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U.S. ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF ENFORCEMENT
OFFICE OF GENERAL ENFORCEMENT
WASHINGTON, D.C. 20460

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                          EPA-340/1-79-010
    REGULATIONS  AND RESOURCE FILE
OF CONTINUOUS MONITORING INFORMATION
           Interim Report
                 by

          William  J.  Pate
   Entropy Environmentalists, Inc.
        Post  Office Box  12291
Research Triangle Park,  N. C.  27709
       Contract  No.  68-01-4148

EPA Project Officer:  Louis R.  Paley



            Prepared for:

U. S. ENVIRONMENTAL PROTECTION AGENCY

        Office of Enforcement
    Office of General Enforcement
       Washington, D. C. 20460
            October, 1979

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                     TABLE OF CONTENTS
                                                         Page

  I.   Introduction	    1-1

 II.   EPA Personnel and Organizations Involved
        With Continuous Monitoring 	   II-l

      A.  Continuous Monitoring Subject Index  ....   II-l
      B.  Regional Office Continuous Monitoring
            Contacts	   II-3
      C.  Organization Function Statements 	   II-5

III.   Monitoring Regulations 	  .....  III-l

      A.  Introduction	III-l

      B.  NSPS Regulations - Promulgated	 .  III-6
            Subpart A - General Provisions 	  III-6
            Subpart D - Fossil-Fuel Fired Steam
                          Generators 	  111-10
            Subpart Da- Electric Utility Steam
                          Generators 	  111-13
            Subpart G - Nitric Acid Plants 	  111-25
            Subpart H - Sulfuric Acid Plants 	  111-26
            Subpart J - Petroleum Refineries 	  111-27
            Subpart N - Iron and Steel Plants
                          (BOPF) 	  111-29
            Subpart P - Primary Copper Smelters  .  . .  III-30
            Subpart Q - Primary Zinc Smelters  ....  111-32
            Subpart R - Primary Lead Smelters  ....  111-33
            Subpart T - Wet-Process Phosphoric Acid
                          Plants 	  111-34
            Subpart U - Superphosphoric Acid Plants  .  111-35
            Subpart V - Diammonium Phosphate Plants  .  111-36
            Subpart W - Triple Superphosphate Plants .  111-37
            Subpart X - Granular Triple Superphos-
                          phate Storage Facilities  . .  111-38
            Subpart Y - Coal Preparation Plants  .  . .  111-39
            Subpart Z - Ferroalloy Production Facili-
                          ties 	  ,  . .  111-40
            Subpart AA- Steel Plants: Electric Arc
                          Plants	  	  111-42
            Subpart BB- Kraft Pulp Mills 	  111-43
            Subpart GG- Stationary Gas Turbines  .  . .  II1-46
            Subpart HH- Lime Manufacturing Plants  . .  111-49
            Reference Methods 1-4,  6-9, 20 	  111-50
            Appendix B - Performance Specifications
                           1, 2, & 3; Excerpts of
                           Preambles 	  111-88

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 Table of Contents - continued
                                                         Page
     C.  SIP Monitoring Requirements 	 III-108
     D.  Summary Tables of Monitoring Regulations  .   . III-118
IV.   Vendors of Continuous Monitoring Equipment  .  .   .  IV-1
 V.   Bibliography	   V-l
     Availability of EPA Publications  	   V-7

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                        INTRODUCTION








     Continuous   monitoring   requirements   were   initially



promulgated October 6,  1975  for  a  few  NSPS  source categories.




Also  on  October  6,  1975,  EPA  promulgated  a  revision  to




Part 51  which  required  the  States  to  revise  their  State




Implementation Plans  (SIP's) to  include  continuous monitoring




requirements  for  certain   specified   existing   source   cat-




egories.  Since  that  time,  the  monitoring  regulations  have



been  revised,  and new  source  categories  have  been added  to




the  list  of  sources  required   to  monitor  emissions   con-




tinuously.  On  June  11,   1979,   EPA   published   regulations




affecting Electric: Utility  Steam Generating  Units constructed




after  September 13,  1978. These.'  regulations  require  the  use




of  continuous monitors  to  determine  continuous  compliance




with the emission standards, and  to  determine compliance with




the required percent  reduction of  potential  emissions.



     Air  pollution  agencies  are  increasingly   incorporating



continuous monitors and continuous monitoring data into  their




surveillance and  enforcement activities.  EPA plans to  apply




monitoring  requirements to  additional  source categories  and




to use  the  monitoring  data  for  purposes other  than as  mere




indicators of emissions.
                        1-1

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     This  report   is   a   compilation  and  organization  of



available  continuous   monitoring   information.  Section  II



identifies  EPA  personnel  working  with  continuous emission



monitoring  and  delineates  the  functions  of  several  EPA



organizations.   Section  III  contains   updated   monitoring



regulations excerpted  from  the Federal  Register,  along with



presently  proposed   regulations,   and   summary  tables  of



regulatory  information. Section  IV  contains  a listing  of




vendors  selling  continuous  monitoring  equipment  and   their



addresses.   Section V   is   a   bibliography   of   continuous



monitoring   literature  and   a   subject   index   for   that



bibliography.
                         1-2

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              CONTINUOUS MONITORING SUBJECT INDEX
Subject
Person-Division
   (FTS)
Phone Number
Federal Register Regulations
  Development

  Enforcement
  Interpretation

Standards

  Development
  Field Evaluation

Monitbring Methods

  Applications, De-
    velopment, & Eval-
    ation
  Enforcement Appli-
    cations

Enforcement

  General Policy
  Training Materials
    & Manuals

  Determinations of
    Applicability

Quality Assurance

  Implementation of
    EPA Quality
    Assurance
  Traceability Pro-
    tocol
  Monitoring Instru-
    mentation Per-
    formance Audits
Larry Jones - ESED
Gene Smith - ESED
Lou Paley - DSSE
Rich Biondi - DSSE
Larry Jones - ESED
George Walsh - ESED
Ed McCarley - ESED
Roger Shigehara - ESED

Lou Paley - DSSE



John Rasnic - DSSE

Lou Paley - DSSE
Kirk Foster - DSSE

Rich Biondi - DSSE
John Clements - EMSL

Darryl Von Lehmden - EMSL
Tom Logan - EMSL
Bill Mitchell - EMSL
   629-5421
   629-5421
   755-8137
   755-2564
   629-5421
   629-5423
   629-5245
   629-2237

   755-8137



   755-2564

   755-8137
   629-4571

   755-2564
   629-2196

   629-2415
   629-2580
   629-2580
                               II-l

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Continuous Monitoring Research
  Transmissometry
  Gas Monitors
  Transport Systems
    (extractive
    analyzers)

  Remote Gas Sensing
  Remote Particulate
    Sensing
Bill Conner - ESRL
Jim Homolya - ESRL
Ro Rollins - ESRL
Jim Cheney - ESRL
Jim Homolya - ESRL

Bill Herget - ESRL

Bill Conner - ESRL
Jim Vincent - NEIC
Continuous Process Monitors
  Use of
James Dorsey - IERL
Bill Kuykendall - IERL
State Implementation Plans
  Revisions
Field Enforcement

  Investigations
Gary Rust - CPDD
Joseph Sableski - CPDD
Gary D. Young - NEIC
Richard Ross - NEIC
Timothy Osag - NEIC
Richard Ida - NEIC
629-3173
629-3085
629-3171
629-3172
629-3085

629-3184

629-3173
239-4656
629-2557
629-2557
629-5365
629-5497
234-2336
234-4661
234-2336
234-4658
                               II-2

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            REGIONAL CONTINUOUS MONITORING CONTACTS
Person
    Division
                                                    (FTS)
                                                 Phone  Number
REGION I:

Cathy McNair

Thomas A. Michel
    S & A

     Enf.
617-861-6700
(commercial)
223-5610
REGION II:

Joseph Spatola
Frank Giaccone
    S & A
Air Facilities
340-6690
264-9627
REGION III:

Gary Gross
Robert Kramer
     Enf.
    S & A
597-8907
597-9843
REGION IV:

Vince Hellwig
     Enf.
257-4298
REGION V:

Eric Cohen
Larry Kertcher
     Enf.
     Enf.
353-2090
353-2086
REGION VI:

Stanley Spruiell
Quirino Wong
     Enf.
    S & A
729-2755
729-2724
REGION VII:

Michael J. Sanderson     Enf.
William Longston        S & A
William A. Spratlin      AHM
                            758-2576
                            758-4461
                            758-3791
                        II-3

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REGION VIII:

John Floyd              S & A                   327-4261
Roxann Varzeas           Enf.                   327-2361
Christine Phillips       Enf.                   327-2361
REGION IX:

Peter Van Patten         Enf.                   556-0970
Kent Kitchingman        S & A                   556-8047
Alvin Chun               AHM                    556-8752
REGION X:

Paul Boys               S & A                    399-1106
                        II-4

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               ORGANIZATION FUNCTION STATEMENTS





 I.   The Division of Stationary Source Enforcement (DSSE)




          The Division of  Stationary  Source Enforcement provides

     for  the  enforcement   of   continuous  emission  monitoring

     regulations by  developing  and distributing  enforcement and

     regulatory guidelines, by developing policies and procedures

     for surveillance programs, by publishing training materials,

     by organizing workshops  in  monitoring-related  areas,  and by

     providing guidance  and  assistance  to regional  offices and

     State  agencies.  DSSE  also   develops  procedures  for  data

     handling  and  reporting,  interprets   the  regulations,  and

     provides  the   regional  offices   with   determinations  of
                                                                •%
     applicability.




II.   The Control Programs Development Division




          The   Control    Programs    Development    Division   is

     responsible  for  the  review  and  evaluation  of  air  program

     activities   by   regional,   state,   and   local   agencies.

     Additional  responsibilities  for  this  division  include the

     management  of   training   and   of   technical   information

     services,  and  the   review  of  SIP  continuous  monitoring

     revisions.
                           II-5

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III.   The Emission Standards and Engineering Division (ESED)



           The  Emission  Standards  and   Engineering  Division  is

      responsible for developing and  revising  the  NSPS  and NESHAP

      continuous monitoring provisions;  for  specifying  continuous

      monitoring  requirements  for  additional  NSPS  and  NESHAP

      source categories;  for  developing  and  evaluating  continuous

      monitoring methods  and  equipment;  for  conducting  continuous

      monitoring   in  support   of  standards   development;   for

      compiling  and  maintaining  emission  test  data;  and  for

      providing guidance  to regional offices on matters pertaining

      to continuous emission monitoring.



 IV.   The   Environmental   Monitoring   and  Support   Laboratory,
      Quality Assurance Branch (EMSL, QAB)


           The  Environmental  Monitoring  and  Support  Laboratory,

      Quality Assurance Branch,  is responsible for developing and

      maintaining quality assurance  programs for  EPA.  QAB is also

      responsible for developing monitoring methods, for executing

      continuous monitoring equipment  performance  audits, and for

      establishing protocol for  traceability of calibration gases

      used with continuous emission monitors.
                             II-6

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 V.  The Industrial Environmental Research Laboratory (IERL)



          The   Industrial    Environmental   Research   Laboratory

     develops  and  evaluates  continuous  emission  and  process

     monitoring,  and  applies   its   findings  in  technological

     studies of industrial and energy processes.



VI.  The  Environmental  Science  Research  Laboratory,  Stationary
     Source Research (ESRL, SSRB)


          The   Environmental    Science    Research   Laboratory,

     Stationary  Source  Research  Branch,  conducts research  and

     development  studies   on  continuous  monitoring  methods  and

     instrumentation  for  measuring   opacity  and  gaseous  and

     particulate pollutants;  develops new measurement methods and

     instrumentation; evaluates prototype and unproven continuous

     monitoring  instruments;  and  conducts studies to  determine

     the correlation between opacity measurements and particulate

     emissions.
                           II-7

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             CONTINUOUS  MONITORING  REGULATIONS
     The  Environmental   Protection   Agency   has   promulgated



revisions  to Parts  51  and  60  of  Title  40  of  the  Code  of



Federal Regulations,  which  require  stationary sources of  air



pollution   to   install,   operate,  and  maintain   continuous



emission monitoring  systems.



     The  EPA,  on October  6,  1975,  promulgated  a  regulation



which   required   the    States   to    revise   their    State



Implementation Plans  by  October  6,  1976,  in order  to  include



legally enforceable  procedures  requiring  certain  categories



of   existing   stationary  sources   to   monitor  emissions



continuously.  The States,  at  a minimum,  were  directed  to



require   existing   stationary   sources   in   the  following



categories  to install, to  operate,  and to maintain equipment



which  would continuously monitor  and  record  emissions:  (1)



Fossil-Fuel-Fired  Steam  Generators,  (2)  Nitric  Acid  Plants,



(3) Sulfuric Acid Plants, and  (4)  Petroleum  Refineries.  The



sources were required  to install  monitoring  systems  which



complied with performance specifications and  to submit to  the



State  quarterly  reports which  included  the  frequency  and



magnitude of excess emissions, and the  inoperativeness of  and



repairs and adjustments  to the continuous monitoring systems.



The States  were  directed to  require  the  sources  to  begin
                        III-l

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monitoring within  18  months of  the  SIP approval  or  the EPA



promulgation. If the States did  not  submit SIP revisions, or



if  the   submitted   revisions   were   inadequate,   EPA  would



promulgate   substitute   regulations   requiring   continuous



emission monitoring.



     Also on  October  6,  1975,  the EPA  promulgated revisions



to New  Source Performance  Standards (NSPS), 40 CFR Part 60,



to require certain  specified  categories of  new and modified



stationary   sources   to   install,   operate,   and  maintain



equipment to  monitor  and record  emissions continuously. The



NSPS revisions  require that monitoring  systems be installed



prior to  the  performance  testing  of  the affected   facility as



required  by  "60.8  (unless  continuous   monitor installation



depends  upon  the  results of the  performance  testing  -  i.e.,



NOx monitor  installation).  Affected  sources  are   required to



evaluate  the  performance  of each  monitoring  system during the



performance  test  or within 30  days  thereafter.  Sources are



required  to  maintain  a  file  of  continuous   monitoring



measurements  and to submit quarterly reports  that  include the



frequency  and  magnitude  of   excess   emissions,  and  the



inoperativeness  of  and  repairs and   adjustments  to  the



continuous monitoring  systems.



     Since the October 6, 1975  promulgation, EPA   has revised



the  original  regulations  and   has  promulgated  monitoring



requirements  for  additional source  categories. On June 11,



1979,   EPA promulgated  performance  standards  for  Electric
                      III-2

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Utility  Steam  Generating  Units.  In  addition  to  setting



emission  standards,  this  regulation  contains  a requirement



for  percent  reduction  of  potential   emissions.  Continuous



monitors will be used  to determine continuous compliance with'



the  emission  standards   and   with   the  percent  reduction



requirement established in this subpart.



     The  compilation  of  regulatory  information  included   in



this document contains excerpts from  Parts 51 and 60  of  the



Code of Federal  Regulations,  requiring  stationary sources  to



monitor   emissions   and/or   processes   continuously.   This



information is compiled  herein to produce  a  concise package



of updated  monitoring  regulations which  is easy  to  use,  but



sufficiently inclusive to  answer  questions and  to  allow  for



interpretations  of  monitoring   regulations.  Parts  of   the



preambles    to    the    various   legislation,    containing



explanations, discussion,  and  background  information,  have



been included for reference.



     Section  I   contains   excerpts    from   the  monitoring



regulations  found  in  Part 60,  NSPS  and  is  divided  into  the



following   subsections:   current    continuous   monitoring



regulations, and presently proposed  regulations and proposed



revisions to existing  regulations.



     Section   II   contains    the  required   SIP   revision



requirements promulgated by EPA.



     Following  Section  II  are  several   summary  tables   of



regulatory  information which  have been  abstracted  from NSPS
                        III-3

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and SIP monitoring requirements. The tables present pertinent



information  in  useful,  concise  formats. However,  it  must be



born in mind  that the tables are summaries,  and  they do not



include all the examples, exceptions, and exemptions  that are



found in the regulations themselves.
                       III-4

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ENVIRONMENTAL
   PROTECTION
    AGENCY
   STANDARDS OF
PERFORMANCE FOR NEW
 STATIONARY SOURCES

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   Subport A—General Prevision*
160.1   Applicability.
  Except as provided in Subparts B and
C, the provisions of this part apply to
the owner or operator of any stationary
source which contain an affected facil-
ity, the construction or modification of
which  is commenced after the date of
publication in this 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
defined herein shall have the meaning
liven them in the Act:
  (•)  "Act" means the Clean Ah* Act
(42 TJJ3.C. 1857 et seq., as amended by
Public Law  01-604. 84  Btat. 1676).
  (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 installation of  an  affected
faculty.
   (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.
   (i) "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
In the background.
  (k) "Nitrogen oxides"  means all ox-
Ides 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°F) 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 gas
flow rate.
  (n) "Isoklnetic   sampling"   means
sampling In which the linear velocity of
the gas entering the sampling nozzle is
equal to that of  the undisturbed gas
etream at the sample point.
  (o) "Startup" means  the  setting In
operation of an affected facility for any
purpose.
  (p) "Shutdown"  means the cessation
of operation of an affected facility for
any purpose.
  (q) "Malfunction" means any sudden
and unavoidable failure of air pollution
control equipment or process equipment
or of a process to operate In a normal
or usual manner. Failures that are caused
entirely or in part by poor maintenance.
careless operation, or any other prevent*
able  upset  condition  or  preventable
equipment breakdown shall not be con-
sidered malfunctions.
   (r) "One-hour period" means any 60
minute period commencing on the hour.
   (s> "Reference  method" means any
method  of  sampling  and analyzing for
 an  air  pollutant  as described in Ap-
pendix A to this part.
  (t) "Equivalent  method" means any
method of sampling and analyzing for an
air pollutant  which have been demon-
strated to the Admlnlstartor's satisfac-
tion to have a consistent and quantita-
tively known  relationship to the refer-
ence method, under specified conditions.
  (u) "Alternative method" means any
method of sampling and analyzing for an
air pollutant which is not a reference or
equivalent method but which has been
demonstrated to the Administrator's sat-
isfaction to, in specific  cases, produce
results adequate for his determination of
compliance.
   (v) "Participate matter" means any
finely divided solid or liquid material.
other than  uncombined water, as meas-
ured by  Method 5  of Appendix A to this
part or  an equivalent  or  alternative
method.
  (w) "Run"  means  the net period of
time during which an emission sample
is collected. Unless  otherwise specified.
a run may be either intermittent or con-
tinuous within the limits of good engi-
neering  practice.
  (x)  "Six-minute period" means any
one of the 10 equal parts of a one-hour
period.
  (y) "Continuous monitoring system"
means  the total  equipment,  required
under the emission monitoring sections
in  applicable  subparts, used to sample
and condition (if applicable), to analyze.
and to provide a  permanent record of
emissions or process parameters.
  (z) "Monitoring  device" means the
total equipment,  required  under the
monitoring of operations sections in ap-
plicable subparts, used to measure and
record 
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nature of the Astern repair* or adjust-
ments
  (4) When 00 excess emissions have
occurred or the continuous monitoring
system (a) have not been Inoperative, re-
paired,  or adjusted, such information
shall be stated in the report.
  (d) Any owner or operator subject to
the provisions of 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
measurements, maintenance, reports, and
records.
 g 60.8   Performance te»U.
   (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 Mamiardi and
     maintenance 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-
 ard* in this part shall be determined by
 conducting  observations In accordance
 wltb Reference Method t in Append* A
 of this part or any alternative method
 that is approved by the Administrator.
 Opacity readings of portions of plumes
 which  contain condensed, uncomblaed
 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
I 60.8.
   (2) Upon receipt from such  owner or
operator of the written report of  the re-
fidts of  the performance tests required
by ( 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 wltli  all
applicable standards for which perform-
ance tests  are  conducted in accordance
with 5 60.8  of  this part but during  the
time such  performance tests are being
conducted  fails 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  FEDERAL REGISTER.
 (S«c. 114 at th» d«aa Air Act a*
 (O U.S.C. 1U70-*).).
 f 60.15   Monitoring requirement*.
   (a) Unless otherwise approved by the
Administrator or specified In applicable
subparts. the requirements of this sec-
tion shall apply to all continuous moni-
toring systems required under applicable
subparts.
  (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)'l) 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 as
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.
  (iii) 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
>.
  (2) An owner or operator who, prior
to September 11. 1074,  entered  into a
binding contractual obligation to pur-
chase  specific   continuous  monitoring
system components except as referenced
by paragraph (c) (2) (111) of this section
shall comply with the following require-
ments:
  (1) 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 aet forth in Performance Specifl-
                                                             III-7

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 cation 1 of Appendix B shall be uaed for
 demonstrating  compliance  with  this
 specification.
   (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 T< .(.,  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)(l)  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
  aero 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 bo
  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 3 for O,
  and CO*, respectively.  The gases may ba
  analyzed at less frequent  intervals if
longer shelf 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. Trie 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) (1)
and (c) (2) of this section for measuring
opacity  of  emissions shall complete a
minimum of one cycle of sampling and
analyzing for each 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
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  and (r)
respectively. Six-minute opacity averages
sha'l be ca. -ur jd from 24 or more data
points  equally 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).
   (1) 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 subpart.
                                                           III-8

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   (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
(or 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.

