or filter). This low-level
calibration gas (or gas cell or filter) need
not be certified. Operate the continuous
monitoring system for an initial 166-hour
period in the manner specified by the
manufacturer. Except during times of
instrument zero, calibration checks, and
system backpurges, the continuous
monitoring system shall collect and
condition the effluent gas sample (if
applicable), analyze the sample for the
appropriate gas constituents, and
produce a permanent record of the
system output Conduct daily zero and
mid-level calibration checks and, when
drift exceeds the daily operating limits,
make adjustments. The data recorder
shall reflect these checks and
adjustments. Keep a record of any
instrument failure during this time. If the
conditioning period is interrupted
because of source breakdown (record
the dates and times of process
shutdown), continue the 168-hour period
following resumption of source
operation. If the conditioning period is
interrupted because of monitor failure,
restart the 168-hour conditioning period
when the monitor becomes functional.
6.3 Operational Test Period. Operate
the continuous monitoring system for an
additional 168-hour period. The
continuous monitoring system shall
monitor the effluent, except during
periods when the system calibration and
response time are checked or during
system backpurges; however, the system
shall produce a permanent record of all
operations. Record any system failure
during this time on the data recorder
output sheet.
It is not necessary that the 168-hour
operational test period immediately
follow the 168-hour conditioning period.
During the operational test period,
perform the following test procedures:
6.3.1 Calibration Error
Determination. Make a total of 15
nonconsecutive zero, mid-level, and
high-level measurements (e.g.. zero, mid-
level, zero, high-level, mid-range, etc.).
11-117
-------
This will result in a set of 5 each of zero.
mid-level, and high-level measurements.
Convert the data output to concentration
units, if necessary, and record the
results on a data sheet (example is
shown in Figure"2-4). Calculate the
differences between the reference
calibration gas concentrations and the
measureTnent system reading. Then
calculate the mean, confidence interval,
and calibration errors separately for the
mid-level and high-level concentrations
using Equations 2-1. 2-2. and 2-3. In
Equation 2-3. use each respective
calibration gas concentration for R.V.
11-118
-------
Figure 2-4. Calibration Error Determination
Run
no.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
Calibration gas
concentration3
ppm
A
Measurement system
reading
ppm
B
Arithmetic Mean (Eq. 2-1) =
Confidence Interval (Eq. 2-2) =
Calibration Error (Eq. 2-3)D =
Arithmetic
differences
ppm
A-B
Hid 1 High
j
" 1
.T ;_
a Calibration Data from Section 6.1.1 or 6.1.2
Mid-level: C * ppm
High-level: D =
b Use C or 0 as R.V. in Eq. 2-3
ppm
Date
Figure 2-5. Response Time
High-level
_ppm
Test Run
3
Average
Upscale
m1n.
Downscale
m1n.
System Response Time {slower of A and B)
min.
11-119
-------
6.3.2 Response Time Test Procedure.
At a minimum, each response lime test
shall provide a check of the entire
sample transport line (if applicable), any
sample conditioning equipment (if
applicable), the pollutant analyzer, and
the data recorder. For in-situ systems,
perform the response time check by
introducing the calibration gases at the
sample interface (if applicable), or by
introducing the calibration gas cells or
filters at an appropriate location in the
pollutant analyzer. For extractive
monitors, introduce the calibration gas
at the sample probe inlet in the stack or
at the point of connection between the
rigid sample probe and the sample
transport line. If an extractive analyzer
is used to monitor the effluent from more
than one source, perform the response
time test for each sample interface.
To begin the response time test
introduce zero gas (or zero cell or filter)
into the continuous monitor. When the
system output has stabilized, switch to
monitor the stack effluent and wait until
a "stable value" has been reached.
Record the upscale response time. Then,
introduce the high-level calibration gas
(or gas cell or filter). Once the system
has stabilized at the high-level
concentration, switch to monitor the
stack effluent and wait until a "stable
value" is reached. Record the downscale
response time. A "stable value" is
equivalent to a change of less than 1
percent of span value for 30 seconds or S
percent of measured average
concentration for 2 minutes. Repeat the
entire procedure three times. Record the
results of each test on a data sheet
(example is shown in Figure 2-5).
Determine the means of the upscale and
downscale response times using
Equation 2-1. Report the slower time as
the system response time.
6.3.3 Field Test for Zero Drift and
Calibration Drift Perform the zero and
calibration drift lesls for each pollutanl
analyzer and data recorder in the
continuous monitoring system.
6.3.3.1 Two-hour Drift. Introduce
consecutively zero gas (or zero cell or
filter) and high-level calibration gas (or
gas cell or filter) at 2-hour intervals until
15 sets (before and after) of data are
obtained. Do not make any zero or
calibration adjustments during this time
unless otherwise prescribed by the
manufacturer. Determine and record the
amount that the output had drifted from
the recorder zero and high-level value
on a data sheet (example is shown in
Figure 2-6). The 2-hour periods over
which the measurements are conducted
need not be consecutive, but must not
overlap. Calculate the zero and
calibration drifts for each set Then
calculate the mean, confidence interval,
and zero and calibration drifts (2-hour)
using Equations 2-1, 2-2. and 2-3. In
Equation 2-3. use the span value for R.V.
6.3.3.2 Twenty-Four Hour Drift. In
addition to the 2-hour drift tests, perform
a series of seven 24-hour drift tests as
follows: At the beginning of each 24-
hour period., calibrate the monitor, using
mid-level value. Then introduce the
high-level calibration gas (or gas cell or
filter) to obtain the initial reference
value. At the end of the 24-hour period,
introduce consecutively zero gas (or gas
cell or filter) and high-level calibration
gas (or gas cell or filter); do not make
any adjustments at this time. Determine
and record the amount of drift from the
recorder zero and high-level value on a
data sheet (example is shown in Figure
2-7). Calculate the zero and calibration
drifts for each set. Then calculate the
mean, confidence interval, and zero and
calibration drifts (24-hour) using
Equations 2-1, 2-2, and 2-3. In Equation
2-3, use the span value for R.V.
11-120
-------
Date
set
no.
1
2 .
3
4
5
6
7
8
9
10
11
12
13
14
15
Date
Time
Begin
End
Zero Rdg
InU. F1n.
A
B
Arithmetic Mean (Eq. 2-1)
Confidence Interval (Eq. 2-2)
Zero Drift3
Zero
drift
C-B-A
Hi-level
Rdg
n1t. Fin.
D
Ca
E
Span
drift
F-E-D
Hbratlon,
dr1fta
Callb.
drift
G-F-C
Date
set
no.
1
2
3
4
5
6
7
Date
T1m
Begin
End
Zerc
InU.
A
Rdg
f\n.
B
Arithmetic Mean (Eq. 2-1)
Confidence Interval (Eq. 2-2)
Zero drift
Zero
drift
C'B-A
Hi-level
Rdg
In1t. Fin.
D
E
Span
drift
F-E-D
Calibration .
Hr>H>a
Callb.
drift
G»F-C
Use Equation 2-3. with the span value for R. V.
Figure 2-7. Zero and Calibration Drift (24-hour)
Use Equation 2-3, with span value for R. V.
Figure 2-6. Zero and Calibration Drift (2 hour)
-------
Note.—Automatic zero and calibration
adjustment* made by the monitoring aystem
without operator intervention or initiation are
allowable at any time. Manual adjustments,
however, are allowable only at 24-hour
intervals, unless a shorter time it specified by
the manufacturer.
6.4 System Relative Accuracy.
Unless otherwise specified in an
applicable subpart of the regulations.
the reference methods for SO>, NOM.
diluent (d or CO,), and moisture are
Reference Methods 6, 7, 3, and 4.
respectively. Moisture may be
determined along with SOa using
Method 6. See Citation 10.8. Reference
Method 4 is necessary only if moisture
content is needed to enable comparison
between the Reference Method and
monitor values. Perform the accuracy
test using the following guidelines:
6.4.1 Location of Pollutant Reference
Method Sample Points. The following
specifies the location of the Reference
Method sample points which are on the
same cross-sectional plane as the
monitor's. However, any cross-sectional
plane within 2 equivalent diameter of
straight runs may be used, by using the
projected image of the monitor on the
selected plane in the following criteria.
6.4.1.1 For point monitors, locate the
Reference Method sample point no
further than 30 cm (or 5 percent of the
equivalent diameter of the cross section,
whichever is less] from the pollutant
monitor sample point.
6.4.1.2 For multipoint monitors,
locale each Reference Method sample
traverse point no further than 30 cm (or
5 percent of the equivalent diameter of
the cross section, whichever is less)
from each corresponding pollutant
monitor sample point
6.4.1.3 For limited-path and path
monitors, locate 3 sample points on a
line parallel to the monitor path and no
further than 30 cm (or 5 percent of the
equivalent diameter of the cross section,
whichever is less) from the centerline of
the monitor path. The three points of the
Reference Method shall correspond to
points in the monitor path at 16.7, 50.0,
and 83.3 percent of the effective length
of the monitor path.
6.4.2 Location of Diluent and
Moisture Reference Method Sample
Points.
6.4.2.1 For sources which require
diluent monitors in addition to pollutant
monitors, locate each of the sample
points for the diluent Reference Method
measurements within 3 cm of the
corresponding pollutant Reference
Method sample point as defined in
Sections 6.4.1.1, 6.4.1.2. or 6.4.1.3. In
addition, locate each pair of diluent and
pollutant Reference Method sample
points no further than 30 cm (or 5
percent of the equivalent diameter of the
cross section, whichever is less) from
both the diluent and pollutant
continuous monitor sample points or
paths.
6.4.2.2 If it is necessary to convert
pollutant and/or diluent monitor
concentrations to a dry basis for
comparison with the Reference data.
locate each moisture Reference Method
sample point within 3 oh of the
corresponding pollutant or diluent
Reference Method sample point as
defined in Sections 6.4.1.1, 6.4.1.2, 6.4.1.3.
or 6.4.2.1.
6.4.3 Number of Reference Method
Tests.
6.4.3.1 For NO, monitors, make a
minimum of 27 NO, Reference,Method
measurements, divided into 9 sets.
6.'4.3.2 For SO, monitors, make a
minimum of 9 SOt Reference Method
tests.
6.4.3.3 For diluent monitors, perform
one diluent Reference Method test for
each SO. and/or NO, Reference Method
test(s).
6.4.3.4 For moisture determinations,
perform one moisture Reference Method
test for each or each set of pollutants)
and diluent (if applicable) Reference
Method tests.
Note.—The tester may choose to perform
more than 9 sets of NO, measurements or
more than 9 SO, reference tr.ethod diluent, or
moisture tests. If this option is chosen, the
tester may, at his discretion, reject up to 3 of
the set or test results, so long as the total
number of set or test results used to
determine the relative accuracy is greater
than or equal to 9. Report all data including
rejected data.
6.4.4 Sampling Strategy for
Reference Method Tests. Schedule the
Reference Method tests so that they will
not be in progress when zero drift,
calibration drift, and response time data
are being taken. Within any 1-hour
period, conduct the following tests: (a)
one set, consisting of 3 individual
measurements, of NO, and/or one SOj;
(b) one diluent if applicable: and (c) one
moisture (if needed). Whenever two or
more reference tests (pollutant, diluent,
and moisture) are cooducted, the tester
may choose to run all these reference
tests within a 1-hour period. However, it
is recommended that the tests be run
concurrently or'consecutively within a
4-minute interval if two reference tests
employ grab sampling techniques. Also
whenever an integrated reference test is
run together with grab sample reference
tests, it is recommended that the
integrated sample be started one-sixth
the test period before the first grab
sample is collected.
In order to properly correlate the
continuous monitoring system and
Reference Method data, mark the
beginning and end of each Reference
Method test period (including theexacl
time of day) on the pollutant and dilueni
(if applicable) chart recordings. Use one
of the following strategies for the
Reference Method tests:
6.4.4.1 Single Point Monitors. For
single point sampling, the tester may: (jj
take a 21-minute integrated sample (e.g,
Method 6. Method 4, or the integrated
bag sample technique of Method 3)f|b)
take 3 grab samples (e.g. Method 7 or
the grab sample technique of Method 3],
equally spaced at 7-minute (±2 min)
' intervals (or one-third the test period);
or (c) take 3 grab samples over a 3-
minute test period.
- 6.4.4.2 Multipoint or Path Monitors.
For multipoint sampling, the tester may
either (a) make a 21-minute integrated
sample traverse, sampling for 7 minute!
[±2 min) (or one-third the test period)al
each point: or (b) take grab samples al
each traverse point scheduling the grab
samples to that they are an equal
interval (7+2 minutes) of time apart (or
one-third the test period).
Note.—If the number of sample points ii
greater than 3, make appropriate adjuilmeolij
to the individual sampling time interval]. Al
times NSPS performance test data may be
used as part of the data base of the
continuous monitoring relative accuracy
tests. In these cases, other test periods at
specified in the applicable subparts of the
regulations may be used.
6.4.5 Correlation of Reference
Method and Continuous Monitoring
System Data. Correlate the continuous
monitoring system data with the
Reference Method test data, as to the
lime and duration of the Reference
Method tests. To accomplish this, first
determine from the continuous
monitoring system chart recordings, the
integrated average pollutant and diluenl
(if applicable) concentration(s) for each
Reference Method test period. Be sureti
consider system response time. Then,
compare each integrated average
concentration against the corresponding
average concentration obtained by the
Reference Method: use the following
guidelines to make these comparisons:
0.4.5.1 If the Reference Method is an
integrated sampling technique (e.g,
Method 6). make a direct comparison ol
the Reference Method results and the
continuous monitoring system integrate'
average concentration.
6.4.5.2 If the Reference Method Is I
grab-sampling technique (e.g.. Method
7). first average the results from allgw
samples taken during the test period,
and then compare this average value
against the integrated value obtained
from the continuous monitoring sysleffl
chart recording.
11-122
-------
8.5 Data Summary for Relative
Accuracy Tests. Summarize the results
on a data sheet: example is shown in
figure 2-8. Calculate the arithmetic
differences between the reference
method and the continuous monitoring
output sets. Then calculate the mean,
confidence interval, and system relative
accuracy, using Equation 2-1. 2-2, and
2-3. In Equation 2-3, use the average of
the reference method test results for
R.V.
7. Equations
7.1 Arithmetic Mean. Calculate the
mean of a data set as follows:
Eqvutton 1-2
Where:
x = arithmetic mean.
n = number of data points.
XX| = algebraic turn of the individual
values, x*.
When the mean of the differences of
pairs of data is calculated, be sure to
correct the data for moisture.
7.2 Confidence Interval. Calculate
the 95 percent confidence interval (two-
sided] as follows:
C.I.,,, • -^^ Jnt* - U*.) Equation 1-3
Where:
C.I.,. = 95 percent confidence interval
estimate of mean value.
t..n = t«i-./.) (see Table 2-2)
BILLING COO£ IMO-01-M
Table 2-2.—I- Vtkxa
If
2
3
4
S
*
•Th* «
gr««» of
'.975
12 70S
43O3
3.182
2.776
2.571
,k*~, n V.,
freedom. U
n-
7
S
*
10
11
IUU*.
li« ff «O
'.975
2447
2.365
2306
2.262
2.229
. tk.Mjy
jal to M
n-
12
13
14
15
1<
corrected IQI
numtMr of r
'.975
2.201
2.179
2.16O
2.145
2.131
n-1 4+
xfco)ua<
11-123
-------
Run
no.
1
2
3
4
5
6
7
8
9
10
11
12
Date and
time
Average
rSV.
. RK
M .IrHff
a ~ "
ppm
Confidence Interval
Accuracy0
N0xb
RM
M .Imff
a
ppm
C02 or 02a
RM, [ M.
*d *d-
so2a
RM 1
M fam
mass/G
:v
NO,"
RM
M
niff
mass/GCV
Make sure that RM and M data are on a consistent basis, either wet or dry
""'"''' '* Figure 2-8. Relative accuracy determination
-------
7.3 Relative Accuracy. Calculate the relative accuracy of a set of data as
follows:
fi.A. •
x 100 Equation 2-3
Where: R. A.
R.V.
« relative accuracy
• absolute value of the arithmetic mean
(from Equation 2-1).
• absolute value of the 95 percent confi-
dence Interval (from Equation 2-2).
* reference value, as defined 1n Sections
6.3.1, 6.3.3.1, 6.3.3.2, and 6.5.
8. Reporting
At a minimum [check with regional
offices for additional requirements, if
any) summarize the following results in
tabular form: calibration error for mid-
level and high-level concentrations, the
slower of the upscale and downscale
response times, the 2-hour and 24-hour
zero and calibration drifts, and the
system relative accuracy. In addition,
provide, for the conditioning and
operational test periods, a statement to
the effect that the continuous monitoring
system operated continuously for a
minimum of 168 hours each, except
during times of instrument zero,
calibration checks, system backpurges.
and source breakdown, and that no
corrective maintenance, repair,
replacement, or adjustment other than
that clearly specified as routine and
required in the operation and
maintenance manuals were made. Also
include the manufacturer's certification
statement (if applicable) for the
calibration gas, gas cells, or filters.
Include all data sheets and calculations
and charts (data outputs), which are
necessary to substantiate that the
system met the performance
specifications.
9. Retest
If the continuous monitoring system
operates within the specified
performance parameters of Table 2-1,
the operational test period will be
successfully concluded. If the
continuous monitoring system fails to
meet any of the specifications, repeat
that portion cf the testing which is
related to the failed specification.
10. Bibliography
10.1 "Monitoring Instrumentation for
the Measurement of Sulfur Dioxide in
Stationary Source Emissions,"
Environmental Protection Agency,
Research Triangle Park, N.C.. February
1973.
10.2 "Instrumentation for the
Determination of Nitrogen Oxides
Content of Stationary Source
Emissions," Environmental Protection
Agency, Research Triangle Park, N.C..
Volume 1, APTD-0847, October 1971;
Volume 2, APTD-0942. January 1972.
10.3 "Experimental Statistics,"
Department of Commerce, Handbook 91,
1963, pp. 3-31. paragraphs 3-3.1.4.
10.4 "Performance Specifications for
Stationary-Source Monitoring Systems
for Cases and Visible Emissions,"
Environmental Protection Agency,
Research Triangle Park. N.C., EPA-650/
2-74-013, January 1974.
10.5 Traceability Protocol for
Establishing True Concentrations of
Cases Used for Calibration and Audits
of Continuous Source Emission Monitors
(Protocol No. 1). June 15,1978.
Environmental Monitoring and Support
Laboratory. Office of Research and
Development. U.S. EPA, Research
Triangle Park. N.C. 27711.
10.6 Westlin. P. R. and J. W. Brown.
Methods for Collecting and Analyzing
Gas Cylinder Samples. Emission
Measurement Branch, Emission
Standards and Engineering Division,
Office of Air Quality Planning and
Standards. U.S. EPA. Research Triangle
Park. N.C., July 1978.
10.7 Curtis, Foston. A Method for
Analyzing NOX Cylinder Cases—
Specific Ion Electrode Procedure.
Emission Measurement Branch,
Emission Standards and Engineering
Division. Office of Air Quality and
Standards. U.S. EPA. Research Triangle
Park, N.C, October 1978.
10.8 Stanley, Jon and P. R. Westlin.
An Alternative Method for Stack Gas
Moisture Determination. Emission
Measurement Branch. Emission
Standards and Engineering Division,
Office of Air Quality Planning and
Standards. U.S. EPA, Research Triangle
Park. N.C.. August 1978.
Performance Specification 3—
Specifications and Test Procedures for
CO, and Oi Continuous Monitors in
Stationary Sources
1. Applicability and Principle
1.1 Applicability. This Specification
• contains (a) installation requirements,
(b) instrument performance and
equipment specifications, and (c) test
procedures and data reduction
procedures for evaluating the
acceptability of continuous COi and O»
monitors that are used as diluent
monitors. The test procedures are
primarily designed for systems that
introduce calibration gases directly into
the analyzer other types of monitors
(e.g.. single-pass monitors, as described
in Section 2.2.7 of Performance
Specification 2 of this Appendix) will be
evaluated on a case-by-case basis upon
written request to the Administrator,
and alternative procedures will be
issued separately.
1.2 Principle. Any CO, or O,
continuous monitor, which is expected
to meet this Specification, is operated
for a specified length of time. During this
specified time period, the continuous
monitor is evaluated to determine
conformance with the Specification.
2. Definitions
The definitions are the same as those
listed in Section 2 of Performance
Specification 2.
3. Installation Specifications
3.1 Measurement Location and
Measurement Points or Paths. Select and
install the continuous monitor at the
same sampling location used for the
pollutant monitor(s). Locate the
measurement points or paths as shown
in Figure 3-1 or 3-2.
3.2 Alternative Measurement
Location and Measurement Points or
Paths. The diluent monitor may be
11-125
-------
installed at a different location from that
of the pollutant monitor, provided that
the diluent gas concentrations at both
locations differ by no more than 5
percent from that of the pollutant
monitor location for CO, or the quantity,
20.9-percent Oj. for O,. See Section 3.4
of Performance Specification 2 for the
demonstration procedure.
4. Continuous Monitor Performance and
Equipment Specifications
The continuous monitor performance
and equipment specifications are listed
in Table 3-1. To be considered
acceptable, the continuous monitor must
demonstrate compliance with these
specifications, using the test procedures
in Section 8.
5. Apparatus
5.1 COj or Oi Continuous Monitor.
Use any continuous monitor, which is
expected to meet this Specification. The
data recorder may either be an analog
strip-chart recorder or other suitable
device having an input voltage range
compatible with the analyzer output.
5.2 Calibration Gases. Diluent gases
shall be air or N5 for COj mixtures, and
shall be Ni for O3 mixtures. Use three
calibration gases as specified below:
11-126
-------
GEOMETRICALLY
SIMILAR
AREA
( 1%OF STACK
CROSS-SECTION)
(a)
GEOMETRICALLY
SIMILAR
AREA
I <1%OF STACK
CROSS-SECTION)
(b)
3-1. Relative locations of pollutant (P) and diluent (D) measurement points in (a) circular
and (b) rectangular ducts. P is located at the centroid of the geometrically similar
area. Note: The geometrically similar area need not be concentric.
11-127
-------
GEOMETRICALLY
SIMILAR
AREAS
( <1% OF STACK
CROSS-SECTION)
GEOMETRICALLY
SIMILAR
AREAS
{ <1%OF STACK
CROSS-SECTION)
PARALLEL
MEASUREMENT
LINES
(a)
PARALLEL
MEASUREMENT
LINES
(b)
Figure 3-2. Relative locations of pollutant (P) and diluent (D) measurement paths for (a) circular
and (b) rectangular ducts. P is located at the centroid of both the geometrically simi-
lar areas and the pollutant monitor path cross-sectional areas. D is located at the cen-
troid of the diluent monitor path cross-sectional area.
11-128
-------
Table *-\.—Performance tndEquipment
Speohctlions
Pwamalar SeaoAcatton
1. Condrboning > 168 hours.
2. Oparabona) MI » 160 hour*.
I. Cafcorabon •rrcx"'- c 5 pet ol aach (md-ranoa and
rawing*. o"M cakbribon gat
•slue,
4. Rapoma ton* _ « 15 mn/fcn.
6. Zoo arm (2- « 0.4 pel CO. or CV
ho.*)*-'.
• Zoo drrfl P4- < 103 pet CO. or (X.
hour)"-'.
T. CafcDrsbon drtl p- < 0 4 pet CO, or O»
ha*)*.
a. Ciwnoon (Ml « 0 J pcL CO. or O»
(24-hour) ».
•. Data racoroar chart Ou>1 ioaJ*l mat b* madatil* to
r»»o*jOon. » momor ihdl not require any corrvcbv* ma*il»-
nanc*. rapair. rap4acam«nc or adjustment othar ff\an 9ul
ctaatly apaciftad •« reutna and ra^uvad in **• oparafaon and
rn*n4ananca manuatm.
> Eiprauad a> Via turn ol »ia ib«ok«a maan valua pkja
Vw 95 pa«ca«< conAoanca tnlarval of a *anai of lasts.
• A kMMaval (i-li parcant of span *•*—) onfl t«U may oa
aubsMMad tor t»a zaro dnfl lasts.
5.2.1 High-Uvel Gas. A CO, or O,
concentration of 20.0 to 22.5 percent. For
O> analyzers, ambient air (20.9 percent
Oi) may be used as the 'high-range
calibration gas; lower high-level O>
concentration may be used, subject to
the approval of the Administrator.
5.2.2 Mid-Level Gas. A CO, or O,
concentration of 11.0 to 14.0 percent; for
O, analyzers, concentrations in the
operational range may be used.
5.2.3 Zero Gas. A CO, or O,
concentration of less than 0.05 percent
For CO, monitors, ambient air (0.03
percent CO,) may be used as the zero
gas.
8. Performance Specification Test
Procedures.
6.1 Calibration Gas Certification.
Follow the procedure as outlined in
Section 8.1.2 of Performance
Specification 2. except use 0.5 percent
CO» or O, instead of the 15 ppm. Figure
3-3 is provided as an example daVa
sheet.
6.2 Conditioning Period. Follow the
same procedure outlined in Section 6.2
of Performance Specification 2.
6.3 . Operational Test Period. Follow
the same procedures outlined in Section
6.3 of Performance Specification 2. to
evaluate the calibration error, response
time, and the 2-hour and 24-hour zero
end calibration drifts. See example data
sheets (Figures 3-4 through 3-7).
11-129
-------
Date
Figure 3-3. Analysis of Calibration'Gases'
__(Must be within 2 weeks prior to the opera-
tional test period)
Reference Method Used
Sample run
Average
Maximum %
deviation
Mid-rangec
ppm
High-range
ppm
Not necessary if the protocol in Citation 10.5 of Perfor-
mance Specification 2 is used to prepare the gas cylinders.
c Average must be 11.0 to 14.0 percent; for 07, see Section
5.2.2. £
Average must be 20.0 to 22.5 percent; for 00, see Section
5.2.1. 2
e Must be £ + 10 percent of applicable average or 0.5 percent,
whichever Ts greater.