(B*c. 114 of UM CMui Air Aot m unimittt
(U OAC. lMTo-«).).
                                                         Ill-9

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Subpart D—Standard* of Performance
for Fossil-Fuel Fired Steam Generators
 § 60.40   Applicability and dr«ignnllon of
     • Hi .-led facility.
  (a) The afTected facilities to which the
 provisions of this subpart apply are:
  (1) Each fossll-fuel-flred  steam gen-
 erating unit of more than 73 megawatu
 beat  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 megawatts  (250 million
 Btu per hour).
  (b) Any change to an existing fossll-
 fuel-flred  steam  generating   unit  to
 accommodate the use  of  combustible
 materials, other  than  fossil  fuels  a*
 denned in this subpart. shall not bring
 that unit under the  applicability of this
 •ubpart.
  (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, 1911. is subject to I he
 requirements of this subpart.
  (d)     The    requirements    of
 §§60.44(a)(4). (a)(5), (b). and  (d). and
 60.45(f)(4)(vi) are applicable to lignite-
 fired steam, generating units that com-
 menced construction  or modification
 after December 22,1678.
 | 60.41   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.
    "F^ossD 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 b; beat transfer.
    "Wood residue" means bark, saw-
 dust, slabs, chips,  shavings, mill trim,
 and  other wood  products derived from
 wood processing and forest management
 operations.
  (f)  "Coal" means all solid fuels clas-
 sified as anthracite, bituminous, subbi-
 tumlnous, or lignite by the American
 Society  for Testing Material. Designa-
 tion D 388-66.
| 60.42   Standard for parrimUu mu
  (a) On and after the date on which
the performance test required to be con-
ducted by | 00.8 ta completed, no owner
or operator subject to the provisions of
this subpart •hall cause to be discharged
feUo the atmosphere from any affected
facility  any gases which:
  (J) Exhibit greater  than 30 percent
opacity except that a  maximum of 40
percent opacity shall be permissible for
I 60.43   Standard for mMmt diavUU.
  (a) On and after the date on which
the performance test required to be con-
ducted by I 80.8 Is complfUvl. 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 contain sulfur
dfoxide  in excess of:
  (1) 340 nanograms 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-
put (1.2 Ib 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 ng/J)
•hall be determined by proration using
the following formula:
               y(340) +1(520)
where:
  PSpoj ic the prorated standard for sulfur
    dioxide when burning different fuels
    simultaneously,  in  nanograms   per
    }'oulc  heat  input derived from  all
     ossil fuels fired or from all fossil fuels
    and wood residue fired,
  V is the percentage of total beat input
    derived from liquid fossil fuel,  and
  i is the percentage of total heat input
    derived from solid fotail fuel.

   (c) Compliance shall be baaed on the
total beat Input from an fossa fuels
burned, including gaseous fuels.
 10*44  flUndard far
   (a)  On and after the date on which
 tttt performance test required to be con-
 ducted by I 00 & ic 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  contain nitro-
 gen oxides, expressed as NO. In excess of:
   (1) 86 nanograms per joule heat input
 (0.20  Ib per million Btu) derived from
 gaseous fossil fuel or gaseous fossil fuel
 and wood residue.
  (2) 130 nanograms per joule heat In-
put  (0.30 Ib per million  Btu)  derived
from liquid fossil fuel or liquid fossil fuel
and wood residue.
  O> 300 nanograms per joule heat In-
put  (0.70 Ib per million  Btu)  derived
from solid fossil fuel or solid fossil fuel
and  wood residue (except lignite or a
solid fossil fuel containing 25 percent.
by welgbt, or more of coal  refuse).
  (4) 260 nanograms  per Joule  heat
input (0.60 Ib per million B^u).derived
from lignite or lignite and wood resi-
due  (except as provided under para-
graph (a)(5) of this section).
  (5) 340 nanograms  per joule  heat
input (0.80  Ib 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:

  PS*,.- ttKMO) tK8«Hv(130)4*300)
               to tx+v-tx
where:
  PSNO, = is the prorated standard for nitro-
     gen  oxides when  burning  different
     fuels  simultaneously,  in  nanograms
     per joule heat Input derived from all
     fossil fuels fired or from all fossil fuels
     and wood residue fired:
  u'=ls the percentage of total heat input
     derived from lignite;
  x=--is  the percentage of total heat input
     derived from gaseous fossil fuel;
  y--is  the percentage of total heat input
     derived from liquid fossil fuel; and
  z-is the percentage ol total heat input de-
      rived from solid fossil fuel (except lig-
      nite).
  (c) When a fossil fuel containing at
least 25  percent,  by weight,  of  coal
refuse is burned in  combination  with
gaseous, Jlquicl. or  other solid  fossil
fuel or wood residue, the standard for
nitrogen oxides docs not apply.
  (d) Cyclone-flrod  units which  burn
fuels containing at least 25 percent of
lignite that is mined In North Dakota,
South  Dakota, or  Montana remain
subject to paragraph (a)(5) of this sec-
Lion regardless  of the  types of  fuel
combusted in combination with  that
lignite.
  | 60.45  Emission and fed monitoring.
   (a) Each owner or operator shall in-
 stall, calibrate,  maintain, and operate
 continuous monitoring systems for meas-
 uring the  opacity of emissions,  sulfur
 dioxide emissions, nitrogen oxides emis-
 sions, and  either oxygen  or carbon di-
 oxide except as  provided  in paragraph
 (b) of this section.
                                                    111-10

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   (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 fossO fuel-fired steam gen-
 erator  that burns  only  gaseous fossil
 fuel, continuous monitoring systems for
 measuring the opacity of emissions and
 sulfur  dioxide  emissions are  not  re-
 quired.
   <3>  For a fossO fuel-fired steam gen-
 erator that does not use a flue gas de-
 •ulf urtzation 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.
   (8)  Notwithstanding  |60.13(b). in-
 stallation of a continuous monitoring
 system for nitrogen oxides may be de-
 layedtintil after the Initial performance
 tests under I 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
 one year after the date of the initial per-
 formance tests under I 60.8 and comely
 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  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  checks
 under |60.13(d), the following proce-
 dures shall be used:
   (1)  Reference Methods 6 or 7, as ap-
 plicable, .shall be used  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-
all fuel(s). the span  value for a continu-
ous monitoring system  measuring the
opacity of emissions shall be  80. BO.  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 parti pw mffliao]
  r+i.ooD>
  • N« appUcahte.
 where:
 »—tbc tnetlOD at total heat Input derived
   tram giaeoua foull fuel, and
 j — the fraction of total beat Input derived
   from liquid foull fuel, and
 c-tbe fraction of total beat Input derived
   Irom eolid IOMU rod.
   (4) All spab  values computed under
 paragraph  (c)(3)  of this  section  for
 burning combinations of fossil fuels shall
 be rounded to the nearest 500 ppm.
   (5) For a  fossil fuel-fired steam gen-
 erator that simultaneously burns fossil
 fuel and  nonfossil  fuel, the  span value
 of all continuous  monitoring  systems
 shall be  subject  to the Administrator's
 approval.
   (d)  (Reserved!
   (e) For any  continuous  monitoring
 system Installed under paragraph (a) of
 Chic section, the following  conversion
 procedures shall  be used to convert  the
 continuous monitoring data into units of
 the applicable standards (ng/J. Ib/mil-
 lionBtu):
   (1) When  a  continuous   monitoring
 system for measuring oxygen  is selected.
•the measurement of the pollutant con-
 centration and  oxygen  concentration
 ahall each be on  a  consistent basis (wet
 or dry). ^Alternative procedures  ap-
 proved by the Administrator  shall be
 used when measurements are on a wet
 basis. When measurements are on a dry
 basis, the following  conversion procedure
 ahallbeused:

       K-CF f      209      1
           C  L 20.9-percent Oj

 where:
 K. C. F. and StO. are determined under para-
   graph (f) of til* aertton

   (2) When a  continuous  monitoring
 system for measuring carbon dioxide is
 •elected,  the measurement of  the  pol-
 lutant concentration and carbon dioxide
 concentration shall each  be  on • con-
 sistent basis (wet or dry) and the fol-
 lowing conversion  procedure  shall be
 used:

         E-CF f    10°    1
         K ~ C'CL percent  CO, J
 where:
 X. C, Ft  and %CO. we determined under
   paragraph (f) of thbeecuon.

   (f) The values used in the equations
 under paragraphs (e> (!) and (2) of thi-v
 •action are derived as follows:
   (1) C'pollutant emissions. ng/J (lb/
 million Btu).
    (2) C=pollutant  concentration, ng/
 dscm (Ib/dscf), determined by multiply-
 ing the average concentration  for
 each one-hour period by 4.15x10* M ng/
 dscm  per  ppm  (2.59x10-'  M Ib/dscf
 per ppm)  where Af=pollutant molecu-
 lar weight, g/g-mole (lb/lb-mole>. Af=
 64.07 for sulfur dioxide and 46.01 for ni-
 trogen oxides.
    (3) %O;.. %CO=  oxygen  or carbon
 dioxide volume (expressed as percent),
 determined with equipment specified un-
 der paragraph  (d)  of this section.
    (4) 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 repre-
 senting a ratio of the volume of carbon
 dioxide generated to  the calorific valur
 at of the fuel  combusted (F.),  respective-
 ly. Values of  T and F. are given as fol-
 lows:
   (1)  For anthracite coal as classified
 according  to A.8.T.M.   D 38B-86  F=
 2.723x10'  dscm/J  (10.140 dscf/million
 Btu>  and F.«»O.S32xlO-' scm  CO,//
 U.980 scf CO,/mlllion Btu).
   (Hi For subbltumlnous and  bituminous
 coal as classified according to  A B T M  D
 388-66.   F=2 637X10'   dscm/J  (9820
 dscf/mllllon  Btu)  and  Fc=0 486x 10'1
 •cm COi/J (1.810 acf COj/milllon Btu)
   (111)  For liquid fossil  fuels including
 crude,   residual,  and   distillate   oils.
 F~ 2.476 xlO-* dscm/J (9.220 dscf /mil-
 lion Btu) and F.=0484X10' acm (XVJ
 (1,430 scf COi/mllllon Btu)
   (Iv) For  gaseous .fossil fuels.  F= 2.347
 XIO^ d*on/J( 8.740 dscf/million Btu).
 For natural  gas. propane, and butane
 fuels. F,=0.279xlO'  acm COt/J U.040
 acf COi/mllllon Btu) for  natural  gas.
 0.322X10-1 Km COt/J  (1,200 scf  COj/
 million Btu) for propane, and 0.338 x 10 '
 scm COi/J u.260 scf COi/million Btu)
 for butane.

  (T) For bark F—2.589X10-*  (tectn/J
(9,640  dscf/milllon Btu)  and  F,=0.500
X10-' scm CO./J (1.860 scf CO,/milUon
Btu). For wood residue other than bark
F=2.492x 10"'dscm/J (9,280 dscf/a»Ulion
Btu)  and F,-= 0.494X10" acm  OCVJ
(1-840 SCf COi/mllllnn  Rtiit
   (vl) For  lignite coal  as classified ac-
 cording   to   A.S.T.M.  D   388-W.
 F=2.659xlO-»  dscm/J (9900 dscf/mU-
 •lion Btu) and Fc=0.516x 10~' scm CO,/
 J (1920 scf CO,/million  Btu).
    (5) The owner or operator may use the
 following equation  to determine  an  F
 factor  (dscm/J or dscf/million  Btu) on
 a dry basis (if It is desired to  calculate  F
 on a wet basis, consult the Administra-
 tor) or F, factor (scm COa//, or scf COi/
 million Btu) on either basis in lieu of the
 F  or F,  factors specified in  paragraph
 (f)(4>  of this section:
                                                     iii-n

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        1227.2 (pet. H)+95.5 (pet. Q + 35.6 (pel. S)+8.7 (pet. N)-28.7 (pet. O)l
                                        GCV

                                    (SI units)

          .  10'13.64(7e//)-H.53(%C)40.S7(%S)-t-O.U(%/y)-0.46(%O)l
                                        GCV

                                  (English units)

                             _   2.0X1Q-* (pet, o
                             r'~      ocv

                                    (SI units)

                               '     321X10»(%C)
                               f'~GCV

                                  (English unite)
  (t)  H. C. B. N. and O art content by
weight of hydrogen, carbon, sulfur, ni-
trogen,  and oxygen (expressed  as  per-
cent) . respectively, ai determined on the
Mr»» bads a* OCV by ultimate analysis
of the fuel fired, using AJS.T.M. method
D3 178-74 or D3178 (solid fuels) . or com-
puted from results using A.B.T.M. meth-
ods   D1137-53C70).  Dl»45-64(73>,  or
DlM6-67(72> (gaseous fuels) as applica-
ble.
   (II) OCV  is the gross calorific  Talue
 (kJ/kg  Btu/lb) of the fuel  combusted.
 determined by the A.S.T.M. test methods
 D 2015-66(72) for solid fuels and D 182ft-
 64(70)  for gaseous fuels as applicable.
   (Ill)  Ffcr affected facilities which  fire
 both fossU 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) of
 this section  shall be prorated In accord-
 ance with the applicable formula as fol-
 lows:
   (g) For the purpose of reports required
under ! 60.7(c). periods of excess emis-
sions that  shall be reported are denned
as follows:
'   (1)  [Reserved!
   (2) Bulfur dioxide.  Exc*ss emissions
for affected facilities are denned as:
   (1) Any   three-hour  period   during
which the  average emissions (arithmetic
average of three contiguous one-hour pe-
riods) of sulfur dioxide as measured by a
continuous monitoring system exceed the
applicable standard under { 60.43.
   (11) [Reserved!
   (3) Nitrogen oxides. Excess emissions
for affected facilities using a continuous
 monitoring system for measuring nitro-
 gen oxides are denned as any three-hour
 period during which  the average emis-
 sions (arithmetic average of three con-
 tiguous one-hour periods) exceed the ap-
 plicable standards under S 60.44.
  (Sac. 114 of the dean Air Act a»
  (41 U.8.C. l«7e-«).).
 vtaere:
        Jti = Uie fraction of total beat Input
              derived from each type of fuel
              (c.g  natural ga>. bltumlooui
              coal, wood residue, etc.)
 Ft or (f«)i=U>e applicable F or F< factor for
              each fuel type determined In
              accordance  with paragraph*
              (f)(4)  and  (f)(5)  ol tnu
              aectlon.
         •=tbe  number   of  fuels  being
              burned In combination.
                                   References:

                                      60.2
                                      60.7
                                      60.8
                                      60.11
                                      60.13
                                      Reference  Methods  6,  7,
                                      Specifications  1.  2.  3
                                                       111-12

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  Authority: Sec. 111. 301 (n) of the Clean Air
Act as amended (42 U.S.C. 7411.7801(n)). and
additional authority as noted below.

Subpart Da—Standard* of
Performance for Electric Utility Steam
Generating Unite for Which
Construction Is Commenced After
September 18,1978

960.40a  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 Bale 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 D388-66.
  "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 9without emission
control systems) and:
  (a) For particulate 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
with one or more electric power
interconnections to the principal
company and which have
geographically adjoining service areas.
   "Net system capacity" means the sum
of the net electric generating oapability.
(not necessarily equul 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
                                                    111-13

-------
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 H
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 for particulate 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 lo the
provisions ot this subpart s;:;:;. uuu.,t. >~
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 from 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/I (1.20 Ib/miilion 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/million 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 Ihc polwiliiil
combustion conccntrution fxorn  pc/ccul
reduction) when emissions an; less Ihun
86 ng/J (0.20 Ib/million Bin) hcnl inpul.
  (c) On  and after the ddle on which the
iniliiil performance Icsl required to be
                                                     111-14

-------
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
£„, = [340 x + 520 y]/100 and
PSO, = 10 percent

  (2) If emissions of sulfur dioxide to the
atmosphere are equal to or less than 260
ng/J (0.60 Ib/million Btu) heat input:
Ego, = [340 x +  520 y]/100 and
PSO, = [90x + 70y]/100
where:
ESO, is the prorated sulfur dioxide emission
    limit (ng/J heat input),
PSO, is the percentage of potential sulfur
    dioxide emission allowed (percent
    reduction required = 100—PSO,).
x is the percentage of total hen! input derived
    from the combustion of liquid or gaseous
    fuels (excluding solid-derived fuels)
y is (ho percentage of total heal input 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 Bmrt
 ng/J Ob/mWon Btu)
    heat input
Gaseous Fuels:
   CoaMerlved fuels „
   AO other fuels	
Liquid Fuels:
   Coal-derived fusts..
   Shale oi	
   All other fuels...
Solid Fuels:
   Coal-dertndfuets	
   Any Iu6l cofltflWnQ morB thsn
     25%, by weight, coal refuse..
    210
     86

    210
    210
    130

    210
(0.50)
(0.20)

(0.50)
(0.50)
(0-30)

(0.60)
Exempt from NO,
 standards and NO.
   Any fuel containing more than
     25%. by weight, ngntte if the
     Ignite Is mined In North
     Dakota. South Dakota, or
     Montana, and is combusted
     In a stag lap furnace	
   Ugnrte no* subject to the 340
     ng/J heal Inpul emission Omit

   Bituminous coal	
   Anthracite coal...
   AD other fuels...
                         fOQutrofnonts
     340

     260
     210
     260
     260
     260
(0.80)

(0.60)
(0.50)
(0.60)
(0.60)
(0.60)
   (2) NO, reduction requirements—
         Fuel type
  Percent reduction
    of 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:
EKO, = (88 w+130 x+210 y+280 zJ/100
where:
RN(I IB the .-ipplicabli: standard Tor nitrogen
    oxides when multiple fuels are
    combusted simultaneously (ny,/) heat
    Input):
w is the percentage uf total heat Input
    derived from the combustion of fuels
    subject to the 86 ng/| 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/I heat input standard; and
2 is the percentage of total heat Input derived
    from the combustion of fuels subject to
    the 260 ng/I 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 Administra'tor,
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 SOa emission reduction
requirements under § 60.43a(c) but must,
as a minimum, reduce SOi 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 SOi
emission reduction requirements under
§ 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)
                                                       111-15

-------
 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.
       Tooftootofly
         Equivalent
         electrical
Podutar*    capacity
        (MW electric*
          output)
 SoH aotewttoaned coal
 FliAltoBd faafl pofnbustlon
  (aftnoapfearic)-
 FUdbad bod covnbuatioft
  (pfmnni^wty .... — »_.—.
 Coal IquMcaian
    SO, 6.000-10.000

    SO,   400-3,000
    so.
    NO.