11-130
-------
Figure 3-4. Calibration Error Determination
Run
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
\5
Calibration Gas
Concentration3
ppm
A
Measurement System
Reading
ppm
B
Arithmetic Mean (Eq. 2-1 )b =
Confidence Interval (Eq. 2-2) =
Calibration Error (Eq. 2-3)b>C =
Arithmetic
Differences
ppm
A-B
Mid
-
Hiqh
-^
'Calibration Data from Section 6.1
Mid-level: C = ppm
High-level: D = ppm
5 See Performance Specification. 2
' Use C or D as R. V.
11-131
-------
Figure 3-5. Response Time
Date
High-Range =
ppm
Test Run
1
2
3
Average
Upscale
min
A =
Ddwnscale
min
B =
System Response Time (slower of A and B) =
mm.
11-132
-------
Dat
set
no
—
• -" —
Date
Time
Begi
End
Zero Rd.
Init.
A
Fin.
B
Arithmetic Mean (Eq. 2-l)a
Confidence Interval (Eq. 2-2)a
Zero drift5
Zero
drift
C=B-A
Hi-Range
Rdg.
Init.
D
Fin.
£
-
Span
rlrif t
F=E-D
Calibration drift
Calib.
drift
G=F-C
.
From Performance Specification 2.
Use Equation 2-3 of Performance Specification 2 and 1.0 for R. V
Figure 3-6. Zero and Calibration Drift (2 hour)
11-133
-------
Data
set
no.
i
Date
Time
Begin
End
Zero Rdg
Init.
A
Arithmetic Mean (Eq. 2-l)a
Fin.
B
Confidence Interval (Eq. 2-2)a
Zero drift
Zero
drift
C=B-A
Hi -Range
Rdg
Init.
0
Fin.
E
-
Calibration
Span
drift
F=E-D
drift b
Calib.
drift
G=F-C
From Performance Specification 2.
Use Equation 2-3 of Performance Specification 2, with 1.0 for R. V.
Figure 3-7. Zero and Calibration Drift (24-hour)
11-134
-------
8.4 System Relative Accuracy. (Note:
The relative accuracy is not determined
separately for the diluent monitor, bat is
determined for the pollutant-diluent
system.) Unless otherwise specified in
an applicable subpart of the regulations.
the Reference Methods for the diluent
concentration determination shall be
Reference Method 3 for CO, or O,. For
this test, Fyrite analyses may be used
for COi and O* determinations. Perform
the measurements using the guidelines
below {an example data sheet is shown
in Figure 2-8 of Performance
Specification 2):
6.4.1 Location of Reference Method 3
Sampling Points. Locate the diluent
Reference Method sampling points
according to the guidelines given in
Section 6.4.2.1 of Performance
Specification 2.
6.4.2 Number of Reference Method
Tests. Perform one Reference Method 3
test according to the guideline in
Performance Specification 2.
8.4.3 Sampling Strategy for
Reference Method Tests. Use the basic
Reference Method sampling strategy
outlined in Section 6.4.4 (and related
sub-sections) of Performance
Specification 2.
6.4.4 Correlation of Reference
Method and Continuous Monitor Data.
Use the guidelines given in Section 6.4.5
of Performance Specification 2.
7. Equations, Reporting. Retest, and
Bibliography. The procedure and
citations are the same as in Sections 7
through 10 of Performance Specification
2.
|FR Doc. 79-01033 Fitaj ]0-»-7» £45 an)
11-135
-------
ENVIRONMENTAL PROTECTION
AGENCY
40 CFR Part 60
IAD-FRL 162&-7]
Standards of Performance for New
Stationary Sources; Proposed
Revisions to General Provisions and
Additions to Appendix A, and
Reproposal of Revisions to Appendix
B
AGENCY: Environmental Protection
Agency (EPA).
ACTION: Proposed Rule and Notice of
Public Hearing. _^____
SUMMARY: This proposed rule (1) revises
the monitoring requirements (§ 60.13) of
the General Provisions, [2] adds
Methods 6A and 6B to Appendix A, and
(3) reproposes revisions to Performance
Specifications 2 and 3 to Appendix B of
40 CFR Part 60. The proposed revisions
to § 60.13 are being made to make this
section consistent with the proposed
revisions to Appendix B. Methods 6A
and 6B are being proposed because they
simplify the determination of the SO»
emission rates in terms of ng/J.
Performance Specifications 2 and 3
revisions are being reproposed because
the changes that have been made to the
performance specifications as a result of
comments received on the original
proposal of October 10.1979 (44 FR
58602) are substantial and involve an
entirely new concept
DATES: Comments. Comments must be
received on or before March 27.1981.
Public Hearing. A public hearing will
be held on February 19,1981 beginning
at 9 a.m.
Request to Speak at Hearings.
Persons wishing to present oral
testimony must contact EPA by
February 12,1981 (1 week before
hearing).
ADDRESSES: Comments. Comments
should be submitted (in duplicate if
possible) to: Central Docket Section (A-
130). Attention: Docket Number
OAQPS-79-1, U.S. Environmental
Proleclion Agency, 401 M Street. SW.,
Washington. D.C. 20460.
Public Hearing. The public hearing
will be held at Emission Measurement
Labatory. R.T.P. North Carolina. Persons
wishing to present oral testimony should
notify Ms. Vivian Phares. Emission
Measurement Branch (MD-13). U.S.
Environmental Protection Agency,
Research Triangle Park. North Carolina
27711. telephone number (919) 541-5423.
Docket. Docket Number OAQPS-79-4
(Performance Specifications 2 and 3)
and Docket Number A-80-30 (Methods
6A and 6B), containing supporting
information used in developing the
proposed rulemaking are located in the
U.S. Enviromental Protection Agency,
Centra] Docket Section. West Tower
Lobby, Gallery 1. Waterside Mall, 401 M
Street. S.W.. Washington, D.C. 20460.
The docket may be inspected between 8
a.m. and 4 p.m. on weekdays, and a
reasonable fee may be charged for
copying.
FOR FURTHER INFORMATION CONTACT:
Mr. Roger T. Shigehara (MD-19). U.S.
Environmental Protection Agency,
Research Triangle Park. North Carolina
27711. telephone number (919) 541-2237.
SUPPLEMENTARY INFORMATION: The
discussion in this section has been
divided into three separate parts. Part A
discusses proposed changes to the
General Provisions of 40 CFR Part 60,
Part B discusses the addition of
proposed Methods 6A and 6B to
Appendix A. and Part C discusses
reproposal of revisions to Performance
Specifications 2 and 3 to Appendix B.
Part A
The proposed revisions to § 60.13 of
the General Provisions are being made
to make this section consistent with the
proposed revisions to Appendix B. Since
the reproposal to Appendix B uses the
concept of evaluating the continuous
emission monitors as a system, based on
relative accuracy test results, the use of
certified cylinder gases, optical filters, or
gas cells is not necessary. The
requirement for quantification of the
zero and span drifts is not a change, but
a clarification of what is required under
the existing performance specifications.
PartB
Two reference methods (Methods 6A
and 68) are proposed. Method 6A.
"Determination of Sulfur Dioxide,
Moisture, and Carbon Dioxide
Emissions from Fossil Fuel Combustion
Sources." combines the sampling and
analysis of SOi and CO,. The SO, is
collected in a hydrogen peroxide
solution and analyzed by the barium-
thorin tilration procedure described in
Method 6. The CO, is collected by a
solid absorbent and analyzed
gravimetrically. The sample gas volume
is measured to allow determination of
SO, concentration. CO, concentration.
moisture, and emission rate from
combustion sources in ng/J. If the only
measurement needed is in terms of
emission rale or if the CO, and moisture
concentrations are not needed, e.g.. to
convert NOM concentration to ng/J, the
volume meter is not required. It is
intended that Method 6A be.used as an
alternative to Methods 8 and 3 for the
purpose of determining SO, emission
rates in ng/J.
Method 6B. "Determination of Sulfur
Dioxide and Carbon Dioxide Daily
Average Emissions from Fossil Fuel
Combustion Sources," employs the same
sampling train and analysis procedure]
as Method 6A. but the operation of the
train is controlled on an intermittent
basis by a timer or on a continuous
basis by using a low, constant flow-rale
pump. This allows an extended
sampling time period and the
determination of an average value for .
that time period of SO, concentration,
CO, concentration, and emission rate
from combustion sources in ng/J.
Method 6B is proposed as an acceptable
procedure for compliance with § 60.47a
(0 of 40 CFR Part 60. Subpart Da. Thij
paragraph (f) requires that in the event
of CEMS breakdown, emission data will
be obtained by using other monitoring
systems or reference methods approved
by the Administrator.
PartC
Revisions to Performance
Specifications 2 and 3 for the initial
evaluation of continuous emission
monitoring systems (CEMS) for SO,,
NO,, and diluent gases were proposed
on October 10. 1979 (44 FR 58602).
Comments received as a result of this
proposal led to revaluation of the
provisions and a change in the overall
approach to the performance
specifications. The reproposed
performance specifications deemphasize
instrument equipment specifications and
add emphasis to the evaluation of the
CEMS and its location as a system. The
specification requirements are limited to
calibration drift tests and relative
accuracy tests. The acceptability limits
for relative.accuracy remain the same as
in the previously proposed revisions to
the performance specifications.
CEMS guidelines will also be
published in a separate document at the
time of proposal to provide vendors,
purchasers, and operators of CEMS with
supplementary equipment and
performance specifications. The •
guidelines will contain additional
procedures and specifications that may
provide further evaluatiojn of the CEMS
beyond that required by-Performance
Specifications 2 and 3, e-g., response
time. 2-hour zero and calibration drifts,
sampling locations, and calibration
value analyses.
Applicability
The proposed revisions would apply
to all CEMS currently subject to
Performance Specifications 2 and 3.
These include sources subject to
standards of performance that have
11-136
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already been promulgated and sources
subject to Appendix P to 40 CFR Part 51.
Since the requirements of the
reproposed performance specification
revisions are limited to daily calibration
drift tests and relative accuracy tests,
existing CEMS that met the
specifications of the current
Performance Specifications 2 and 3 also
meet the requirements of these revised
specifications and, therefore, do not
require retesting.
This reproposal has retained the
definition of a "continuous emission
monitoring system" and includes the
diluent monitor, if applicable. This
definition requires the relative accuracy
of the CEMS to be determined in terms
of the emission standard, e.g, mass per
unit calorific value for fossil fuel-fired
steam generators. Several commenters
felt that the limits of relative accuracy
should be relaxed from the present 20
percent because of the addition of the
diluent analyzer output Others added
that errors with the manual reference
methods could increase the possibility
of poor relative accuracy determinations
now that an additional measurement is
required. The Administrator has
reviewed a number of relative accuracy
tests and has concluded that the
variations in the manual reference
method determinations are not the
major cause of failure, but that the
difference between the mean of the
reference method and the CEMS values
is the most probable cause. This
situation is correctable.
Comments on Proposal
Numerous commenters noted that the
proposed revisions go far beyond
clarification and considered them as
significant changes. A large part of this
concern was because they felt that
many existing CEMS were not Installed
according to the proposed installation
specifications. In addition, many
commenters felt th« need for greater
flexibility in selecting alternative CEMS
measurement locations. Several
commen'crs desired ths inclusion of test
procedures to evaluate single-pass, in
situ CEMS. Otherg objected to the length
and cost of testing. Opposing views
were presented on the need for
stratification checks. Many commenters
dealt with specific parts of the proposal
and a few raised issues beyond the
scope of the revisions. Because the
Administrator has changed the overall
approach to performance specifications
as mentioned in the beginning of Part C,
many of these comments no longer
apply and many of the objections have
been resolved.
The quality assurance requirement*
for CEMS and associated Issues were
raised by many corrunenters. Most
commenters stated that there was a
need for EPA to issue guidelines or
requirements for quality assurance. EPA
is developing such procedures, and they
will be published later this year or early
next year as Appendix E to 40 CFR Part
60. Some commenters erroneously
assumed that the quality assurance
procedures were an integral part of the
specifications. Although related, this
specification should be evaluated on the
basis of its adequacy in evaluating a
CEMS after their initial installation.
The reproposed performance
specifications include a provision that
the relative accuracy of a CEMS must be
within ±20 percent of the mean
reference value or ±10 percent of the
applicable standard, whichever is
greater. Several commenters endorsed
this change, while one felt the change to
allow an accuracy of ±10 percent of the
applicable standard is too lenient at low
emission rates. The Administrator feels
that it is restrictive to require a high
degree of relative accuracy when the
actual emission levels are equivalent to
50 percent or less of the applicable
emission standard.
Request for Comments on Other Views
A number of suggestions were
received which were not incorporated in
these revisions. Because they represent
differing views, EPA requests comments
on them to determine what course of
action should be taken in the final rule
making. The suggestions are as follows:
1. Section 60.13(b) was revised to
exclude the mandatory 7-day
conditioning period used to verify the
CEMS operational status. Once
commenter feels that the mandatory
conditioning period should not only be
retained, but should be made longer
depending on how the CEMS is usad
(i.e., for operation and maintenance
requirements or for compliance/
enforcement purposes) as follows:
a. The presently required 7-day
conditioning period should be retained
for CEMS used for operation and
maintenance requirements.
b. If the CEMS is used for compliance/
enforcement purposes, a 30-day
conditioning period should be required
and that the relative accuracy tei'.s
should be spread over 3 days instead of
one.
c. Ail CEMS, whether for operation
and mainlenace requirements or for
compliance/enforcement purposes,
should be Installed and operational for
60 or 90 days prior to the initial NSPS
test
If the above are done, the commenter
feels that (1) the owner/operator/agency
would be aware of the progress made by
the control system in complying with the
emission standards, (2) there would be a
greater chance of the CEMS passing the
performance specification test and of
the facility complying with the
regulations within the time requirements
of § 60.8. and (3) the operator/vendor/
tester/agency would minimize loss of
valuable resources and time.
2. Once commenter feels that
5 60.12f.c) should require all CEMS
Performance Specification Tests to be
done concurrent with NSPS tests under
5 60.8. This would streamline the
process and save resources for owners
and agencies alike.
3. Section 60.13(d) was revised to
delete the requirements listed under
(d)(l) and (d)(2) because EPA felt that
the relative accuracy test would validate
the GEMS system which includes the
calibration gases or devices. One
comrnenter, however, feels that the
requirement to introduce zero and span
gas mixtures into the measurement
system at the probe at the stack wall
should be retained and conducted in
such a way that the entire system
including the sample interface is
checked. This requirement would
provide a means to check the CEMS on
a daily basis. In addition, the commenter
feels that the requirement for checking
the calibration gases at 6-month
intervals may be deleted provided that
the values used for replacement gas
cylinders, calibration gas cells or optical
filters are approved by the control
agency.
4. One coramenter feels that the
following specifications should be
added in Section 4 of Performance
Specification 2:
a. The CEMS relative accuracy should
be relaxed by using a sliding function of
the allowable emission standard and/or
the reference method tests for very low
emission limits, e.g., 0.10 pounds per 10*
Btu emission limit under PSD permits,
b. Each new compliance/enforcement
CEMS installed after 1983 must have an
external means of checking the
calibration of the instrument using
separate calibration/audit materials.
c. A oinimum data recovery
specification of at least 18 hours in at
least 22 out of 30 days (or similar)
should be included. This would mean
that a performance specilication test
would not be officially completed until
after the 30 days.
5. One commenler feels that EPA
should consider using Section 7.1 of
Performance Specification 2 to specify
that during the GEMS performance
specification test all data be recorded
both in separate units of measurements
(ppm end percent CO, or O3) as well a*
combined units of the standard.
11-137
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6. In Performance Specification 2, the
definition of "Relative Accuracy" is
incorrect Instead of a degree of
correctness, it is actually a measure of
"relative error." One commenter feels
thai "relative accuracy" should be
changed to "relative error."
7. In Section 7.3 of Performance
Specification 2, the tester Is allowed to
reject up to three samples provided that
the total number of test results used to
determine the relative accuracy is
greater than or equal to nine. EPA had
considered using statistical techniques
to reject outliers, but found that these
techniques were too restrictive. One
commenter feels that statistical
techniques should be used. At a
minimum, the commenter feels that the
control agencies should be consulted
before any data is rejected.
Miscellaneous
.. Authority: This proposed rule making is)
blued under the authority of lections 111.
114. and 301(a] of the Clean Air Act as
• mended (42 U.S.C 7411. 7414. and 7601(a)).
Dated: January 13.1981.
Douglas M. Cos tie,
Administrator,
It is proposed that §5 60.13, 60.46. and
60.47a. Appendix A, and Appendix B of
40 CFR Part 60 be amended as follows:
1. By revising f 60.13(b). 60.13(c)(2](ii).
and 60.13(d). by removing
subparagraphs (1), (2). and (3) of
§ 60.13(b). and by removing
subparagraphs (1), (2), and (3) of
§ 60.13(d) as follows:
§ 60.13 Monitoring requirements.
• * • • •
(b) All continuous monitoring systems
and monitoring devices shall be
installed and operational prior to
conducting performance tests under
§ 6O.8. Verification of operational status
shall, as a minimum, include completion
of the manufacturer's written
requirements or recommendations for
installation, operation, and calibration
of the device.
(e) * * '
(2) • • •
(ii) Continuous monitoring systems for
measurement of nitrogen oxides or
sulfur dioxide shall be capable of
measuring emission levels within rt20
percent with a confidence level of 95
percent The performance tests and
calculation procedures set forth in
Performance Specification 2 of
Appendix B shall be used for
demonstrating compliance with this
specification.
• • • • •
(d) Owners and operators of all
continuous emission monitoring systems
installed in accordance with the
provisions of this part shall check the
zero and span drift at least once daily in
accordance with the method prescribed
by the manufacturer of such systems
unless the manufacturer recommends
adjustments at shorter intervals In
which case such recommendations shall
be followed. The zero and span shall, as
a minimum, be adjusted whenever the
24-hour zero drift of 24-hour span drift
limits of the applicable performance
specifications in Appendix B are
exceeded. The amount of excess zero
and span drift measured at the 24-hour
interval checks shall be quantified and
recorded. For continuous monitoring
systems measuring opacity of emissions.
the optical surfaces exposed to the
effluent gases shall be cleaned prior to
performing the zero and span drift
adjustments except that for systems
using automatic zero adjustments, the
optical surfaces shall be cleaned when
the cumulative automatic zero
compensation exceeds 4 percent
opacity. Unless otherwise approved by
the Administrator, the following
procedures shall be followed for
continuous monitoring systems
measuring opacity of emissions.
Minimum procedures shall include a
method for producing a simulated zero
opacity condition and an upscale(span)
opacity condition using a certified
• neutral density filter or other related
technique to produce a known
obscuration of the light beam. Such
procedures shall provide a system check
of the analyzer internal optical surfaces
and all electronic circuitry including the
lamp and photodetector assembly.
• • • • •
2. By revising § 60.46(a)(4) as follows:
§ 60.46 Test method* and procedures.
W-
(4) Method 6 for concentration of SO>.
Method 6A may be used whenever
Methods 8 and 3 data are used to
determine the SO, emission rate In ng/J,
and
« • • « •
3. By revising § 60.47a(h}(l] as follows:
§ 60.47m Emission monitoring.
• • • • «
no • • •
(1) Reference Methods 3. 6. and 7 as
applicable, are used. Method 6B may be
used whenever Methods 6 and 3 data
are used to determine the SO, emission
rate in ng/J. The sampling location(s)
are the same as those used for the
continuous monitoring system.
• • • « •
4. By adding to Appendix A of 40 CFR
Part 60 two new methods. Methods 6A
and Method 68, to read as follows:
Appendix A—Reference Teit Melhodi
• • • • •
Method 6/4.—Determination of Sulfur
Dioxide. Moisture, and Carbon Dioxide
Emissions from Fossil Fuel Combustion
Sourcft
1. Applicability and Principle
1.1 Applicability. Thji method applies to
the determination of sulfur dioxide (SO,)
emissions from fossil fuel combustion >ourcei
in terms of concentration (mg/m1) and in
terms of emission rate {ng/J) and to the
determination of carbon dioxvde (CJ,)
concentration (percent). Moisture, if desired.
may also be determined by this method.
The minimum detectable limit, the upper
limit,- and the interference* of the method for
the measurement of SO, are the same at for
Method 0. For a 20-liter sample, the method
has a precision of 0.5 percent CO, for
concentrations between 2.5 and 25 percent
COi and 1.0 percent moisture for moisture
concentrations greater than 5 percent
1.2 Principle. The principle of sample
collection is the same as for Method 6 except
that moisture and CO, are collected In
addition to SO, in the tame sampling train.
Moisture and CO, fractions axe determined
gravimetrically.
2. Apparatus
2.1 Sampling. The sampling train is
shown in Figure 6A-1: the equipment
required is the same as for Method 6. except
as specified belovv:
2.1.1 Midget Impingers. Two 30-ml midget
impingers with a 1-rrun restricted tip.
2.1.2 Midget Bubbler. One 30-ml midget
bubbler with an unrestricted tip.
2.1.3 CO, Absorber. One 2SO-ml
Erlenmeyer bubbler with an unrestricted tip,
or equivalent.
2.2 Sample Recovey and Analysis. The
equipment needed for sample recovery and
analysis i» the same as required for Method
6. In addition, a balance to measure within
0.05 g is needed for analysis.
3. Reagents
Unless otherwise indicated, all reagents
must conform to the specifications
established by the Committee on Analytical
Reagents of the American Chemical Society.
Where such specifications are not available,
use the best available grade.
3.1 Sampling. The reagents required for
sampling are the same ai specified in Method
6, except that 80 percent isopropano! and 10
percent potassium iodide solutions are not
required. In addition, the following reagenti
are required:
11-138
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THERMOMETER
PROBE (END PACKED''
WITH QUARTZ OR
PYREX WOOL)
STACK WALL MIDGET BUBBLERS
MIDGET IMPINGERS
RATE METER fJEEDLE VALVE
ICE EATH
THERMOMETER
PUMP
Figure 6A-1. Sampling train. SURGE TANK
11-139
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3.1.1 Orients'.' Anhydrous calcium sulfate
(CaSOi) desiccant, 3 mesh.
3.1.2. Ascarite. Sodium hydroxide.coaled
asbestos for absorption of CO,. 8 to 20 mesh.
3.2 Sample Recovery and Analysis. The
reagents needed for sample recovery and
analysis are the same as for Method 8,
Sections 3.2 and 3.3. respectively.
4. Procedure
4.1 Sampling
4.1.1 Preparation ofCollection'Train.
Measure IS ml of 3 percent hydrogen
peroxide into each of the first two midget
impingers. Into the midget bubbler, place
about 25 g of drierite. Clean the outsidea of
the impingeri and the drierite bubbler and
weigh (at room temperature, — 20" C) to the
nearest 0.1 g. Weigh the three vessels
simultaneously and record this initial mass.
Place a small amount of glass wool In the
Erlenmeyer bubbler. The glass wool should
cover the entire bottom of the flask and be
aboul 1-cm thJdc. Place about 100 g of
ascarite on top of the glass wool and
carefully insert the bubbler top. Plug the
bubbler exhaust leg and invert the bubbler to
remove any ascarite Com the bubbler tube. A
wire may be useful in assuring that no
ascarite remains in the rube. With the plug
removed and the outside of the bubbler
cleaned, weigh (at room temperature (at room
temperature, — 20" C), to the nearest 0.1 g.
Record this initial mass.
Assemble the train as shown in Figure 6A-
1. Adjust the probe heater to a temperature
sufficient to prevent water condensation.
Place crushed ice and water around the
impingers and bubblers.
Note.—For stack gas streams with high
participate loadings, an in-stack or heated
oul-of-stack glass fiber mat filler may be used
in place of the glass wool plug in the probe.
4.1.2 Leak-Check Procedure and Sample
Collection. The leak-check procedure and
sample collection procedure are the same as
specified in Method 6. Sections 4.1.2 and
4.1.3, respectively.
4.2 Sample Recovery.
4.2.1 Moisture Measurement. Disconnect
the peroxide unpingers and the drierile
bubbler from the sample train. Allow time
(about 10 minutes) for them to reach room
temperature, clean the outsides and then
weigh them simultaneously in the same
manner as in Section 4.1.1. Record this final
mass.
4.2.2 Peroxide Solution. Pour the contents
of the midget impingers into a leak-free
polyethylene bottle for shipping. Rinse the
two midget impingers and connecting tubes
with deionized distilled water, and add the
washings to the came storage container.
"Mention of trade ntmei or ipecific producu
doei not constitute endorsement by the U.S.
Environmental Protection Ageacy.
4.2.3 CO, Absorber. Allow the Erlenmeyer
bubbler to warm to room temperature (aboul
10 minutes), clean the outside, and weigh to
the nearest 0.1 g In the same manner as in
Section 4.1.1. Record this final mass and
discard the used ascarite.
4.3 Sample Analysis. The sample analysis
procedure for SO, is the same as specified in
Method 6, Section 4 J.
5. Calibration
The calibrations and checks are the same
as required in Method 6, Section S.
8. Calculations
Carry out calculations, retaining at least 1
extra decimal figure beyond that of the
acquired data. Round off figures after final
calculation. The calculation nomenclature
and procedure are the same as specified in
Method 8 with the addition of the following:
8.1 Nomenclature.
CH>*o = Concenlration of moisture, percent
co^i:: Concentration of CO,, dry basis.
percent.
171,,= Initial mass of peroxide impingers and
drierile bubbler, g.
m%1 = Final mass of peroxide impingers and
drierile bubbler, g.
01.4 = Initial mass of ascarite bubbler, g.
m^ = Final mass of ascarite bubbler, g.
VcoM'"<» = Standard equivalent volume of
CO, collected, dry basis, m1.
6.2 CO, volume collected, corrected to
standard conditions.
m.,-mj (Eq. 6A-1I
6.3 Moisture volume collected, corrected
to standard conditions.
Xstd
) • 1.336 x 10~3 (m
-3
- m .)
wi'
(Eq. 6A-2)
6.4 SO- concentration.
* VC02(std)
(Eq. 6A-3)
6.5 CO- concentration.
C02(std)
C02 Vn,(std) +
x TOO
(Eq. 6A-4)
6.6 Moisture concentration.
H0(std)
_
7m(std) + VH20(std) + VC0(std)
(Eq. 6A-5)
7. Emission Rate Procedure
If the only emission measurement desired
is in terms of emission rate of SO, (ng/J), an
abbreviated procedure may be used. The
differences between Method 6A and the
abbreviated procedure are described below.
7.1 Sample Train. The sample train is the
same us shown iu Figure 6A-1 and as
described in Section 4. except that the dry
gas meter is not needed.
7.2 Preparation of the collat'-ion train.
Follow the same procedure as in Section
4.1.1. except that the peroxide i.-npingers and
drierite bubbler need not be weighed before
or after the test run. '"-
7.3 Sampling, Operate ihe train as
described in Section 4.1.3. ercepl that dry 8as
11-140
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meter readings, barom-tric pressure, and dry
g*s meter temperatures need not be recorded.
7.4 Sample Recovery. Follow the
procedure in Section 4.2. except that the
peroxide impinge™ and drie.-ile bubbler need
not be weighed.
7.5 Sample Analysis. Analysis of the
peroxide solution Is the same as described In
Section 4.3.
7.6 Calculations.
7.6.1 SO, mass collected.
Where:
32.03 (Vt - Vtb)
Mass of SO- collected, mg.
7.6.2 Sulfur dioxide emission rate.
(Eq. 6A-7)
SO
F (1'829 x 10
V/liere:
£30^1 = Emission rate of SO». ng/J.
F,=Carbon F factor for the fuel burned.
m'/J. from Method 19.
8. Bibliography
8.1 Same as for Method 6, citations 1
through 8, with the addition of the following:
8.2 Stanley, Jon and P.R. Westlin. An
Alternate MeLhod for Slack Gas Moisture
Determination. Source Evaluation Society
Newsletter. Volume 3. Number 4. November
1978.
8.3 Whittle. Richard N. and P.R. Westlin.
Air PollutioD Test Report; Development and
Evaluation of an Intermittent Integrated
SO./CO. Emission Sampling Procedure.
Environmental Protection Agency,
Emission Standard and Engineering
Division, Emission Measurement
Branch. Research Triangle Park. North
Carolina. December 1979.14 oaeea.
"SO,
(Eq. 6A-8)
Method 6B—Determination of Sulfur Dioxide
and Carbon DioxJde Daily A verage
Emissions From Fossil Fuel Combustion
Sources
1. Applicability and Principle
1.1 Applicability. This method applies to
the determination of sulfur dioxide (SO,)
emissions form combustion sources in terms
of concentration (mg/M1) and emission rale
(n8/D- ar|d for the determination of carbon
dioxide (COi) concentration (percent) on a
daily (24 hours) basis.
The minimum detectable limit, upper limit,
and the interferences for SOi measurements
•re the tame as for Method 0. For a 20-liter
sample, the method has a precision of 0.5
percent CO. for concentrations between 2,5
and 25 percent CO..
1.2 Principle. A gas sample it extracted
from the sampling point in the stack
Intermittently over a 24-hour or other
specified time period. Sampling may also be
conducted continuously if the apparatus and
procedure are modified (see the note in
Section 4.1.1). The SO, and CO, are separated
• nd collected in the sampling train. The SO.
fraction It measured by the barium-thorin
titration method and CO. is determined
yavimetrically.
2. Apparatus
The equipment required for this method is
the same as specified for Method 8A, Section
2, with the addition of an industrial timer-
•wilch designed to operate In the "on"
position from 3 to 5 continuous minutes and
"off" the remaining period over a repeating,
2-hour cycle.
3. Reagents
All reagents for sampling end analysis are
the same as described in Method 6A, Section
3.
4. Procedure.
4.1 Sampling
4.1.1 Preparation of Collection Train.
Preparation of the sample train Is the «ame »»
described in Method 6A. Section 4.1.4 with
the addition of the following-.
Assemble the train as shown in Figure 6B-
1. The probe must be heated to a temperature
sufficient to prevent water condensation and
must include a filter (either in-slack, out-of-
•lack, or both) to prevent particulate
entrainment in the perioxide impinger*. The
electric supply for the probe heat should be
continuous and separate from the timed
operation of the sample pump.
Adjust the timer-switch to operate in the
"on" position form 2 to 4 minutes on a 2-hour
repeating cycle. Other timer sequences may
be used provided there are at least 12 equal,
evenly spaced periods of operation over 24
hours and the total sample volume is
belwren 20 and 40 liters for the amounts of
sampling reagents prescribed in this method.
Add cold water to the tank until the
Impingers and bubblers are covered at least
two-thirds of their length. The Lmpingcrs and
bubbler tank must be covered and protected
from intense heat and direct sunlight. If
freezing conditions exist the impinger
solution and the water bath must be
protected.
II-1-41
-------
I
I—'
l-o
PRODE (END PACKED'
WITH QUARTZ OR
PYREX WOOL)
fcc
X
STACK WALL
THERMOMETER
MIDGET nUDDLERS
MIDGET IMPINGERS /\ ff
ICE DATH
THERMOMETER
RATE METER NEEDLE VALVE
DRY
GAS f/.ETEft
Figure 6B-1. Sampling train.
SURGE TANK
.; ..I.i
-------
Not*.—Sampling may be conducted
continuously If a low flow-rale sample pump
(>24ml/min) li used. Then the timer-twitch
it not necessary. In addition, if the sample
pump i« designed for constant rate sampling.
the rate meter may be deleted. The total gai
volume collected should be between 20 and
40 liters for the amounts of sampling reagents
prescribed in this method.
4.1.2 Leak-Check Procedure. The leak-
check procedure is the same as describedf in
Method 6. Section 4.1.2,
4.1.3 Sample Collection. Record the initial
dry gas meter reading. To begin sampling,
position the tip of the probe at the sampling
point, connect the probe to the first impinger
(or /ilter). and start the timer and the sample
pump. Adjust the cample flow to a constant
rale of approximately 1.0 liter/min ai
indicated by the rotameler. Assure thai the
timer is opeiating as Intended, i.e.. in the "on"
position 3 to 5 minutes at 2-hour intervals, or
olher lime interval specified.
During the 24-hour sampling period, record
the dry gas meter temperature between 9.OO
a.m. and 11:00 aja, and the barometric
pressure.
At the conclusion of the run, turn off the
timer and the sample pump, remove the probe
from the stack, and record the final gas meter
volume reading. Conduct a leak check as
described in Section 4.1.2, If a leak is found.
void the test run or use procedures
acceptable to the Administrator to adjust the
s.implc volume for leakage. Repeat the steps
in this Section (4.1.3) for successive runs.
4.2 Sample Recovery. The procedures for
sample recovery (moisture measurement,
peroxide solution, and ascarite bubbler) are
the same as in Method 6A, Section 4.2.
4.3 Sample Analysis. Analysis of the
peroxide impinger solutions is the same as in
Method 6. Section 4.3.
S. Calibration
5.1 Metering System,
5.1.1 Initial Calibration. The initial
calibration for the volume metering system is
the tame as for Method 6, Section 5.1.1.
5.1.2 Periodic Calibration Check. After 30
days of operation of the test train conduct a
calibration check as in Section 5.1.1 above.
except for the following variations: (1) The
Irak check is not be conducted, (2) three or
more revolutions of the dry gas meter may be
used, and (3) only two independent runs need
be made. If the calibration factor does not
deviate by more than 5 percent from the
initial calibration factor determined in
Section 5.1.1, then the dry gas meter volumes
obtained during the test tenet are acceptable
and use of the train can continue. If the
calibration factor deviates by more than 5
percent, recalibrate the metering ivslem as in
Section 5.1.1: and for the calculations for the
preceding 30 doys of data, use the calibration
factor (initial or recalibralion) that yields the
lower gas volume for each lest run. Use the
Ulesl calibration factor for succeeding tests.
5.2 Tnemotncterr. Calibrate against
mercury-in-glais thermometers initially and
• ! 30-day interval*.
SJ Rotamtttr. The rotameler oeed not be
calibrated, but should be cleaned And
m«ioLamed according to the manufacturer's
Inilruction.
5.4 Barometer. Calibrate against a
mercury barometer Initially and at 30-day
intervals.
5.S Barium PerchJoraie Solution.
Standardize the barium perchJorale solution
against 25 ml of standard sulfuric acid to
which 100 ml of 100 percent isopropanal has
been added.
6. Calculations
The nomenclature and calculation
procedures are the seme as in Method 6A
with the following exceptions:
Pku = lnitial barometric pressure for the lest
period, mm Hg.
T.. = Absolute meter temperature for the
test period "K.
7. Emission Kate Procedure
The emission rate procedure is the same as
described in Method 6A, Section 7, except
that the timer is needed and is operated as
described in this method.
8. Bibliography
The bibliography is the same as described
in Method 6A. Section A.
• ••«.•
5. By revising Performance 2 and
Performance 3 of Appendix B of 40 CFR
Part 60 to read as follows:
Appendix B—Performance Specifications
Performance Specification 2—Specifications
and Test Procedures for SO, and A'O,
Continuous Emission Monitoring Systems in
Stationary Sources
1. Applicability and Principle
1.1 Applicability. This specification is to
be used for evaluating the acceptability of
SO, and NO, continuous emission monitoring
systems (CEMS) after the initial installation
and whenever specified in an applicable
subpart of the regulations. The CEMS may
include, for certain stationary sources.
diluent (O, or CO,) monitors.
1-2 Principle. Installation and
measurement location specifications.
performance and equipment specifications,
lest procedures, and data reduction
procedures axe included in this specification.
Reference method (RM) tests and calibration
drift tests are conducted to determine
conformance of the CEMS with the
specification.
2. Definition*
2.1 Continuous Emission Monitoring
System (CEMS). The tola) equipment
required for the determination of a gas
concentration or emission rale. The system
consists of the following major subsystems:
2.1.1 Sample Interface. That portion of the
CEMS that is used for one or more of the
following: Simple acquisition, sample
transportation, and sample conditioning, or
protection of the monitor from the elfects of
the stack effluent
2.1.2 Pollutant Analyzer. That portion of
the CEMS that senses the pollutant gat and
generates an output that is proportjfinal lo the
gas concentration.
2.1 J Diluent Anojyztr (if applicable).
That portion of the CEMS that sense* the
diluent gas [e.g, CO, or O,) and generates an
output that is proportional to the ga*
concentration.
2.1.4 Data Recorder. That portion of the
CEMS that provides a permanent record of
the analyzer output The data recorder may
include automatic data reduction capabilities.
UL Point CEMS. A CEMS that measure*
(he gai concentration either at a single point
or along a path that It equal to or lest than 10
percent of the equivalent diameter of the
slack or duct cross section.
2J Path CEMS. A CEMS that mesures the
gas concentration along a path thai is greater
than 10 percent of the equivalent diuneler of
the stack or duct cross section.
2.4 Span Value. The upper limit of • gal
concentration measurement range that it
specified for ajfected source categories in the
applicable subpart of the reflation*.
2J Relative Accuracy. (HA). The absolute
mean difference between the ga*
concentration or emission rale determined by
the CEMS and the value determined by the
reference method(s) plus the 2-5 percent error
confidence coefficient of a series of tests
divided by the mean of the reference method
(RM) test* or the applicable emission limit
2.B Calibration Drift (CD). The difference
in the CEMS output readings from the
established reference value sfter a staled
period of operation during which no
unscheduled maintenance, repair, or
adjustment took pi a re.
17 Centroidci Area. A concentric area
that is g-ecme^-ica!])- similar to the stack or
duct cross section and is no greater than 1
percent of the stack or d-.icl cross-sectional
area.
2.8 Representative Results. As defined l>y
the RM test procedure outlined in this
ipecifi cation.
3. Installation and Measurement Location
Specifications
3.1 CEMS Installation and Mecsurcmcnt
Location. Install the CEMS at an accessible
location where the pollutant concentration or
emission rate measurements ere directly
representative or can be corrected so as to be
representative of the total emissions from the
affected facility. Then select representative
measurement poin'J or paths for monitoring
such that the CEMS will pass the relative
accuracy (RA) test (see Section 7). If the
cause of failure to meet the RA test Is
determined to be the measurement location,
the CEMS may be required lo be relocated.
Suggested measurement locations and
points or paths are listed below; other
locations and points or paths may be less
likely lo provide data that will meet the RA
requirement*. '"-
3.1.1 CEMS Location. It Is suggested thai
the measurement location b« al least two
equivalent diameters downstream from the
nearest control device or otScr point at which
a change In the pollutant concentration or
emission rate may occur and at least a half
equivalent diameter upstream from the
efJCuenl exhaust
3.1.2 Point CEMS. 1\ I* suggested thai th«
measurement point,be (1) no lets than 1.0
meter from the slack or duel wnll. ot (2)
within or centrally located over loe
centroidal are« of the slack or doci cro**
section.
II-143
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3.1J Path CEMS. It !i suggested that the
effective measurement path (1) be totally
within the Inner ares bounded by a line 1.0
meter from the stack or duct wall, or [2] have
• t least 70 percent of the path within tha
Inner 50 percent of the slack or duct cross-
lectionaJ aj-ea, or (3) be centrally located
over any part of the centroidal area.
J_2 RM Measurement Location.and
Traverse Points. Select an RM measurement
point that ii accessible and at least (wo
equivalent diameters downstream from the
nearest control device or other point at which
• change in the pollutant concentration or
emission rate may occur and at least a half
equivalent diameter upstream from the
effluent exhaust. The CEMS and RM
locations need not be the tame.
Then select traverse point* that assure
acquisition of representative samples over
the stack or duct cross section. The minimum
requirements are as foUowi: Establish a
"measurement line" that passes through the
centroidal area. If this line Interferes with the
CEMS measurements, displace the line up to
30 cm [or 5 percent of the equivalent diameter
of the cross section, whichever is less) from
the centroidal area. Locate three traverse
point! at 16.7. 50.0, and S3.3 percent of the
measurement line. If the measurement line is
longer than 2.4 meters, the three traverse
points may be located on the line at 0.4. 1-2,
and 2.0 meters from the stack or duct wall.
The tester may select other traverse points,
provided that they can be shown to the
satisfaction of the Administrator to provide a
representative sample over the stack or duct
cross section. Conduct all necessary RM testa
within 3 cm (but no less than 3 cm from the
(tack or duct wall) of the traverse points.
4. Performance and Equipment
Specifications
4.1 Instrument Zero and Span. The CEMS
recorder span must be set at 90 to 100 percent
of recorder full-scale using a span level of 90
to 100 percent of the span value (the
Administrator may approve other span
levels). The CEMS design must also allow the
determination of calibration drift at the zero
and span level points on the calibration
curve. If this i» not possible or ia Unpractical,
the design mud allow these determinations
to be conducted at a low-level (0 to SO
percent of span value) point and at a high-
level [80 to 100 percent of ipan value) point
In special cases, if not already approved, the
Administrator may approve a single-point
calibration-drift determination,
4_2 Calibration Drjft The CEMS
calibration must not drift or deviate from the
reference value of the gas cylinder, gas cell,
or optical filter by more than 2.5 percent of
the ipan value. U the CEMS Include*
pollutant and diluent nonitors, the
calibration drift must be determined
separately for each in terms of concentration*
(see Performance Specification 3 for tha
diluent ipecifications).
4J C£MS Relative Accuracy. The RA of
the CEMS must be no greater than 20 percent
of the mean value of the RM test data In
tenni of the unjta of the emission standard or
10 percent of the applicable standard,
whichever Is greiter.
5. Performance Specification Test
Procedure
5.1 Pretest Preparation. Install the CEMS
and prepare the RM test aite according to the
specificalions In Section 3, and prepare the
CEMS for operation according to the
manufacturer's written instruction*.
5.2 Calibration Drift Test Period. While
the affected facility is operating at more than
SO percent capacity, or aa specified in an
applicable subpart, determine the magnitude
of the calibration drift (CD) once each day (at
24-hour intervals) for 7 consecutive days
according to the procedure given in Section 6.
To meet the requirement of Section 4.2. none
of the CD's must exceed (he specification.
5.3 RA Test Period. Only, after the CEMS -
passes the CD test, conduct the RA teat
according to the procedure given in Section 7
while Ihe affected facility U operating at
more than 50 percent capacity, or aa specified
in an applicable subpart. To meet the
specifications, the RA must be equal to or
less than 20 percent or 10 percent of the
applicable standard, whichever ia greater.
For Instruments that use common
components to measure more than one
effluent gas constituent, all channels must
simultaneously pass the RA requirement,
unless it can be demonstrated that any
adjustments made to one channel did not
affect the others.
8. CEMS Calibration Drift Test Procedure
The CD measurement la to verify the ability
of the CEMS to conform to the established
CEMS calibration used for determining the
emission concentration or emission rate.
Therefore, if periodic automatic or manual
adjustments are made to the CEMS :cro and/
or calibration settings, conduct the CD test
Immediately before these adjustments.
Conduct the CD test at the two points
specified In Section 4.1. Introduce to the
CEMS the reference gases, gas cells, or
optical filters (these need not be certified).
Record the CEMS response and subtract this
value from the reference value (see example
data sheet In Figure 2-1).
If an Increment addition procedure is used
to calibrate the CEMS, a single-point CD test
may be used as follows: Uie an increment
cell or calibration gaa ith a value that will
provide a total CEMS response (Le.. stack
plus cell concentrations) between 60 and 95
percent of the span value. Compare the
difference between the measured CEMS
response and the expected CEMS response
with the increment value to establish the CD.
11-144
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O)
>
-------
Relative Accuracy Test Procedure
7.1 Sampling Strategy for RM Tests.
Conduct the RM tests such that they will
yield results representative of the emissions
from the source and can be correlated to the
CEMS data. Although It Is preferable to -
conduct the diluent (if applicable), moisture
(if needed), and pollutant measurement*
simultaneously, the diluent and moisture
meesuremenls thai are taken within a 30- to
eo-mlnule period, which Includes the
pollutant measurements, may be used to
calculate dry pollutant concentration and
emission rate.
In order to correlate the CEMS and RM
data properly, mark the beginning and end of
each RM test period of each run (including
the exact time ofMhe day) on the CEMS chart
recordings or other permanent record of
output. Use the following strategies for the
RM tests:
7.1.1 For integrated samples, e.g.. Method
0 and Method 4, maVe a sample traverse of at
least 21 minutes, sampling for 7 minutes at
each traverse point
7.1.2 For grab samples, e.g. Method 7,
take one cample at each traverse point.
scheduling the grab samples so that they are
taken simultaneously (within a 3-minute
period} or are an equal interval of time apart
over a 21-minule (or less) period.
Note.—At times, CEMS RA tests are
conducted during NSPS performance tests. In
these cases, RM results obtained during
CEMS RA tests may be used to determine
compliance as long as the source and test
conditions are consistent with the applicable
regulations,
7.2 Correlation ojRM and CEMS Data.
Correlate the CEMS and the RM test data as
to the time and duration by Erst determining
from the CEMS final output (the one used for
reporting) the integrated average pollutant
concentration or emission rate for each
pollutant RM test period. Consider system
response time, if important, and confirm thai
the pair of results are on a consistent
moisture, temperature, and diluent
concentration basis. Then, compare each
integrated CEMS value against the
corresponding average RM value. Use the
following guidelines to make these
comparisons.
7-2.1 If the RM has an Integrated sampling
technique, make a direct comparison of the
RM results and CEMS integrated average
value.
7.2-2 If the RM has • grab sampling
technique, first average the results from all
grab camples taken during the test run and
then compare this average value against the
integrated value obtained from the CEMS
chart recording during the. run.
7 J Number of RM Tests. Conduct a
minimum of nine sets of all necessary RM
tests. For grab samples, e.g. Method 7, • set
Is made up of at least three separate
measurements. Conduct each set within*
period of 30 to 60 minutes.
Note.—The tester may choose to perform
more than nine sets of RM testa. If this option
is chosen, the tester may, at his descrelion.
reject a maximum of three sets of the test
result! so long as the total number of test
results used to determine the relative
accuracy is greater than or equal to nine, but
he must report all data including the rejected
data.
7.4 Reference Methods. Unless otherwise
specified in an applicable subpart of the
regulations. Methods 6, 7, 3. and 4. or their
approved alternatives, are the reference
methods for SO,, NO,, diluent (O, or CO,).
and moisture, respectively.
7.5 Calculations. Summarize the results
on a data sheet; an example is shown in
Figure 2-2. Calculate the meaji of the RM
values. Calculate the arithmetic differences
between the RM and the CEMS output sets.
Then calculate the mean of the difference.
standard deviation, confidence coefficient,
and CEMS RA, using Equations 2-1. 2-2. 2-3.
and 2-4.
8. Equations
C.1 Arithmetic Mean. Calculate the
arithmetic mean of the difference, d. of a data
set as follows:
Where:
n
£
1-1
(Eq. 2-D
Number of data points.
Algebraic sun of the individual differences, d.
When the mean of the differences of pair*
of data is calculated, be sure to correct the
data for moisture, if applicable.
11-146
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Run
No.
1
2
3
4
5
6
7
8
9
10
11
12
Date and
time
Average
so2
RM
M
Diff
ppmc
Confidence Interval
Accuracy0
<
RM
M
Diff
ppmc
C02 or 02a
RM
M
%d xd
^
RM
M | Diff
mass/GCV
NO;
RM| M
Diff
mass/GCV
H
'For steam generators; Average of three samples; c Make sure that RM and M data are on a consistent basis,
„....;., , either wot or dry.
Figure 2-2. Relative accuracy determination.
-------
8.2 Standard Deviation. Calculate the
standard deviation S, as followi:
Wbere:
•0.975 = I-value* face Table 2-1)
Table 2-1.1-VALUES
ft «,
1-1
',)
U«7S
<0.t7J
(to. i-z
8.3 Confidence Coefficient. Calculate tie *-
2.5 percent error confidence coefficient (one-
tailed) CC is follows: ~
12.708 7 2.*47 12 2.J01
4J03 • ZJ6S II 2.17*
J.1&2 • 2JO8 14 1160
2.77V 10 12*3 IS 2.14S
1.571 11 1229 1* 2.131
*) vai
VB]M«* bi lM§ table ar» «V-1
of Irrrdoox U»e • r<]u*l le the euoibcr of
a. 4 Relative Accuracy. Calculate the RA
of • tel of data as follows:
led
X TOO
(Eq. 2-4)
V/here:
ffl
ICC
RM
= Absolute value of the mean of differences
(from Equation 2-1).
= Absolute (value of the confidence coefficient
(from Equation 2-3).
= Average RM value or applicable standard.
calculations, and charts (record of data
outputs) that are necessary to substantiate
that the performance CEM$ met the
performance specification.
9. Reporting
At a minimum (check with the appropriate
regional office, or Slate or local agency for
additional requirement*, if any) summarize in
tabular form the calibration drift tests and
the RA tests. Include all data iheed.
10. Bibliography
10.1 "Experimental Statistics."
Department of Commerce. Handbook 91.
1963, pp. 3-31. paragraphs 3-3.1.4.
Performance Specification 3—Specifications
and Test Procedures for O, and CO,
Continuous Emission Monitoring Systems in
Stationary Sources
1. Applicability and Principle
1.1 Applicability. This specification is to
be u»ed for evaluating the acceptability of 0,
and CO, continuous emission monitoring
systems (CEMS) after initial installation and
whenever specified in an applicable subpart
of the regulations. Tbe specification applies
lo O, and CO, monitors that are not included
under Performance Specification 2.
The definitions, installation measurement
location specifications, test procedures, dad
reduction procedures, reporting requirement!,
and bibliography are the same as in
Performance Specification 2, Sections 2, 3, 5,
6. 8. 9. and 10. and also apply lo O, and C0t
CEMS under this specification. The
performance and equipment specifications
and the relative accuracy (RA) lest
procedures for O, and CO, CEMS differ from
SO, and NO, CEMS, unless otherwise noted,
and are therefore included here.
1.2 Principle. Reference method (RM)
tests and calibration drift tests are conducted
to determine conformance of the CEMS with
the specification.
2. Performance and Equipment
Specifications
2.1 Instrument Zero and Span. ThU
specification is the same as Section 4.1 of
Performance Specification 2.
2.2 Calibration Drift. The CEMS
calibration must not drift by more than 0.5
percent O, or CO, from the reference value of
the gas, gas cell, or optical filter.
2-3 CEMS Relative Accuracy. The RA of
the CEMS roust be no greater than 20 percent
of the mean value of the RM lest data or 1.0
percent O, or CO,, whichever is greater.
3. Relative Accuracy Test Procedure
3.1 Sampling Strategy for RM Tests,
correlation of RM and CEMS data, Number
of RM Tests, and Calculations. This is the
same as Performance Specification 2,
Sections 7.1. 7.2. 7J. and 7.5. respectively.
3.2 Reference Meihod. Unless otherwise
specified in an applicable subpart of the
regulations. Method 3 of Appendix A or any
approved alternative is the reference method
for O, or CO*.
(Sec. 114. Clean Air Act. as amended [42
U.S.C 7414)}
[TR Doc. I1-2&37 FJlnJ 1-rV-ei: US >n]
11-148
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SIP MONITORING REQUIREMENTS - PROMULGATED
11-149
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RULES AND KEGUIATIONS
Tttlt 40—Protection of Environment
CHAPTER I—ENVIRONMENTAL
PROTECTION AGENCY
SUBCMAPTtR C—AIR PROGRAMS
|PRL 423-61
PART 51—REQUIREMENTS FOR THE
PREPARATION. ADOPTION AND SUB-
MITTAL OF IMPLEMENTATION PLANS
Emission Monitoring of Stationary Sources
On September 11, 1974. the Environ-
mentafTProtertion Agency (EPA) pro-
posed revisions to 40 CFR Part 51. Re-
quirements for the Preparation, Adop-
tion, and Submittal of Implementation
Plans. EPA proposed to expand 5 51.19 to
require States to revise their State Im-
plementation Plans (SIP's) to include
legally enforceable procedures requiring
certain specified categories of existing
stationary sources to monitor emissions
on a continuous basis. Revised SIP's sub-
mitted by States in response to the pro-
cosed revisions to 40 CFR 51.19 would
• have (1) required owners or operators
of specified categories of stationary
sources to install emission monitoring
equipment within one year of plan ap-
proval. (2) specified the categories of
sources subject to the requirements, (3)
identified for each category of sources
the pollutant(s) which must be moni-
tored, (4) set forth performance specifi-
cations for continuous emission monitor-
ing instruments. required that such
Instruments meet performance specifi-
cations through on-site testing by the
owner or operator, and (6) required that
data derived from such monitoring be
summarized and made available to the
State on a quarterly basis.