 400-1.200
750-10.000
                                  15.000
 §6d48a Comptanc* provision*.
  ^(a) Compliance with the particulate
 matter emission limitation under
 S 60.42a(a)(l) constitutes compliance
 with the percent reduction requirements
 for particulate matter under
 5 eo.42a{a)(2) and (3).
  (b) Compliance with the nitrogen
 oxides emission limitation under
 S 60.44a(a) constitutes compliance with
 the percent reduction requirements
 under i 6ft.44a(a)(2).
  (c) The. particulate matter emission
 standard*, under { 60.42a and the
 nitrogen oxides emission standards
 under S 80.44a apply at all times except
 during periods of startup, shutdown, or
 malfunction. The sulfur dioxide emission
 standards, under 8 60.43a apply at all
 times except during periods of startup,
 shutdown* or when both emergency
 conditions exist and the procedures
 under paragraph (d) of this section are
 implemented.
  (d) During emergency conditions in
 the principal company, an affected
 facility with a malfunctioning flue gas
 deaulfuriz|tion system may be operated
 if sulfur dioxide emissions are
 minimized] by:
  (1) Operating all operable flue gas
 desulfurization system modules, and
 bringing back into operation any
 malfunctioned module as soon as
 repairs are completed,
  (2) Bypassing flue gases around only
 those flue gas desulfurization system
 modules that have been taken out of
 operation because .they were incapable
 of any  sulfur dioxide emission reduction
or which would nave suffered significant
physical damage if they had remained in
operation, and
  (3) Designing, constructing, and
operating a spare flue gas
desulfurization system module for an
affected facility larger than 365 MW
(1.250 million Btu/hr) heat input
(approximately 125 MW electrical
output capacity). The Administrator
may at his discretion require the owner
or operator within BO days of
notification to demonstrate spare
module capability. To demonstrate this
capability, the owner or operator must
demonstrate compliance with the
appropriate requirements under
paragraph (a), (b), (d), (e), and (i] under
 § 60.43a for any period of operation
lasting from 24 hours to 30 days when:
  (i) Any one flue gas desulfurization
module is not operated,
  (ii) The affected facility is operating at
the maximum heat input rate,
  (iii) The fuel fired during  the 24-hour
to 30-day period is representative of the
type and average sulfur content of fuel
used over a typical 30-day period, and
  (iv) The  owner or operator has given
the Administrator at least 30 days notice
of the date and period of time over
which the demonstration will be
performed.
  (e) After the initial performance test
required under § 60.8, compliance with
the sulfur dioxide emission limitations
and percentage reduction requirements
under  { 60.43a and the nitrogen oxides
emission limitations under { 60.44a is
based on the average emission rate for
30 successive boiler operating days. A
separate performance test is completed
at the end  of each boiler operating day.
after the initial performance test, and a
new 30 day average emission rate for
both sulfur dioxide and nitrogen oxides
and a new percent reduction for sulfur
dioxide are calculated to show
compliance with the standards.
  (f) For the initial performance test
required under § 60.8. compliance with
the sulfur dioxide emission limitations
and percent reduction requirements
under § 60.43a and the nitrogen oxides
emission limitation under S 60.44a is
based on the average emission rates for
sulfur dioxide, nitrogen oxides, and
percent reduction for sulfur dioxide for
the first 30 successive boiler operating
days. The initial performance test is the
only test In which at least 30 days prior
notice is required unless otherwise
specified by the Administrator. The
initial performance test is to be
scheduled so that the first boiler
operating day of the 30 successive boiler
operating days is completed 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 m me
facility.
  (g) Compliance is determined by
calculating the arithmetic average of all
hourly emission rates for SOi and NO,
for the 30 successive boiler operating
days, except for data obtained during
startup, shutdown, malfunction (NO.
only), or emergency conditions (SOi
only). Compliance with the percentage
reduction requirement for SO, is
determined based on the average inlet
and average  outlet SOt emission rates
for the 30 successive boiler operating
days.
  (h) If an owner or operator has not
obtained the minimum quantity of
emission data as  required under S 60.47a
of this subpart, compliance of the
affected facility with the emission
requirements under §§ 60.43a and 60.44a
of this subpart for the day on which the
30-day period ends may be determined
by  the Administrator by following the
applicable procedures in sections 6.0
and 7.0 of Reference Method 19
(Appendix A).

§ 60.47a  Emission monitoring.
  (a) 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
opacity of emissions discharged to the
atmosphere,  except where gaseous fuel
is the only fuel  combusted. If opacity
interference due to water droplets exists
in the stack (for example, from the use
of an FGD  system), the opacity is
monitored upstream of the interference
(at the inlet to the FGD system). If
opacity interference  is experienced at
all  locations  (both at the inlet and outlet
of the sulfur dioxide  control  system),
alternate parameters indicative of the
particulate matter control system's
performance are monitored (subject to
the approval of the Administrator).
  (b) 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
sulfur dioxide emissions, except where
natural gas is the  only fuel combusted.
as follows:
  (1) Sulfur dioxide emissions are
monitored at both the'inlet and outlet of
the sulfur dioxide control device.
  (2) For a facility which qualifies under
the provisions of S 60.43a(d), sulfur
dioxide emissions are only monitored as
discharged to the  atmosphere.
  (3) An  "as fired" fuel monitoring
system (upstream of coal pulverizers)
meeting the requirements of Method 19
(Appendix A) may be used to determine
                                                    111-16

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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 8 60.13(h) are
expressed in ng/J.(lbs/million Btu) heat
input and used to calculate the average
emission rates under 8 60.46a. The 1-
hour averages are calculated using the
data points required under 8 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 8 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 SOi 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
8 60.l3(c) and calibration checks under
8 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 2 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 60
percent and for a continuous monitoring
system measuring nitrogen oxides is
determined as follows:
        Foot fuel
                         Span vakM tor
                       nitrogen
 Gas.
 SoU....
 Contain
                                   500
                                   500
                                  1,000
 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
 c 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 ,contror
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, Cluan Air Act as amended (42
U.S.C. 7414).)

§ 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 8 60.42a.
   (1) Method 3 is used for gas analysis
when applying method 5 or method 17.
   (2) Method 5 is used for determining
particulate 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 Miter
holder heating system in the sampling
 train is set to provide a gas temperature-
no greater than 160°C (32°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'Fe-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 desulfurixation system.
   (b) The following procedures and
methods are used to determine
compliance with the sulfur dioxide
standards under 8 60.43a.
   (1) Determine the percent of potential
combustion concentration (percent PCC)
emitted to the atmosphere as follows:
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  (i) Fuel Pretreatment (% R/J:
Determine the percent reduction
achieved by any fuel pretreatment 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
§ 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 Contrdl System (%
fifj: Determine the percent sulfur
dioxide reduction achieved by any
sulfur diojtide 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 k'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 (% Ro):
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 (% PCC):
Calculate the percent of potential
combustion concentration emitted to the
atmosphere using the following
equation: Percent PCC=100-Percent RO
  (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
paniculate 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 CG.
The potential uncontrolled particulate
matter emission rate from a gas turbine
is defined as 17 ng/J (0.04 Ib/million Btu)
heat input.

5 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 period.
  (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 "F" 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 § 60.46a(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 (n,) 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 (£,,*) 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
(Eo*)  and the allowable emission rate
(EM,,)  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
§ 60.48a(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;
  (v)  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 § 60.43a is claimed, the owner or'
operator of the  affected facility shall
submit a signed statement:
1  (1) Indicating what percentage
cleaning credit was taken for the
calendar quarter, and whether the credit
was determined in accordance with the
                                                    111-18

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provisions of § 60.48a and Method 19
(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 pretreatment 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
mininnirfi 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.  All quarterly reports
shall be postmarked  by the 30th day
following  the end of each calendar
quarter.
(Sec. 114. Clean Air Act as amended (42
U.S.C. 7414).)
  4. Appendix A to part 60 is amended
by adding new reference Method 19 as
follows:
Appendix A—Reference Methods
Method 19. Determination of Sulfur
Dioxide Removal Efficiency and
Particulate, 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
dioxide (ng/joule. Ib/million Btu)
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  Particulate, 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
particulate, 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 each
raw coal lot and one gross sample for
each product coal lot.
  2.1.2  ASTM Lot Size. For the purpose
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 die  raw coal and
product coal.
  Note.—Alternate definitions of fuel Jot
sizes may be specified subject to prior
approval of the Administrator.
  2.1.3   Cross Sample Analysis.
Determine the percent sulfue 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  Lot Size. For the purposes of
Section 2.2.1, the weight of product fuel
from one pretreatment facility and
intended as one shipment (snip 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 aa the
fuel delivered to the desulhirtzatton
pretreatment facility or to the steam
generating plant. For pretreated oil the Input
oil to the oil desulfurization process (e.g.
hydrotreatment emitted) is 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.
  1 Use the moit recent revision or designation of
the ASTM procedure specified.
  1 Use the most recent revision or designation of
the ASTM procedure specified.
                                                     111-19

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   2.3  Calculation of Sulfur Dioxide
 Removal Efficiency Due to Fuel
 Pretreatment. Calculate the percent
 sulfur dioxide reduction due to fuel
 pretreatment using the following
 equation:
             100
 Where:
 %R(=Sulfur dioxide removal efficiency due
    pretreatment; percent.
 %S£1=Sulfur content of the product fuel lot on
    a dry basis; weight percent.
 %S,=Sulfur content of the inlet fuel lot on a
    dry basis; weight percent.
 GCV0= 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; k)/kg (Bta/lb).
   Note.—If more than one fuel type is used to
 produce the product fuel, use the following
 equation to calculate the sulfur contents per
 unit of heat content of the total fuel lot, %S/
 GCV:
    ss/scv
                  n
                  £
                 k=1
 Where:
 Yk=The fraction of total mass input derived
    from each type, k, of fuel.
 %Sk=Sulfur content of each fuel type, k, on a
    dry basis; weight percent
 GCVk=Gross calorific value for each fuel
    type, k, on a dry basis; kj/kg (Btu/lb).
 n=The number of different types of fuels.

 3. Determination of Sulfur Removal
 Efficiency 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 methods specified in the
 applicable subpart of the regulations
 and the procedures specified in Section
 5. The inlet sulfur dioxide emission rate
may be determined through fuel analysis
 (Optional, see Section 3.3.)
  3.2.  Calculation.  Calculate the
percent removal efficiency using the
following equation:
• -SR,    »   100  x  (1.0   -
                                         Where:
                                         %R, = Sulfur dioxide removal efficiency of
                                             the sulfur dioxide control system using
                                             inlet and outlet monitoring data; percent.
                                         Ego 0=Sulfur dioxide emission rate from the
                                             outlet of the sulfur dioxide control
                                             system; ng/] (Ib/million Btu).
                                         Eso i=Sulfur dioxide emission rate to the
                                             outlet of the sulfur dioxide control
                                             system; ng/J (Ib/million Btu).
                                           3.3   As-fired Fuel Analysis (Optional
                                         Procedure). If the owner or operator of
                                         an electric utility steam generator
                                         chooses to determine 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 collected
                                         in accordance with applicable
                                         paragraph in Section 2. The sampling
                                         can be conducted upstream of any fuel
                                         processing, e.g., plant coal pulverization.
                                         For the purposes of this section, a fuel
                                         lot size is defined as the weight of fuel
                                         consumed in 1 day (24 hours] and is
                                         directly related to the exhaust gas
                                         monitoring data at the outlet of the
                                         sulfur dioxide control system.
                                           3.3.1  Fuel Analysis. Fuel samples
                                         must be analyzed for sulfur content and
                                         gross calorific value. The ASTM
                                         procedures for determining sulfur
                                         content are defined in the applicable
                                         paragraphs of Section 2.
                                           3.3.2  Calculation of Sulfur Dioxide
                                         Input Rate. The sulfur dioxide imput rate
                                         determined from fuel analysis is
                                         calculated by:
               2.0(*S.)       ,
                     T    x 10'
                                                                           for S. I. units.
                                                                   x 10    for English units.
                                          Where:
     I    * Sulfur dioxide input rate from as-fired  fuel  analysis,

            ng/J (1b/m1111on Btu).

     XSf  - 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).

  3.3.3  Calculation of Sulfur Dioxide     3.3.2 and the sulfur dioxide emission
Emission Reduction Using As-fired Fuel   rate, ESOJ. determined in the applicable
Analysis. The sulfur dioxide emission      paragraph of Section 5.3. The equation
reduction efficiency is calculated using     for 8ulfur dioxide emission reduction
the sulfur imput rate from paragraph    '   efficiency is:
       Rg(f)  '
                                                           100  x   (1.0  -
                                                                             'SO,
                                          Where:

                                               *Rq(f)  " Sulfur 
-------
 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 redaction as:

      «    -   looci.o.
Where:

      W   » Overall sulfur dioxide  reduction; percent.

      SRf  • Sulfur dioxide removal  efficiency of fuel pretreataent

             fro* Section 2; percent.   Refer to applicable subpart

             for definition of applicable averaging period.

      IR   • Sulfur dioxide removal  efficiency of sulfur dioxide  control

             device either 0. or C02 - based calculation or calculated

             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, and Nitrogen Oxides Emission
Rates
and oxygen concentrations have been
determined in Section 5.1, wat or dry P
factors are used. (Fw) factors jand
associated emission calculation
procedures are not applicable and may
not be used after wet scrubbers; (Pc) or
(Fd) factors and associated emission
calculation procedure* are used after
wet scrubbers.) When pollutant and
carbon dioxide concentration) have
been determined In Section 54, Pc
factors are used.           i
  5.2.1  A verage FFactors, table 1
shows average P* F*. and Fe factors
(scm/I, Bcf/ntlllion Btu) detertnined for
commonly used fuels. For fuels not
listed in Table 1, the P factors .are
calculated according to the procedures
outlined in Section 5.2.2 of this section.
  6.2.2  Calculating an P Factor. If the
fuel burned is not listed in Table 1 or if
the owner or operator choose* to
determine an P factor rather (ban 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.
  5.1  Sampling. Use the outlet SO» or
Oi or COs concentrations data obtained
in Section 3.1. Determine the paniculate,
NO,, and Oi 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, tiie selected or calculated'F factors
are prorated using the procedures in
Section 5.Z3. 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 i' the ratio of
the volume of dry flue gases generated
to the calorific value of the fuel
combusted; a wet F factor (Fw) is  the
ratio of the volume of wet flue 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
of the fuel combusted When pollutant
 For SI Units:
            Z27.0(1H) + 95.7(«C) * 35.4(«3) * 8.6(30  -  28.5(tO)
                                   SCV
            347.4(SH)+95.7(XC)+35.4(tS)+8.6(tn)-28.S(«0)+13.0{tH20)<
For English Units:
Fd
F-
Fc
. 106[5.57(*H) +
106[5.57(SH)-H
._ 106[0.321(tC)]
scv
1.53(tC) * 0.57(tS) * 0.14(tt) - 0.
.53(lC)+O.S7(tS)+0.14(IN)-0.46(JO)+0
6CVW
46(SO>]
.ardHjO

 The XHjO tern may be OBltted If XH and SO Include  the unavailable
hydrogen and oxygen in the forn of H.O.
                                                    HI-21

-------
Where:
Fa, Pw, and Pe 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 per- rant) of hydrogen,
    carbon, sulfur, 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* for liquid fuels, and D1826' for
    gaseous fuels as applicable in
    determining GCV.
  5.2.3   Combined Fuel Firing FFactor.
for affected facilities firing
combinations of fossil fuels or fossil
fuels and wood residue, the Fd, F^, or Fe
factors determined by Sections 5.2.1 or
5.2.2 of this section shall be prorated in
accordance with applicable formula as
follows:
                                        r
                                        L
          n
          £- x
k Fdk
                  wk
                       or
               2079 - S02(JJ

  5.3.1.2  Wet Basis. When both the
percent oxygen (%O»») and the pollutant
concentration (Cw) are measured in the
flue gas on a wet basis, the following
equations are applicable: (Note: Fw
factors are not applicable after wet
scrubbers.)
Where:
xk=The 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, SOS, and NO,
emission rate. The values in the
equations are defined as:
E=Pollutant emission rate, ng/J (Ib/million
    Btu).
C=Pollutant concentration, ng/scm (Ib/scf).
  Note,—It IB necessary in some cases to
convert measured concentration units to '
other units for these calculations.
  Use the following table for such
conversions:
     Convereton Peetore for Concentration

     From—          To—       Multiply b»—

g/Gcfn	 riQ/scfn	_.«».        10*
mg/8cfn	„.	 ng/scfn	....................        10*
fb/scf	„	 rtg/ecm		   1.602x10u
Ppm(SCU	 ng/scm	   2.680x10*
ppm(KOJ		 ng/cem	   1.812x10*
ppm/(SOJ......		 to/ccf	   1.680x10"'
ppm/(NOJ	.'.		 a>/ed		   1.194x10-'

  5.3.1  Oxygon-Based F Factor
Pnn:udure.
  5.3.1.1   Dty Basis. When both percent
oxygen (%O«d) and the pollutant
concentration (Cy are measured in the
flue gas on a dry basis, the following
equation is applicable:
                           (a)    E  - C  F   [;
                                                    20.9
                                              20.911 - B,,,) -
                                        Where:
                                        8,,=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    	»
X20.9(l  - Bwa) - S02ws'

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) BVI=0.027. This factor may be used
as a constant value at any location.
   (ii) Bn=Highest monthly average of
Bm which occurred within a calendar
year at the nearest Weather Service
Station.
   (iii) Bwa=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)
       E  " C«F
-------
              xsg

Where:
£„ = Pollutant emission rate from steam
    generator effluent, ng/J (Ib/million Btu).
EC = Pollutant emission rate in combined
    cycle effluent; ng/J (Ib/million Btu).
£0=Pollutant emission rate from gas turbine
    effluent; ng/| (Ib/million Btu}.
X^=Fraction of total heat input from
    supplemental fuel fired to the steam
    generator.
Xn = Fraction 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
supplemental fuel fired to the steam
generator and the heat input  to the steam
generator from the exhaust gases from the
gas 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.
                        Table \*-\.—F Factors tor Various fuels'
                                                  F.
        Fuel type
                         dscm
                          J
                                   dscf
                                  10* Btu
wscrn
 J
 wscf
10* Btu
scm
 J
 scf
10* Btu
Coal;
Anthracite* 	
BltumJnoue*
Ugrite 	 __ 	
Oil*... 	 	 	 _ 	
Gas:
Natural 	

Butane 	 _ ._ 	 	
Wood
Wood Bark

• A* dandled accordbia to AST1
2.71 x 10-
263x10*
2.65x10-
2.47x10-
2.43x10"
2.34x10"
234x10'
2.48x10"
2,56x10-

* 0388-66.
(10100)
(9780)
(9860)
(9190)
(8710)
(8710)
(8710)
(9240)
(9600)


2.83x10-'
288x10"'
3.21x10"'
2.77X10"'
2.85x10-'
2.74X10'*
2.79x10"'




(10540)
(10840)
(11950)
(10320)
(10610)
(10200)
(10390)




0.530x10''
0484x10"'
0.513X10"'
0.383X10-'
0.287x10"'
0321X10"'
0.337X10"'
0492X10"'
0497X10"'


(1970)
(1800)
(1910)
(1420)
(1040)
(1190)
(1250)
(1B3CA
(18501


   • Crude. reeldual. or cMMata
   •Determined at standard condition*: 20* C (68*.F) and 760 mm Hg (29.92 In. Hg).
6. Calculation of Confidence Limits for
Inlet and Outlet Monitoring Data

   6.1  Mean Emission Rates. Calculate
the mean emission rates using hourly
averages in ng/J  (Ib/million Btu) for SO,
and NO. outlet data and, if applicable,
SO, inlet data using the following
equations:
                                           6.2  Standard Deviation of Hourly
                                         Emission Rates. Calculate the standard
                                         deviation of the available outlet hourly
                                         average emission rates for SO, and NO,
                                         and, if applicable, the available inlet
                                         hourly average emission rates for SO,
                                         using the following equations:
 1         n,

Where:
E,,=Mean outlet emission rate; ng/J (lb/
    million Btu).
E|=Mean inlet emission rate; ng/J (Ib/million
    Btu).
XB=Hourly average outlet emission rate; ng/J
    (Ib/million Btu).
Xi=Hourly average in let emission rate; ng/j
    (Ib/million Btu).
n^=Number of outlet hourly averages
    available for the reporting period.

n,=Number of inlet hourly averages
    available for reporting period.
                                       Where:
                                       80=Standard deviation of the average outlet
                                          hourly average emission rates for the
                                          reporting period: ng/J (Ib/million Btu).
                                       BI= 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 confidence limit for the mean
                                       outlet emission rates for SO»and NO.
                                       and, if applicable, the upper confidence
                                       limit for the mean inlet emission rate for
                                       SO* using the following equations:
                                                PCC
                                                PCC
                                                           '1
              V*2
                                          Where:
                                       E,*=E,+t0.Ms1
                                       Where:
                                       Eo*=The lower confidence limit for the mean
                                          outlet emission rates; ng/J (Ib/million
                                          Btu).
                                       E/=The upper confidence limit lor the mean
                                          inlet emission rate; ng/J (Ib/million Btu).
                                       U.««= Values shown below for thje indicated
                                          number of available data points (n):
       n
       2
       3
       4
       S
       6
       7
       e
       a
      10
      11
    12-18
    17-21
    22-26
    27-31
    32-61
    52-01
   92-151
152 or more
                                                                                                 Value* tor tw.
 6.31
 2.42
 2.35
 2.13
 2.02
 1.94
 1.89
 1.88
• 1.83
•• 1.81
 1.77
 1.73
 1.71
 1.70
 1.86
 1.87
 148
 1.6S
                                       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 pretreatment (% R,) is
                                       included in the overall reduction in
                                       potential sulfur dioxide emissions (% RJ
                                       and the "as-fired" fuel analysis is not
                                       used, the potential combustion
                                       concentration (PCC) is determined as
                                       follows:
                        fi s,    i s:.
              ^**«  Iwr-rf
                  '1

                _    xs^
               ^CTI "  sCig
                              107; ng/J
                    10 ; Ib/mill1on  Btu.
                                                                Potential  emissions removed by the  pretreatment
                                                                process, using the fuel  parameters  defined In
                                                                section 2.3;  ng/J (Ib/m11l1on Btu).
                                                        111-23

-------
  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 sulfur dioxide emissions (%
RO), the potential combustion
concentration (PCC) is determined as
follows:
PCC = I.
    Where:
    I,—The *ulfar dioxide input rate as denned
        in section 3.3
      7.1.3  When die "as-fired" fuel
    analysis Is used and the removal
    efficiency due to fuel pretreatment [% R,)
    is included in the overall reduction (%
    RO), 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 (% R,) is not included
in the overall'reduction in potential
sulfur dioxide emissions (% RO), the
potential combustion concentration
(PCC) is determined as follows:
PCC = E,'
Where:
EI* = The upper confidence limit of the mean
    inlet emission rate, aa determined in
    section 6.3.