As a minimum, EPA proposed that
States must adopt and implement legally
enforceable procedures to require moni-
toring of emissions for existing sources
In the following source categories (but
only for sources required to limit emis-
sions to comply with an adopted regula-
tion of the State Implementation Plan):
(a) Coal-fired steam generators of
more than 250 million BTU per hour heat
input (opacity, sulfur dioxide, oxides ol
nitrogen and oxygen);
(b> Oil-fired steam generators of more
than 250 million BTU per hour heat In-
put fsulfur dioxide, oxides of nitrogen
and oxygen). An opacity monitor was re-
quired only if an emission control device
is needed to meet particulate emission
regulations, or if violations of visible
emission regulations are noted;
(c) Nitric acid plants (oxides of
nitrogen);
(d) Sulfuric acid plants fsulfur di-
oxide); and
(e> Petroleum refineries' fluid catalytic
cracking unit catalyst regenerators
(opacity).
Simultaneously, the Agency proposed
similar continuous emission monitoring
requirements for new sources for each of
the previously identified source categor-
ies, subject to the provisions of federal
New Source Performance Standards set
forth in 40 CFR Part 60. Since many of
the technical aspects of the two proposals
were similar, if not the same, the pro-
posed regulations for Part 51 (i.e..,those
relating to SIP's and existing sources)
included by reicrcnrr many specific tech-
nical details set forth in 40 CFR Part 60,
(39 FR 32852).
At the time of the proposal of the con-
tinuous emission monitoring regulations
in the FEDERAL REGISTER, the Agency in-
vited comments on the proposed rule-
makinK action Many interested parties
submitted comments. Of the 76 comments
received, 35 were from electric utility
companies, 26 were from oil refineries or
other industrial companies, 12 were from
governmental agencies, and 3 were from
manufacturers and'or suppliers of emis-
sion monitors. No comments were re-
ceived from environmental groups. Fur-
ther, prior to the proposal of the regula-
tions in the FEDERAL REGISTER, the Agency
sought comments from various State and
local air pollution control agencies and
instrument manufacturers. Copies of
each of these comments are available
for public inspection at the EPA Freedom
of Information Center, 401 M Street.
S.W.. Washington. D.C. 20460. These
commenls have been considered, addi-
tional information collected and assessed,
and where determined by the Adminis-
trator to be appropriate, revisions and
amendments have been made in for-
mulating these regulations promulgated
herein.
General Discussion of Comments. In
general, the comments received by the
Agency tended to raise various objections
with specific portions of the regulations.
Some misinterpreted the proposed reg-
ulations, not realizing that emission
monitoring under the proposal was not
required unless a source was required to
comply with an adopted emission limita-
tion or sulfur in fuel limitation that was
part of an approved or promulgated State
Implementation Plan. Many questioned
the Agency's authority and the need to
require sources to use continuous emis-
sion monitors. Others stated that the
proposed regulations were inflationary,
and by themselves could not reduce emis-
sions to the atmosphere nor could they
improve air quality. A relatively common
comment was that the benefits to be de-
rived from the proposed emission moni-
toring program were not commensurate
with the costs associated with the pur-
chase, installation, and operation of such
monitors. Many'stated that the proposed
regulations were not cost-effectively ap-
plied and they objected to all sources
within an identified source category be-
ing required to monitor emissions, with-
out regard for other considerations. For
instance, some suggested that it was un-
necessary to monitor emissions from
steam generating plants that may soon
be retired from operation, or steam gen-
erating boilers that are infrequently used
(such as for peaking and cycling opera-
tions) or for those sources located in
areas of the nation which presently have
ambient concentrations better than na-
tional ambient air quality standards. This
latter comment was especially prevalent
In relation to the need for continuous
emission monitors designed to measure
emissions of oxides of nitrogen. Further,
commentors generally suggested that
state and local control agencies, rather
than EPA should be responsible for
determining which sources should moni-
tor emissions. In this regard, the corn-
mentors suggested that a determination
of the sources which should install con-
tinuous monitors should be made on a
case-by-case oasJs. Almost all objected to
the data reporting requirements stating
that the proposed requirement of sub-
mission of all collected data was excessive
and burdensome. Comments from state
and local air pollution control agencies in
general were similar to those from the
utility and industrial groups, but in addi-
tion, some indicated that the manpower
needed to implement the programs re-
quired by the proposed regulations was
not available.
Rationale for Emission Monitoring
Regulation. Presently, the Agency's reg-
ulations setting forth the requirements
for approvable SIP's require States to
have legal authority to require owners
or operators of stationary sources to in-
stall, maintain, and use emission moni-
toring devices and to make periodic
reports of emission data to the State
(40 CFR 51.11 (a) (6)). This requirement
was designed to partially implement the
requirements of Sections 110(a)(2>(F)
'ii) and (iii) of the Clean Air Act, which
state that implementation plans must
provide "requirements for installation
of equipment by owners or operators of
stationary sources to monitor emissions
from such sources", and "for periodic
reports on the nature and amounts of
such emissions". However, the original
Implementation plan requirements did
not require SIP's to contain legally en-
forceable procedures mandating contin-
uous emission monitoring and recording.
At the time the original requirements
were published, the Agency had accumu-
lated little data on the availability and
reliability of continuous monitoring de-
vices. The Agency believed that the
state-of-the-art was such that it was
not prudent to require existing sources
to Install such devices.
Since that time, much work has been
done by the Agency and others to field
test and compare various continuous
emission monitors. As a result of this
work, the Agency now believes that for
certain sources, performance specifica-
tions for accuracy, reliability and dura-
bility can be established for continuous
emission monitors of oxygen, carbon
dioxide, sulfur dioxide, and oxides of
nitrogen and for the continuous meas-
urement of opacity. Accordingly, it is
the Administrator's judgment that Sec-
tions 110(a)(2)(F) (ID and (111) should
now be more fully imolemented.
The Administrator believes that a
sound program of continuous emission
monitoring and reporting will play an
important role in the effort to attain
and maintain national standards. At the
present time, control agencies rely upon
infrequent manual source tests and
periodic field inspections to provide
much of the enforcement information
necessary to ascertain compliance of
sources with adopted regulations. Man-
ual source tests are generally performed
on a relatively infrequent basis, such as
RMIAL UCISTEI, VOL 40, NO. 1»4 MONDAY, OCTOtU 4, 1?7i
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RULES AND REGULATIONS
once per year, and in some cases, affected
sources probably have never been tested.
Manual stack tests are generally per-
formed under optimum operating con-
ditions, and as such, do not reflect the
full-time emission conditions from a
source. Emissions continually vary with
fuel firing rates, process material feed
rates and various other operating condi-
tions. Since manual stack tests are only
conduced for a relatively short period
of time (e.g.. one to three hours', they
cannofbe representative of all operating
conditions. Further, frequent manual
stack tests (such as conducted on a
quarterly or more frequent basis' are
costly and may be more expensive than
continuous monitors that provide much
more Information. State Agency en-
forcement by field Inspection is also
sporadic, with only occasional inspection
of certain sources, mainly for visible
emission enforcement.
Continuous emission monitoring and
recording systems, on the other hand,
can provide a continuous record of emis-
sions under all operating conditions. The
continuous emission monitor is a good
Indicator of whether a source is using
good operating and maintenance prac-
tices to minimize emissions to the at-
mosphere and can also provide a valu-
able record to Indicate the performance
of a source in complying with applicable
emission control regulations. Addition-
ally, under certain Instances, the data,
from continuous monitors may be suf-
ficient evidence to issue ft notice of vio-
lation. The continuous emission record
can also be utilized to signal a plant
upset or equipment malfunction so that
the plant operator can take corrective
action to reduce emissions. Use of emis-
sion monitors can therefore provide val-
uable information to-minimize emissions
to the atmosphere and to assure that
full-time control effprts. such as good
maintenance and operating conditions,
are being utilized by source operators.
The,Agency believes that it is necessary
to establish national minimum require-
ments for emission monitors for specified
sources rather than allow States to de-
termine on a case-by-case basis the spe-
cific sources which need to continuously
monitor emissions. The categories speci-
fied in the regulations represent very sig-
nificant sources of emissions to the at-
mosphere. States in developing SIP's
have generally adopted control regula-
tions to minimize emissions from these
sources. Where such regulations exist, the
Agency believes that continuous emission
monitors are necessary to provide infor-
mation that may be used to provide an
Indication of source compliance. Further.
it is believed that if the selection of
sources on a case-by-case basis were left
to the States, that some States would
probably not undertake an adequate
(mission monitoring program. Some
8UU Agencies who commented on the
propowd regulations questioned the
•Ut«-of-the-art of emission monitoring
ww iut*d their opinion that the pro-
P»«l requirements were premature.
Th»r»foT8. It U the Administrator's
)w*m«t that. In order to assure an
adequate nationwide emission monl-
torine pi'oenim. minimum emission mon-
itorinp requirement* must be established.
The source categories affected by the
regulation1! were selected because they
are significant sources of emissions and
because the Agency's work at the time of
the proposal of these retaliations In the
field of continuous emission monitoring
evaluation focused almost exclusively on
these source categories. The Agency is
continuing to develop data on monitoring
devices for additional source categories.
It is EPA's intent to expand the minimum
continuous emission monitoring require-
ments from time to time when the eco-
nomic and technological feasibility of
continuous monitoring equipment is
demonstrated and where such monitor-
ing is deemed appropriate for other sig-
nificant source categories.
Discussion ol Major Comments. Many
rommentors discussed the various cost
aspects of the proposed regulations, spe-
cifically stating that the costs of con-
tinuous monitors were excessive and In-
flationary. A total of 47 commentors ex-
pressed concern for the cost and/or cost
effectiveness of continuous monitors.
Further, the Agency's cost estimates for
purchasing and installing monitoring
systems and the costs for data reduction
and reporting were questioned. In many
cases, sources provided cost estimates for
installation and operation of continuous
monitors considerably in excess of the
cost estimates provided by the Agency.
In response to these comments, a fur-
ther review was undertaken by the Agen-
cy to assess the cost impact of the regu-
lations. Three conclusions resulted from
this review. First, it was determined that
the cost ranges of the various emission
monitoring systems provided by the
Agency are generally accurate for new
sources. Discussions with equipment
manufacturers "and suppliers confirmed
this cost information. Approximate in-
vestment costs, which include the cost
of the emission monitor. Installation cost
at a new facility, recorder, performance
testing, data reporting systems and asso-
ciated engineering costs are as follows:
for opacity, 520,000; for sulfur dioxide
and oxygen or oxides of nitrogen and
oxygen, S30.000: and for a source that
monitors opacity, oxides of nitrogen, sul-
fur dioxide and oxygen, $55,000. Annual
operating costs, which include data 're-
duction and report preparation, system
operation, maintenance, utilities, taxes,
insurance and annualized capital costs
at 109; for 8 years are: $8.500; $16.000;
and $30.000 respectively for the cases
described above.) 1)
Secondly, the cost review indicated
that the cost of installation of emission
monitors for existing sources could be
considerably higher than for new sources
because of the difficulties in providing
access to a sampling location that can
provide a representative sample of emis-
sions. The cost estimates provided by the
Agency in the proposal were specifically
developed for new sources whose in-
stallation costs are relatively stable since
provisions for monitorinc equipment cnn
be incorporated at the time of plant de-
sign. This feature is not available for ex-
isting sources, hence higher costs gei
erally result. Actual costs of installatir
at existing sources may vary from 01
to five times the cost of normal instalb
tion at new sources, and in some cas<
even higher costs can result For exam
pie. discussions with Instrument suppl:
ers indicate that a typical cost of instal
latlon of an opacity monitor on an exisi
ing source may be two to three times tlv
purchase price of the monitor. Difficul
ties also exist for Installation of gaseou
monitors at existing sources.
It should be noted that these installs
tion costs Include material costs for seal
folding, ladders, sampling ports an-
other items necessary to provide acce?
to a location where source emissions cai
be measured. It is the Agency's opinio:
that such costs cannot be solely attrib
uted to these continuous emission moni
toring regulations. Access to samplini
locations is generally necessary to dc
termine compliance with applicable stati
or local emission limitations by routint
manual stack testing methods. There-
fore, costs of providing access to a rep-
resentative sampling location are more
directly attributed to the cost of com-
pliance with, adopted emission limita-
tions, than with these continuous emis-
sion monitoring regulations.
Lastly, the review of cost information
indicated that a numb;r of commentor-
misinterpreted the extent of the pro-
posed regulations, thereby providing cost
estimates for continuous monitors which
were not required Specifically, all com-
mentors did not recognize that the pro-
posed regulations required emission mon-
itoring for a source only if an applicable
State or local emission limitation of an
approved SIP affected such a source. For
example, if the approved SIP did not
contain an adopted control regulation to
limit oxides of nitrogen from steam-
generating, fossil fuel-fired boilers of a
capacity in excess of 250 million BTU per
hour heat input, then such source need
not monitor oxides of nitrogen emis-
sions. Further, some utility industry com-
mentorn Included the costs of continuous
emission monitors for sulfur dioxide. The
propossd regulations, however, generally
allowed the use of fuel analysis by speci-
fied ASTM procedures as an alternative
which, in most cases, is less expensive
than continuous monitoring. Finally, the
proposed regulations required the con-
tinuous monitoring of oxygen in the
exhaust gas only if the source must
otherwise continuously monitor oxides of
nitrogen or sulfur dioxide. Oxygen in-
formation is used solely to provide a cor-
rection for excess air when converting
the measurements of gaseous pollutants
concentrations in the exhaust gas stream
to units of an applicable emission limi-
tation. Some eommentors did not recog-
nize this point (which was not specifical-
ly stated In the. proposed regulations)
and provided cost estimates for oxygen
monitors when thev were not required by
the proposed regulations.
While not all commentors' cost esti-
mates were correct, for various reasons
noted above, it is clear that the costs
associated with implementing these
emission monitoring regulations are sig-
UCIJTit, VOL 40, NO. I»4—MONOAV, OCTOIEI *, 1*75
11-151
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RULES AND REGULATIONS
niftcant. The Administrator, however.
believes that the benefits to be derived
from emission monitoring are such that
the costs are not unreasonable. The Ad-
ministrator does, however, agree with
many commentors that the proposed reg-
ulations, in some cases, were not applied
cost-effectively and, as such, the regula-
tions promulgated herein have been
modified to provide exemptions to cer-
tain sources from these minimum re-
quirements.
One ^comment from another Federal
Agency" concerned the time period that
emissions are to be averaged when re-
porting excess emissions Specifically, the
commentor assumed that the emission
control regulations that have been
adopted by State and local agencies were
generally designed to attain annual am-
bient air quality standards. As such, the
commentor pointed out that short-term
emission levels in excess of the adopted
emission standard should be acceptable
for reasonable periods of time.
The Administrator does not agree with
this rationale for the following reasons.
First, it is not universally true that an-
nual ambient standards were the design
basis of emission control regulations. In
many cases, reductions to attain short-
term standards require more control
than do annual standards. Even if the
regulations were based upon annual
standards, allowing excess emissions of
the adopted emission control regulation
on a short-term basis could cause non-
compliance with annual standards. More
importantly, however, a policy of legally
allowing excesses of adopted control reg-
ulations would in effect make the current
emission limitation unenforceable If the
suggestion were implemented, a question
would arise as to what is the maximum
emission level that would not be consid-
ered an excess to the adopted regulation.
The purpose of the adopted emission lim-
itation was to establish the acceptable
emission level. Allowing emissions in ex-
cess of that adopted level would cause
confusion, ambiguity, and in many cases
could result in an unenforceable situa-
tion. Hence the Administrator does not
concur with the commentor's suggestion.
Modifications to the Proposed Regu-
lations. The modification to the regu-
lations which has the most significant
impact involves the monitoring require-
ments for oxides of nitrogen at fossil
fuel-fired steam generating boilers and
at nitric acid plants Many commentors
correctly noted that the Agency in the
past (June 8, 1973. 38 FR 15174-1 had in-
dicated that the need for many emis-
sion control regulations for oxides of
nitrogen were based upon erroneous
data. Such a statement was made after
m detailed laboratory analysis of the ref-
erence ambient measurement method
for nitrogen dioxide revealed the method
to give false measurements. The
sampling technique generally Indicated
concentrations of nitrogen dioxide
higher than actually existed in the
•tmosphere. Since many control agen-
cies prior to that announcement had
•dopted emission regulations that were
determined to be needed based upon
these erroneous data, and since new data,
collected by other measurement tech-
niques, indicated th.it in most areas of
the nation such control regulations were
not necessary to satisfy the requirements
of the SIP. the Agency suggested that
States consider the withdrawal of
adopted control regulations for the con-
trol of oxides of nitrogen from their SIP's
(May 8. 1914. 39 FR 16344). In many
States, control agencies have not taken
action to remove these regulations from
the SIP. Hence, the commentors pointed
out that the proposed regulations to re-
quire continuous emission monitors on
sources affected by such regulations is
generally unnecessary.
Because of the unique situation in-
volving oxides of nitrogen control regu-
lations, the Administrator has deter-
mined that the proposed regulations to
continuously monitor oxides of nitrogen
emissions may place an undue burden on
source operators, at least from a stand-
point of EPA specifying minimum moni-
toring requirements. The continuous
emission monitoring requirements for
such sources therefore have been modi-
fied. The final regulations require the
continuous emission monitoring of
oxides of nitrogen only for those sources
in Air Quality Control Regions (AQCR's >
where the Administrator has specifically
determined that a control strategy for
nitrogen dioxide is necessary. At the
present time such control strategies are
required only for the Metropolitan Los
Angeles Intrastate and the Metropoli-
tan Chicago Interstate AQCR's.
It should be noted that a recent com-
pilation of valid nitrogen dioxide air
quality data suggests that approximately
14 of the other 245 AQCR's in the nation
may need to develop a control strategy
for nitrogen dioxide. These AQCR's are
presently being evaluated by the Agency.
If any additional AQCR's are identified
as needing a control strategy for nitro-
gen dioxide at that time, or any time
subsequent to this promulgation, then
States in which those AQCR's are lo-
cated must also revise their SIP's to
require continuous emission monitoring
for oxides of nitrogen for specified
sources. Further, it should be noted that
the regulations promulgated today are
minimum requirements, so that States,
if they believe the control of oxides of
nitrogen from sources is necessary may,
as they deem appropriate, expand the
continuous emission monitoring require-
ments to apply to additional sources not
affected by these minimum requirements.
Other modifications to the proposed
regulation resulted from various com-
ments. A number of commentors noted
that the proposed regulations included
some sources whose emission impact on
air quality was relatively minor. Specifi-
cally, they noted that fossil fuel-fired
steam generating units that were used
solely for peaking and cycling purposes
should be exempt from the proposed reg-
ulations. Similarly, some succcsted that
smaller sized units, particularly steam-
generating units less than 2.500 million
BTU per hour heat input, should also
be exempted. Others pointed out that
units soon to be retired from operation
should not be required to install con-
tinuous monitoring devices and that
sources located in areas of the nation
that already have air quality better than
the national standards should be relieved
of the required monitoring and reporting
requirements. The Agency has considered
these comments and has made the fol-
lowing judgments.
In relation to fossil fuel-fired steam
generating units, the Agency has deter-
mined that such units that have an an-
nual boiler capacity factor of 30% or less
as currently defined by the Federal Power
Commission shall be exempt from the
minimum requirements for monitoring
and reporting. Industrial boilers used at
less than 307r of their annual capacity,
upon demonstration to the State, may
also be granted an exemption from these
monitoring requirements. The rationale
for this exemption is based upon the fact
that all generating units do not produce
power at their full capacity at all times.
There are three major classifications of
power plants based on the degree to
which their rated capacity is utilized on
an annual basis. Baseload units are de-
signed to run at near full capacity almost
continuously. Peaking units are operated
to supply electricity during periods of
maximum system demand. Units which
are operated for intermediate service
between the extremes of baseload and
peaking are termed cycling units.
Generally accepted definitions term
units generating 60 percent or more of
their annual capacity as baseload, those
generating less than 20 percent as peak-
ing and those between 20 and 60 percent
as cycling. In general, peaking units are
older, smaller, of lower efficiency, and
moro costly to operate than base load or
cycling units. Cycling units are also gen-
erally older, smaller and less efficient
than base load units. Since the expected
life of peaking units is relatively short
and total emissions from such units are
small, the benefits gained by installing
monitoring instruments are small in
comparison to the cost of such equip-
ment. For cycling units, the question of
cost-effectiveness is more difficult to as-
certain. The units at the upper end of
the capacity factor range (i.e.. near 60^
boiler capacity factor) are candidates for
continuous emission monitoring while
units at the lower end of the range (i.e..
near 207 boiler capacity factor* do not
represent good choices for continuous
monitors. Based upon available emission
information, it has been calculated that
fossil fuel-fired steam generating plants
with a 307r or less annual boiler capacity
factor contribute approximately less
than 5O of the total sulfur dioxide from
all such power plants. (2) Hence, the
final regulations do not afTert any boiler
that has an annual boiler capacity factor
of less than SOCr Monitoring require-
ments will thus be more cost effectively
applied to the newer, larger, and more
efficient units that burn a relatively
Iftrrer portion of the total fuel supply.
Some commentors noted that the age
of the facility should be considered in
relation to whether a source need com-
KDHAl IJGIJTU, VOL 40, NO. It4—MONDAY, OCTOtH *, 1«7S
11-152
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RULES AND REGULATIONS
ply with the proposed regulations. For
fossil fuel-fired steam generating units.
the exemption relating to the annual
boiler capacity factor previously dis-
cussed should generally provide relief for
older units. It is appropriate, however,
that the age of the facility be consid-
ered for other categories of sources af-
fected by the proposed regulations. As
such, the final regulation!: allow thnt any
source "5hat Is scheduled to be retired
within five years of the inclusion of mon-
HorlngTrequirements for the source in
Appendix P need not comply with the
minimum emission monitoring require-
ments promulgated herein. In the Ad-
ministrator's judgment, the selection of
five years as the allowable period for
this exemption provides reasonable re-
lief for those units that will shortly be
retired. However, It maintains full re-
quirements on many older units with a
number of years of service remaining.
In general, older units operate less effi-
ciently and are less well controlled than
newer units so that emission monitoring
is generally useful. The exemption pro-
vided In the final regulations effectively
allows such retirees slightly more than a
two-year period of relief, since the sched-
ule of implementation of the regulations
would generally require the installation
of emission monitors by early 1978.
States must submit, for EPA approval.
the procedures they will implement to
use this provision. States are advised
that such exemptions should only be pro-
vided where a bona fide intent to cease
operations has been clearly established.
In cases where such sources postpone
retirement. States shall have established
procedures to require such sources to
monitor and report emissions. In this re-
gard, it should be noted that Section
113(c> (2) of the Act provides that any
person who falsifies or misrepresents a
record, report or other document filed or
required under the Act shall, upon con-
viction, be subject to fine or Imprison-
ment, or both.
A further modification to the proposed
regulations affects the minimum size of
the units within each of the source cate-
gories to which emission monitoring and
reporting shall be required. As suggested
by many commentors. the Agency has in-
vestigated the cost effectiveness of re-
quiring all units within the identified
source categories to install emission mon-
itors. Each pollutant for each source
category identified in the proposed reg-
ulations was evaluated. For fossil fuel-
fired steam generating units."the pro-
posal required compliance for all boilers
with 250 million BTU per hour heat in-
put, or greater. For opacity, the proposed
regulations required emission monitoring
for all coal-fired units, while only those
oil-fired units that had been observed as
violators of visible emission regulations
or must use an emission control device to
meet particulate matter regulations were
required to install such devices. Gas-
fired units were exempted by the pro-
posed regulations.
After investigating the particulate
emission potential of these sources. It has
been determined that no modification In
the size limitation for boilers in relation
to opacity is warranted. The rationale
for this Judgment is that the smaller-
sized units affected by the proposed reg-
ulation tend to be less efficiently oper-
ated or controlled for particulate matter
than are the larger-sized units. In fact.
smaller units generally tend to emit more
particulate emissions on an equivalent
fuel basis than larger-sized units. '21
Because of the potential of opacity regu-
lation violations, no modifications have
been made to the regulations as to the
size of steam generating boilers that
must measure opacity.
Emissions of oxides of nitrogen from
boilers are a function of the temperature
in the combustion chamber and the cool-
ing of the combustion products. Emis-
sions vary considerably with the size and
the type of unit. In general, the larner
units produce more oxides of nitrogen
emissions. The Agency therefore finds
that the minimum size of a unit affected
by the final regulations can be increased
from 250 to 1.000 million BTU per hour
heat input, without significantly reduc-
ing the total emissions of oxides of nitro-
gen that would be affected by monitoring
and reporting requirements. Such a mod-
ification would hnve the effect of exempt-
ing approximately 56% of the boilers
over 250 million BTU per hour heat input
capacity, on a national basis, while main-
taining emission monitoring and report-
ing requirements for approximately 78%
of the potential oxides of nitrogen emis-
sions from such sources.^' Further, in
the 2 AQCR's where the Administrator
has specifically called for a control
strategy for nitrogen dioxide, the boilers
affected by the regulation constitute 50%
of the steam generators greater than 250
million BTU per hour heat input, yet
they emit 807, of the nitrogen oxides
from such steam generators in these
2 AQCR's.(2)
Also, certain types of boilers or burn-
ers, due to their design characteristics.
may on a regular basis attain emission
levels of oxides of nitrogen well below
the emission limitations of the applica-
ble plan. The regulations have been re-
vised to allow exemption from the
requirements for installing emission
monitoring and recording equipment for
oxides of nitrogen when a facility is
shown during performance tests to op-
erate with oxides of nitrogen emission
levels 30% or more below the emission
limitation of the applicable plan. It
should be noted that, this provision ap-
plies solely to oxides of nitrogen emis-
sions rather than other pollutant emis-
sions, since oxides of nitrogen emissions
are more directly related to boiler de-
sign characteristics than are other
pollutants.
Similar evaluations were made for
nitric acid plants, sulfuric acid plants
and catalytic cracking unit catalyst re-
generators at petroleum refineries. For
each of these Industries it was found that
modifications to the proposed regulations
could be made to increase the minimum
size of the units affected by the proposed
regulations without significantly de-
creasing the total emissions of various
pollutants that would be affected by
these monitoring and reporting require-
ments. Specifically, for nitric acid plants
it was found that by modifying the pro-
posed regulations to affect only those
plants that have a total daily production
capacity of 300 tons or more of nitric acid
(rather than affecting all facilities as
proposed) that approximately 79% of
the nitric acid production on a national
basis would be affected by the provisions
of these monitoring and reporting re-
quirements. On the other hand, such a
modification reduces the number of
monitors required for compliance with
these regulations by approximately 46%.
(2) At the present time, only nitric acid
plants in AQCR's where the Administra-
tor has specifically called for a control
strategy for nitrogen dioxide will be can-
didates for continuous emission monitor-
ing requirements for the reasons men-
tioned previously. In the 2 AQCR's where
such a control strategy has be«n called
for. there is only one known nitric acid
plant and that is reported to be less than
300 tons per day production capacity—
hence no nitric arid plants at the present
time will be affected by these monitoring
requirements.
Similarly, evaluations of sulfuric acid
plnnts and catalytic cracking catalyst re-
generators at petroleum refineries re-
sulted in the conclusion that minimum
size limitations of 300 tons per day pro-
duction rate at sulfuric acid plants, and
20.000 barrels per day of fresh feed to
any catalytic cracking unit at petroleum
refineries could be reasonably estab-
lished. Such modifications exempt ap-
proximately 37% and 39" respectively
of such plants on a national basis from
these emission monitoring and reporting
reouirements. while allowing about 9%
of the sulfur dioxide emissions from sul-
furic acid plants and 12% of the par-
ticulate matter emissions from catalytic
cracking units to be emitted to the at-
mosphere without being measured and
reported. (2) The Agency believe that
such modifications provide a reasonable
balance between the costs associated
with emission monitoring and reporting,
and the need to obtain such information.
A number of commentors suggested
that sources be exempt from the pro-
posed emission monitoring regulations If
.«uch sources are located within areas of
the nation that are already attaining
national standards. The Administrator
does not believe that such an approach
would be consistent with Section 110 of
the Clean Air Act, which requires con-
tinued maintenance of ambient stand-
ards after attainment. In many areas.
the standards are being attained only
through effective implementation of
emission limitations. Under the Clean Air
Act. continued compliance with emis-
sion limitations In these areas is just as
important as compliance in areas which
have not attained the standards.
Another major comment concerned
the proposed data reporting require-
ments. Thirty-four (34) commentors ex-
pressed concern at the amount of data
which the proposed regulations required
to be recorded, summarized, and submit-
ROflAl UCISTH, VOL 40, NO. 1f4 MONDAY, OCTOIEI t. 1975
11-153
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RULES AND REGULATIONS
ted to the State. It was generally indi-
cated by the rommentors that the data
reporting requirements were excessive.
Commentors questioned the purpose of
reporting all measured dats while sonic
State agencies indicated they have lim-
ited resources to handle such informa-
tion. EPA believes that, in some cases.
the commentors misconstrued the data
reporting reouirements for existing
sourresTIn light of each of these com-
ments, the final regulations, with respect
to the Snta reporting requirements for
(aseous pollutants and opacity, have
been modified.
For gaseous emissions, the proposed
regulations required the reporting of all
one-hour averages obtained by the emis-
sion monitor. Because of the comments
on this provision, the Agency has reex-
amined the proposed data reporting re-
quirements. As a result, the Agency has
determined that only information con-
cerning emissions in excess of emission
limitations of the applicable plan is nec-
essary to satisfy the intent of these reg-
ulations. Therefore, the data reporting
requirements for gaseous pollutants
have been modified. The final regulations
require that States adopt procedures that
would require sources to report to the
State on emission levels in excess of the
applicable emission limitations 'i.e., ex-
cess emissions! for the time period spec-
ified in the regulation with which com-
pliance is determined In other words, If
an applicable emission limitation re-
quired no more than 1.0 pounds per .hour
SO, to be emitted for any two-hour aver-
aging period, the data to be reported by
the source should identify the emission
level (i.e., emissions stated in pounds per
hour) averaged over a two-hour time
period, for periods only when this emis-
sion level was in excess, of the 1.0 pounds
per hour emission limitation. Further,
sources shall be required to maintain a
record of all continuous monitoring ob-
servations for gaseous pollutants 'and
opacity measurements) for a period of
two years and to make such data avail-
able to the State upon request. The final
regulations have also been amended to
add a provision to require sources to re-
port to the State on the apparent reason
tor all noted violations of applicable reg-
ulations.
The proposed data reporting require-
ments for opacity have also been modi-
led. Upon reconsideration of the extent
of the data needed to satisfy the intent
of these regulations, it is the Adminis-
trator's judgment that for opacity States
must obtain excess emission measure-
ments during each hour of operation.
However, before determining excess
emissions, the number of minutes gen-
erally exempted by State opacity regu-
lations should be considered. For ex-
ample, where a regulation allows two
minutes of opacity measurements in
excess of the standard, the State
need only require the source to re-
port all opacity measurements in excess
of the standard during any one hour,
minus the two-minute exemption. The
excess measurements shall be reported
In actual per cent opacity averaged for
one clock minute or such other time pe-
riod deemed appropriate by the State.
Averages may be calculated either by
arithmetically averaging a minimum of
4 equally spaced data points per minute
or by integration of the monitor output
Some commentors raised questions
concerning the provisions in the proposed
regulations which allow the use of fuel
analysis for computing emissions of sul-
fur dioxide in lieu of Installing a con-
tinuous monitoring device for this pol-
lutant. Of primary concern with the fuel
analysis approach among the com-
mentors -was the frequency of the analy-
sis to determine the sulfur content of the
fuel. However, upon Inspection of the
comments by the Agency, a more sig-
nificant issue has been uncovered. The
issue involves the determination of what
constitutes excess emissions when a fuel
analysis is used as the method to measure
source emissions. For example, the sulfur
content varies significantly within a load
of coal, i.e., while the average sulfur
content of a total load of coal may be
within acceptable limits in relation to a
control regulation which restricts the
sulfur content of coal, it is probable that
portions of the coal may have a sulfur
content above the allowable level. Simi-
larly, when fuel oils of different specific
gravities are stored within a common
tank, such fuel oils tend to stratify and
may not be a homogeneous mixture.
Thus, at times, fuel oil in excess of allow-
able limits may be combusted. The ques-
tion which arises is whether the combus-
tion of this higher sulfur coal or oil is a
violation of an applicable sulfur content
regulation. Initial investigations of this
issue have indicated a relative lack of
specificity on the subject.
The Agency is confronted with this
problem not only in relation to specifying
procedures for the emission reporting re-
quirements for existing sources but also
in relation to enforcement considerations
for new sources affected by New Source
Performance Standards. At this time, a
more thorough investigation of the situ-
ation in necessary prior to promulgation
of procedures dealing with fuel analysis
for both oil and coal. At the conclusion
of this investigation, the Agency will set
forth its findings and provide guidance
to State and local control agencies on
this issue. In the meantime, the portion
of the proposed regulations dealing with
fuel analysis is being withheld from pro-
mulgation at this time. As such, States
shall not be required to adopt provisions
dealing with emission monitoring or re-
porting of sulfur dioxide emissions from
those sources where the SUtes may
choose to allow the option of fuel anal-
ysis as an alternative 'to sulfur dioxide
monitoring. However, since the fuel
analysis alternative may not be utilized
by a source that has installed sulfur di-
oxide control equipment (scrubbers),
States shall set forth legally enforceable
procedures which require emission moni-
tors on such sources, where these emis-
sion monitoring regulations otherwise
require their installation.
Other Modifications to Proposed Reg-
ulations. In addition to reducing the
number of monitors required under the
proposed regulations, a number of modi-
fications to various procedures In the
proposed regulations have been con-
sidered and are included in the final
regulations. One modification which has
been made is the deletion of the require-
ment to install continuous monitors at
"the most representative" location. The
final regulations require the placement
of an'emission monitor at "a representa-
tive" location in the exhaust gas system.
In many cases "the most representative"
location may be difficult to locate and
may be inaccessible without new plat-
forms, ladders, etc., being installed. Fur-
ther, other representative locations can
provide adequate information on pollut-
ant emissions if minimum criteria for
selection of monitoring locations are ob-
served. Guidance in determining a repre-
sentative sampling' location is contained
within the Performance Specification
for each pollutant monitor in the emis-
sion monitoring regulations for New
Source Performance Standards (Appen-
dix B, Part 60 of this Chapter). While
these criteria are designed for new
sources, they are also useful in deter-
mining representative locations for ex-
isting sources.
A further modification to the proposed
regulation is the deletion of the require-
ment for new performance tests when
continuous emission monitoring equip-
ment is modified or repaired. As pro-
posed, the regulation would have re-
quired a new performance test whenever
any part of the continuous emission
monitoring system was replaced. This
requirement was originally incorporated
in the regulations to assure the use of
a well-calibrated, finely tuned monitor.
Commentors pointed out that the re-
quirement of conducting new perform-
ance tests whenever any part of an in-
strument is changed or replaced is costly
and in many cases not required. Upon
evaluation of this comment, the Admin-
istrator concurs that performance tests
are not required after each repair or re-
placement to the system. Appropriate
changes have been made to the regula-
tions to delete the requirements for new
performance tests. However, the final
regulations require the reporting of the
various repairs made to the emission
monitoring system durlne each quarter
to the State. Further, the State must
have nrocedures to require sources to re-
port to the State on a quarterly basis in-
formation on the amount of time and the
reason why the continuous monitor was
not in operation. Also the State must
have legnlly enforceable procedures to
reouire a source to conduct a new per-
formance test whenever, on the basis of
available information, the State deems
su<-h tost is necessary.
Thr time period proposed for the in-
sUIlntion of the reouired monitorine
system, i.e.. one vcar after plan apnroval.
wns thoucht bv 21 commentors to be too
brief, nrimarilv berause of lack of avail-
able instruments, the lack of trained ner-
sormpl and the time available for instal-
lation of the reouired monitor*. Eouip-
mcnt supoliers were contacted by the
Aeencv and thev confirmed the avail-
ability of emission monitors. However.
HOUAl KOISTH, VOl. 40, NO. 1»«—MONDAY, OCTOift 4, 1»TS
11-154
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HULES AND REGULATIONS
the Administrator has determined that
the time necessary for purchase, instal-
lation and performance testinc of such
monitors n;a\ require more than one
year for certain installations, especially
where gaseous monitors arc required. In
order to provide sources with ample time.
the Agency has modified the final regula-
tions to allow States to adopt procedures
that will provide sources 18 months after
the approval or promulgation of the re-
vised SIP to satisfy the installation and
performance testing procedures required
by these continuous monitorinc regula-
tions. A-provision is also included to al-
low, on a case-by-case basis, additional
extensions for source? where pood faith
efforts have been undertaken to purchase
and install equipment, but where such
installation cannot be accomplished
within the time period prescribed by
the regulations.
A number of State and local acencies
also commented on the lack of time pro-
vided sources to install the monitors re-
quired by the proposed regulations.
These acencies also indicated that they
must Acquire sufficient skilled manpower
to implement the regulations, such as
personnel to provide guidance to sources.
to monitor performance tests and to
analyze the emission data that are to be
submitted by the sources. Further, some
State agencies indicated that more than
six months was needed to develop the
necessary plan revisions. Most State
agencies who commented stated that one
year should be provided to allow States
to revise their SIP'S The Administrator
is aware of the various priorities which
confront State and local agencies at this
time 'e.g . compliance schedules, enforce-
ment actions, litigation proceedings, re-
evaluation of adequacy of SIP's to attain
and maintain national standards, etc.'
and, as such, believes that a six-month
postponement in the submittal of plan
revisions to require emission monitoring
and reporting is justified and prudent.
Hence, States must submit plan revisions
to satisfy the requirement? of this sec-
tion within one year of promuleation of
these regulations in the FEDERAL REGIS-
TER. However. States are advised that
such plan revisions may be submitted
any time prior to the final date, and are
encouraged to do so where possible.
The proposed regulations provided the
States with the option of allowing sources
to continue to use emission monitoring
equipment that does not meet perform-
ance specifications set forth in the regu-
lations for up to five years from the date
of approval of the State regulations or
EPA promulgation. Some commenters
asked that this provision be extended
indefinitely. In some cases they indicated
they had recently purchased and had
already installed monitoring systems
which were only marginally away from
meeting the applicable performance spec-
ifications. The Agency believes, how-
ever, that such a modification to the pro-
posed regulations should not be allowed.
It is believed that such a provision would
result in inadequate monitoring systems
being maintained after their useful life
has ended. Though some monitoring sys-
tems will probably last longer than five
years, it is believed that this time period
will provide adequate time to amortize
the cost of such equipment. In ca^es
where existing emission monitors arc
known not to provide reasonable esti-
mates of emissions. States should con-
sider more stringent procedures to pro-
vide a more speedy retirement of such
emission monitoring systems.
Some commentors raised the question
of whether existing oxygen monitors
which are installed in most fossil fuel-
fired steam generating boilers to monitor
excess oxygen for the purposes of com-
bustion control could be used to satisfy
the requirement for monitoring oxygen
under the proposal. Upon investigation,
it has been determined that, in some
cases, such oxygen monitors may be used
provided that they are located so that
there is no influx of dilution air between
the oxygen monitor and the continuous
pollutant monitor. In some cases, it may
be possible to install the continuous
monitoring device at the same location
as the existing oxygen monitor. Care
should be taken, however, to assure that
a representative sample is obtained Be-
cause of the various possibilities that
may arise concerning the usefulness of
existing oxygen monitors, the State
should determine, after a case-by-case
review, the acceptability of existing oxy-
gen monitors.
Another technical issue which was
raised suggested that continuous emis-
sion monitors which provide direct
measurements of pollutants in units com-
parable to the emission limitations and
other devices not i-pecifically identified
in the proposed regulations are avail-
able for purchase and installation. The
Agency is aware that various monitor-
ing systems exist but has not as yet de-
termined specific performance specifica-
tions for these monitoring systems that
are directly applicable to the source
categories covered by these regulations.
However, it is not EPA's intent to deny
the use of any equipment that can be
demonstrated to be reliable and accurate.
If monitors can be demonstrated to pro-
vide the same relative degree of accuracy
and durability as provided by the per-
formance specifications in Appendix B
of Part 60. they shall generally be ac-
ceptable to satisfy the requirements of
these regulations under Section 3.9 of
Appendix P. Further, where alternative
procedures (e.g.. alternate procedures
for conversion of data to units of appli-
cable regulations) can be shown by the
State to be equivalent to the procedures
set forth in Appendix P of these regula-
tions, then such alternate procedures
may be submitted by the State for ap-
proval by EPA. Section 3.9 of Appendix P
identifies certain examples where alter-
native emission monitoring systems or
alternative procedures will generally be
considered by the Agency for approval.
It should be noted that some sources
may be unable to comply with the regu-
lations because of technical difficulties,
(e.g.. the presence of condensed water
vapor in the flue gas), physical limita-
tions of accessibility at the plant facility,
or. in other cases, because of extreme
economic hardship. States should use
their judgment in implementing these
requirements in such cases. Section 6 of
Appendix P of this Part provides various
examples where the installation of con-
tinuous emission monitors would not be
feasible or reasonable. In such cases
alternate emission monitoring (and re-
porting1 by more routine methods, such
as manual stack testing, must be re-
quired. States in preparing their revised
SIP must set forth and describe the cri-
teria they will use to identify such un-
usual cases, and must further describe
the alternative procedures they will im-
plement to otherwise satisfy the intent of
these regulations. States are advised that
this provision is intended for unusual
cases, and. as such, should not be widely
applied.
It was pointed out by some com-
mentors that carbon dioxide monitors
could probably be used in lieu of oxygen
monitors to provide information to con-
vert emission data to the units of the
applicable State regulation Detailed
discussion of the technical merits and
limitations of this approach is discussed
in the Preamble to the Part 60 Regula-
tions. As pointed out. in that Preamble.
such monitors may be used in certain
situations. Modifications have therefore
been made to the Part 51 regulations to
allow the use of such monitors which in-
clude references to technical specifica-
tions contained in Part 60 for carbon di-
oxide monitors. Also, the cycling time for
oxygen monitors has been changed from
one hour to 15 minutes to correspond to
the specification in Part 60. The differ-
ence between cycling times in the two
proposals was an oversight. The cycling
time for carbon dioxide monitors will
also be 15 minutes as in Part 60.
A number of other miscellaneous tech-
nical comments were also received. Corn-
mentors indicated that the proposed ex-
emption for opacity monitoring require-
ments that may be granted to oil-fired
and gas-fired steam generators should
also apply to units burning a combina-
tion of these fuels. The Administrator
concurs with this r.uggestion and an ex-
emption for such sources burning oil and
pas has ben provided in the final regu-
lations subject, to the same restrictions
as are imposed on oil-fired steam
generators.
As previously indicated, the regula-
tions for emission monitoring for exist-
ing sources refer in many cases to the
specific performance specifications set
forth in the emission monitoring regula-
tions for new sources affected by Part 60.
Many of the comments received on the
proposed recxilations in effect pointed to
issues affecting both proposals. In many
cases, more specific technical issues are
discussed in the Preamble to the Part 60
Regulations and as such the reader is
referred to that Preamble. Specifically,
the Part 60 Preamble addresses the fol-
lowing topics: data handling and report-
ing techniques; requirements for report-
ing repairs and replacement parts used;
location of monitoring instruments:
changes to span requirements, operating
KDftAl UGISTH, VOL. 40, NO. 1»« MONDAY, OCTO»» *.
11-155
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RULES AND REGULATIONS
frequency requirements, sulfuric ncid and
nitric arid plant conversion factors;
and, for opacity monitoring equipment.
changes in the cycling time and in alipn-
mcnt procedures. The reader is cau-
tioned, however, that specific reference
to regulations in the Part 60 Preamble
Is strictly to federal New Source Perform-
ance Regulations rather than State and
local control agency regulations which
affect existing sources and which are part
of an applicable plan.
In addition to the many technical
comments received, a numher of legal
issues tt'ere raised Several commentors
questioned EPA's statutory authority to
promulgate these regulations and pointed
out other alleged legal defects in the pro-
posal. The Administrator has considered
these comments, and has found them un-
persuasive.
One commentor argued that new 40
CFR 51.19(e) will require "revisions" to
existing state plans; that-'revisions" may
be called for under Section 110
of the Clean Air Act only where EPA has
found that there are "improved or more
expeditious methods" for achieving am-
bient standards or that a state plan is
"substantially inadequate" to achieve the
standards: that the new regulation Is
based upon neither of these findings; and
that therefore there is no statutory au-
thority for the regulation. This argu-
ment fails to take cognir.ance of Section
110(a) (2) (F) (ii) of the Act. which man-
dates that all state implementation plans
contain self-monitoring requirements.
The fact that EPA originally accepted
plans without these requirements be-
cause of substantial uncertainty as to the
reliability of self-monitoring equipment
does not negate the mandate of the
statute.
In essence, new 5 51.19(e) does not call
for "revisions" as contemplated by the
Act. but for supplements to the original
plans to make them complete. At any
rate, it is the Administrator's Judgment
that the new self-monitoring require-
ments will result in a "more expeditious"
achievement of the ambient standards.
Since these requirements are valuable
enforcement tools and Indicators of mal-
functions, they should lead to a net de-
crease in emissions.
Other commentors argued that even if
EPA has statutory authority to require
self-monitoring. It has no authority to
impose specific minimum requirements
for state plans, to require "continuous"
monitoring, or to require monitoring of
oxygen, which is not a pollutant. These
comments fail to consider that a basic
precept of administrative law is that an
agency may fill in the broad directives of
legislation with precise regulatory re-
quirements. More specifically, the Ad-
ministrator has authority under Section
30Ha) of the Clean Air Act to promul-
gate "such regulations as are necessary
to carry out his functions under the Act".
Courts have long upheld the authority of
agencies to promulgate more specific re-
quirements than are set forth in en-
abling legislation, so long as the require-
ments are reasonably related to the pur-
poses of the legislation. Since the Act
requires self-monitoring without further
guidance. EPA surely has the authority
to set specific requirements in order to
carry out its function of assuring that the
Act is properly implemented.
In EPA's judqnicnt. the requirements
set forth in 5 51.19'e) are necessary to
assure that each state's self-monitoring
program Is sufficient to comply with the
Act's mandate. The fact that oxygen and
carbon dioxide are not air pollutants
controlled under the Act is legally ir-
relevant, since in EPA's judgment, they
must be monitored in order to convert
measured emission data to units of emis-
sion standards
Other commentors have argued that
the self-monitoring requirements violate
the protection against self-incrimination
provided in the Fifth Amendment to the
U.S. Constitution, and that the informa-
tion obtained from the monitoring is so
unreliable as to be Invalid evidence for
use in court.
There are two reasons why the self-
incrimination argument is invalid First.
the self-incrimination privilege does not
apply to corporations, and it is probable
that a great majority of the sources cov-
ered by these requirements will be owned
by corporations. Secondly, courts have
continually recognized an exception to
the privilege for "records required by
law", such as the self-monitoring and
reporting procedures which are required
by the Clean Air Act. As to the validity
of evidence issue, in EPA's opinion, the
required performance specifications will
assure that self-monitoring equipment
will be sufficiently reliable to withstand
attacks in court.
Finally, some comments reflected a
misunderstanding of EPA's suggestion
that states explore with counsel ways to
draft their regulations so as to automati-
cally incorporate by reference future
additions to Appendix P and avoid the
time-consuming plan revision process.
(EPA pointed out that public participa-
tion would still be assured, since EPA's
proposed revisions to Appendix P would
always be subject to public comment on
a nation-wide basis.)
EPA's purpose was merely to suggest
an approach that a state may wish to
follow if the approach would be legal
under that state's law. EPA offers no
opinion as to whether any state law
would allow this. Such a determination
is up to the individual states.
Summary of Revisions and Clarifica-
tions to the Proposed Regulations.
Briefly, the revisions and clarifications to
the proposed regulations include:
(1) A clarification to indicate that con-
tinuous emission monitors are not re-
quired for sources unless such sources
are subject to an applicable emission
limitation of an approved SIP.
(2) A revision to require emission
monitors for oxides of nitrogen in only
those AQCR's where the Administrator
has specifically called for a control
strategy for nitrogen dioxide.
(3) A revision to include a general pro-
vision to exempt any source that clearly
demonstrates that it will cease operation
within fivp years of the inclusion of moni-
toring requirements for the source in
Appendix P.
MI Revisions to exrmpt smaller-sized
sources and infrequently used sources
within the specified source categories
15i A revision to the data reporting
requirements to-require the submittal by
the source of the State, emission data in
excess of the applicable emission limita-
tion for both opacity and gaseous pol-
lutants, rather than all measured data, as
proposed A provision has been added to
require information on the cause of all
noted violations of applicable regulations.
<6> A clarification to indicate that the
continuous monitoring of oxygen is not
required unless the continuous monitor-
ing of sulfur dioxide and/or nitrogen
oxides emissions is required by the appli-
cable SIP.
(7) A revision to allow the placement
of continuous emission monitors at "a
representative location" on the exhaust
gas system rather than at "the most
representative location" as required by
the proposed regulations.
<8> A revision to delete the require-
ments of new performance tests each
time the continuous monitoring equip-
ment is repaired or modified. However, a
new provision is included to require that
a report of all repairs and maintenance
performed during the quarter shall be re-
ported by the source to the State.
(9> A modification to provide sources
18 months rather than one year after
approval or promulgation of the revised
SIP to comply with the continuous moni-
toring regulations adopted by the States.
(10) A modification to provide States
one year, rather than the six months
after the promulgation of these regula-
tions in the FEDERAL REGISTER to submit
plan revisions to satisfy the requirements
promulgated herein.
Requirements of States. States shall be
required to revise their SIP's by Octo-
ber 6, 1976 to include legally enforceable
procedures to require emission monitor-
ing, recording and reporting, as a mini-
mum for those sources specified in the
regulations promulgated herein. While
minimum requirements have been estab-
lished, States may, as they deem appro-
priate, expand these requirements.
The regulations promulgated herein
have been revised in light of the various
comments to generally provide a more
limited introduction into this new meth-
odology. Cooperation among affected
parties, i.e., State and local control agen-
cies, sources, instrument manufacturers
and suppliers, and this Agency is neces-
sary to move successfully forward in
these areas of emission monitoring and
reporting prescribed in the Clean Air
Act. Assistance can be obtained from the
EPA Regional Offices in relation to the
technical and procedural aspects of these
regulations.
Copies of documents referenced'in this
Preamble are available for public inspec-
tion at the EPA Freedom of Information
Center, 401 M Street, S.W., Washington,
D.C. 20460. The Agency has not pre-
pared an environmental impact state-
ment for these regulations since they
KDUAl KGISTEt, VOL 40, MO. 1*4 MONDAY, OCTOtEI t, 1*75
11-156
-------
RULES AND REGULATIONS
were proposed (September 11, 1974 > prior
to the effective date for requirmc volun-
tary environmental Impact statements
on ETA'<; regulatory actions (see 39 FR
16186, May 7, 1974).
The regulations set forth below are
promulgated under the authority of sec-
tions 110 (2> (FMin-Ull) and 301<2HF>. 1857g
<») 1 and are effective November 5, 1975.
Dated: September 23. 1975.
JOHN QUAFITS.
Acting Xdminisirotor.
;. Jenkins. R E . Strategies and Air Stand-
ards Division. OAQPS. EPA. Memo to R L.
AJax. Emission Standards and Engineering
Division. OAQPS. EPA. Emission Monitoring
Costs February 3T, 1975
2. Young. D. E.. Control Programs Develop-
ment Division, OAQPS. EPA Memo to E. J.