  7.2  Determine Allowable Emission
Rates (Eaa).
  7.2.1  NOV Use the allowable  %
emission rates for NO, as directly
defined by the applicable standard in
terms of ng/J (Ib/million Btu).
  7.2.2  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/m1l11on Btu.

    is used as E^. If the applicable standard
    is an allowable percent emission,
    calculate the allowable emission rate
    (E,td) using the following equation:
    Where:
    % PCC = Allowable percent emission as
        defined by the applicable standard-
        percent.

      7.3  Calculate £> ' /E*». To determine
    compliance for the reporting period
    calculate the ratio:
    Where:
    E,, -= The lower confidence limit for the
        mean outlet emission rates, as defined in
        section 6.3: ng/J (Ib/million Btu).
    Eaa — Allowable emission rate as defined in
        section 7.2; ng/J (Ib/million Btu).
   .   If Eo'/Biu >s equal to or less than 1.0, the
    facility is in compliance: if Eo*/Ew«i is greater
    than 1.0, the facility is not in compliance for
    the reporting period.
    |FR Doe. 79-17807 Filed 8-B-7ft KM an]
    BIUMQ CODE •660-0 t-M
                                                     111-24

-------
 •ubpart Q—Standards of Ptrformanc* for
           Nitric Add Plant*
 g 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.
  (b) Any facility under paragraph (a)
 of this section that commences construc-
 tion or modification after August 17.
 1971. is subject to the  requirements of
 thte tubpart.
160.71  Definition*.
  As used In this subpart, all terms not
defined herein  shall have the meaning
given them in toe Act and in Subpart A
of this part.
  (a) "Nitric  add  production  unit"
means any facility producing weak nltrto
acid by either  the pressure  or atmos-
pheric pressure process.
   (b)  -Weak nitric acid" means add
which Is SO to 70 percent In strength.
be determined by dividing the reference
method test data averages by the moni-
toring data averages to obtain a ratio ex-
pressed in units of the applicable stand-
ard to units of the monitoring data. l.e..
kg/metric ton per ppm (Ib/short ton per
ppm). The conversion factor shall be re-
established during any performance test
under 8 60.8 or any continuous monitor-
ing system performance evaluation under
|60.13(c).
   (c) The owner or operator shall record
the dally production rate and hours of
operation.
   (d)  [Reserved]
   (e) For the purpose of reports required
under 5 60.7(c).  periods of excess emis-
sions that shall be reported are defined
as any  three-hour period during  which
the  average  nitrogen oxides emissions
(arithmetic average of three contiguous
one-hour periods) as measured by a con-
tinuous monitoring system  exceed  the
standard under 8 60.72(a).
(Sac. 114 of tha C3MD Air Act M
(41 UAC. l»7o-fl).).
 160.72  Standard for nitrogen oxide*.
   (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 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 add.
   (2) Exhibit  10  percent  opacity,  or
 greater.
 8 60.73  Emlatton monitoring.
   (a)  A continuous monitoring system
 for the measurement of nitrogen oxides
 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  1 60.13(d) to
 this part, shall be nitrogen dioxide (NO,) .
 The span shall be set at 500 ppm of nltro-
jcen  dioxide.  Reference Method 7 shall
 be used for conducting monitoring sys-
 tem performance evaluations under 1 60.-
   (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/short ton) . The conversion factor
 •hall be established by measuring emis-
 sions with  the  continuous monitoring
 system concurrent with measuring emis-
 sions 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  shall
                                      References:

                                         60.2
                                         60.7
                                         60.8
                                         60.11
                                         60.13
                                         Reference  Method
                                         Specification  2
                                                       111-25

-------
 •ubpart H—Standard* of Performance for
           Sulfurtc Acid Plants
 | 60.80  Applicability and designation of
     •ffecled facility.
  (a) The provisltas of this subpart are
applicable to each sulfuric acid produc-
tion unit, which is the affected facility.
   Any facility under paragraph (a)
of this section that commences construc-
tion or  modification after August  17,
1071, la subject to  the  requirements of
Ibis subpart.
160.81  Definition*.
  As used In this subpart, all terms not
defined herein shall have the meaning
liven them  in the Act and In Subpart A
of this part.
  (a) "Sullurlc  acid  production unit"
means  any facility  producing sulfuric
add by the contact process by burning
elemental sulfur, alkylation add, hydro-
gen sulflde, organic sulfldes and mer-
captans, or  acid sludge, but does not In-
clude faculties where conversion to sul-
f uric add la utilized primarily as a means
of  preventing emissions to  the  atmos-
phere of sulfur dioxide  or other sulfur
compounds.
  (b) "Add mist" means sulfurlc acid
mist, as measured by Method 8 of Ap-
pendix A to this part or an equivalent or
alternative method.
f 60.82  Standard for sulfur 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  affected
facility any gases which contain sulfur
dioxide In excess of  2  kg per metric ton
of acid produced  (4 Ib  per ton), the pro-
duction being expressed as 100 percent
HjBO..
        CF=k
ri.ooo-o.c
L     r-s
tor shall be determined, as a minimum.
three times dally by measuring the con-
centration of sulfur dioxide entering the
converter using suitable methods '(e.g.,
the Reich test. National Air Pollution
Control Administration Publication  No.
M9-AP-13) and calculating the  appro-
priate conversion factor for each eight-
hour period as follows:

                    )-0.015r I


wbere:
  Cf  = conversion (actor (kg/metric ton per
       ppm, Ib/short ton per ppm).
   k  = constant derived from material  bal-
       ance. For determining CF in metric
       unite, k = 0.0653. For determining CF
       In English unite. k=0.1SOfl.
   r  = percentage of sulfur dioxide by vol-
       ume entering the gas converter. Ap-
       propriate corrections must be mad*
       for air Injection plants subject to the
       Administrator's approval.
   t  = percentage of sulfur dioxide by  vol-
       ume In the emissions to the atmos-
       phere determined by the continuous
       monitoring system required under
       paragraph (a) of this section.

   
-------
Subpatt J—atandard* of
§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
nart.
  (h) "Coke  burn-off" means the rake
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 8 60.106.
  (1)  "Claus  sulfur  recovery plant"
means  a process unit which recovers
sulfur  from  hydrogen  sulfide  by a
vapor-phase   catalytic   reaction  of
sulfur dioxide and hydrogen sulfide.
  (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 sulfide.
  (1) "Reduced   sulfur  compounds"
mean hydrogen sulfide (H>S), carbonyl
sulfide  (COS) and carbon  dlsulflde
(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
oil  processing capacity of 137,500 bar-
rels per stream day or less.
160.101  Definition*.
  As used In this subpart. all terms not
defined herein  shall have the meaning
liven 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 oil
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
(as at  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  upeet 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 i*
conducted.
  (g) "Fuel  gas  combustion  device"
means  any equipment, such as process
heaters, 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 sulfuric acid.
§ 60.102  Standard for participate matter.
  (a) On and after the date on which
the performance test required to be
conducted  by 960.8 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.
   (I) Oates exhibiting greater than SO
 percent opacity, except for one six-min-
 ute average opacity reading In  any  one
 hour period
 § 60.101  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/dscin  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 followed by in-
cineration, or
  (ii) 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  EmiMioo monitoring.
  (a)  Continuous monitoring systems
shall be installed, calibrated, maintained,
and operated by the owner or operator M
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 •panned 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
sulflde is Installed under paragraph (a)
(4) of this section).  The pollutant gas
used to prepare  calibration gas mixture*
under paragraph 2.1, Performance Speci-
fication 2 and for calibration checks un-
der I 60.13(d),  shall be sulfur dioxide
(SOi). The span shall be set at 100 ppm.
For conducting  monitoring system  per*
formance evaluations  under 160.13(c).
Reference Method 6 shall be used.
  (4) An Instrument for continuously
monitoring  and recording concentra-
tions, of hydrogen sulfide in fuel gases
burned  in  any  fuel  gas  combustion
device,     if    compliance    with
§60.104
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the use of an oxidation control system
or a reduction control system followed
by Incineration. The span of this con-
tinuous monitoring system  shall  be
sent at 500 ppm.
  (6) An instrumcnt(s) for continuous-
ly monitoring and  recording the con-
centration  of  H,S and reduced sulfur
compounds in  the  gases  discharged
into the atmosphere from any  Claus
sulfur recovery  plant  if  compliance
with § 60.104(a)(2) 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 kllogram/hr)  and hours of
operation for any fluid catalytic  crack-
ing unit catalyst regenerator subject to
§80.102 or 160.103 shall  be recorded
dally.
  (d) 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  (Ilters/hr or
kllograms/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 60.7(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 exceed* 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 §60.103 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)(l) 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.
  (ii)  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  §60.104(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.
                                    References:
                                      60
                                      60
                                      60
                                      60
                                      60
 2
 7
.8
.11
.13
                                                        111-28
                                      Reference Methods
                                      Specifications 1.
                   6,
                   2

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Subpart N—Standards of Performance for
          Iron and Stovl Ptonts  *
 160.140  Applicability and designation
     of effected facility. 6 4

   (a)  The affected facility to which the
 provisions of this subpart apply is aach
 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 this
 subpart.


 160.141   Definition*.
   As used In this subpart, an terms not
 denned herein shall  have  the  meaning
 given them In the Act and In subpart A
 rf this part.
   (a)  "Basic oxygen process  furnace"
 '; ">PF>  means any  furnace producing
     .by charging scrap steel, hot metal.
 a..ii flux materials Into a vessel and  in-
 troducing a  high volume of an oxygen-
 rich sas.
   (l^  "Steel production cycle"  means
 the  fp'rations required to produce each
 batch of steel and Includes the following
 majur functions: Scrap charging, pre-
 heating (when used), hot metal charg-
 ing, primary oxygen  blowing, additional
 oxygen  blowing  (when used),  and tap-
 ping.
   
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Subpart P—Standard* of RsrformanM fer
        Primary Copper Smelters
• 60.160  Applicability and
    of affeeaed facility.
   (a) The proviaions of tills robpart are
likable to the following affected facili-
ties In primary copper smelters: dryer,
roaster, smelting furnace, and copper
converter.
   (b) Any facility under paragraph (a)
aff this section that commences construc-
tion or modification  after October 18,
1974.  to subject to the requirement* of
this subpart.

 % 60.161  Definition*.
   As used In this subpart, all terms not
 defined herein shall  have  the meaning
 given  them  m the Act and in Subpart
 A of this part.
   (a) "Primary copper smelter" means
any Installation or  any intermediate
process engaged  In  the production  of
copper from copper sulflde ore concen-
trates through the use of pyrometallurgl-
cal techniques.
   (b)  "Dryer" means  any facility  in
which a copper sulflde ore  concentrate
charge is heated In the presence of air
to eliminate a portion of the moisture
from  the charge, provided  less than 5
percent of the sulfur contained In the
charge is eliminated  in the  facility.
   (c)  "Roaster"  means any facility in
which a copper sulflde ore concentrate
charge is heated in the presence of au-
to eliminate  a significant portion (5 per-
 cent  or more) of the sulfur  contained
in the charge.
   (d)  "Calcine" means the solid mate-
 rials produced by a roaster.
   (e>  "Smelting"  means    processing
 techniques for the melting  of a copper
 sulfide ore concentrate or calcine charge
 leading to the formation of separate lay-
 ers of molten slag, molten copper, and/or
copper matte.
   (D "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.
    provided the
affected  facility, including air pollution
control  equipment, is maintained  and
operated in a manner  consistent with
                                                 HI-30

-------
Rood air pollution  control practice (or
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 (•) of the Clean Air
Act as amended (43 VS.C. l«57c-e. 18S7c-0,
18S7g(a)).)
                                                                            References:

                                                                               60.2
                                                                               60.7
                                                                               60.8
                                                                               60.11
                                                                               60.13
                                                                               Reference Methods 6,
                                                                               Specifications  1. 2
                                               111-31

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 Subvert Q—Standanfc of PsrtemaRce for
         Primary Zinc Smoltore
g 60.170  Applicability  end
   (a) Tae provisions of this subpart ore
 applicable to toe following affected facili-
 ties in primary zinc ssaeltsro : scoter Bad
 Binterlns KaacMne,
 .  
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Subpart R—Standards of PwformanM far
         Primary Lead Smelters
160.180  Applicability
     •f effected facility-
    <»> Tbe provisloas of this subpart are
  applicable to  the  following affected
  faclUUee In primary lead smelters: sin-
  tering machine, sintering machine dis-
  charge end. blast furnace, dross rever-
  berator? furnace, electric smelting fur-
  nace, and converter.
    (b) Any facility under paragraph (a)
  of this section that commences con-
  struction  or modification  after October
  16. 1874. Is subject  to the requirements
  of thissubpart.
 160.181   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 slnter-
' Ing machine.
     For  the purpose of  reports re-
 quired under 160.7(c). periods of excess
 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
 I 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.
(Sec. 114 of UM OMO Air Act M

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Subpart T—Standards of Performance for
  the Phosphate Fertilizer Industry: Wet-
  Process Phosphoric Acid Plants
§60.200  Applies ».ility  and designation
     of affected facility.

    The affected facility to ^blcb the
 provisions of this subpart apply It each
 wet-process phosphoric acid plant For
 the purpose of this subpart, the affected
 facility  Includes  any combination of:
 reactors, filters,  evaporators,  and  hot-
 wells.
   (b) Any faculty under paragraph (a)
 of this  section  that commences  con-
 struction or  modification after October
 22, 1974, Is subject to the requirements
 of thia subpart.
160.201  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)   "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 S 60.204, or equivalent or alternative
methods.
   (c) "Equivalent P.O. feed" means the
quantity  of phosphorus,  expressed  as
phosphorous pentoxlde, fed to the proc-
ess.
§ 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.
(Sac.
      114 of tha Cteaa Air Act a*
        . tas7c-e>.).
                                                                               References:
                                                                                 60.2
                                                                                 60.7
                                                                                 60.8
                                                                                 60.11
                                                                                 60.13
                                                     111-34

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Subpart U—Standard* of Performance for
  trw Phosphate Fertilizer Industry: Super-
  phosphoric Acid Plants
• 60.210  Applicability  and
     •{affected facility.

   (a) The affected facility to which the
provisions of this subpart apply to each
superphosphoric  acid   plant  for  the
purpose of this  subpart. the affected
facility  Includes  any combination of:
evaporators,  hotwells, add samps, end
cfffftlng tanks.
   (b) Any facility under paragraph (a)
of this section that commences  con-
struction or modification after October
23. 1974. to subject to the requirements
of this subpart
1 60.211  Definiti
  As used in tola subpart. all terms not
defined herein shall have the meaning
given them In the Act and in Subpart A
of this part.
   (a)  "Superphosphortc  acid   plant"
means  any facility which concentrates
wet-process phosphoric acid to 66 per-
cent or greater PiO, 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 { 60.214. or equivalent or alter-
native methods.
   (c) "Equivalent PXX feed" means the
quantity  of  phosphorus, expressed as
phosphorous   pentoxlde.  fed  to   the
process.
| 60.215  Monitoring of operation*.
  (c) The owner or operator  of  any
superpbosphorlc acid plant 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  ± 8  percent  over its
operating range.
(••c 114 of th* a«an Air Act at
(U UAC. lU7c-«).).
                                                                              References:

                                                                                 60.2
                                                                                 60.7
                                                                                 60.8
                                                                                 60.11
                                                                                 60.13
                                                        HI-35

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 •ubpart V—Standards of Performance for
   the Phosphate Fertilizer Industry. DUnv
   monium Phosphate Plants
 160.220   Applicability and  4t»icnatfam
     of affected f«elv.ty.
   (a) The affected facility to which the
 provisions of this subpart apply to each
 granular dtammonlum phosphate plant.
 For the purpose of this subpart, the ef-
 fected facility Includes any combination
 of: reactors, granulatore, dryers, coolers.
 screens, and mills.
   (b) Any facility under paragraph (a)
 of this section that commences construc-
 tion  or modification  after October 22.
 1974, Is subject to the requirements  of
 this subpart
 160.221   Definitions.
   As used in this subpart. all terms not
 denned herein shall have the meaning
 given them in the Act and in Subpart A
 of this part.
   (a) "Granular  dlammonium  phos-
 phate  plant"  means any plant manu-
 facturing granular diammonium phos-
 phate  by reacting phosphoric acid with
 ammonia.
   (b)  "Total fluorides" means elemental
 fluorine and all  fluoride compounds as
 measured by  reference methods specl-
' fled in ! 60.224, or equivalent or alter-
 native methods.
   (c)  "Equivalent P,O5 feed" means the
 quantity of  phosphorus, expressed as
 phosphorous pentoxlde. fed to the proc-
 ess.
 § 60.223  Monitoring of operations.

      *      *     *     *      *

   (c) The owner or operator of  any
 granular dlammonium phosphate plant
 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 scrubbing
 system. The monitoring device shall have
 an accuracy of ±& percent over its op-
 erating range.
 (8«c. 114 of tb« Cl«*n Air Act M
 (O U.8.C. 18fi7c-«).).
                                                                               References:

                                                                                  60.2
                                                                                  60.7
                                                                                  60.B
                                                                                  60.11
                                                                                  60.13
                                                        HI-36

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Subpart W—Standard* of Pwfonnaim for
  the Phosphate Fertilizer Industry: Triple
  Superphosphate Plants
160.230  Applicability  mm* doaign
     of affected facility.
   (a) The affected facility to which the
provisions of this aubpart apply Is each
triple superphosphate plant. For the pur-
pose of this EUbpart. the affected facility
Includes any  combination  of: mixers.
curing belts  (dens), reactors, granula-
tors. dryers, cookers, screens, mills, and
facilities which store nm-of-plle 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 requirements of
thlssubpart.
160.231  Definition*.
  As used In this subpart. all terms not
defined herein «h»ii have the mptmipg
given them in the Act and In Bubpart A
of this part.
  (a> "Triple  superphosphate  plant"
means any facility manufacturing triple
superphosphate by reacting phosphate
rock with phosphoric acid. A nm-of-plle
triple  superphosphate  plant  Includes
curing and storing.
  (b) "Run-of-pUe  triple   superphos-
phate" means any triple superphosphate
that has not been processed In a granu-
lator and  is  composed of  particles at
least 25 percent by weight of  which
(when not caked) will pass through a 16
mesh screen.
  (c> "Total   fluorides"   means  ele-
mental  fluorine and all  fluoride com*
pounds  as   measured   by  reference
methods specified in i 60.234. or equlra-
lent or alternative methods.
§ 60.233  Monitoring of operation*.
   (c) The owner or operator of any triple
superphosphate plant subject to the pro-
visions of this part shall Install, calibrate,
maintain, and operate a monitoring de-
vice which continuously measures and
permanently records the total pressure
drop across the process scrubbing system.
The monitoring  device shall have an ac-
curacy of ±5 percent over  its operating
range.

(fl*e. 114 at th* OMB Air Aet a> an*B4af
(4IUAC.
                                                                              References:

                                                                                 60.2
                                                                                 60.7
                                                                                 60.8
                                                                                 60.11
                                                                                 60.13
                                                      111-37

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tubpart X—Standards of Performance tor
  th« Phosphate Fertilizer  Industry: Gran-
  ular Triple  Superphosphate Storage Fe-
  cUtties
160.240  ApplioSUily  and  dr«i«nalion
     of affected facility.
  <•) The Affected faculty to which the
provisions of this aufcpart apply  to each
granular triple superphosphate  storage
facility, for ttie purpose of this subpart.
the affected facility Includes any combi-
nation of:  storage or curing piles, con-
veyors, elevators, screens, and mills.
  (b) Any facility under paragraph (a)
of this section that commences construc-
tion or modification  after October 22,
1974. Is subject to the requirements of
this subpart.
8 60.241  Definition*.
  A3 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) "Granular  triple  superphosphate
storage facility" means any facility cur-
Ing or storing granular triple superphos-
phate.
  
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 Subpart Y—Standards of Performance tor
         Coal Preparation Plants
160.250  Applicability  and dcatgjutfion
     of affected facility.

   (a) The provisions of tlila aubpart are
 applicable to any of the following af-
 fected facilities  in coal  preparation
 plants which process more than 200 tons
 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
 loading systems.
   (b) Any facility under paragraph (a)
 of this section that commences construc-
 tion or modification after  October 24,
 1974. is subject to the requirements of
 8 60.251  Definitions.
   As used In this subpart. all terms not
 denned 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, and thermal drying.
   (b) "Bituminous coal" means solid fos-
 sil fuel classified as bituminous coal by
 AJB.T.M. Designation D-388-66.
,   (c) "Coal" means all solid fossil fuels
 clamlfled as anthracite, bituminous, sub-
 bltumlnous, or lignite by A.8.T.M. Des-
 ignation D-388-6fl.
   (d) "Cyclonic flow" means a splrallng
 movement of exhaust gases within a duet
 or stack.
   (e) "Thermal dryer" means any fa-
 cility In which the  moisture content of
 bituminous coal Is  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 r-l«««Mlfff
 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.
   (b) "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
 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 ±8* 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 i 60.13(b) (3).
(B*c. 114 of UM d*ui Air Act M
(U O.S.C.
                                       References:
                                                                                 60,
                                                                                 60.
                                                                                 60,
                                                                                 60.
                                             2
                                             7
                                             8
                                             11
                                                                                 60.13
                                                     111-39

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•ubpart Z—Standard* of Performance tor
     Ferroalloy Production Facilities
(60.260  Applicability  and
     of affected facility.
   (ft) The provtalo-4 ol this subpart are
 applicable to the following  affected f»-
 ennies: electric submerged arc furnaces
 which produce silicon metal, f erroslllcon.
 calcium silicon, Silicomanganese zircon-
 ium,   ferrochrome   silicon,   silvery
 tron, high-carbon  ferrochrome. charge
 chrome, standard ferromanganese, alll-
 oomanganese, ferromanganeae silicon, or
 calcium  carbide:  and dust-handling
 equipment.
   (b) Any facility under paragraph (a)
 of ttiis section ttiat commences construc-
 tion or modification after  October 21.
 1074, is subject to the requirements of
 tote subpart.
 § 60.261  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 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 this subpart.
   (d) "Slag" means the more  or leas
 completely  fused  and vitrified  matter
 separated  during  the reduction  of a
 metal from its ore.
    "Tapping" means the removal of
 slag or product  from the electric sub-
 merged arc furnace under  normal op-
 erating conditions such  as removal of
 metal under normal pressure and move-
 ment by gravity  down the spout into the
 ladle.
    (f) "Tapping  period" means the time
 duration from initiation of the process
 of opening the tap hole until plugging of
 the tap hole is complete.
    (g) "Furnace  cycle" means the time
 period from  completion  of a furnace
 product tap to the completion of the next
 consecutive product tap.
    (h)  "Tapping station"  means  that
 general area where molten product or
 ffing is removed  from the electric  sub-
 merged arc furnace.
   (i) "Blowing  tap" means any  tap in
 which an evolution of gas forces or pro-
 jects jets of flame or metal sparks  be-
 yond the ladle, runner, or collection hood.
    (J) "Furnace power input" means the
 resistive electrical power consumption of
an  electric submerged arc  furnace  aa
measured in kilowatts.
   "Calcium carbide" means material
containing 70 to 85 percent calcium car-
bide by weight.
  (q) "High-carbon ferrochrome" means
that alloy as  denned by A.S.T.M.  desig-
nation A101-66 grades HC1 through HC6.
  (r) "Charge chrome" means that alloy
containing  52 to 70 percent by weight
chromium, 5 to 8 percent by  weight car-
bon, and 3 to 6 percent by weight silicon.
  (s)  "Silvery iron" means  any  ferro-
silicon. as defined by A.S.T.M. designa-
tion  100-69,  which contains less  than
30 percent silicon.
  (t) "Ferrochrome silicon"  means that
alloy as denned by AJ3.T.M.  designation
A482-66.
  (u)   "Silicomanganese   zirconium"
means that alloy containing 60 to 65 per-
cent by weight silicon, 1.5 to 2.5 percent
by  weight  calcium,  5  to 7  percent  by
weight zirconium, 0.75 to 125 percent by
weight aluminum,  5 to 7  percent  by
weight manganese, and 2 to 3 percent by
weight barium.
  (v)  "Calcium  silicon" means  that
alloy  as denned by A.S.T.M.  designation
A495-64.
  (w) "Ferrosilicon" means that alloy as
defined by A.S.T.M. designation A100-69
grades A, B, C, D, and E  which contains
50 or more percent by weight silicon.
  (x) "Silicon metal" means any silicon
alloy  containing more than 06 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.
§ 60.262  Standard for paniculate mat-
    ter.
  (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 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 S 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  Emiaiion 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 device(s).
  (b) For the purpose  of reports re-
quired under S 60.7(c), 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.
§ 60.265  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 partlculate  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
                                                     111-40

-------
operator to demonstrate the accuracy of
the monitoring device relative to Meth-
ods 1 and 2 of Appendix A to this part
  (d) When performance tests are con-
ducted under the provisions of 9 60.8 of
this  part  to  demonstrate compliance
with  the  standards under 5860.262 of this sec-
tion determine the volumetric flow rate
through each fan of the capture system
from the  fan power  consumption, pres-
sure drop across the fan and the fan per-
formance curve. Only data specific to the
operation of the  affected electric sub-
merged arc furnace are acceptable for
demonstration of compliance with  the
requirements  of   this paragraph.  The
owner or  operator shall maintain on file
a permanent  record of  the  fan per-
formance curve (prepared for a specific
temperature)  and shall:
   (1) Install,  calibrate, maintain,  and
operate a device to continuously measure
and record the power consumption of the
fan motor (measured In kilowatts).  and
   (2) Install,  calibrate, maintain,  and
operate a device  to continuously meas-
ure and record the pressure drop across
the fan. The fan power consumption and
pressure  drop measurements must be
synchronized to allow real time compar-
isons of the data. The monitoring de-
vices must have an accuracy of ±5 per-
cent over their normal operating ranges.
   (f) The volumetric flow rate through
each fan  of the capture system must be
determined from the fan power con-
sumption, fan pressure drop,  and  fan
performance curve specified under para-
graph (e) of thU section, during any per-
formance  test required  under 160.8
to demonstrate  compliance with  the
standards under  8 5 60.262 (a)  (4)  and
 (5). The  owner or operator shall deter-
mine the volumetric flow rate at a repre-
 sentative temperature for furnace power
 Input levels of 50 and 100 percent of the
 nominal rated capacity  of  the  electric
 submerged arc furnace. At all times the
 electric  submerged arc  furnace  is- op-
 erated, the owner or operator shall main-
 tain the fan power consumption and fan
 pressure drop at levels such that the vol-
' umetrlc flow rate Is at or  Above the levels
 established during the most recent per-
 formance test for that furnace power in-
 put level. If emissions due to tapping are
 captured and  ducted  separately  from
 emissions of the electric submerged arc
 furnace, during  each tapping period the
 owner or operator shall maintain the fan
 power consumption and fan  pressure
 drop at  levels such that the volumetric
 flow rate Is at or above the levels estab-
 lished during the most recent perform-
 ance test. Operation at lower flow rates
 may be considered by the Administrator
 to be unacceptable operation and main-
 tenance of the affected facility. The own-
 er or  operator may request that these
 flow rates be reestablished by conducting
 new performance tests under { 60.8. The
 Administrator may require the owner or
 operator to verify the fan performance
 curve by monitoring necessary fan oper-
 ating  parameters and determining the
 gas volume moved relative to Methods 1
 and 2 of Appendix A to this part.
   (g)  All  monitoring devices  required
 under paragraphs (c) and  (e)  of this
 section are to be checked for calibration
 annually in accordance with the proce-
 dures  under J60.13(b).
 (••e. 114 of tb* Ctetn Air Act M
 <«1 VAC.
                                       References:
                                         60.
                                         60.
                                         60.
                                         60.
2
7
8
11
                                         60.13
                                                    111-41

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 Subpart AA—Standards of Pwrformanc*
  for StMl Plants: EtoctrkAic Furnaces
160.270  Applicability  and *f»»«narinn
    of affected facility.
  (a) The provisions of this oUbpart are
applicable to the following affected fa-
cilities in ateel plants: electric arc fur-
naces and dust-handling equipment.
  (b) Any facility under paragraph (a)
of this section that commences construc-
tion or modification  after October 31.
1974. to subject  to the  requirements of
tfcJsatibpait.
160.271  Definition*.
  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) "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 Is
cast into the shape of finished products.
such as in 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 nib-
part.
   (c)  "Control  device" means the air
pollution control equipment used to re-
move participate matter generated by
an EAF(s) from the effluent gas stream.
   (d)   "Capture system"  means  the
equipment (including ducts, hoods,  fans,
dampers, etc.) used to capture or trans-
port participate 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.
ft 60.272
    ter.
Standard for paniculate mat-
  (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:
  (i) Shop opacity greater than zero per-
cent, but less than 20 percent, may occur
during charging periods.
  (ii)  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 8 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.
§ 60.273  Emission 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 defined as  all six-
minute periods during which the aver-
age opacity is three percent or greater.
(S«c. 114 of tb» ciua Air Act M
(41 O.8.C. 1M70-B).).
                                      References:
                                         60.
                                         60.
                                         60.
                                         60.
                                   2
                                   7
                                   8
                                   11
                                                                                 60.13
                                                   111-4.2

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 Subport U—Standard* of Performance for
           Kraft Pulp MM*
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,
lime  kiln, and  condensate  stripper
system. In  pulp mills  where  kraft
pulping Is combined with neutral sul-
fite semichemlcal 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 facility 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.

9 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  sulflte 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 steamerts),
and condensers).
  (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
condenserfs)  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.
  (i) "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 sulfidity 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 semichemical  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 mill.

§60.282  Standard foAoarticulate matter.
  (a) On and after we 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 recovery furnace any
gases which:
  (i) Contain  particulate  matter  in
excess of 0.10  g/dscm (0.044 gr/dscf)
corrected to 8 percent oxygen.
  (ii)  Exhibit 35 percent  opacity  or
greater. •
  (2) From any smelt dissolving tank
any gases  which contain  particulate
matter  in  excess  of 0.1  g/kg black
liquor  solids (dry wetght)[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 (0.067 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
    (TRS).
  (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 of 5 ppm by volume on a dry
basis, corrected to 10 percent oxygen.
unless  the  following conditions are
met:
  (i) The gases are combusted in a lime
kiln subject to the provisions of para-
graph (a)<5) of this section; or
  (11) The gases are combusted in a re-
covery furnace subject  to the provi-
sions of paragraphs (a)(2) or (a)(3)  of
this section; or
 .(ill) The  gases  are combusted with
other waste gases in an incinerator  or
other device, or combusted in a  lime
kiln or recovery furnace not subject to
the provisions of this subpart, and are
subjected to a minimum temperature
of 1200' F. for at least 0.5 second; or
  (iv) It has been demonstrated to the
Administrator's  satisfaction  by  the
owner  or operator that  incinerating
the exhaust gases from a new, modi-
fled, or reconstructed black liquor oxi-
dation system or brown stock washer
system in an existing facility is  tech-
nologically or economically not feasi-
ble. Any exempt system  will become
subject to the provisions  of  this  sub-
part if the facility is changed so  that
the gases can be incinerated.
  (2) From any straight kraft recovery
furnace any gases which contain TRS
in excess of 5 ppm by volume on a dry
basis, corrected to 8 percent oxygen.
  (3) From any cross recovery furnace
any gases which contain TRS in excess
of 25 ppm  by volume on  a dry basis,
corrected to 8 percent oxygen.
  (4) From any smelt dissolving tank
any gases which contain TRS in excess
of 0.0084 g/kg black liquor solids (dry
weight)  [0.0168 Ib/ton liquor solids
(dry weight)].
  (5) From  any lime kiln any  gases
which contain TRS in excess of 8 ppm
by volume on  a dry basis,  corrected to
10 percent oxygen.
                                                     111-43

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5 60.284  Monitoring of emissions and op-
   erations.
  (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
kiln,    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) (ill) 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:
  (1) 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(a)(l)(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:
  (i) A 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    §60.283(a)(4)
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 (c)(l) 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:
       Cm=C^x(21 -X/21 - Y)
where:
C
-------
tufe Is no greater than 205* C 
-------
PART 60—STANDARDS OF
PERFORMANCE FOR NEW
STATIONARY SOURCES

  It is proposed to amend Part 60 of
Chapter I. Title 40 of the Code of Federal
Regulations as follows:
  1. By adding subpart GG as follow"-
Subpart GG—Standards of Performance for
Stationary Gas Turbines
Sec.
61X330  Applicability and designation of
    affected fncility.
60.331  Definitions.
60.332  Standard for nitrogen oxides.
60.333  Standard for sulfur dioxide.
60.334  Monitoring of operations.
60.335  Test methods  and procedures.   .
  Authority: Sees. Ill and 301(a) of the Clean
Air Act as amended. [42 L'.S.C. 1857c-7.
l&57g(a)]. and additional authority as noted
below.

Subpart GG—Standards of
Performance for Stationary Gas
Turbines

§ 60.330  Applicability and designation of
affected faculty.
  The provisions of this subpart are
applicable to the  following affected
facilities: all 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  Definition*.
  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
                                                   HI-46

-------
exhaust gases to prehcal 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 lurbine" means
any stationary ges turbine which
operates as a mechanical or i:K-clric:tl
power source only whnn thr primary
|iiu\>:r source for a fHcilily has burn
p-ndi-red inoperable by «n umcrjjunr.y
situation.
  (fl "Ice fog" means an atmospheric
suspension of highly reflective ice
crystals.
  (g) "ISO standard dny conditions"
means 2btt 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 bf 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.
  (j) "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 oil/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.
  (p) "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.

§60.332  Standard tor rrttreqen oxides.
  (a) On and after the date on which the
performance test required by 160.8 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). (g). (h). and (i) of this
section.
  (I) No owner or operator subject to
the provisions of this subpart shall
cmisc to be discharged into the
atmosphere from any stationary gas
turbine, any g«s«s which contain
nitroRcn oxides in excess of:
STD  --  0.0075
                  (14.4)
                  ---  —
                          32
STf) = allowable NO, emissions (pen.cnl liy
    vulnmi! at 15 percent oxygon and on a
    dry l>;isis).
Y~-mitnufac.turer's rated hout rate nl
    manufacturer's rated load (kilojnules per
    uvull hour) or, actual meHSiired hi;at rate
    batted on lower heating value of fuel as
    measured et actual peak load for the
    facility. The value of Y shall not exceed
    14.4 Icilojoules 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  = 0.0150  (1—-) +  F


where:
STD=allowablc NO, emissions (percent by
    volume at 15 percent oxygen and on a
    dry basis).
Y=manufacturer's rated heal rate at
    manufacturer's rated peak load
    (kilojoules per watt hour), or actual
    measured heat rale based on lower
    htdtmj; value of fm:l us mi.-usured nt
    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:
 Fuel-Bound Nitrogen            f
 (ye rcer.t by "trightj    (NO percent by volume)
      N < 0.015

 0 015 • N ^ 0.1

 (I.I « II « 0.35

    N » 0.?S
       0.0«(N)

0.004 4 0.0067(N-0.1)

      O.OOS
where:
N = the nitrogen content of the fuel (percent
    hy weight).
or

  Manufacturers may develop custom
fuel-bound nitrogen allowances for each
 gas lurbinu model they manufacture.
 These fuel-bound nitrogen allowances
 shall he substantiated with data and
 must be approved for use by the
 Administrator before the initial
 performance test required by § 00.8.
 Notices of approval of custom fuel-
 bound nitrogen allowances will be
 published in the Federal Register.
   (b) Stationary R;IS luibir.c:i witli a lieat
 input nt peak load jirr.cler Ihnn  KV/.2
 Ri|;;ijr>iili!S per hour (10!) nv.lliiin lilu/
 lio;!!J b;r.':il mi the lr,wi.-r luiiitm" viilui.'
 ill tin: I'unl liiml i'v..r|>l 0.:):i2(ii) shall comply v.-illi I!IH
 provisions of § &0.'J.tZ(a)(11
   (c) Stationary >;as  turbines with a huat
 input at peak load equal to or f*t cater
 than 10.7 gigajoules per hour 110 million
 Blu/hour) but luss than or equal to 107.2
 gigHJoules per hour (UK) million Btu/
 hour) based on the lower heuting value
 of the fuel fired, bhall comply with the
 provisions of § 60.332(8)12).
   (d) Stntionary gas turbines employed
 in oil/ga» production or oil/gas
 transportation and not Incalrd in
 Metropolitan Statiblir.nl Areas; and
 offshore platform turbines shall comply
 with the provisions of § W.332(n)(2).
   (e) Stationary gar, turbines with a heat
 input at peak load equal to or greater
 than 10.7 gigajoules p<-i hour (in million
 Btu/hour) but less than or equal to 107.2
 gigajoules per hour (10VI million lltu/
 hour) based on the lower heating value
 of the fuel fired and that have
 commenced construct ion prior to
 October 3,1902 are exempt from
 paragraph (a) of this section.
   (f) Stntionary gas turbines using water
 or steam injection for control of NO,
 emissions are exempt from paragraph
 (a) when ice fog is ditemed a traffic
 hazard by the owni;i or operate, r of llse
 gas turbine.
   (g) Emergency gas turbines, military
. gas turbines for use in other than a
 garrison facility, military gas turbines
 installed for use as military training
 facilities, and fire fighting gas turbines
 are exempt from paragraph (a] of this
 section.
   (h] Stationary gas turbines engaged by
 manufacturers in research end
 development of equipment for both gas
 turbine emission control techniques and
 gas turbine efficiency improvements are
 exempt from paragraph (a) on a case-by-
 case basis as determined by the
 Administrator.
   (i) Exemptions from the requirements
 of paragraph (a) of this section will be
 granted on a case-by-case basis as
 determined by the Administrator in
 specific geographical areas where
 mandatory water restrictions arc
 required by governmental agencies
 because of drought conditions. These
                                                      111-47

-------
 exemptions will be allowed only while
 the mandatory water restrictions are in
 effect.