Ullls, Control Programs Development Dl-
Ylslon. OAQPS, EPA, Emission Source Data
for In-Slack Monitoring Regulations. June 4,
1975.
1. Section 51.1 is amended by adding
paragraphs (z>, (aa) , (bb) , (cc), (dd).
and (ee) as follows:
§ 51.1 Dcfmilion!i.
(z) "Emission standard" means a reg-
ulation (or portion thereof) setting forth
an allowable rate of emissions, level of
opacity, or prescribing equipment or fuel
specifications that result in control of
air pollution emissions.
"Capacity factor" means the
ratio of the average load on a machine or
equipment for the period of time consid-
ered to the capacity rating of the ma-
chine or equipment.
(bb) "Excess emissions" means emis-
sions of an air pollutant in excess of an
emission standard.
(cc) "Nitric acid plant" means any fa-
cility producing nitric acid 30 to 70 per-
cent in strength by either the pressure or
atmospheric pressure process.
(dd) "Sulfuric acid plant" means any
facility producing sulfurlc acid by the
contact process by burning elemental sul-
fur, alkylation acid, hydrogen sulfide, or
acid sludge, but does not include facili-
ties where conversion to sulfuric acid is
utilized primarily as a means of prevent-
ing emissions to the atmosphere of sul-
fur dioxide or other sulfur compounds.
(ee) "Fossil fuel-fired steam gener-
ator" means a furnace or boiler used in
the process of burning fossil fuel for the
primary purpose of producing steam by
heat transfer.
2. Section 51.19 is amended by adding
paragraph (e) as follows:
I 51.19 Source •urvrillanrr.
(e) Legally enforceable procedures to
require stationary sources subject to
tenlislon standards as part of an appli-
cable plan to install, calibrate, maintain,
and operate equipment for continuously
toonltoring and recording emissions; and
to provide other information as specified
to Appendix P of this part.
(1) Such procedures shall identify the
types of sources, by source category and
capacity, that must install such instru-
ments, and shall identify for each source
category the pollutants which must be
monitored.
(2) Such procedures shall, as a mini-
mum, require the types of sources set
forth in Appendix P of this part (as such
appendix may be amended from time to
time) to meet the applicable require-
ments set forth therein.
(3) Such procedures shall contain pro-
visions which require the owner or op-
erator of each source subject to continu-
ous emission monitoring and recording
requirements to maintain a file of all
pertinent information. Such information
shall include emission measurements.
continuous monitoring system perform-
ance testing measurements, performance
evaluations, calibration checks, and ad-
justments and maintenance performed
on such monitoring systems and other re-
ports and records required by Appendix
P of this Part for at least two years fol-
lowing the date of such measurements or
maintenance.
(4) Such procedures shall require the
source owner or operator to submit in-
formation relating to emissions and
operation of the emission monitors to the
State to the extent described in Appendix
P as frequently or more frequently as
described therein.
(5> Such procedures shall provide that
sources subject to the requirements of
5 51.19(e) (2> of this section shall have
installed all necessary equipment and
shall have begun monitoring and record-
ing within 18 months of <1> the approval
of a State plan requiring monitoring for
that source or (2) promulgation by the
Agency of monitoring requirements for
that source. However, sources that have
ma'le good faith efforts to purchase, in-
stall, and begin the monitoring and re-
cording of emission data but who have
been unable to complete such Installa-
tion within the time period provided may
be given reasonable extensions of time as
deemed appropriate by the State.
(6 > States shall submit revisions to the
applicable plan which implement the
provisions of this section by October 6,
1976.
3. In Part 51, Appendix P is added as
follows:
APPENDIX P—MINIMUM EMISSION MONITORING
RtQtnUEMENTS
1.0 Purpose. This Appendix P sets forth
the minimum requirements for continuous
emission monitoring and recording that each
State Implementation Plan must Include In
order to be .\pproved under the provisions of
40 CFR 51 10(e) These requirements Include
the source categories to be affected; emission
monitoring, recording, and reporting re-
quirements lor these sources; performance
specifications for accuracy, reliability, and
durability of acceptable monitoring systems;
and techniques to convert emission data to
units of the applicable Stntc emission stand-
ard Such data must be reported to the State
as an Indication of whether proper mainte-
nance and operating procedures arc betYig
utilized by nourci- operators to maintain
emission levels at or below emission stand-
ards. Such data may be used directly or In-
directly for compliance determination or any
other purpose deemed appropriate by the
Stale Though the monitoring requirements
are specified In detail. States are given some
flexibility to resolve difficulties that may
arise during the Implementation of these
regulations.
1.1 Applicability.
The State plan ihull require the owner or
operator of MI emf*slon source In a category
listed In this Appendix to: (1) Install, cali-
brate, operate, and maintain all monitoring
equipment necessary for continuously moni-
toring the pollutants specified In this Ap-
pendix for the applicable source category;
and (2) complete the Installation and per-
formance tests of such equipment and begin
monitoring and recording within 18 months
of plan approval or promulgation. The source
categories and the respective monitoring re-
quirements are listed below.
1.1.1 Fossil fuel-fired steam generators, as
specified In paragraph 2.1 of this appendix.
shall be monitored for opacity, nitrogen
oxides emissions, sulfur dioxide emissions.
and oxygen or carbon dioxide.
1.1.2 Fluid bed catalytic cracking unit
catalyst regenerators, as specified In para-
graph 2.4 of this appendix, ahall be moni-
tored for opacity.
1.1.3 Sulfuric acid plants, as specified In
paragraph 2.3 of this appendix, shall be
monitored for sulfur dioxide emissions.
1.1.4 Nitric acid plants, as specified in
paragraph 2.2 of this appendix, shall be
monitored for nitrogen oxides emissions.
1.2 Exemptions
The States may Include provisions within
their regulations to grant exemptions from
the monitoring requirements of paragraph
1.1 of this appendix for any source which Is:
1.2.1 subject to a new source performance
standard promulgated In 40 CFR. Part 60
pursuant to Section 111 of the Clean Air
Act: or
1.2 2 not subject to an applicable emission
standard of an approved plan; or
1.23 scheduled for retirement within 5
years after Inclusion of monitoring require-
ments Tor the source In Appendix P. provided
that adequate evidence and guarantees are
provided that clearly show that the source
will cease operations prior to such date.
1.3 Extensions.
States may allow reasonable extensions of
the time provided for Installation of monitors
for facilities unable to meet the prescribed
tlmeframe (I.e.. 18 months from plan ap-
proval or promulgation) provided the owner
or operator of such facility demonstrates that
good faith efforts have been made to obtain
and Install such devices within such pre-
acrlberi tlmeframe.
1.4 Monitoring System Malfunction.
The Stale plan may provide a temporary
exemption from th* monitoring and report-
Ing requirements of this appendix during any
period of monitoring system malfunction.
provided that the source owner or operator
shows, to the satisfaction of the St»te. that
the malfunction was unavoidable and It
being repaired as e.ipedltlously as practicable.
20 .Minimum Monitoring Requirement.
States must. MS a minimum, require the
sources listed In paragraph 1.1 of this appen-
dix to meet the following basic requirements
2.1 Fositl furl-fired iteam generators.
Each fossil fuel-fired »tei\m generator, ex-
cepl as provided In the following lubpara-
graphs, with mi unrrunj average capacity fac-
tor of greater than 30 percent, as reported to
the Federal Power Commission for calendar
year 1D74. or iva otherwise demonstrated to
the SIMe by the owner or operator, shall con-
form with the following monitoring require-
ments when such facility is subject to an
emission standard of an applicable plan lor
the pollutant in question.
KMIAl UOISTEt, VOL 40, NO. 194 MONDAY, OCTOtH «, 1»7i
11-157
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RULES AND REGULATIONS
3.1.1 A continuous monitoring system for
the measurement of op»clty which meets the
performance specifications of paragraph
3 I 1 of this appendix shall be Installed, cali-
brated, maintained, and operated In accord-
ance with the procedures of this appendix bj
the owner or operator of any tuch itenin
generator of greater than 2So' million BTU
per hour heat input except where:
2.1.1.1 (aaeous fuel I* the only fuel burned.
or
3.1.If oil or a mixture of gas and oil are
the only fuels burned and the source Is able
to comply with the applicable participate
matter and opacity regulations without utili-
zation .of paniculate matter collection
•qulpme'nt. and where the source ha* never
been found, through any administrative or
Judicial proceedings, to be In violation of any
Ttslble emission standard of'the applicable
plan.
2.1.2 A continuous monitoring system for
the measurement of sulfur dioxide which
meets the performance specifications of para-
graph 3.1 3 of this appendix shall be Installed,
calibrated, maintained, and operated on any
fossil fuel-fired steam generator of greater
th&n 250 million BTU per hour heat Input
which has Installed sulfur dioxide pollutant
control equipment.
2.1.3_ A continuous monitoring system for
the measurement of nitrogen oxides which
meets the performance specification of para-
graph 3.1.2 of this appendix shall be Installed.
calibrated, maintained, and operated on fos-
•II fuel-fired steam generators of greater
than 1000 million BTU per hour heat Input
when such facility Is located In an Air Qual-
ity Control Region where the Administrator
has specifically determined that a control
strategy for nitrogen dioxide Is necessary to
attain the national standards, unless the
•ource owner or operator demonstrates dur-
ing source compliance tests as required by
the State that such a source emits nitrogen
oxides at levels 30 percent or more below the
emission standard within the applicable
plan.
2.1 4 A continuous monitoring system for
the measurement of the percent oxygen or
carbon dioxide which meets the perform-
ance specifications of paragraphs 3.1.4 or
3.1 5 il this appendix shall be installed, cali-
brated, operated, and maintained on fossil
fuel-fired steam generators where measure-
ments of oxygen or carbon dioxide In the flue
gis are required to convert either sulfur di-
oxide or nitrogen oxides continuous emis-
sion monitoring data, or both, to units of
the emission standard within the applica-
ble plan.
2.2 Nitric afiti plants.
Each nitric acid plant of greater than 300
tons per day production capacity, the pro-
duction capacity being expressed as 100 per-
cent acid, located In an Air Quality Control
Region where the Administrator ha.s specif-
ically determined that a control strategy for
nitrogen dioxide Is necessary to attain the
national standard shall Install," calibrate.
maintain, and operate a continuous moni-
toring system for the measurement of nitro-
gen oxides which meets the performance
*peciflc»tlons of paragraph 3.1.2 for each
nitric acid producing facility within such
plant.
3.3 Siil/vrif and plants
Each Sulfurtc acid plant of greater than
SOO tons per day production capacity, the
production being expressed as 100 percent
•cid, shall Install, calibrate, maintain and
operate a continuous monitoring system for
the measurement of sulfur dioxide which
meets the performance specifications of 3 1.3
for each sulfurlc acid producing facility
within such plant.
24 Fluid bed catalytic cracking i/nf( cata-
lyst regenerators at petroleum refineries.
Each catalyst regenerator for fluid bed
catalytic cracking units of greater than 20.-
000 barrels per day fresh fe«d capacity shall
Install, calibrate, maintain, and operate a
continuous monli/orlng system for the meas-
urement of opacity which meets the per-
formance specifications of 3 1.1.
30 Minimum specifications.
All State plane shall require owners or op-
erators of monitoring equipment installed
to comply with this Appendix, except as pro-
vided In paragraph 3.2. to demonstrate com-
pliance with the following performance spec-
ifications
3 I Prr/ormancr specifications.
The performance specifications set forth
In Appendix B of Part 60 are Incorporated
herein by reference, and shall be used by
States to determine acceptability of monitor-
Ing equipment Installed pursuant to this
Appendix except that (1) where reference Is
made to the "Administrator" in Appendix B.
Part 60, the term "State" should be inserted
for the purpose of this Appendix (eg, In
Performance Specification 1. 1.2. " . . moni-
toring systems subject to approval by the
Administrator," should be Interpreted as,
". . . monitoring systems subject to approval
by the State"), and (2) where reference Is
made to the "Reference Method" In Appendix
B. Part 60. the State- may allow the use of
either the State approved reference method
or the Federally approved reference method
as published In Part 60 of this Chapter The
Performance Specifications to be used with
each type of monitoring system are listed
below.
3.1.1 Continuous monitoring systems for
measuring opacity shall comply with Per-
formance Specification 1.
31.2 Continuous monitoring systems for
measuring nitrogen oxides shall comply with
Performance Specification 2.
3.1.3 Continuous monitoring systems for
measuring sulfur dioxide shall comply with
Performance Specification 2.
3.1 4 Continuous monitoring systems for
measuring oxygen shall comply with Per-
fonnnnce Specification 3
3.1.5 Continuous monitoring systems for
measuring carbon dioxide shall comply with
Performance Specification 3.
3.2 Exemptions
Any source which has purchased an emis-
sion monitoring system(s) prior to Septem-
ber 11, 1974. mivy be exempt from meeting
such test procedures prescribed In Appendix
B of Part 60 for a period not to exceed five
years from plan approval or promulgation.
3.3 Calibration Gases.
for nitrogen oxides monitoring systems in-
stalled on fossil fuel-fired steam generators
the pollutant gas used to prepare calibration
gas mixtures (Section 2.1, Performance Spec-
ification 2, Appendix B, Part 60) shall be
nitric oxide (NO). For nitrogen oxides mon-
itoring systems. Installed on nitric acid plants
the pollutant gas used to prepare calibration
gas mixtures (Section 2 1, Performance Spec-
ification 2, Appendix B. Part 60 of this Chap-
ter) shall be nitrogen dloxld- (NO.). These
gases shall also be used for daily checks under
paragraph 3.7 of this appendix as applicable.
For sulfur dioxide monitoring systems in-
stalled on fossil fuel-fired st«axn generators
or sulfurlc acid plants the pollutant pas used
to prepare calibration gas mixtures (Section
2.1. Performance Specification 2. Appendix B.
Part 60 of this Chapter) shall be sulfur di-
oxide (SO.) Span and zero gases should be
trtceible to NAtlnn.il Bureau o( Standards
reference gases whenever these reference
gases are available. Every six months from
date of manufacture, span and z«ro gases
shall b« reanalyzed by conducting triplicate
analyses using the reference methods In Ap-
pendix A. Part 80 of this chapter as follows:
for sulfur dioxide, use Reference Method 6;
for nitrogen oxides, uss Reference Method 7;
and for carbon dioxide or oxygen. u»e Ref-
erence Method 3 The gases may b; analyzed
at less frequent Intervals if longer shelf lives
are guaranteed by the manufacturer
3 4 Cycling times
Cycling times Include the total time a
monitoring »ysl*m requires to sample.
analyze and record an emisMon measurement
3.4.1 Continuous monitoring systems for
measuring opacity shall complete a mini-
mum of one cycle of operation (sampling.
analyzing, and data recording) for each suc-
cessive 10-second period
3.4 2 Continuous monitoring systems for
measuring oxides of nitrogen, carbon diox-
ide, oxygen, or sulfur dioxide shall complete
a minimum of one cycle of operation (sam-
pling, analyzing, and data recording) for
each successive 15-mlnute period.
3.5 Monitor location.
State plans shall require all continuous
monitoring systems or monitoring devices to
be Installed such that representative meas-
urements of emissions or process parameters
(I e., oxygen, or carbon dioxide) Irom the af-
fected facility are obtained. Additional guid-
ance for location of continuous monitoring
systems to obtain representative samples are
contained In the applicable Performance
Specifications of Appendix B of Part 6O of
this Chapter.
3.6 Combined effluents
When the effluents from two or more af-
fected facilities of similar design and operat-
ing characteristics are combined before being
released to the atmosphere, the State plan
may allow monitoring systems to be installed
on the combined effluent. When the affected
facilities are not of similar design and operat-
ing characteristics, or when the effluent from
one affected facility Is released to the atmos-
phere through more than one point, the State
should establish alternate procedures to Im-
plement the Intent of these requirements.
3 7 Zero and drift.
State plans shall require owners or opera-
tors of all continuous monitoring systems
Installed In accordance with the require-
ments of this Appendix to record the 7*ro and
span drift In accordance with the method
prescribed by the manufacturer of such In-
struments: to subject the Instruments to the
manufacturer's recommended zero and span
check at least once dally unless the manu-
facturer has recommended adjustments at
shorter Intervals. In which case such recom-
mendations shall be followed: to adjust the
zero and span whenever the 24-hour zero
drift or 24-hour calibration drift limits of
the applicable performance specifications in
Appendix B of Part 60 are exceeded, and to
adjust continuous monitoring svstems refer-
enced by paragraph 3.2 of this Appendix
whenever the 24-hour zero drift or 24-hour
calibration drift exceed 10 percent of the
emission standard.
3.8 Spin.
Instrument span should be approximately
200 per cent of the expected Instrument data
dlsplnv output corresponding to the emission
standard for the source
39 Alternative procedures and require-
ments.
In cases where States wish to utilize differ-
ent, but equivalent, procedures and require-
ments for continuous monitoring systems.
the State plan must provide a description of
such alternative proreduers for approval by
the Administrator Some examples of "Situa-
tions that may require alternatives follow:
3.9 1 Alternative monitoring requirements
to accommodate continuous monitoring sys-
tems that require corrections for stack mois-
ture conditions leg., an Instrument measur-
ing si earn generator SO emissions on a wet
basis could be used with an Instrument mea-
suring oxvgen concentration on a dry basis
if acceptable methods of measuring stick
moisture conditions are used to allow »c-
M«IJT«, VOl. 40, NO 194 MONDAY, OCTO4EI *,
11-158
-------
RULES AND REGULATIONS
curate adjustment of the measured SO. con-
centration to dry basis )
39.2 Alternative locations lor Instilling
con'.ir-T'JS monl'or-.p.g systems or monitor-
Jng devices »hen the owner or operator can
demonstrate that Installation at alternative
location' will enable accurate and represent-
ative measurements.
39.3 Alternative procedures for perform-
ing calibration checks te.g . »ome instruments
may demonstrate superior drift characteris-
tics that require checking at less frequent
intervals")
3.94 Alternative monitoring requirement.';
when the effluent from one affected facility or
the combined effluent from two or more
Idcntic-aT affected facilities is released to the
atmosphere through more than one point
(e.g. an extractive, gaseous monitoring sys-
tem used at several points may be approved
If the procedure? recommended are suitable
for generating accurate emission averages)
39.S Alternative continuous monitoring
systems that do not meet the spectral re-
sponse requirements In Performance Speci-
fication 1. Appendix B of Part 60. but ade-
quately demonstrate a definite and consistent
relationship between their measurements
»nd the opacity measurements of a system
complvlng with the requirements In Per-
formance Specification 1 The State may re-
quire trial such demonstration be performed
for each aflected facility
4.0 Minirmnn data requirements
The folio-wing paragraphs set forth the
minimum data reporting requirements neces-
«ary to comply with J 51 19(e) (3) and (4).
4 1 The State plan shall require owners
or operators of facilities required to Install
continuous monitoring systems to submit a
written report of excess emissions for each
calendar quarter and the nature and cause of
the excess emissions. If known. The averaging
period used for data reporting should be
established by the State to correspond to the
averaging period specified In the emission
test method used to determine compliance
with an emission standard for the pollutant1
source category In question. The required re-
port shall Include, as a minimum, the data
ttlpulaled In this Appendix.
4.2 For opacity measurements, the sum-
mary shall consist of the magnitude In actual
percent opacity of all one-minute (or such
other time period deemed appropriate by the
State) averages of opacity greater than the
opacity standard in the applicable plan for
each hour of operation of the facility. Aver-
age values may be obtained by Integration
over the averaging period or by arithmeti-
cally averaging a minimum of four equally
"paced Instantaneous opacity measurements
per minute Any time period exempted shall
be considered before determining the excess
averages of opacity (e.g.. whenever a regu-
lation allows two minutes of opacity meas-
urements In excess of the standard, the State
•hall require the source to report all opacity
averages, in any one hour. In excess of the
•Undard. minus the two-mlnut« exemp-
tion) If more than one opacity standard
applies, excess emissions data must be »ub-
mltted In relation to all such standards
4.3 Tor gaseous measurements the sum-
mary shall consist of emission averages, In
the units of the applicable standard, for each
averaging period during which the appli-
cable standard was exceeded.
4.4 The' date and time Identifying each
period during which the continuous moni-
toring system was, inoperative, except for
zero and span checks, and the nature of
system repairs or adjustments ahall be re-
ported. The State may require proof of con-
tinuous monitoring system performance
whenever tyiUm repairs or adjustment* have
been made.
4 5 When no excess emissions have oc-
curred and the continuous monitoring sys-
temis) have not been Inoperative, repaired.'
or adjusted, such Information shall be In-
cluded In the report.
4 6 The State plan shall require owners or
operators of affected facilities to maintain
a Me of all Information reported In the quar-
terly summaries, and all other data collected
either by the continuous monitoring system
or as necessary to convert monitoring datn
to the units of the applicable standard for
a minimum of two years from the date of
collection of tuch data or submission of
•uch summaries
5.0 Data Reduction
The State plnn shall require owners or
operators of affected facilities to use the
following procedures for converting moni-
toring data to units of the standard where
necessary-
5.1 For fossil fuel-fired steam generators
the following procedures shall be used to
convert ga.seous emission monitoring datn In
parts per million to g'mllllon cal llb'mllllon
BTU) where necessary:
5.1.1 When the owner or operator of a
fossil fuel-fired steam generator elects under
subparagraph 2 1 4 of this Appendix to meas-
ure oxygen In the flue gases, the measure-
ments of the pollutant concentration and
oxygen concentration shall erven be on a dry
basis and the following conversion procedure
used:
5.1.2 When the owner or operator elects
under subparagraph 2.1 4 of this Appendix
to measure carbon dioxide In the flue cases.
the measurement of the pollutant concen-
tration and the carbon dioxide concentration
shall each be on a consistent basis (wet or
dry) and the following conversion procedure
used:
5.1.3 The values used In the equations un-
der paragraph 5 1 are derived as follows
E=r pollutant emission, g/mllllon
cal (lb/milllon BTU).
C = pollutant concentration. g'
dscm (Ibi'dscf), determined by
multiplying the average concen-
tration (ppm) for each hourly
period by 4 16V10-" M g'dscm
per ppm (264^ 10-" M Ib/dscf
per ppm) where M = pollutant
molecular weight, g, g-mole (lb/
Ib-mole) M = 64 for sulfur di-
oxide and 46 for oxides of nitro-
gen
'/rO.. r*CO. = Oxygen or carbon dioxide vol-
ume (expressed as percent) de-
termined with equipment spec-
ified under paragraph 4 1.4 of
this appendix.
F, F. = a factor representing a ratio of
the volume of dry flue gases
generated to the calorific value
of the fuel combusted (F). and
a factor representing a ratio of
the volume of carbon dioxide
generated to the calorific value
of the fuel combusted (F.) re-
spectively. Values of F and F.
are given In i6045(f) of Part
00. as applicable.
5.2 For sulfurlc acid plants the owner or
operator shall:
52 1 establish a conversion factor three
times dally according to the procedures to
• 60 84(b) of this chapter:
5.2.2 multiply the conversion factor by the
average lulfur dioxide concentration In the
flue gases to obtain average sulfur dioxide
emissions in Kg/metric ton (Ib/short ton):
and
5.2.3 report the average sulfur dioxide
emission for each averaging period In excess
of the applicable emission standard In the
quarterly nummary.
53 For nitric acid plants the owner or
operator shall:
531 establish a conversion factor accord-
Ing to the procedures of I60.73(b) of this
chapter.
5 3.2 multiply the conversion factor by the
average nitrogen oxides concentration In the
flue gases to obtain the nitrogen oxides emis-
sions in the units of the applicable standard,
53.3 report the average nitrogen oxides
emission for each averaging period In excess
of the applicable emission standard. In the
quarterly summary.
5.4 Any State may allow data reporting
or reduction procedures varying from those
set forth In this Appendix If the owner or
operator of a source shows to the satisfaction
of the State that his procedures are at least
as accurate as those In this Appendix Such
procedures may Include but are not limited
to. the following
5.4.1 Alternative procedures for computing
emission averages that do not require Inte-
gration of data (e.g.. some facilities may dem-
onstrate that the variability of their emis-
sions Is sufficiently small to allow accurate re-
duction of data based upon computing aver-
ages from equally spaced data points over the
averaging period).
5 4.2 Alternative methods of converting pol-'-
lutant concentration measurements to the
units of the emission standards.
6 0 Special Consideration
The State plan may provide for approval, on
a case-by-case basis, of alternative monitor-
Ing requirements different from the provi-
sions of Parts 1 through 5 of this Appendix If
the provisions of this Appendix (I.e. the In-
stallation of a contlmious emission monitor-
Ing system) cannot b« Implemented by a
source due to physical plant limitations or
extreme economic reasons To make use of
this provision. States must Include In their
plan specific criteria for determining those
physical limitations or extreme economic.
situations to be considered by the State. Jn
such, cases, when the State exempts any
source subject to this Appendix by use of this
provision from Installing continuous emis-
sion monitoring systems, the State shall set
forth alternative emission monitoring and
reporting requirements (e.g.. periodic manual
stack tests) to satisfy the Intent of these
regulations. Examples of such special cases
Include, but are not limited to, Uie following:
6.1 Alternative monitoring requirements
may be prescribed when Installation of a con-
tinuous monitoring system or monitoring de-
vice specified by this Appendix would not pro-
vide accurate determinations of emissions
(e.g., condensed, uncomblned water vapor
may prevent an accurate determination of
opacity using commercially available con-
tinuous monitoring systems).
6.2 Alternative monitoring requirements
may be prescribed when the affected facility
Is Infrequently operated (e.g.. some affected
facilities may operate less than one month
per year).
6.3 Alternative monitoring requirements
may be prescribed when the State determines
that the requirements of this Appendix would
Impose an extreme economic burden on the
aource owner or operator.