 § 60.333  Standard for sulfur dloxld*.
   On and after the date on which the
 perfohnance test required to be
 conducted by § 60.8 is completed, every
 owner or operator subject to the
 provision of thij subpart shall comply
 with one or the other of the following
 conditions:
   (a) 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 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 slnlionary jjas turbine any fuel
 which contains sulfur in excess of 0.8
 percent  by weight.

 § 60.334  M»nilub.=nie;isured combustor inlet absolute
     pressure at test nmbient pressure.
 Hob. = specific humidity of ambient air at test.
 e=transcendental constant (2.718).
 TA.MB = tempera lure of ambient air at test.
   The adjusted NO, emission level shall
 be used to determine compliance with
 S 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 nitrog«n
 oxides emission level measured  by the
 performnncc test as provided for in
 § (30.0 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
                   air pollution control system was
                   deactivated, and the date and time the
                   air pollution control system was
                   reactivated shall be reported. AH
                   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. 18S7c-9|).

                   § 60.335 Test method* aid procedures.
                     (a) The reference methods in
                   Appendix A to this part, except as
                   provided in § 60.8(b). shall be used to
                   determine compliance with the
                   standards prescribed in 9 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
                                                               AMB .1.53
                                              -  0.00633)
                   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
                   oxygen or
                     (2) ASTM D2880-71 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(h).
                     (c) Analysis for. the purpose of
                   determining the sulfur content and the
                   nitrogen content of the fuel as required
                   by § 
-------
Subport  HH—Standards  of  Perfor-
   mance   for   Lime  Manufacturing
   Plants

Sec.
60.340  Applicability and designation of af-
    fected facility.
60.341  Definitions.  •
60.342  Standard for participate matter.
60.343  Monitoring of emissions and oper-
    ations.
60.344  Test methods and procedures.
  AUTHORITY: Sec. 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 faculties 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. calcltic 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.
  (d) "Lime hydrator" means  a unit
used to produce hydrated  lime prod-
uct.

§ 60.342  Standard for paniculate natter.
  (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:
  (1) 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 particulate 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- 
-------
                                       «r. K  -MI VKlOir.i
                                        Br*ii»:.Aliy Hen HI l-fl
                            I  I  Principle. 'I'D Hid in the ri|u.-.-l1l-.,ln ..... _:lsuri-
                          mmi of pollutant i-inisMiiMui and/or loial volumelm: flow
                          nil- from a stationary source, a measurement sit* where
                          ,l,o effluent stream i" flowing  In a known direction  "
                          «i-lcri«d. mid tlic i-ro» --.-wi-iion of Die stack is divided Into
                          :> number or «|iial arras. A traverse iwiut is Ili.-n located
                          within each of these equal areas.
                            I a  Applicability. This method is applicable. U) flow-
                          inK gas streams In  duels, slacks, ami Hues. Tin- method
                          rmnot bo uscil when: 11) flow is cyclonic or swirling (sec
                          Section 2 4)  (2) a alai-k is smaller tlian aboul 0.30 meter
                          (12 in.) in diameter, or 0.071 m" (113 In.') in e.ross-swt-
                          tional area, or (3) the measurement silo is less than two
                          slaek or duel diameters downstream or IMS than a hall
                          diameter upsi.n-.im from a How disturbance.
                            The. ri-i|'mv"ie.nts "f this mrthod inusl l«- considered
                          lu-rnreennstriielioii of n new lacilliy (nniiwliic-.li emissions
                           will l» nii-asnreil; tallnn- to do so may r'wpiire Kulmociueiit
                          ullorations to llio sl*-k or deviation from tile standard
                           nrui-i-durr. (•ivnis Involving varlanlH nr<- mibjrcl to ap-
                           |ir«,v»\ by  Hi" Ailn.inisiiiiiiir. l'.^. KnviniiiJiii-nlal
                             '.'.I  Seleeliiin  or  Mi-ayiiri-ini-nl  Silr. _Sainpliiig  or
                           reloeitv nieaKiiri-inent is |j4-rfonm-d at a site located at
                           least eight swk or dnr-i diameters downstream and two
                           diainplfin upstream  fiom any flow disturbance such as
                           a bend eipansion, or -onlriu'tion in the stack, or Iron) a
                           visible flame. If n«M>.-sary, an alternative location may
                           be, selected, at a position at least two slack or ductdi-
                           nim-fors downstream and a hall diameter upstream from
                           any flow disturbance. Fur a rectangular cross section,
                           an eo.uivalc.nt diame.t. r (!>.} shall be calculated from the
                           following equation,  to determine  the upytrnam and
                           dowiislnan: d is I »i ;•••-.-
                                                         wlinf /.iliiiiKiliaud IP -wi.ltli.             .
                                                           •i-l  Dcteniiiiiing Hi" Niiiiibi.i-nf Trn\. points, or n gronlor value,
                                                         so that for clrc.ulnr stacks Urn  number Is \\ multiple ol 4,
                                                         und  lor rwlaufdilnr slacks, ihn mimbur is one of lliose
                                                         shown in T:iMn 1-1.

                                                         TM-.lt. 1  I.  i'm....-..c/;nn.i/  l-fjwil f'ir r.rlnnoulur slnrkl

                                                                                                     .1/0-
                                                                                                     IrtZ
                                                                                                      Olltt

                                                                                                      ::x3
                                                                                                      US
                                                                                                      4x4
                                                                                                                          (U6
                                                                                                                          Tl6
                    Figure  1-1.  Minimum number of traverse  points  for particulate  traverses.
       0.5
DUCT DIAMETERS UPSTREAM  FROM FLOW DISTURBANCE (DISTANCE  A)

                    1.0                             1.5                            2.0
    50
25
O
Q.
LU
V)
oc
O
cc
LU
CO
     40
     30
     20
^   10
X
T
A
_t
I
B
i
—


i
I
^
DISTURBANCE

MEASUREMENT
:- SITE

DISTURBANCE

                * FROM POINT OF  ANY TYPE  OF
                  DISTURBANCE  (BEND.  EXPANSION,  CONTRACTION.  ETC.)
                                                                                                           8
                                                                                                                      10
                  DUCT  DIAMETERS DOWNSTREAM  FROM FLOW DISTURBANCE {DISTANCE B)

                                                                   111-50

-------
       0.5
DUCT DIAMETERS UPSTREAM FROM FLOW DISTURBANCE (DISTANCE A)

                     1.0                           1.5                          2.0
                                                            2.5
    50
     40

0
a.
LU
£
UJ
530
     20

Z   10
                                        I
                                       I
I
I
\
T
A

i
i


3
i
^•^




t
Is.
DISTURBANCE

MEASUREMENT
?•- SITE

DISTURBANCE
                                                      1
                       3              4               5              67              8              9

               DUCT DIAMETERS DOWNSTREAM FROM FLOW DISTURBANCE (DISTANCE R)
                                                                                                                   10
          Figure 1-2.  Minimum number of traverse points for velocity (nonparticulate) traverses.
                                               3.2.2  Velocity  (Non-Purtieirtate)  Traverses.  When
                                              velocity or voluioatrtc flaw rate Is to to determined (but
                                              not narttculale matter), the same procedure as that (or
                                              nartlcalalc traverses (Section 2.2.0 Is followed, except
                                              tlmt Figure. I 2 may bo used instead of Figure 1-1.
                                               2.3 (!ross-8eclional Layout and Location of Traverse
                                              I'ohiLs,
                                               2.8.1  Circular Hlaclo. Locale the traverse points on
                                              two iNirnemliculor diameters udrording to Table 1-2 and
                                              HID esamplo shown In KlRiiro  1-3. Any equation (for
                                              rxamides, sen Citations'.'. and :i in the Ilililiograpliy) that
                                              Rives the sixmo values :is those- m Tallin 1  'i may Iw used
                                              in lieu uf Table 12.
                                               Cor parliciilaln travenvs, nm> of II ie ilintup.ters must Im
                                              in a |>lanu containing thnKr^xi.i^texijm-.ted iwncAntralitm
                                              variation, e.g., after lM:mls, one illHiiietur fthall bo in thn
                                              plane of llw Ijeud. This ritiiuirttinent Ixwinies less critical
                                              aH Urn distanoi! from thn disliirliance ineri*it8«!s; thnreffirc.,
                                              <>iher diami'terlufAlions in;ty IK: usfnl, KiilijtMittoapiirovul
                                              uf the Administrator.
                                               In adililion. for stacks having fljium'tora greater than
                                              n.(U m CIA in.) no tmvi ra: (Kiints shall be located within
                                              'il> centimeters (1.00 in.) uf tin: stock walls; »i.U (or sta<:lc
                                              iliamcli:rs i»pial to or U.'.ss than 0.61 m (24 In.), no trav^rsi:
                                              jjolnLssluiM br.loealed wll.hln 1.3cm (O.fXlin.)of tliestauk
                                              walls. To meet ihesc i:rlu>ria, oli»:rvo  the  procedures
                                              given In-low.
                                               2.3.1.1 Slacks Wilh Diameters On'nt'-r Than O.B1 m
                                              (24 In.). When any of the Iruvrrw, poinls as locatcil in
                                              Section  2.3.1 fall within 2.Scm (l.OUin.) of the stack walls,
                                              reloeali: them away from the slock walls U>: (1) a distance
                                              of 2U> cm (1.00 In.); or c£\ a distance equal to the nozr.le
                                              inside diameter, whichever Ls larger. These relocalvd
                                              trnvenw pojnts (on each end of a diameter) shall be the
                                              "adjusiefl" traverse  ]njints.
                                               Whenever two snreusslvo traverse |iolnl.s are combined
                                              to form a single tnljiiHled traveisn |»inl, treat the ad-
                                              justed (Kiiitl. as l.wo si<|»uat<^  traverse poinl.-,, both in the
                                                     tor vein-it y iiiciii!iir..>ini-iil.) pr(«r«-
-------
TRAVERSE
POINT
1
2
3
4
5
6
DISTANCE,
% of diameter
4.4
14.7
29.5
70.5
85.3
95.6
               Figure 1-3.  Example showing circular stack cross section divided into
               12 equal areas, with location of traverse points indicated.



Table 1-2.   LOCATION OF TRAVERSE POINTS IN CIRCULAR STACKS

         (Percent of stack diameter from inside wall to traverse point)
Traverse
point
number
on a •
diameter
1
2
3
4|
5'
6
7
8
9
10
11
12J
13
14
15
16
17
18
19
20:
21
22
23
24
Number of traverse points ..on a diameter
2
14.6
85.4












!







'

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
10.5
19.4
32.3
67.7
80.6
89.5
96.8












.



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
25.0
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
22.0
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
81.2
85.4
89.1
92.5
95.6
93.6






20
1.3
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
  5.3.1.2  Stacks With Diameters Equal to or Less Than
0.61 m (24 In.). Follow the procedure In Section 2.3.1.1.
noting 011)7 that any "adjusted" point*  should be
relocated away from the stacK walls to: (Da dlstam-c of
1.3 cm (0.60 In.); or (2) a distance equal  to the nozzle
Inside diameter, whichever Is larger.
  2.3.2  Rectangular  Stacks. Determine  the  number
of traverse points as explained in flections 2.1 and 2.2 of
this method. From Table 1-1. determine  the grid  con-
figuration. Divide the stack cross-section  Into as many
equal rectangular elemental areas as traverse points, .
and  then locate a traverse point at the centrold of each
equal area according to the example in Figure 1-1.
  The situation of traverse points being too close to the
stack walls Is not expected to arise  with  rectangular
stacks.  If this  problem should ever arise, the Adminis-
trator must be contacted for resolution  of the matter.
  2.4  Verification of Absence of Cyclonic  Plow. In  most'
stationary  sources,  the direction  of  stack gas (low is
essentially  parallel  to  the stack  walls.  However,
cyclonic flow may exist (1) after such devices as cyclones
and  inertia! demlsters following vcnturi  scrubbers, or
 Q) In stacks having tangential  Inlets or other duct con-
figurations which tend to Indue* swirling; In  these
Instances, the presence or absence of cyclonic flow at
the sampling location must be determined. The following
techniques are acceptable for this determination.
I
0 | 0
1

O | . 0
1
r
0 | O
1
1
.
O

--"1
O


O

•

O


O


O

-
                                                                                                        Figure 1-4. Example showing rectangular stack cross
                                                                                                        section divided into 12 equal areas, with a traverse
                                                                                                        point at centroid of each area.


                                                                                                         Level 'and tero the manometer. Connect a Type  B
                                                                                                       pilot tube to the manometer. Position the Type 8 pilot
                                                                                                       tube at each traverse point. In succession, so that  the
                                                                                                       planes of the face openings of the pilot tube ore perpendic- I
                                                                                                       ular to the stack cross-sectional plane: when the Type B
                                                                                                       pilot tube Is In this position, it is at "0° reference." Nole
                                                                                                       the differential pressure (Ap) reading at each traverse
                                                                                                       point.  U a null (tero)  pilot  reading  Is obtained at 0°
                                                                                                       reference at a given traverse  point, an acceptable flow
                                                                                                       condition exists at that point.  If the pltot reading Is not
                                                                                                       cero at 0° reference, rotate thCpltot tube (up to ±90° yaw
                                                                                                       angte),nnUlanuJu'readl nils obtained. Carefully determine
                                                                                                       and record the value of the  rotation  angle (a)  to  the
                                                                                                       nearest degree. After the null technique has been applied
                                                                                                       at each travrse point, calculate the average of the abso-
                                                                                                       lute values of a; assign a values of 0° to thorn points for
                                                                                                       which no rotation was required, and Include those In inn
                                                                                                       overall average. If the average value of at Is greater limn
                                                                                                       10°, the overall (low condition In the stack l» unacceptable
                                                                                                       and alternative methodology, subject to the approval of
                                                                                                       the Administrator, must be  used to perform accurate
                                                                                                       sample and velocity traverses.
                                                                                                         1. Determining Dust Concentration In a das Stream.
                                                                                                       ARME. Performance  Test  Code No.  27. New  York.
                                                                                                       1957.
                                                                                                         •t.  Devorkln, Howard, et el. Air Pollution Source
                                                                                                       Testing Manual. Air  Pollution Control  District.  I-is
                                                                                                       Angeles, CA. November 1903
                                                                                                         3.  Methods for Determination of Velocity, Volume,
                                                                                                       Dust and Mist Content of liases. Western Precipitation
                                                                                                       Division of Joy  Manufacturing Co. Ix»  Angeles, CA.
                                                                                                       Bulletin WP-60. 1968.
                                                                                                         4. Standard Method for Sampling Stacks for Paniculate
                                                                                                       Matter. In: 1971 Book of ABTM  Standards.  Part 2.1.
                                                                                                       ASTM Designation D-2928-71. Philadelphia, Pa. 1971.
                                                                                                         S. Hanson. H. A..etal. Paniculate Sampling Slralegiiis
                                                                                                       for  Large Power Plants Including Nonunlform  Flow.
                                                                                                       USEPA. ORO,  ESRL, Research Triangle Park, N.U.
                                                                                                       EPA-600/2-76-170. June 1076.
                                                                                                         6. Entropy Environmentalists. Inc.  Determination of
                                                                                                       the Optimum Number of Sampling Points: An Analysis
                                                                                                       of Method 1 Criteria. Environmental Protection Agency.
                                                                                                       Research Triangle Park, N.C. EPA Contract No. 68-01-
                                                                                                       8172. Task 7.
                                                               HI-52

-------
                         METHOD 2— DETERMINATION  or STACK (!« VELOCITY
                          AND VOLUMETRIC FLOW IIATI (TYPE 8 1'ITOT TUIIE)

                         1. l"rlnclflr atut AppHcatMUt

                           1.1  Principle. The average gas Telocity In a-stack Is
                         determined from the gas density and from measurement
                         of HIP average velocity head with a Typo & (Stausscheiuo'
                         or reverse type) pilot lube.
                           1.2  A ppucahilily. This  method  Is applicable .for
                         measurement of the average velocity of a gas stream and
                         for i|tianlifyli>it fax flow.
                           This pmcoduro Is nut applicable at measttremrnl si Ins
                         which Cull to innet the criteria nf Method  I.  flection 2.1.
                         Also, the method cannot l>e used for dlrecl measurement
                         in nycliinir. or swirling gnu streams; Bw.tlon 2.4 of Method
                         I shows hnw to dulermine ryclonic or swirling Dow con-
                         ditions. When unacceptable conditions exist. alternative
                         (iroccduras. subject to the approval of the Administrator,
                         Vl.S. Knvironmenlal I'rotwlion Agency, must be em-
                         ployed u> make octuirale (low rate  detenninailons;
                         ciamples of such alternative (irocedures are: (I) to install
                         slrBigntciilng vanes: (2) to calculate the total volumetric
                         flow rale sloichlomelrically, or (3)  to move to another
                         fncasurumonl site at which the flow ta acceptable.
                                                  2.

                                                    S|*cin.ca( Inns for the spiamt'n.i are given hrlnw. Any
                                                  other apparatus that has been dumon.strated (subject to
                                                  Biiproval of the Administrator) to Ixi capable of meeting
                                                  the spcclllcations will bo considered acceptable.