6.4 Alternative monitoring requirements
mnv be prescribed when the State determines
that monitoring systems prescribed by this
Appendix cannot be Installed due to physical
limitations at the facility.
|FR Doc.75-26566 Filed 10-3-75:8:45 ami
KDUAl ItCISTE*. VOL. 40, NO 1*4—MONDAY. OCTOtH t. 1*75
11-159
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SUMMARY OF TABLES OF MONITORING REGULATIONS
11-160
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TABLE #1
NSPS SOURCE CATEGORIES WHICH ARE
REQUIRED TO MONITOR CONTINUOUSLY
Subpart
D
Da
Source Category
STEAM GENERATORS
Solid Fossil Fuel
Liquid Fossil Fuel
Gaseous Fossil Fuel
ELECTRIC UTILITY STEAM
GENERATING UNITS
Solid Fossil Fuel
Liquid Fossil Fuel
Pollutant
Opacity
S02
NOX
Opacity
S02
NO
Process
02 or C02
02 or C02
02 or C02
Opacity 02 or C02
S02 (at inlet and
outlet of control
device)
NOX
Opacity 02 or C02
S02 (at inlet and
outlet of control
device)
G
H
J
Gaseous Fossil Fuel
NITRIC ACID PLANTS
SULFURIC ACID PLANTS
PETROLEUM REFINERIES
FCCU
Combustion of Fuel
Gases
NOX 02 or C02
S02
Opacity
CO
S02 or
H2S
11-161
-------
Table #1, continued
Subpart
J
(cont'd)
R
TUVWX
AA
Source Category Pollutant
PETROLEUM REFINERIES (cont'd)
Sulfur Recovery Plant S02a, H2Sb, TRSb
IRON AND STEEL PLANTS
Process
PRIMARY COPPER SMELTERS
PRIMARY ZINC SMELTERS
PRIMARY LEAD SMELTERS
PHOSPHATE FERTILIZER PLANTS
COAL PREPARATION PLANTS
FERROALLOY PRODUCTION
FACILITIES
STEEL PLANTS:
ELECTRIC ANC FURNACES
Opacity
S02
Opacity
SO 2
Opacity
S02
Opacity
Opacity
Pressure loss
through venturi
scrubber water
supply pressure
Total pressure
drop across pro-
cess scrubbing
systems
Exit gas temp.
pressure loss
through venturi
water supply
pressure to con-
trol equipment
Flowrate through
hood
Furnace power
input
Volumetric flow
rate through each
separately ducted
hood. Pressure
in the free space
inside the elect-
ric arc furnace.
a For oxidation control systems.
b For reduction control systems not followed by incineration.
11-162
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Table #1, continued
Subpart
BB
HH
Source Category Pollutant
KRAFT PULP MILLS
Recovery Furnace
Process
Opacity
TRS (dry basis)
Lime kiln, digester
system, brown stock washer
system, multiple effect evapo-
rator system, black liquor oxi-
dation system, or condensate
stripper system
Point of incineration of
effluent gases, brown stock
washer system, multiple effect
evaporator system, black liquor
oxidation system, or condensate
stripper system
Lime kiln or smelt dissolving
tank using a scrubber
TRS (dry basis)
LIME MANUFACTURING PLANTS
Rotary Lime Kilns
Opacity'
(dry basis)
(dry basis)
Temperature
Pressure loss of
the gas stream
through the con-
trol equipment
Scrubbing liquid
supply pressure
Pressure loss
of steam through
the scrubber
Scrubber liquid
supply pressure
a Does not apply when there is a wet scrubbing emission control device.
11-163
-------
Table #1, continued
Subpart Source Category Pollutant process
HH LIME MANUFACTURING PLANTS
(cont'd)
Lime Hydrator Scrubbing liquid
flow rate
Measurement of
the electric
current (amperes)
used by the
scrubber
11-164
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Subpart
TABLE #2
OPERATIONAL MONITORING REQUIREMENTS (NSPS)
(Non-Continuous)
Requirement
rE. Incinerators
"p. Portland Cement
Plants
G. Nitric Acid Plants
H. Sulfuric Acid Plants
Petroleum Refineries
K.
Storage Vessels for
Petroleum Liquids
0.
P.
S.
Sewage Treatment
Plants
Primary Copper
Smelter
Primary Aluminum
Reduction Plants
Daily charging rates and hours of operation.
Daily procuction rates and kiln feed rates.
Daily production rate and hours of operation.
The conversion factor shall be determined, as a
minimum, three times daily by measuring the con-
centration of sulfur dixoide entering the con-
verter.
Record daily the average coke burn-off rate and
hours of operation for any fluid catalytic
cracking unit catalyst regenerator subject to the
particulate or carbon monoxide standard.
Maintain a file of each type of petroleum liquid
stored and the dates of storage. Show when
storage vessel is empty. Determine and record
the average monthly storage temperature and true
vapor pressure of the petroleum liquid stored if:
(1) the petroleum liquid, as stored, has a vapor
pressure greater than 26 mm Hg but less than
78 mm and is stored in a storage vessol other
than one equipped with a floating roof, a vapor
recovery system or their equivalents; or (2) the
petroleum liquid has a true vapor pressure, as
stored, greater than 470 mm Hg and is stored in a
storage vessel other than one equipped with a
vapor recovery system or its equivalent.
Install, calibrate, maintain, and operate a flow
measuring device which can be used to determine
either the mass or volume of sludge charged to
the incinerator.
Keep a monthly record of the total smelter charge
and the weight percent (dry basis) of arsenic,
antimony, lead, and zinc contained in this
charge.
Determine daily, the weight of aluminum and anode
produced. Maintain a record of daily production
rates of aluminum and anodes, raw material feed
rates, and cell or potline voltages.
11-165
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Subpart
TABLE #2 (cont'd)
OPERATIONAL MONITORING REQUIREMENTS (NSPS)
(Non-Continuous)
Requirement
-T. Phosphate Fertilizer
Industry: Wet-
Process Phosphoric
Acid Plants
U. Phosphate Fertilizer
Industry: Super-
phosphoric Acid
Plants
V. Phosphate Fertilizer
Industry: Diammon-
ium Phosphate Plants
W. Phosphate Fertilizer
Industry: Triple
Superphosphate
Plants
X. Phosphate Fertilizer
Industry: Granular
Triple Superphos-
phate Storage
Facilities
Z.
Ferroalloy Production
Facilities
AA.
Steel Plants:
Electric" Arc
Furnaces
Determine the mass flow of phosphorus-bearing
feed material to the process. Maintain a daily
record of equivalent P205 feed.
Determine the mass flow of phosphorus-bearing
feed material to the process. Record daily the
equivalent P2C>5 feed.
Determine the mass flow of phosphorus-bearing
feed material to the process. Maintain a daily
record of equivalent P2^5 feed.
Determine the mass flow of phosphorus-bearing
feed material to the process. Maintain a daily
record of equivalent ^2^5 feed..
Maintain an accurate account of triple super-
phosphate in storage. Maintain a daily record
of total equivalent ?2®5 stored.
Maintain daily records of (1) the product;
(2) description of constitutents of furnace
charge, including the quantity, by weight;
(3) the time and duration of each tapping period
and the identification of material tapped (slag
or product); (4) all furnace power input data;
and (5) all flow rate data or all fan motor power
consumption and pressure drop data.
Maintain daily records of (1) the time and
duration of each charge; (2) the time and
duration of each tap; (3) all flow rate data;
and (4) all pressure data.
11-166
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TABLE #3
EMISSION LIMITATIONS (NSPS)
SUBPART
D Fossil Fuel-Fired
Steam Generators
Liquid fossil fuel
Solid fossile fuel
Gaseous fossil fuel
Mixture of fossil
fuel
POLLUTANT
Particulate
Opacity
S02
NOX
Particulate
Opacity
S02
NOX
Particulate
Opacity
NOX
Particulate
Opacity
S02
EMISSION LEVELS
43 ng/joule
(0.10 lb/106 Btu)
20% except 27% for 6 min/hr
340 ng/joule
(0.80 lb/106 Btu)
130 ng/joule
(0.30 lb/106 Btu)
43 ng/joule
(0.10 lb/106 Btu)
20% except 27% for 6 min/hr
520 ng/joule
(1.2 lb/106 Btu)
300 ng/joule
(0.70 lb/106 Btu)
43 ng/joule
(0.10 lb/106 Btu)
20% except 27% for 6 min/hr
86 ng/joule
(0.20 lb/106 Btu)
43 ng/joule
(0.10 lb/106 Btu)
20% except 27% for 6 min/hr
y(340) + z(520) *
y + z
x(86) + y(130)
z(300)
y + z
* x = percentage of total heat input from gaseous fossil fuel
y = percentage of total heat input from liquid fossil fuel
z = percentage of total heat input from solid fossil fuel
11-167
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TABLE #3 (cont'd)
EMISSION LIMITATIONS (NSPS)
SUBPART
G Nitric Acid Plants
H Sulfuric Acid Plants
J Petroleum Refineries
Fluid catalytic
cracking unit
Glaus sulfur recovery
plant
N Iron and Steel Plants
(BOPF)
POLLUTANT
NO 2
Opacity
SO 2
H2S04 mist
Particulate
Opacity
CO
SO 2
TRS
H2S
Particulate
Opacity
P Primary Copper Smelters
Dryer . Particulate
EMISSION LEVELS
1.5 kg/metric tons of acid
produced (4.0 Ib/ton of
acid produced)
10%
2 kg/metric tons of acid
produced (4.0 Ib/ton of
acid produced)
0.075 kg/metric tons of
acid produced (0.15 Ib/ton)
1.0 kg/1000 of coke burn-
off
30%
0.050%
0.025%
0.030%
0.0010%
50 mg/dscm
10%
>10% but <20% may occur
once per steel production
cycle
50 mg/dscm (0.022 gr/dscf)
11-168
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TABLE #3 (cont'd)
EMISSION LIMITATIONS (NSPS)
SUBPART
Roaster, smelting
furnace, copper
converter
Q Primary Zinc Smelters
Sintering machine
Roaster
R Primary Lead Smelters
POLLUTANT
Opacity
SO 2
Particulate
Opacity
SO 2
Opacity
Blast or reverberatory Particulate
furnace, sintering
machine discharge end
Sintering machine,
electric smelting
furnace, converter
T Phosphate Fertilizer
Industry: Wet Process
Phospheric Acid Plants
U Phosphate Fertilizer
Industry: Super-Phos-
phoric Acid Plants
V Phosphate Fertilizer
Industry: Diammonium
Phosphate
W Phosphate Fertilizer
Industry: Triple Super-
Phosphate
Opacity
S02
Opacity
Total Fluorides
Total Fluorides
Total Fluorides
Total Fluorides
EMISSION LEVELS
20%
0.065%
50.mg/dscm (0.022 gr/dscf)
20%
0.065%
20%
50 mg/dscm (0.022 gr/dscf)
20%
0.065%
20%
10 g/metric ton of
(0.020 Ib/ton)
5 g/metric ton of
(0.020 Ib/ton)
30 g/metric ton of
(0.060 Ib/ton)
feed
feed
feed
100 g/metric ton of equival-
ent ?205 feed (0.20 Ib/ton)
11-169
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TABLE #3 (cont'd)
EMISSION LIMITATIONS (NSPS)
SUBPART
X Phosphate Fertilizer
Industry: Granular
Triple Superphosphate
POLLUTANT
Total Fluorides
EMISSION LEVELS
0.25 g/hr/metric ton of
equivalent ^2^5 stored
(5.0 x 10~4 Ib/hr/ton)
Y Coal Preparation Plants
Thermal Dryer
Pneumatic coal
cleaning equipment
Processing and
conveying equipment,
storage systems, trans-
fer and loading systems
Z Ferroalloy Production
Facilities
Electric submerged
Particulate
Opacity
Particulate
Opacity
Opacity
Particulate
Dust handling
equipment
Opacity
CO
Opacity
0.070 g/dscm (0.031 gr/dscf)
20%
0.040 g/dscm (0.031 gr/dscf)
10%
20%
0.45 kg/MW-hr (0.99 Ib/MW-hr)
(high silicon alloys)
0.23 kg/MW-hr (0.51 Ib/MW-hr)
(chrome and manganese alloys)
15%
20%
10%
11-170
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TABLE #3 (cont'd)
EMISSION LIMITATIONS (NSPS)
SUBPART
POLLUTANT
AA Steel Plants
Electric Arc furnaces Particulate
Control device Opacity
Shop roof Opacity
Dust handling
equipment
BB Kraft Pulp Mills
Recovery Furnace
Straight recovery
furnace
Cross recovery
furnace
Smelt dissolving
tank
Lime kiln
gaseous fuel
liquid fuel
Opacity
Particulate
Opacity
TRS
TRS
Particulate
TRS
TRS
Particulate
Particulate
Digester system, brown
stock washer system,
multiple-effect vaporation
system, black liquor
oxidation system or
condensate stripper TRS
EMISSION LEVELS
12 mg/dscm (0.0052 gr/dscf)
3%
0%, except:
20% - charging
40% - tapping
10%
0.10 g/dscm
35%
5 ppm
25 ppm
0.Ig/kg black liquor
(dry out)
0.0084 g/kg black liquor
(dry out)
8 ppm
0.15g/dscm
0.30g/dscm
5 ppm
11-171
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TABLE #3 (cont'd)
EMISSION LIMITATIONS (NSPS)
SUBPART POLLUTANT EMISSION LEVELS
HH Lime Manufacturing
Plants
Rotary Lime Kiln Particulate 0.15 kg/megagram of lime-
stone feed
Opacity 10%
Lime Hydrator Particulate 0.075 kg/megagram of lime
feed
11-172
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TABLE #4
PROPOSAL AND PROMULGATION DATES OF EMISSION LIMITATIONS FOR NSPS SOURCE CATEGORIES
Subpart
D
Da
E
F
G
H
I
J
K
L
M
N
0
P
Q
R
S
TUVWX
Y
Z
AA
BB
DD
HH
Source
Fossil Fuel Fired Steam Generators
Electric Utility Steam Generators
Incinerators
Portland Cement Plants
Nitric Acid Plants
Sulfuric Acid Plants
Asphalt Concrete Plants
Petroleum Refineries
Storage Vessels for Petroleum Liquids
Secondary Lead Smelters
Brass and Bronze Production
Iron and Steel Plants
Sewage Treatment Plants
Primary Copper Smelter
Primary Zinc Smelter
Primary Lead Smelter
Primary Aluminum Reduction Plants
Phosphate Fertilizer Industry
Coal Preparation Plants
Ferroalloy Production Plants
Steel Plants: Electric Arc Furnaces
Kraft Pulp Mills
Grain Elevators
Lime Manufacturing
Promulgation
Date
12/23/71
6/11/79
12/23/71
12/23/71
12/23/71
12/23/71
3/08/74
3/08/74
3/08/74
3/08/74
3/08/74
3/08/74
3/08/74
1/15/76
1/15/76
1/15/76
1/26/76
8/06/75
1/15/76
5/04/76
9/23/75
2/23/78
8/03/78
3/07/78
Proposed
Date
8/17/71
9/18/78
8/17/71
8/17/71
8/17/71
8/17/71
6/11/73
6/11/73
6/11/73
6/11/73
6/11/73
6/11/73
6/11/73
10/16/74
10/16/74
10/16/74
10/23/74
10/22/74
10/24/74
10/21/74
10/21/74
9/24/76
1/03/77*
8/03/78
3/03/77
a Suspended on 6/24/77.
11-173
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TABLE #5
NSPS CONTINUOUS MONITORING REQUIREMENTS
I. Installed and operational prior to conducting performance tests.1
II. Conduct monitoring system performance evaluations during performance
tests or 30 days thereafter.
III. Check zero and span drift at least daily (see Table #8).
IV. Time for cycle of operations (sampling, analyzing, and data recording).
A. Opacity - 10 seconds
B. Gas Monitors - 15 minutes
V. Installed to provide representative sampling
VI. Reduction of data.
A. Opacity - 6-minute average
B. Gaseous Pollutants - hourly average
VII. Source must notify agency, more than 30 days prior, of date upon which
demonstration of continuous monitoring system performance is to com-
mence.
Performance tests shall be conducted within 60 days after achieving the
maximum production rate at which the affected facility will be operated, but
not later than 180 days after initial startup of such facility.
11-174
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TABLE # 6
QUARTERLY REPORTING REQUIREMENTS1 (NSPS)
I. Excess Emissions
A. Description of Excess Emission
1. Magnitude
2. Conversion factors used
3. Date and time of commencement and completion
B. Explanation of Excess Emission
1. Occurrances during start-ups, shutdowns, and malfunctions
2. Nature and cause of malfunction
3. Corrective and preventative action taken
C. To be submitted in Units Same as Standard
II. Continuous Monitoring Systems
A. Date and Time when System was Inoperative (except for zero and span
checks)
B. Nature of System Repairs or Adjustments
III. Lack of Occurrances During A Quarter
A. Absence of Excess Emissions during Quarter
B. Absence of Adjustments, Repairs, or Inoperativeness of Continuous
Monitoring System
1 "Each owner or operator required to install a continuous monitoring system
shall submit a written report . . . for every calendar quarter"
"All quarterly reports shall be postmarked by the 30th day following the
end of each calendar quarter ..."
11-175
-------
TABLE #7
DEFINITION OF EXCESS EMISSIONS (NSPS)
SUBPART POLLUTANT EXCESS EMISSION
D opacity any six-minute period during which the average opa-
city of emissions exceed 20% opacity, except that one
six-minute average per hour of up to 27% opacity need
not be reported.
S02 any three-hour period during which the average
emissions of S02 (arithmetric average of three con-
tiguous one-hour periods) exceed the standard.
NOX any three-hour period during which the average
emissions of NOX (arithmetric average of three con-
tiguous one-hour periods) exceed the standard.
G NOX any three-hour period during which the average nitro-
gen oxides emissions (arithmetric average of three
contiguous one-hour periods) exceed the standard.
H S02 all three-hour periods (or the arithmetric average of
three consecutive one-hour periods) during which the
integrated average sulfur dioxide emissions exceed the
applicable standards.
J Opacity all one-hour periods which contain two or more six-
minute periods during which the average opacity
exceeds 30 percent.
CO all hourly periods during which the average CO con-
centration exceeds the standard.
S02 any three-hour period during which the average con-
centration of S02 emissions from any fuel gas com-
bustion device exceeds the standard.
S02 any twelve-hour period during which the average con-
centration of S02 emissions from any Glaus sulfur
recovery plant exceed the standard.
P Opacity any six-minute period during which the average opacity
exceeds the standard.
S02 any six-hour period during which the average emissions
of S02 (arithmetric mean of six contiguous one-hour
periods) exceed the standard.
Q Opacity any six-minute period during which the average opacity
exceeds the standard.
S02 any two-hour period during which the average emissions
of S02 (arithmetric mean of two contiguous one-hour
periods) exceed the standard.
11-176
-------
SUBPART
R
TABLE #7
DEFINITION OF EXCESS EMISSIONS (NSPS)
POLLUTANT EXCESS EMISSION
AA
Opacity
S02
Opacity
Opacity
BB
Recovery TRS
Furnace
Opacity
Lime Kiln TRS
Digester TRS
system,
brown stock
washer system,
multiple-effect
evaporator system,
black liquor oxidation
system, or condensate
stripper.
HH
Opacity
any six-minute period during which the average opacity
exceeds the standard.
any two-hour period during which the average emissions
of S02 (arithmetric mean of two contiguous one-hour
periods) exceed the standard.
all six-minute periods in which the average opacity is
15 percent or greater.
all six-minute periods during which the average opa-
city is 3 percent or greater.
any twelve-hour period during which the TRS emissions
exceed the standard.
any six-minute period during which the average opacity
exceeds the standard.
any twelve-hour period during which the TRS emissions
exceed the standard.
any twelve-hour period during which the TRS emissions
exceed the standard.
all six-iainute periods during which the average opa-
city is greater than the standard.
11-177
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TABLE #8
SPANNING AND ZEROING (NSPS)
I. Explanation of Zero and Span Checks
A. Extractive gas monitors
1. Span gas composition
a. S02 ~ sulfur dioxide/nitrogen or air-gas mixture
b. NO - nitric oxide/oxygen-free nitrogen mixture
c. N02 - nitrogen dioxide/air mixture
2. Zero gases
a. Ambient air
or b. A gas certified by the manufacturer to contain less than
1 ppm of the pollutant gas
3. Analysis of span and zero gases
a. Span and zero gases certified by their manufacturer to be
traceable to National Bureau of Standards reference gases
shall be used whenever these gases are available.
b. Span and zero gases should be reanalyzed every six months
after date of manufacture with Reference Method 6 for
S02 and 7 for NOX
c. Span and zero gases shall be analyzed two weeks prior to
performance specification tests
B. Non-extractive gas monitors
1. Span check - certified gas cell or test cell
2. Zero check - mechanically produced or calculated from upscale
measurements
C. Transmissometers
1. Span check is a neutral density filter that is certified within
+^3 percent opacity
2. Zero check is a simulated zero.
D. Span values are specified in each subpart
1. Span check is 90 percent of span.
II. Adjustment of Span and Zero
A. Adjust the zero and span whenever the zero or calibration drift
exceeds the limits of applicable performance specification in
Appendix B
1. For opacity, clean optional surfaces before adjusting zero or
span drift
2. For opacity systems using automatic zero adjustments, the opti-
cal surfaces shall be cleaned when the cumulative automatic zero
compensation exceeds four percent opacity
III. How to Span and Zero
A. Extractive gas monitors
1. Introduce the zero and span gas into the monitoring system as
near the probe as practical
B. Non-extractive gas monitors
1. Use a certified gas cell or test cell to check span
2. The zero check is performed by computing the zero value from
upscale measurements or by mechanically producing a zero
C. Transmissometers
1. Span check with a neutral density filter
2. Zero check by simulating a zero opacity
11-178
-------
SUBPART
D Fossil Fuel Fired Steam
Generators
liquid fossil fuel
solid fossil fuel
gaseous fuel
mixutures of fossil fuels
Da Electric Utility Steam
Generators
gaseous fuel
liquid fossil fuel
solid fossil fuel
*FGD Inlet
*FGD Outlet
G Nirtic Acid Plants
H Sulfuric Acid Plants
J Petroleum Refineries
Catalytic Cracker
Claus Recovery Plant
Fuel Gas Combustion
TABLE #9
SPAN SPECIFICATIONS (NSPS)
POLLUTANT
SPAN
opacity
S02
NOX
opacity
S02
X
NO
x
opacity
S02
Opacity
NOX
NOX
NOX
SO 2
SO 2
NO 2
SO 2
opacity
CO
SO 2
H2S
TRS
SO 2
H2S
80, 90, or 100% opacity
1000 ppm
500 ppm
80, 90, or 100% opacity
1500 ppm
1000 ppm
500 ppm
80, 90, or 100% opacity
lOOOy + ISOOz1
500 (x + Y) + lOOOz
60%-80%
500 ppm
500 ppm
1000 ppm
125% of max. estimated
potential emissions
50% of max. estimated
hourly potential emissions
500 ppm
1000 ppm
60, 70, or 80% opacity
1000 ppm
500 ppm
20 ppm
600 ppm
100 ppm
300 ppm
*Span values for S02 are specified for FGD inlet and outlet and apply to
liquid and solid fossil fuels.
-------
SUBPART
P Primary Copper Smelters
TABLE #9
SPAN SPECIFICATIONS
POLLUTANT
opacity
S02
SPAN
80 to 100% opacity
0.20% by volume
Q Primary Zinc Smelters
opacity
S02
80 to 100% opacity
0.20% by volume
R Primary Lead Smelters
opacity
S02
80 to 100% opacity
0.20% by volume
Z Ferroalloy Production
Facilities
opacity
not specified
AA Steel Plants
BB Kraft Pulp Mills
Recovery Furnace
Kime Kiln, recovery furnace
digester system, brown stock
washer system, multiple effect TRS
evaporator system, black liquor
oxidation system, or condensate
stripper system
opacity
opacity
02
HH Lime Manufacturing Plant
opacity
not specified
70% opacity
20%
30 ppm
(except that for any
cross recovery furnace
the span shall be 500 ppm)
40% opacity
x = fraction of total heat input from gas
y = fraction of total heat input from liquid fossil fuel
z = fraction of total heat input from solid fossil fuel
Span value shall be rounded off to the nearest 500 ppm.
11-180
-------
TABLE #10
NOTIFICATION REQUIREMENTS1
Requirements
I. Date of Commencement of Construction
II. Anticipated Date of Initial Start-Up
III. Actual Date of Initial Start-Up
IV. Any physical or operational change to a
facility which may increase the emission
rate of any air pollutant to which a
standard applies
A. The precise nature of the change
B. Present and proposed emission control
systems
C. Productive capacity before and after
the change
D. Expected completion date of change
V. Date upon which demonstration of continuous
monitoring system performance commences
Time Deadline
Less than 30 days after
such date
Less than 60 or more than
30 days prior to date
Within 15 days after date
Postmarked 60 days or as
soon as practical before
the change is commenced
More than 30 days prior
1 "Any owner or operator subject to the provisions of this part will furnish
the Adminstrator written notification..."
11-181
-------
TABLE #11
SUBPART Da EMISSION LIMITATIONS
AND REQUIRED PERCENT REDUCTIONS
Fuel
Coal
Pollutant
S02
NO
x
Liquid Fossil
Fuel
Particulate Matter
SO 2
Gas
NOX
Particulate Matter
S02
NOX
Particulate Matter
Coal-derived NOX
gaseous fuel
Emission Limitation
520ng/J (1.201b/106Btu)
210ng/J (0.501b/106Btu)
13ng/J (0.03lb/106Btu)
340ng/J (0.801b/106Btu)
130ng/J (0.301b/106Btu)
13ng/J (0.03lb/106Btu)
340ng/J (0.801b/106Btu)
86ng/J (0.201b/106Btu)
13ng/J (0.03lb/106Btu)
210ng/J (0.501b/106Btu)
Required
Percent Reduction
90%
(70% if emissions
are less than
260ng/J)
65%*
99%*
90%
(if emissions are
below 86ng/J, there
is no reduction
requirement)
30%*
70%*
90%
(if emissions are
below 86ng/J, there
is no reduction
requirement)
25%*
25%*
* Compliance with the emission limitation constitutes compliance with the
percent reduction requirements.