                                                    l!.l 'J'y|K! K 1'iUli  Tlllui.  The Tyfio S nilol Inlm
                                                  (FiKtire 2-1) shall bo made of metal lulling' fr.R., sUiin-
                                                  less «t«>l).  It Is recommniidod thul the oxtcrmil tuliinK
                                                  dlunioter (dlniensloQ !>,, Figure  2-2h) be between OM
                                                  and O.Ufi ccntimeterg (Me and H Inc^h).  Thoro shall >M
                                                  an equal distance from the bam of eiich  log of the pit/it
                                                  tube to Its face-opening plane (dimensions 1't and I'a,
                                                  Figure 2-2h); It u rocotnninnded lli:it this distamxi bu
                                                  between 1.06 and 1.00 (linos the external In hi nc dinmelnr.
                                                  The face openings of the pilot tube shall, preferably, be
                                                  aligned an shown In Figure 2-2; however, slight inisuliun-
                                                  inents of the openings are permissible (see Figure 2- :<).
                                                    The Type 8 pilot tube snail have a known raelllcient,
                                                  determined as outlined In Section 4. An idenUficalion
                                                  number shall be assigned to the pilot tube; this number
                                                  shall be permanently marked or engraved on Ihe liody
                                                  of the tube.
                                 Figure 2-1.   Type S  pilot tube manometer assembly.
1.90 -2.54 cm*
(0.75 -1.0 in.)
           T    I  7.
,62 cm (3 in.)*
                                           ,
                                         *j      TEMPERATURE SENSOR
                     •SUGGESTED (INTERFERENCE  FREE)
                      PITOT TUBE • THERMOCOUPLE SPACING
                                                                    111-53

-------
    TRANSVERSE
    TUBE AXIS
              \
                         FACE
                    •*- OPENING
                        PLANES

                          (a)
                         A SIDE PLANE
LONGITUDINAL
TUBE AXIS
' Dt
. t
A
B
                                                   NOTE:

                                                   1.05Dt
-------
        TRANSVERSE
         TUBE AXIS
                               j      <•>      I
LONGITUDINAL
  TUBE AXIS—
                                                  (I)
                                                  (g)

             Figure 2-3. Types of face-opening misalignment that can result from field use or Im-
             proper construction of Type S pitot tubes. These wtU not affect the baseline value
             of Cp(s) so long as ai and 02 < 10°, 01 and 02 < 5°. z < 0.32 cm (1/8 In.) and w <
             0.08 cm (1/32 In.) (citation 11 in Section 6).
                                           111-55

-------
   A ttftiidhrri rlullnbn nifty l>ftct
 l»v:isi]rr hi.liw nl slaiiiliird pilot tulwa are auoepllbm to
 pliir'.-inc In  |nir(lrnluli--lftilr-n nan ilriiims.  Tnorofiin-,
 »h..|i.'vcr B sliiiutiirit pilot tnlw I* u»''IIIIK>: n| I In' piint tnlw lmvi> rot pliwd up during His
 travi-rsr ivri'Ml: this run !«• ilonn hy  iJiking  & vi'Iixiily
 hi'Mil ilol tnhr. by
 "liri'-k-pnrvin^" with prcssnrim! ixir, ;ut A/» ri'iHlinn* miulo In-fore and
 nflrr llii'airiiw.'i'iin-llii-saiiKM  I R piwnl), llio Ir.iviTSO
 it  :u-c.-|llftl,l!>cd wllh a  10-ln.  (wal«r  column) inchiii-d-
 vcrlical nmiioin.-.UT. havlliK O.OI-ln. Hi»> divisions on tho
IV  to i-ln. Incliiipcl scale, anil li.l-in. IIiO divisions on tho
 I-  to iil-lii. vertical s-uln. This  type of  mannmctw (or
other gallE* of nquiviili-nt srnsltlvlly) Is sal lnfiu'.lory for
 tin' iniwnirernr.iit ol Ap values  at low as 1.3 mm (O.fHl in.)
 lli«>. However, a  dllWonllal  pressure gauge of xriMlcr
sensitivity shall Iw used (subject to the aiiproval of the
AilmlnlslruUir). If any  of the following  Is found to be
Inn-: (I) tbn arithmetic  average of all Ap readings at tho
 traverse points in the stack Is less than 1.3 mm (0.05 in.)
 HrO; (?) for travcrsi* ol 12 or more polnUi, more than  10
 pwnnt of the Individual Ap readings are Iwlow 1.3 rnm
 (0.05 in.) JliO;  (3)  for traverses ol fewer  than 12 points,
more than one Ap reading la below 1.3 mm (0.06 In.) TliO.
 Citation lit In Section 0 dereribes commercially available
instrumentation for thn moasnromon t of low-range gaa
velorllira.
  As un altcrnntlvo to criteria  (I) through (3) above, the
following calculation may be |>crfnrmcd to determine the
neoiswily of using n more sensitive difTivmiUal imcaura
where:
  Ap(=Tndividnal velocity head reading  at a traverse
        point, mini I iO (in. H.O).
    n=Totalnumberoftravorsepotnts.
    A'=0.13 mm 1I>O when metric units  are used and
        0.006 In IIiO when English units are used.

If  T ia greater than 1.05, the velocity head data are
unncceplable and » more scnsillvo differential pressure
gauge muni Ixi used.
  NOTE.— If diffcToiilial  pressure  gauges olhnr  than
Inclined manometers arn used (e.g., iiiftgnoliollc gawx).
their calibration must Iw chocked aflcr each tnsl mri<«.
To chuck the calibration of a differential pressure garnie,
compare AJJ readings of the gunge wilh thoso of a gauge-
oil  innnoinelcr in a minimum of three polnla, approxi-
mately representing Hie range of Ap values in Ihe stack.
If, al each point, the values nf Ap as read by the differen-
tial  pressure gauge nml gauge-oil nmnonieler agree to
wjl.hin '.t percent., tho differential pressure guuge shall bn
considered lo be in pn>|.er nillbnition.  Otherwise, thn
test si-iies shall cither  hi: voided, or proeediim lo adjust
the measured A;< valuta ami final results shall l>o used,
subject lo the approval >>r Lhn Administrator.
  2.:!  TcmpeiiiMiro  c.'uige.  A thermocouple, Hipii'l-
filli-d bulb IhiTinomrler,  bimetallic llierinoineler,  rniT-
cury-in-glass tln-rniomiiti-r,  or olher  EUHKC caiittbln of
mi'iisurlng h>.ni|n:niliirc to within !.!> percent nfllm mini-
mum  absolute  slack  tomiH'ralurc  shall be used.  Tho
temperature gauge shull be atlacln:d  Lo Iho pilot  lnl>e
such  Ihal Ihe.scrisor ti|i lines  not tdiieli  any me.tal; tho
gnnge si.all be in an inlTfcrmicc-friv! armngen:enl v*ith
n-siiect lo tht-  pilot tnhf  fane openings (see KiKure '2-1
anil also Figure i!-7 in Section 4). Alternate positions may
be  used if the pilot tiibe-tcmporaturc gauge system is
calibrated according to Ihn procedure of Seclion 4.  Pro-
vided Ihal a difference of nol more than 1 percent In the
average velocity measurement is introduced, the  ttm-
 poralura gange need not he attached Ui the pilot tnh«:
 this  alternative  is  subject  to  the approval  ot  the
 /ilmlnUtralor.
  ".4  Prcwiiiro Prolieand dn'iee. A pler.ometiT tube and
 ninre.ury. or wulnr-iillrd IJ.lubr nianometer capable of
 iiii-nsiiring stm-.k pressure to within 2.S nun (n.l In.) Hg
 ir usi-il. The st.ftt,ic lap ol a standard type pilot lube or
 o-in lei; ol a Typo X pilot Lube with the faco opening
 plains positi'ineil parallnl to (he B;IS (low may also  bo
 usi-d :is Ihe pressure prol>e.
  ^.5  BarotncliT. A mercury, aneroid, or other barom-
 eler  capable  ol  measuring  almospherlc  pressure  to
 within Z.ft mm Hg  (0.1 In. llg) may be used. In many
 cases, the  barometric reading may be obtained from a
 neiirby national weather service station.  In  which case
 tho  station  valuo (which Is  the absolute  barometric
 pleasure)  shall bo  requested and an adjustment for
 elevation  dllTorences between the weather station and
 t' e sampling point shall be applied at a rate of minus
 2..1 nun (O.I In.)  Ilg pnr :e B pltot tul>e Is necessary (see Section 4), a standard
 pilot tuba Is usod- as a reference. Tbe standard  pltot
tube shall, preferably, have a k now n coefficient, obtuned
either (1)  directly from the National Bureau of Stand-
 ards, Route 270, Quince Orchard Hoad,  Qallherabtirg,
                                                                                                                  Maryland, or (2) by calibration M;nlnsl another standard
                                                                                                                  pltot  tulio wllh an  MiH-lruianlilc  ^mlllcliinl  Alter-
                                                                                                                  natively, a standard  pilot lube  ili-slgned ncconllnt; 1,1
                                                                                                                  the criteria Klven In '2.7.1 throiiKh 2.7..ri In-low ami illus-
                                                                                                                  trated In Figure 2-4 (SUM- nlsii (Stations V. K, and 17 In
                                                                                                                  Section 6) may be. used. I'ilol lulms di-slKncil ai'»irdlnr
                                                                                                                  to these siiecllleallons will have  hiueline eoellicieiits of
                                                                                                                  almiitO.Mi.L-0.fll.
                                                                                                                    2.7.1   Hemispherical (shown In  Figure.2 4),e.lli|iniidal
                                                                                                                  or ennleal lip.
                                                                                                                    2.7.2   A nilnlmuinorsl. the exlernal diameter of  tin; ini,e) I,I.|,VM en  the
                                                                                                                  tip and the static pressure liolu.i.
                                                                                                                    2.7.3  A  minimum  ot eight diameters  straight run
                                                                                                                  between the static pressure holes and the. eeMle.ilino of
                                                                                                                  Hie external tube. lollowiitR'thc. (JO dftrri-e. b<>nd.
                                                                                                                    2.7.4  St.at.ic pressure holesole*<|Ual si7,e MMipniMlnialely
                                                                                                                 0.1 It), c<|Ually s|)a<.-eil In a ple7.omeler rint' eiinlieuralion.
                                                                                                                    2.7.5  Ninety degree bend,  with curved or milcrcd
                                                                                                                 jnne.Uon.
                                                                                                                    2.8   Dlirerenllal Pnissnrn flange fur Type S  I'ilut
                                                                                                                 Tu)>c (julibratlon. An  inclined niannrni-ler ur eiiulvalent
                                                                                                                 Is used.  II  the  single-velocity callbrati.m  liwlmiiiuc Is
                                                                                                                 employed (see Section 4.1.2.3), the calibration iliireren-
                                                                                                                 tlal pressure gauge shall IK readable U> Hie ncon'sl (1.1.1
                                                                                                                 rnm IIiO (H.OOSln. IIiO). For mulUvelnclty callbmlion.i,
                                                                                                                 tho gauge shall be readable to the nearest (). 1.1 mm I ho
                                                                                                                 (0.005 In IIiO) for Ap values between l.:i und 25 mm IIiO
                                                                                                                 (0.05 and 1.0 In. HrO). and to the nearest 1.3 nun lltO
                                                                                                                 (0.06 in. 11 iO) for Ap valued above JB mm IIiO (1.0 In.
                                                                                                                 HrO). A spedal, more sensitive gaun will be required
                                                                                                                 to read Ap values below  1.3 mm HiO (0.05 In. IIiO]
                                                                                                                 (aee Cllattun 18 In Section 0).
                                                                                                                       CURVED OR
                                                                                                                  MITEREO JUNCTION
                                                                                                                                     STATIC
                                                                                                                                     HOLES
                                                                                                                                    (-0.1D)
                                                                                                                      .HEMISPHERICAL
                                                                                                                               TIP
                                                                     Figure 2-4.  Standard pilot tube design  specifications.
                                                        3. i'roctdure

                                                          3.1  Set  np tlifl apparnlii.H ft-s almwn In fU'.um  2-1.
                                                        Capillary tuoiriK or survo tanks instulh-tl hci.wcon the
                                                        rT):uion)i:tcr and pilot tuw may bn nsod'Lo fliiuipcn Ap
                                                        fluc.luutions. II is rocnmmmiflwl, but not rdjuirwj, that
                                                        a jmapst, leak-check be c/^rulucU^l, in follows: (1) blow
                                                        Ittrougti the pilot iinpucl opening until at )t-ast 7.6 cm
                                                        (3 in.) 11 iO velfxiily pnis.suni n^istr.rs on thn in:ii:omcier;
                                                        th**», close o(T the impact opnnint*. The prossi.ro shall
                                                        remain stable for at Inast  15 aocnnds; T2) do thn .  Other lc-tk-checlc
                                                        pn>cc),
                                                         3.'f  Mrn'iuro tti<; vlndly hou»l  ftn-l triiiiri'.rnliifi' ut Mm
                                                       truvcrmi nointH MI M* I HI-'I by M»lh'Ml  1. l':ii::nrn Ihui. KM.
                                                       propor dMpin'.ntial |>nnsijro KUURO IK bt:ini< uncil  fi.r tho
                                                       ruiute of Ap vnlu-H Kn''.'iiint.i>.r<-(l (wn Unction x.2).  If II  ia
                                                       rn«;f!WWiry Ui chaiiK" to  a more .Kc.niOlive KJUIK*', do :v>, mnl
                                                       nunoiiMiirn tho Ap and  Ic.mjMiruturo rt^ulinKs ut "H<;h tra-
                                                       viirifi point. (.'orHlur.ta jirtst-tnstloak f:hc<-.k ftnan'hil.nry),
                                                       (w dc.scrlbc'l ;   ^aiun H.I ubovo,  to vali'laf: the lr;iv:nio
                                                       run.
                                                         ;i.4  Mca:.iirn tlie st;iUc pressure in thi slii':k. '»ue
                                                       r'lading in usually adci^uutb.
                                                         3.6  Determine thft almoHpherlr, prcsstirn. .
                                                                             111-56

-------
PLANT.
DATE .
        , RUN NO.
STACK DIAMETER OR DIMENSIONS, m(in.)
BAROMETRIC PRESSURE, mm Hg (in. Hg)
CROSS SECTIONAL AREA.
OPERATORS __
PITOTTUBEI.D.NO.
  AVG. COEFFICIENT, Cp = .
  LAST DATE CALIBRATED.
                                     SCHEMATIC OF STACK
                                        CROSS SECTION
   Traverse
    PL No.
Vel.Hd..Ap
mm (mj HjO
                                 Stack Temperature
mm
 pfl
Hg (in.Hg)
                                 Avtrap
                     Figure 2-5t Velocity traverse data
                              111-57

-------
 S.« Determine the stack ge/i dry molecular weight.
For combustion  processes or processee that emit essen-
tially COt. O», CO. and Ni. ose Method 8. For processes
emitting essentially air, an analysis need not be con-
ducted; use a dry molecular weight of 29.0. For other
processes, other methods, subject to the approval of the
Administrator, must be used.
 3.7 Obtain the  moisture content  from  Reference
Method 4 (or er dvalent) or from Method 5.
 3.8 Determine tbe crosa-eectional area of the stark
or  duct at toe sampling location. Whenever possible,
physically measure the stack  dimensions rather than
using blueprints.

4. CUfora/lM

 4.1 Type 8 Pltot Tube. Before its Initial use, care-
fully mr«mhm the Type 8  pltot tube In  top, side, and
end views to verify that the face openings of tbe tube
are aligned within the specifications Illustrated In Figure
9-t or 3-3. The pitot tube shall not be osed If it fails to
meet these fiiigiii»*mt specifications.
 Altar verifying the face opening alignment, measure
and record tbe following dimensions of the pltot tube:
(a) the external tubing diameter (dimension Di, Figure
2-2b); and (b) the  baw-to-openmg  plane distances
(dlmenskna P* and Pa, Figure 2-2b). If D, It between
0.48 and 098 cm (M« and H In.) and If Pi and Pe are
equal and between 1.08 and 1.50 R,. there are two possible
options: (1) the pltot tube may be calibrated according
to tbe procedure outlined  in Sections  4.1.2 through
4.1.S below, or (2) a baseline (Isolated tube) coefficient
value of 0.84 may be assigned to the pilot tube. Note,
however, that if the pltot tube Is part of an assembly,
calibration may still  be required,  despite knowledge
of the baseline coefficient  value  (see Section  4.1.1).
  If Di, PA, and PS are outside tbe specified limits, the
pltot tube must be calibrated as outlined In 4.1.2 through
4.1.6 below.
  4.1.1 Type 8 Pilot Tube Assemblies. During sample
and velocity traverses, the Isolated Type 8 pltot tube Is
not always used: In many Instances, the pltot tube la
used In combination with other sourofreampllng compon-
ents (thermocouple, sampling probe, notile) as part of
an "assembly." The presence of other sampling compo-
nent* can sometimes affect the baseline value of the Type
8 pltot tube coefficient (Citation 9 In Section 8); therefore
an assigned (or otherwise known)  baseline coefficient
                                                                            value may or may not be valid tor a given assembly. Tim
                                                                            baseline and assembly coefficient values will be identical
                                                                            only when tbe relative placement of the components In
                                                                            tbe assembly Is such that aerodynamic Interference
                                                                            effects are eliminated. Figures 2-6 through 2-8 IllustnUn
                                                                            Interference-free component arrangements for Typo s
                                                                            pltot tubes having external tubing diameters bolweimj
                                                                            0.48 and 0.88 cm (Mo and H In.). Type 8 pilot tnbo assem-l
                                                                            biles that fall to meet any or all of the specifications of
                                                                            Figures 2-6 through 2-8 shall be calibrated according Ui
                                                                            the procedure outlined In Sections 4.1.2 through 4.1.5
                                                                            below, and prior to calibration, the values of the Inlrr-
                                                                            component spaolngs (pltol-uoule, pitoUhcrmocouiili',
                                                                            pilot-probe shealb) shall be measured and recorded.
                                                                              Nont.—Do not use any Type 8 pltot tube assembly
                                                                            which Is constructed such that the Impact pressure open-
                                                                            Ing plane of the pltot tube Is below the entry plane of the
                                                                            noirle (see Figure 2-6b).
                                                                              4.1.2  Calibration Betnp. If the Type 8 pltot tube Is to
                                                                            be calibrated, one leg of the tabe shall be permanently
                                                                            marked A, and the other,  i. Calibration shall be done In
                                                                            a flow system having the following essential design
                                                                            features:
                      IfL
                                                     TYPE SP8TOT TUBE
                                 J K £ 1J6 on (3/4 in.) FOR DR »1.3 cm (1/2 in.)

                                B*^*^HH'|BMBMMMH^^^nc^MiAHiMMHMBDMBVMaBm^^MEBMaMVA-v^
                   SAMPLING NOZZLE
           A. BOTTOM VIEW §HOWtNG MINIMUM E»!T@T-NOZZLE SEPARATION.
SAMPLING
  PROBE
                          \
                                                      SAMPLING
                                                        NOZZLE
                                                         STATIC PRESSURE
                                                           QPENB^G PLANE-
                                                                                          IMPACT PRESSURE
                                                                                            OPENING PLAiE
                   SIDE VIEW; TO PREVENT PITOT TUSE
                   FROM INTERFERING WITH GAS FLOW
                   STREAMLINES APPROACHING THE
                   NOZZLE. THE IMPACT PRESSURE
                   OPENING PLANE OF THE PITOT TUBE
                   SHALL BE EVEN WITH OR  ABOVE THE
                   NOZZLE ENTRY PLANE.
         Figure 2-6.  Proper pitot tube • sampling nozzle configuration to present
         aerodynamic interference; buttonhook • type nozzle; centers of nozzle
         and pitot opening aligned; Df  between 0.48 and 0.95 cm (3/16 and
         3/8 in-).
                                              J.II-58

-------
                    THERMOCOUPLE
                                              «V>7.S2cm
                                                (3»J
 -rr
                                 -rr
                                                    Z> 1.90 cm (3/4 in.)
                                                                  THERMOCOUPLE
                                                                                                   2>S.M)cm
           Dt
TYPE SWOT TUBE
    SAMPLE PROBE
                                                                              r-
                                                                                                               -O-
                                                                                                   TYfES PITOT TUBE
                                                        , SAMPLE PROBE
                                 Figure 2-7.  Proper thermocouple placement to prevent interference;
                                 Of between 0.48 and 0.95 cm (3/16 and 3/8 in.).
                                                                          TYPE SPITOT TUBE
                                                            Y>7.62em(3inJ
                                                       n;i!i  mi
                                                 SAMPLE PROBE
Figure  2-8.  Minimum pitot-sample probe separation needed to prevent  interference;
     between 0.48 and 0.95 cm  (3/16 and 3/8 in.).
  4.1.2.1 Tbe flowing gas stream must be confined to a
duct of definite croBB-eecttonal area, either circular or
rectangular. For circular crosMecUona,  the minimum
duct dmmeter shall be 30.6 em (12 In.);  lor rectangular
iTom-aeetlona, the width (shorter side) shall be at leaot
r>.4cm (10 In.).
  4.1.2.2 The cross-sectional area ol the calibration duct
must be constant over a distance ol 10 or more duct
diameters. For a rectangular cross acctlon, me an equiva-
lent  diameter, calculated from tbe following equation,
to determine the number of duct diameters:


                n __2y
                *A — ... . jjj'S
                                Kqualinn 2-1

  //.=Equivalent diameter

   ll'=Wid'th

  To ensure the presence of stable, fully developed flow
patterns at  the calibration site, or "test section," tbe
site must be located at least eight diameters downstream
and two diameters upstream from the nearest disturb-
ances.
  NOTE.—The eight- and two-diameter criteria are not
absolute; other lest section locations may be used (sub-
Jncl to approval of the Administrator), provided that the
flow «t the ttet site is stable and demonstmbry parallel
to the duct axis.
  4.1.2.3 Tbe flow system shaD  bave the capacity to
iroiierate a lost-section velocity around 915 m/min (3,000
                                               fVuiln). This velocity most be constant with time to
                                               guarantee steady lluw  during calibration. Not* that
                                               Type 8 pilot lube cmfllclenls obtained by single-velocity
                                               calibration at 916 ni/min (3,000 ft/mln) will generally be
                                               valid to within ±3  |»rcent  for the measurement of
                                               velocities above 9116 m/mln (1,000 ft/mln) and to within
                                               ±S to 0 percent for Hie measurement of velocities be-
                                               tween 180 and 306 m/inin (600 and 1,000 fl/mln). If a
                                               more precise correlation Iwtwecn C, and velocity is
                                               desired, the (low system uhall bave tbe  capacity  to
                                               generate at least four distinct. time-Invariant tostaectlon
                                               velociUee coverlug the velocity range from 180 to 1-525
                                               m/min (900  to 6,000 ft/mln), and calibration data shall
                                               l>e taken at regular velocity intervals over this range
                                               (see Citations 9 and 14 in Section 8 for details).
                                                 4.1.2.4 Two entry  ports, one each for the standard
                                               and Type 8 pi tot tubes, shall be cut In the test section;
                                               the standard pitot entry port shall be located slightly
                                               downstream of tbe Type 3 Port, so that the standard
                                               and Type 8 impact openings will lie in the same cross-
                                               sectional plane during calibration. To facilitate align-
                                               ment of the pitot lubns during calibration, it is advisable
                                               that the test section be constructed ol pleiig!as>or some
                                               other transparent material.
                                                 4.1.3 Calibration Procedure. Note lliat this procedure
                                               Is a general one and most not be used without llrst
                                               referring to the .special considerations presented in 8w>
                                               lion 4.1.5. Note also that this procedure applies only to
                                               single-velocity calibration. To obtain calibration data
                                               lor the A and U sides of lue Type S pitot lube, proceed
                                               as follows:
                                                 4.1:3.1 Make sure  that the manometer is properly
                                               filled and that the oil Is free from contamination ana Is of
                                               the proper den.-ity. Inspect mid li'ak-chn-b all pilot linci;
                                               repair or n-pUice if nwr; «.ary.
                                                                         4.1.3.2  I*evel and KOTO the manometer. Turn on lh»
                                                                       fan and »llow tbe flow to stabilize. Beul the Type S mm y
                                                                       port.
                                                                         4.1.8.3  Ensure that the manometer lit level and uroitl.
                                                                       Position the standard pitot tube at the calibration pol.it
                                                                       (determined as outlined to fiction 4.1.6.1), and align l)i»
                                                                       tube so that Its Up Is pointed directly into the now. 1'ar-
                                                                       tloolar care should be taken In aligning the tube to avoid
                                                                       yaw ant) pitch angles. Make sure that the  entry |M>rl
                                                                       surrounding the tube is properly sealed.
                                                                         4.1.3.4  Read Apuj and record it» value in a 
-------
 PITOTTUBE IDENTIFICATION NUMBER:

 CALIBRATED BYr.	
                    .DATE:.