11-182
-------
Table #11, continued
Fuel
Lignite mined in
Pollutant
NO,
N. Dakota, S. Dakota,
or Montana and is com-
- busted in a slag type
furnace
Other Lignite
NO,
Subbituminous Coal NO,
Bituminous Coal NO
Anthracite Coal NO,
x
Emission Limitation
340ng/J (0.81b/106Btu)
Required
Percent Reduction
65%*
260ng/J (0.61b/106Btu)
210ng/J (0.51b/106Btu)
260ng/J (0.61b/106Btu)
260ng/J (0.61b/106Btu)
65%*
65%*
65%*
65%*
* Compliance with the emission limitation constitutes compliance with the
percent reduction requirements.
11-183
-------
TABLE #12
PERFORMANCE SPECIFICATIONS
TRANSMISSOMETERS
Calibration Error
Zero Drift (24-hour)
Calibration Drift (24-hour)
Response Time
Operational Test Period
NOV and S02
Accuracy
Calibration Error
Zero Drift (2-hour)
Zero Drift (24-hour)
Calibration Drift (2-hour)
Calibration Drift (24-hour)
Response Time
Operational Period
0? and CO?
Zero Drift (2-hour)
Zero Drift (24-hour)
Calibration Drift (2-hour)
Calibration Drift (24-hour)
Operational Period
Response Time
£3 percent opacity
£2 percent opacity
£2 percent opacity
10 seconds maximum
168 hours
£20 percent of the mean value
of the reference method test
data
£5 percent of (50 percent, 90
percent) calibration gas mix-
ture value
2 percent of span
2 percent of span
2 percent of span
2.5 percent of span
15 minutes maximum
168 hours minimum
£0.4 percent Q£ or C02
£0.5 percent 02 or C02
£0.4 percent 02 or C02
£0.5 percent 02 or C02
168 hours minimum
10 minutes
11-184
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TABLE #13
UHEN TO RUN THE MONTIOR PERFORMANCE TEST
Initial
Facility
Start-up
180
Days
Max.
Max.
Production
Rate Reached
Performance
Test and Submit
Report for
Compliance
60
Days
Monitor
Performance
Test
t
30
Days
I
60
Days
Monitor Performance
Test Report
11-185
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TABLE #14
REQUIREMENTS FOR SIP REVISIONS
I. Submit SIP revisions by October 6, 1976
II. Contain monitoring requirements for the following sources (as a minimum)
A. Fossil Fuel-Fired Steam Generators
B. Sulfuric Acid Plants
C. Nitric Acid Plants
D. Petroleum Refineries
(see Table #15)
III. Require that sources evaluate the performance of their monitoring system
IV. Require the sources to maintain a file of all pertinent continuous moni-
toring data
A. Emission measurements
B. Monitoring system evaluation data
C. Adjustments and maintenance performed on the monitoring system
V. Require the source to submit periodic (such period not to exceed 3
months) reports containing the following information
A. Number and magnitude of excess emissions
B. Nature and cause of excess emissions
C. Statement concerning absence of excess emissions and/or monitor in-
operativeness
VI. Require that monitoring begin within 18 months of EPA approval of the
SIP revision (or within 18 months of EPA promulgation)
11-186
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TABLE #15
EXISTING SOURCES REQUIRED TO CONTINUOUSLY MONITOR EMISSIONS
Source
Fossil-Fuel Fired
Steam Generators
Pollutant
SO 2
NO,
Opacity
Nitric Acid Plants
Sulfuric Acid Plants
Petroleum Refineries
NOX
SO 2
Opacity
Comments
1. >250 x 106 Btu/hr
2. Source that has control equip-
ment for S02
1. >1000 x 106 Btu/hr
2. Located in a designated non-
attainment area for N0£
3. Exempt if source is 30% or
more below the emission
standard
1. >250 x 106 Btu/hr
2. Exempt if burning gas
3. Exempt if burning oil, or a
mixture of oil and gas are the
only fuels used and the source
is able to comply with the
applicable particulate matter
and opacity standards without
installation of control equip-
ment
1. >300 ton/day
2. Located in a designated non-
attainment area for N02
1. >300 tons/day
1. >20,000 barrels/day
11-187
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SECTION III
VENDORS OF CONTINUOUS MONITORING EQUIPMENT
III-l
-------
Acurex Autodata
485 Clyde Avenue
Mountain View, CA 94042
Allis Chalmers Corporation
Box 512
Milwaukee, WI 53201
Analytical Instrument
Development, Inc.
Rt. 41 and Newark Road
Avondale, PA 19311
Asarco, Inc.
3422 South 700 West
Salt Lake City. UT 84119
B G I, Inc.
58 Guinan Street
Waltham, MA 02154
Bachrach Instrument Co.
2300 Leghorn Street
Mountain View, CA 94043
Bambeck Co.
1000 Quail St., Suite 290
Newport Beach, CA 92660
Bausch & Lomb Anal.
Division
820 Linden Avenue
Rochester, NY 14625
Sys.
Bendix Corp. EPID Div.
Box 831
Lewisburg, WV 24901
Bio Marine Industries, Inc.
45 Great Valley Center
Malvern, PA 19355
CEA Instruments, Inc.
15 Charles Street
Westwood, NJ 07675
Chemetrics, Inc.
Mill Run Drive
Warrenton, NJ 22186
Chemtrix, Inc.
163 SW Freeman Avenue
Hillsboro, OR 97123
Andersen Samplers, Inc.
4215-C Wendell Dr. SW
Atlanta, GA 30336
Astro Ecology/Astro
Resource
801 Link Road
League City, TX 77058
Babcock & Wilcox Co.
Bailey Meter Co.
29801 Euclid Avenue
Wickliffe, OH 44092
Bahnson Div. Envirotech
Corporation
Box 10458 Salem Station
Winston-Salem, NC 27108
Baseline Industries, Inc.
Box 649
Lyons, CO 80540
Beckman Inst. PID
2500 Harbor Blvd.
Fullerton, CA 92634
Berkeley Controls
2700 Dupont Dr.
Irvine, CA 92715
Brinkman Instruments, Inc.
Cantiague Road
Westbury, NY 11590
Calibrated Instruments, Inc.
731 Saw Mill River Road
Ardsley, NY 10502
Chemical Sensor Develop.
Co.
5606 Calle de Arboles
Torrance, CA 90505
Clean Air Engineering, Inc.
835 Sterling Avenue
Palatine, IL 60067
III-2
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Cleveland Controls, Inc.
5755 Granger Rd., Suite 850
Cleveland, OH 44109
Columbia Scientific Inds.
Box 9908
Austin, TX 78766
Control Instruments Corp.
18 Passaic Avenue
Fairfield, NJ 07006
Datatest, Inc.
1117 Cedar Avenue
Croydon, PA 19020
Delta Scientific Div.
250 Marcus Blvd.
Hauppauge, NY 11787
Dynamatrion, Inc.
168 Enterprise Drive
Ann Arbor, MI 48103
Dynatech R/D Co.
99 Erie St.
Cambridge, MA 02139
Ecologic Instrument
132 Wilbur Place
Bohemia, NY 11716
Energetics Science, Inc.
85 Executive Blvd.
Elmsford, NY 10523
Environmental Data Corp.
608 Fig Avenue
Monrovia, CA 91016
Esterline Angus Div. Esterline
Box 24000
Indianapolis, IN 46224
Foxboro/ICT Inc.
414 Pendleton Way
Oakland, CA 94621
Gil Enterprises, Inc.
Box 3356
Cherry Hill, NJ 08034
Gow Mac Instrument Co.
Box 32
Bound Brook, NJ 08805
Climet Instruments Div. WEHR
1320 W. Colton Ave., Box 151
Redlands, CA 92373
Contraves-Goerz Corp.
610 Epsilon Dr.
Pittsburgh, PA 15238
Dasibi Environmental Corp.
616 E. Colorado St.
Glendale, CA 91205
Delta F Corporation
One Walnut Hill Park
Wo burn, MA 01801
Dupont Instrument Products
Concord Plaza
Wilmington, DE 19898
Dynasciences Env. Prods. Div.
Township Line Road
Blue Bell, PA 19422
Dynatron Inc.
Box 745
Wallingford, CT 06492
Electronics Corp. of Amer.
1 Memorial Drive
Cambridge, MA 02142
Enmet Corp.
2308 S. Industrial
Ann Arbor, MI 48104
Environmental Techtronics Corp.
101 James Way
Southampton, PA 18966
Fischer & Porter Co.
125E County Line Road
Warminster, PA 18974
G C A Precision Scientific
3737 W. Cortland St.
Chicago, IL 60647
General Monitors, Inc.
3019 Enterprise St.
Costa Mesa, CA 92626
III-3
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Gubelin Inds., Inc.
45 Kensico Dr., Box 307
Mt. Kisco, NY 10549
High Voltage Eng. Corp. Ind.
Corp.
South Bedford Street
Burlington, MA 01803
Horiba Instruments, Inc.
1021 Duryea Avenue
Irvine, CA 92714
Hydrolab Corp.
Box 9406
Austin, TX 78766
ITT Barton
Box 1882
City of Industry, CA 91749
Instruments SA, Inc.
173 Essex Avenue
Metuchen, NJ 08840
InterScan Corp.
9614 Cozycroft Avenue
Chatsworth, CA 91311
K V B Equipment Corp.
17332 Irvine Blvd.
Tustin, CA 92680
Lamotte Chemical Prods. Co.
Box 329
Chestertown, MD 21620
Leco Corp.
3000 Lakeview Avenue
St. Joseph, MI 49085
Lockwood & Mclorie, Inc.
Box 113
Horsham, PA 19044
M D A Scientific, Inc.
Bob Busse Highway
Park Ridge, IL 60068
Mast Development Co.
2212 East 12th St.
Davenport, IA 52803
H N U Systems, Inc.
30 Ossipee Road
Newton Upper Falls, MA 02164
Honeywell, Inc.
1100 Virginia Drive
Ft. Washington, PA 19034
Houston Atlas, Inc.
9441 Baythorne Street
Houston, TX 77041
I R T Corp.
7650 Convoy Court
San Diego, CA 92111
Infrared Industries, Inc.
Box 989
Santa Barbara, CA 93102
International Sensor Tech.
3201 South Halladay St.
Santa Ana, CA 91311
Jacoby Tarbox Corp.
808 Nepperhan Avenue
Yonkers, NY 10703
Kernco Instruments Co., Inc.
420 Kenazo Avenue
El Paso, TX 79927
Lear Siegler, Inc.
74 Inverness Drive East
Englewood, CO 80110
Leeds & Northrup
Sumneytown Pike
North Wales, PA 19454
Lumicor Safety Products Corp.
5364 NW 167th St.
Miami, FL 33014
Martek Instruments, Inc.
17302 Daimler, Box 16487
Irvine, CA 92713
Meloy Labs, Inc.
6715 Electronic Drive
Springfield, VA 22151
III-4
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Meteorology Research, Inc.
Box 637
Altadena, CA 91001
Mine Safety Applicances Co.
600 Penn Center Blvd.
Pittsburgh, PA 15235
Monitor Labs, Inc.
10180 Scripps Ranch Blvd.
San Diego, CA 92131
Napp, Inc.
8825 N. Lamar
Austin, TX 78753
Oceanography Intl. Corp.
Box 2980
College Station, TX 77840
Overhoff & Associates
P. 0. Box 8091
Cincinnati, OH 45208
Particle Measuring Systems,
Inc.
1855 S. 57th Court
Boulder, CO 80301
Phoenix Precision Instru.
Route 208
Gardner, NY 12525
Photomation, Inc.
270 Polaris Avenue
Mt. View, CA 94043
Princeton Aqua Science
789 Jersey Avenue
New Brunswick, NJ 08902
Pullman Kellogg Div. of Pullman
1300 Three Greenway Plaza E
Houston, TX 77046
Rexnord, Inc. Instrument PDTS
30 Great Valley Parkway
Malvern, PA 19355
Science Spectrum
Box 3003
Santa Barbara, CA 93105
Milton Roy Co. Hays Republic
4333 S. Ohio St.
Michigan City, IN 46360
Modern Controls, Inc.
340 Snelling Avenue S.
Minneapolis, MN 55406
Montedoro Whitney Corp.
Box 1401
San Luis Obispo, CA 93406
National Draeger, Inc.
401 Parkway View Drive
Pittsburgh, PA 15203
Orion Research, Inc.
380 Putnam Avenue
Cambridge, MA 02139
PCI Ozone Corp.
One Fairfield Crescent
West Caldwell, NJ 07006
Perkin Elmer Corp.
411 Clyde Avenue
Mountain View, CA 94043
Photobell Co., Inc.
162 5th Avenue
New York, NY 10010
Preferred Instru. Div.
Preferred Utilities Mfg. Corp.
11 South St.
Danbury, CT 06810
Process Analyzers, Inc.
1101 State Road
Princeton, NJ 08540
Research Appliance Co.
Moose Lodge Rd., P.O. Box 2
Cambridge, MD 21613
Schneider Instrument Co.
8115 Camargo Rd. - Madeira
Cincinnati, OH 45243
Scientific Resources, Inc.
3300 Commercial Avenue
Northbrook, IL 60062
III-5
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Sensors, Inc.
3908 Varsity Drive
Ann Arbor, MI 48104
Sierra Instruments
Box 909 Village Square
Carmel Valley, CA 93924
Source Gas Analyzers, Inc.
7251 Garden Grove Blvd.
Garden Grove, CA 92641
T S I
Box 43394
St. Paul, MN 55164
Teledyne Analytical Insts.
Box 70
San Gabriel, CA 91776
Thermo Electron Corp. Env.
108 South St.
Hopkinton, MA 01748
Theta Sensors
17635 A Rowland St.
City of Industry, CA 91748
United McGill Corp.
Box 820
Columbus, OH 43216
Wallace & Tiernan Div. Pennwalt
25 Main St.
Belleville, NJ 07109
Wellsbach Ozone Sys. Corp.
3340 Stokley St.
Philadelphia, PA 19129
Western Research & Dev., Ltd.
1313 44th Avenue NE
Calgary, Alta. Canada T2E6L5
Xonics, Inc.
6862 Hayvenhurst Avenue
Van Nuys, CA 91406
Siemens Corp. P. E. Div.
186 Wood Avenue S.
Iselin, NJ 08830
Sierra Misco, Inc.
1825 E. Shore Highway
Berkeley, CA 94710
Systems Science & Software
Box 1620
La Jolla, CA 92038
Taylor Instrument Div. Sybron
95 Ames St.
Rochester, NY 14601
Thermco Instrument Corp.
Box 309
La Porte, IN 46350
Thermox Instruments, Inc.
6592 Hamilton Avenue
Pittsburgh, PA 15206
Tracor, Inc.
6500 Tracor Lane
Austin, TX 78721
Virtis Co.
Route 208
Gardner, NY 12525
Wallace Fisher Instrument Co.
Box 51 Ocean Grove Station
Swansea, MA 02777
Western Precipitation Division
Joy Manufacturing Company
Post Office Box 2744 Termina Annex
Los Angeles, CA 90051
Whittaker Corp.
10880 Wilshire Blvd.
Los Angeles, CA 90024
III-6
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SECTION IV
BIBLIOGRAPHY OF GEM RELATED ARTICLES
IV-1
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BIBLIOGRAPHY OF GEM RELATED ARTICLES
lt Application of Light Transmissometry and Indication Sodium Ion Measurement
To Continuous Participate Monitoring In The Pulping Industry. NCASI
Technical Bulletin No. 79.May 1975.
:- 2. Avetta, Edward D. In-Stack Transmissometer Evaluation and Application to
r Particulate Opacity Measurement. EPA Contract No. 68-02-0660.
Owens, Illinois. NTIS PB 242402. January 1975.
3. Baladi, Emile. Manual Source Testing and Continuous Monitoring
Calibrations at the Lawrence Energy Center of Kansas Power and Light
Company. Midwest Research Institute. EPA Contract No. 68-02-0228.
EPA Report No. 73-SPP-3. May 7, 1976.
4. Beeson, H. G. Continuous Monitoring Excess Emission Report; Evaluation
and Summary. Entropy Environmentalists, Inc. EPA Contract No.
68-01-4148, Task 59. June 1979.
5. Beeson, H. G. Evaluation of Continuous Monitoring Excess Emission Reports
and Validation of Report Data. Entropy Environmentalists, Inc. EPA
Contract No. 68-01-4148, Task 45. March 1979.
6. Cheney, J. L. and J. B. Homolya. "The Development of a Sulfur Dioxide
Continuous Monitor Incorporating a Peizo-Electric Sorption Detector,"
The Science of the Total Environment, vol. 5, p. 69-77, 1976.
7. Cline, J. R., et. al. Compilation and Analysis of State Regulations for
S02, NOy, Opacity, Continuous Monitoring and Applicable Test Methods:
Executive Summary and Volumes I, II, and III. Engineering Sciences
Inc. EPA Contract No. 68-01-4146, Task 40. EPA Report No. 340/
1-78-009 a, b, c, d. July 1978.
8. Connor, William D. "A Comparison Between In-Stack and Plume Opacity
Measurements at Oil-Fired Power Plants," presented at the Fourth
National Conference on Energy and the Environment in Cincinnati, Ohio,
October 4-7, 1976.
9. Connor, William D. Measurement of the Opacity and Mass Concentration of
Particulate Emissions by Transmissometry. Chemistry and Physics
Laboratory. EPA-650/2-74-128. November 1974.
10. Connor, W."D. and J. R. Hodkinson. Optical Properties and Visual Effects of
Smoke-Stack Plumes. EPA Publication AP-30, second printing. May 1972.
11. Curtis, Foston. "A Method for Analyzing NOX Cylinder Gases, Specific Ion
Electrode Procedure," Source Evaluation Society Newsletter, February
1979. (Study done for Emission Measurement Branch, US EPA, October
1978.)
12. Decker, C. E., R. W. Murdoch, and F. K. Arey. Final Report on Analysis of
Commercial Cylinder Gases of Nitric Oxide and Sulfur Dioxide at Source
Concentrations. EPA Contract No. 68-02-2725. February 1979.
IV-2
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13. "Environmental Monitoring." Transcript of Science Technical Hearings, 95
Congress 1 Serial 44, September 13-15, 1977.
14. Fennelly, Paul F. Development of an Implementation Plan for a Continuous
Monitoring Program. GCA Corporation. March 1977.
15. Gregory, M. W., et. al. "Determination of the Magnitude of S02, NO,
CC>2 Stratification in the Ducting of Fossil Fuel Fired Power Plants,"
Paper 76-35.6 presented at the 1976 APCA Meeting, Portland, Oregon.
'16. Herget, W. F., et. al. "Infrared Gas-Filter Correlation Instrument for
In-Site Measurement of Gaseous Pollutant Concentrations," Applied
Optics, vol. 15:1222-1228, May 1976.
17. Homolya, J. B. "Current Technology for Continuous Monitoring of Gaseous
Emissions," Journal of the Air Pollution Control Association, vol. 24,
no. 8, p. 809-814, August 1975.
18. Jahnke, James A. and G. J. Aldina. Continuous Air Pollution Source
Monitoring Systems; Handbook. Northrup Services, Inc. EPA
625/6-79-005.June 1979.
19. Jaye, Frederic C. Monitoring Instrumentation for the Measurement of Sulfur
Dioxide in Stationary Source Emissions. TRW Systems Group. EPA
Project 17205, NTIS PB 220202.
20. Karels, Gale G., et. al. Use of Real-Time Continuous Monitors in Source
Testing. Paper 75-19.5 presented at APCA Annual Meeting, June 15-20,
1975. NTIS PB 230934/AS GPO.
21. Lillis, E. J. and J. J. Schueneman. "Continuous Emission Monitoring:
Objectives and Requirements," Journal of the Air Pollution Control
Association, vol. 25, no. 8, August 1975.
22. Lord III, Harry C. "In-Stack Monitoring of Gaseous Pollutants,"
Engineering Science and Technology, vol. 12, no. 3, p. 264-69, March
1978.
23. McRanie, Richard D., John M. Craig, and George 0. Layman. Evaluation of
Sample Conditioners and Continuous Stack Monitors for Measurement of
SO?, NOY, and Opacity in Flue Gas. Southern Services, Inc. February
1975.
24. McNulty, K. J., et. al. Investigation of Extractive Sampling Interface
Parameters. Walden Research Division of Abcor, Inc. EPA Contract No.
68-02-0742. EPA 650/2-74-089. October 1974.
25. Nader, John S., Frederic Jaye, and William Connor. Performance
Specifications for Stationary Source Monitoring Systems for Gases and
Visible Emissions. NERC Chemistry and Physics Laboratory. NTIS PB
209190. January 1974.
26. Osborne, Michael C. and M. R. Midgett. Survey of Continuous Source Emission
Monitors; Survey No. 1 - Nov and SO?. EPA 600/4-77-022. April 1977.
IV-3
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27. Osborne, Michael C. and M. Rodney Midgett. Survey of Transmissometers Used
in Conducting Visible Emissions Training' Courses. EPA - 600/4-78-023.
May 1978.
28. Peeler, James W. Continuous Opacity and Particulate Emissions Monitoring in
the Federal Republic of Germany; Selected Papers From Current
: Literature. Entropy Environmentalists, Inc. EPA Contract No.
29. Reisraan, E., W. D. Gerber, and N. d. Potter. In-Stack Transmissometer
Measurement of Particulate Opacity and Mass Concentration. Philco-Ford
Corporation. EPA Contract No. 68-02-1229. NTIS PB 239864/AS.
November 1974.
30. Repp, Mark. Evaluation of Continuous Monitors for CO in Stationary Sources.
EPA 600/2-77-063. March 1977.
31. Rhodes, Raymond C. and H. Seymour. "Challenges of Implementing Quality
Assurance in Air Pollution Monitoring Systems," presented at APCA
Quality Assurance in Air Pollutiong Measurement Conference, March
11-14, 1979, New Orleans, Louisiana.
32. Roberson, R. L., et. al. "Continuous Emission In the Electric Utility
Industry," Paper 80-42.1 presented at APCA Annual Meeting, June 22-27,
1980, Montreal, Quebec, Canada.
33. Shigehara, R. T. "Sampling Location for Gaseous Pollutant Monitoring in
Coal-Fired Power Plants," Source Evaluation Society Newsletter. July
1978.
34. Stanley, Jon and Peter R. Westlin. "An Alternative Method for Stack Gas
Moisture Determination," Source Evaluation Society Newsletter.
November 1978.
35. Tomaides, M. Instrumentation for Monitoring the Opacity of Particulate
Emissions Containing Condensed Water. EPA 600/2-77-005. June 1979.
36. Tretter, V. J. and Matthew Gould. "A New Concept In Compliance Monitoring,"
presented at TAPPI Environmental Conference, April 25-27, 1979,
Houston, Texas.
37. United States Environmental Protection Agency. "Standards of Performance
for New Stationary Sources," Federal Register 40:46250-70. October 6,
1975. "
38. Van Acker, P- "Continuous and Semi-Continuous Measurements of Dust
Emissions In a Power Plant Burning Fuel Oil," Environmental
International, vol. 2, no. 2, p. 107. 1979.
39. West, P- W. , D. L. McDermott, and K. D. Reiszner. "Development of Long-
Term Sulfur Dioxide Monitor Using Permeation Sampling," Engineering
Science and Technology, vol. 13, no. 9, September 1979.
IV-4
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40. Westlin, Peter R. and John W. Brown. "Methods for Collecting and Analyzing
Gas Cylinder Samples," Source Evaluation Society Newsletter, September
1978.
41. Woffinden and Ensor. Optical Method for Measuring the Mass Concentration of
Particulate Emissions. Meteorology Research, Inc. EPA Contract No.
: 68-02-1749. EPA 600/2-76-062. March 1976.
IV-5
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Availability of EPA Publications
Copies of United States EPA publications are available free of charge, as
long as supplies last, from the EPA Library in Research Triangle Park, North
Carolina. When supplies are exhausted, one may purchase publications from the
United States Government Printing Office or the National Technical Information
Service.
U. S. Environmental Protection Agency
Library (MD-35)
Research Triangle Park, N. C. 27711
commercial phone 919-541-2777
FTS phone 629- 2779
National Technical Information Service
U. S. Department of Commerce
5285 Port Royal Road
Springfield, Virginia 22151
phone 703-487-4600
Superintendent of Documents
Government Printing Office
Washington, D. C. 20402
IV-6
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TECHNICAL REPORT DATA
(Please read Instructions on the reverse before completing)
1. REPORT NO.
EPA 34n/]-ai-nn«
3. RECIPIENT'S ACCESSION NO.
4. TITLE AND SUBTITLE
Regulations and Resource File of Continuous
Monitoring Information
6. REPORT DATE, „„ ,
October, 1981
6. PERFORMING ORGANIZATION CODE
7. AUTHOR(S)
WilS.am J. Pate
8. PERFORMING ORGANIZATION REPORT NO.
9. PERFORMING ORGANIZATION NAME AND ADDRESS
* **. .
Kilkelly Environmental Associates, Inc.
Post Office Box 31265
Raleigh, North Carolina 27622
1O. PROGRAM ELEMENT NO.
11. CONTRACT/GRANT NO.
68-01-6317
12. SPONSORING AGENCY NAME AND ADDRESS
U. S. Environmental Protection Agency
Office of Enforcement
Office of General Enforcement
Washington. D. C. 20460
13.
D PERIOD COVERED
14. SPONSORING AGENCY CODE
15. SUPPLEMENTARY NOTES
16. ABSTRACT
The Environmental Protection Agency has promulgated continuous emission
monitoring requirements for several NSPS source categories. The EPA has also
required states to revise their SIPs to include continuous emission monitoring
regulations.
This report is a compilation of the following continuous emission moni-
toring information: EPA regional continuous monitoring contacts; continuous
emission monitoring regulations; vendors of continuous monitoring equipment;
and a bibliography of continuous monitoring literature.
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.lOENTIFIERS/OPEN ENDED TERMS
c. COS AT I Field/Group
Continuous Emission Monitoring
Regu-lations
New Source Performance Standards
Continuous Emission
Monitoring
13B
14D
18. DISTRIBUTION STATEMENT
Release Unlimited
.,SECURITY.CJ,ASS (This Report)
Unclassified
21. NO. OF
;ES
20. SECURITY CLASS {Thispage}
Unclassified
22. PRICE
EPA Porn 2220-1 (R»«. 4-77) Previous EDITION n OBSOLETE
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