RUN NO.
1
2
3
"A" SIDE CALIBRATION
' A pad
cm H20 •
(in. HzOi




Ap(i)
cmH20
(in. H20)



Cp (SIDE A)
Cp(s)





DEVIATION
Cp(,) • Cp(A)





RUN HO.
1
t
3
"B" SIDE CALIBRATION
Ap$td
emH20
(in.H20)




AP(S)
crnHjO
(in.HzOI



Cp (SIDE B)
Cp(s)





' DEVIATION
Cp(,)-Cp(B)
•



                                                  S|Cp($)-Cp(AORB)|

      AVERAGE DEVIATION =  o (A OR B) =	
                             •MUSTBE<0.01
      | Cp (SIDE A)-Cp (SIDE B) |-*-MU$T BE <0.01
                         Figure 2-9.  Pitot tube calibration data.
  4.1 .4.3  Calculate the deviation of each of the threw A-
slde values of CV(,) from C, (slnVA ), and tho deviation of
each U-slde value of epc.> from "t\ (side B ). Use the fol-
lowing equation:


        Deviation- G'pr. > — <'„( A or  II)
                                                                                                           4.M.4  CalonlaU ff, thfl average deviation from ill')
                                                                                                         moan, for both Uio A. and U sides nf the pilot lube. Use
                                                                                                         the following equation:
                                                                                                           a (side A or IJ) =
                                A p.

                                  Equation 2-2
where:
   C»{.)=Type B pilot lube coufDclont
 ft      n>  *•  .1  II » * l~    l¥t l   l     A AA l« 11    iiv*««l», wlu isp VBIUD  *» j, vim JI1ISU1 Jl-nluo CUOIIIl'.lullh,
 CV(.,d>=8tandajdpltot tub* coefficient; use 0.99 If the  calculate  the  difference  between  them  two  average
         coefficient Is unknown and the tube la designed  rallies.
         according to tbe criteria of Suctions 2.7.1 to
         2.7.5 of this method.
   Ap.id=Velocity bead measured by tho standard pilot
         tube, cm HiO (In. 1I|O)
    Aj).=Veloclty head measured by the Type B pilot
         tube, cm 1W (In. HiO)
  4.1.4.2  Calculate  V, (side A),  tbe mean A-side coef-
ficient, and C, (side B), thn moan I) side coefficient;

                                   Equation 2-4

  4.1 .-1:5  Use Ihc Type S pilot tube only if Iho values of
v (Siiln A) and a (side 11) arc less than or equal to 0.01
and if the absolute value of the difference between C'F
(A) and C, (B) Is 0.01 or less.
  4.1.T, Special considerations.
  4.1.5.1  Selection of calibration point.
  4.1.5.1.1  When an  Isolated Type 8 pilot lube is cali-
brated, select a calibration point at or near the center of
the duct, and follow tho procedures outlined in Ructions
4.1.3 and 4.1.4 above. The Type B pilot coefficients so
obtained, l.e-.'Cp (side A) and C, (side fi), will  be valid,
so long as either: (1) the isolated pilot  tube is used; or
(2) tho pilot tube is used with other components (nozcta,
thermocouple, sample probe) In an arranKcnio.nl that is
free from aerodynamic  interference effects (see Figures
2-0 through 2-8).
  4.1.5.1.2  For Typo B pilot tube-thermocouple com-
binations (withoul sample probe), select a calibration
point at or near the center of tho duct, and follow the
procixlurca outlined in Sections 4.1.3 and 4.1.4 abov«.
The cxmfUclonts so obtained will bn valid so long as thn
pilot  tube-thermocouple combination Is usod by Itself
orwlthollmrcomponnnlsin an Inlfrferonee-free arrange
incut (Figures 2^ and 2-8).                         i
  4.1.5.1.3  For  assemblies with  sample probus,  Hint
calibration point should be located at or near thn center
of tlin duct; however, Insertion of a probe shralh Into a
small duct  may  cnuso  slRniUciint cross-sectional  area
blockage and yield incorrect coefficient values (Citation 9
in Section 9). Therefore, to minimize th« blockage effect,
the calibration  point may be a  few Inches olf-ccntor if
necessary. The actual blockage effect will be ncgllgihln
when the  theoretical blockage,  as determined  by a
projectod-aroa model of the probe sheath, is 2 percent or
less of the duct cross-sectional area for assemblies without
external sheaths (Figure 2-10a), and 3 percent or less for
assemblies with external sheaths (Figure 2-10b).
  4.1.5.2  For those probe  assemblies in which  pilot
tube-nozzle interference  is a factor (i.e., those  in which
the pltot-nozzel separation distance  fails to meet the.
specification illustrated  In Figure 2-6a), the value of
Opt.) depends upon  the amount of free-space belween
the tube and nozzle, and therefore Is a function of nozzle
size. In these instances, separate calibrations shall be
performed with each of the commonly used  nozzle sizes
In place.  Note that the single-Telocity calibration tech-
nique Is acceptable for this purpose, even  though llio
larger no2zle?sizcs O0.63Bcm or 'A in.) are not ordinarily
used  for  Isokinelic sampling at velocities  around 915
m/min (3,000 ft/mln), which is tho calibration velocity;
note also that It is not necessary to draw an Isokinetic
sample during calibration (see Citation 19 in Section 0).
  4.1 5.3  For a probe assembly constructed such  that
IU pi tot tube is always used in the same orientnlion, only
one side of the pilot tulw need  be calibrated  (the eitln
which will face the flow). The pi lot lube nnist still niei.l
IhnaUgnmenlnper.incalionsof Figure'2 Vior'/.  :t, however,
find must, have an :ivcr:igc devluli'ti!  (>r
less '-:ce Hrnlinii4.l.4.4).
                                                                111-60

-------
                                                           ESTIMATED
                                                           SHEATH
                                                           BLOCKAGE
[puc
                            OUCTAREA
                                               xlQO
                             Figure 2-10.   Projected-area models for  typical pitot tube assemblies.
   4.1.8 Field TJso and liccalibralion.
   4.1.8.1  Field Use.
   4.1.6.1.1  When a Type 8 pilot tube (Isolated tube or •
 assembly) la used in tbo Held, the appropriate coefficient
 value (whether assigned or obtained by calibration) shall
 b« used to perform velocity calculations. For calibrated
 Type S pitol tube*, the A side coefficient shall be used
 when the A side of the tutie bees tlm How, and Uie D sidn
 coefficient shall be used when the 11 side tafia the How;
 alternatively, the arithmetic average of the A and B sidn
 coefficient values may bo used, irrespective of which sldo
 bees the flow.
   4.1.0.1.2  When a probe assembly Is used to sample a
 small duct (12 to 30 in. In diameter), the probo sheatli
 ROinntimes blocks a significant part of tho duct cross-
 section, causing a reduction In the effective value of
 7,(.). Consult Citation 9 In Section 0 for details. Con-
 ventional  pilot-sampling probe  assemblies  are  not
 recommended for use in duels having Inside diameters
 smaller than 12 inchns (Citation 1C in Section UJ.
   4.1.n.2  Itocalibration.
   4.1.0.2.1  Isolated Pilot Tubes. After «arh Held use, Ihn
 pitot tube shall be carefully renjuunincd in top, side, and
 end views.  If the pitol fan< oiicnings arn mill aligned
 within the spc<-iflninKS
 or the tiilxi shall he discorded.
   4.1.6.2.2  Pitot Tulie Asscinhlics. After each Held UK*.
 cheek the face opening alignment uf the pilot tube, :i:i
 In Section 4.1.0.2.1; also, remcasnrc the Intercomponent
- spacings of the assembly. If the intercomponont spacing
 have  not changed  and tho  face opening alignment is
 acceptable, it can IM assumed that the cocflicicnt of the
 assembly has not changed. If the face opening alignment
 Is no longer within the specifications of Kigurcs 2-2 or
 2-3, eilber repair llie damage or replace the pilot tuho
 (calihralint.* the new assembly, if necessary). If Die inlei-
 componenl simi-ings have chaniy:d, restore the urigin:il
 S|iacings or n?cali brain Die asscnilily.
   4.2  Slandard pilot lube fif applicable). If u standard
 pitot tube Is used for the velocity travcrsx Die tune shall
 be constructed according to the criteria of Section 2.7 and
 shall be assigned a baseline coefnclmt value of 0.99. If
 UK standard pilot tube Is used as iiart of an avcmbly.
the tube shall be In an interference-free arrangement
(subject to the approval of the Administrator).
  4.3  Temperature Gauges. After 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  stack temperature. For temperatures up to
405° C (701° F), use an A8TM inercury-lo-glass reference
Ihermometer, or equivalent, as a reference; alternatively,
either a  reference  thermocouple  and iwtentlometer
'calibrated by NUB) or Ihemionielrio flied  poiuls, e.g.,
ice bath  and. boiling water (corrected for barometric
pressure) may bo used. For temperatures above 405° C
(7(1° F), use an N US-calibrated reference Ihermocouplo-
polentiometer system or an alternate reference, subject
to the approval of the Administrator.
  If, during calibration, Ihe absolute temperatures meas-
ured with the gauge being calibrated and the reference
Kauge agree  within  1.5 percent, the temiwrature  data
luken In Iho Held shall  be  considered valid. Otherwise,
the pollutant emission  test shall either be considered
invalid or adjustments (if appropriate) of the test results
shall be madu, subject to the approval of the Administra-
tor.
  4.4  ftaroinclcr. Calibrate I he Imromelcr used against
a morciiry barometer.

5. Cakitlaliom

  Carry out rali-nlatinns,  rrlnining at lyrist one i-xtm
d(y^iraal ftgiiro beyond that of Lhc artjuireit duui. Hound
off Tiguria after final calculalinn.
  6.1  Komenclalure.
   A— Cross-soclional area of flack, m1 (ft*).
  Ha— Water vapor in the gas stream (from  Method r> or
       Referents Method  4), proportion  by vohnne.
   C,— Pitot tube cocfficicnl, dimcnsionlera.
  h',~ Pitot tube constant,

     IA 07  _"'  n»/ff-n><'l«0(min UK) "I"1

            H;cL   (0K)(ininllsO)   J
t»r i
                   aii4
                          for thn English system.
                              Mj=Molecular weight of stack gas, dry basis (see
                                 Section 3.6) g/g-mole (Ib/lb-mole).
                              M.=>Molecular weight of stack gas, wet basis, g/g-
                                 mole (IbAb-mole).

                                 =A/<(1—/J,,)+18.0B—          Equation 2-5

                             /'b.,=Baroinetrlc pressure at measurement site, nun
                                 Hg (In. Hg).
                              P,=Stack static pressure, mm Hg (In. Hg).
                              r,=Absolute slack gas pressure, mm Hg (In. Hg);

                                 =Ptu+P,                      Equation 2-6

                             /'.,,i=8landard absolute pressure, 760 mm Hg (29.92
                                 in. Hg).
                              y..i=Dry volumetric stack gas flow rate corrected to
                                 standard conditions, dsam/hr (dscf/hr).
                               '.—Black temperature, °O (*F).
                               /'.-Absolute slack temperature, "K (°R).
                                 =273+*. for metric

                                 -.400+(. for English
E>iuallon2 7

Kquatlon 2-8
                             T.-..t -Standard absolute temperature, 29:) °K (»2S° It)
                               ». =Avurage.stiu'.k gas velocity, m/sec (fl/snc).
                              A ;>- Velocity lucid of slack ins, mm lift) (in. IfiO).
                            ?,nfK)— Conversion factor, scc/nr.
                             1N.D -Molecular weight  uf  wutor,  g/g-mole  (ll>-lb-
                                molo).
                            5.2  Average slack gas velocity.
                                                            Equation 29

                                Avi:i:tgc :-loi-.k gas dry volumetric flow rate.
            ft  r(|b/lb-"iolc)(in-1|K)T/*
           K<;(-  L                      ~
                                                                                     Kquution 2-10
                            1. Mark, L. 8. Mechanical Engineers' HandlMok. Now
                          York, McOraw-UlU Book Co., Inc. 1961.
                            2. ferry, J. If. chemical Enclneera' Handbook. New
                          York  McGraw-Hill Book Co.,lno. I960.
                                                                      111-61

-------
  .1. Shigcbara,  R.  T.. W.  P. Todd, and W. 8. Smith.
Significance of Krrors in Hluck Sampling Measurements.
U.S.  Environmental Proleclion  Agency,  Research
Triangle Park, N.C. (Presented at the Annual Meeting of
the Air Pollution Control  Association. St. Louis, Mo.,
June 14 19, 176.
  13. Vollaro,  H.  V. An Evaluation of Single-Velocity
Calibration Techniciucw as a Means of Determining Type
8 Pilot Tube Coefficients.  U.S. Environmental Protec-
tion Agency, Emission  Measurement Branch, Kosearoh
Triangle Park, N.C. August 197S.
  14. Vollaro.  R. 1'. The Use of Typo 8 Pilot Tubes for
the Measurement of Low Velocities. U.S. Environmental
Protection  Agency,  Emission Measurement Branch,
Research Triangle Park, N.C. November 1970.
  15. Smilh, Marvin L. Velocity Calibration of EPA
Type  Source  Sampling Probe.  United Technologies
Corporation,  Pratt  and  Whitney  Aircraft Division,
East Hartford. Conn. 1978.
  16. Vollaro, R. F. Recommended Procedure for Sample
Traverses in Ducts Smaller than 12 Inches In Diameter.
U.S.   Environmental  Proleclion Agency, Emission
Measuremenl  Branch,  Research  Triangle Park, N.C.
November 1078.
  17. Ower, E. and R. C. Pankhursl. The Measurement
of Air Flow, 4th Ed., London, Pergamon Press. 1986.
  18. Vollaro, R. F. A survey of Commercially Available
Instrumentation for the Measurement of Low-Range
(las Velocities. U.S. Environmental Protection Agency,
Emission  Measurement Branch, Research Trlanglo
Park, N.C. November 1976. (Unpublished Paper)
  19. Onyp, A. W.. C.  C.  St. Pierre, D. 8.  Smith, D.
Motion, and J. Slelnor. An Eiperimcnlal Invesllgallon
of the  Effect of Pilot Tubo-8ami>llng Probe  Configura-
tions on the Magnitude of  Ihe S Type Pilot Tube  Co-
efllcienl for  Commercially  Available Source Sampling
Probes. Prepared by the University of Windsor for the
Ministry of Ihe Environment, Toronto, Canada. Feb-
ruary 1975.
                                          111-62

-------
MKTHOD  3-- n\»  ANAI.THI*  ro» C*nnon DIOXIDC,
  oxroxN, R XCEW AJR, ANI> UBT MOI.KCUI.AB WEIOHT
I.  I'riwliilr
  1.1  1'rlneiple. A Km sample Is extracted fruin a stack;
liy one of the following methods: (1) single-point, grab
Dimpling; (2) single-point. Integrated sampling; or (1)
multi-point,  inleiiruUid  sainpliiit. Thn gas sample la
analyzed [or  |K:n:nnl carbon dioxide (COt), Percent oiy-
ttcn ((),), an. I. U necessary, pnrciint carbon monoxide
U!(>). If a dry mnlramtar wHghl determination Is io to
m:yle, either  an Orsul or a Kyrllo * analyzer nmy boused
for the analysis; fur exeess uir ta omission rule. ritrrtrllon
Iivl'ir ilr-lnriiiiniilliin, nn (Irani analyvr must IHI UNM|.
  1.2  A|iplli'iil>lllly. Thb nicllnxl la ni>p!lcal>U> fur do-
tiTiiiluliiK (.'<>> fni'l <*? ronrcnlrfttlons. fxcmm air, .and
dry mnlrculur wHclit of n SHinpIo rrnin a Ran filrrani of a
fossil-fuel aunliWillnii pncuss. The method tu»y aLio to
npl'licalilntoi'lliiTpnicnssi'SwIinrelt lias h«*n determined
Hint rnniitoiinils olhnr limn < Mii. (>i. CO. and
'(N,) arc nut present  In  conraiitnltons  raOUdenl to
 alfHct the results.
  Other method*, tv* well aft niodlfleaUnnfi to the proce-
 dure dnncrllKid herein, an; also applicable for some or all
 of the above determinations. Kxnmples at specific miah-
•i»ls and inodlflcations include;: (I) a multi-point samp-
 ling method using an  Orsat analyzer tn analyze Indi-
 vidual grub sampler obtained at each point; (2) a method
 using CO: or Oi and stolchlomclrtc calculntlons to dc.U-r-
 niino dry molecular weight and excess air; (3) assigning a
 Viiiue ol au.u fur dry moierular weight. In lieu of actual
 mntsuromenU, for procisson burning natural gas, coal, or
 '.li
 systems Is subject lo the approval of the Administrator.
   2.1  Urab Sampling (Klguro 8-1).
   2.1.1   Probe. The probe should be made of slaiuleas.
 steel or borosilicale glass tubing and should l>o equipped
 with an in-stack or out-stack lilter to remove paniculate
 matter (a plug of gloss wool is satisfactory for this pur-
 pose). Any other material inert to Ot, COt, CO, and Nt
 and resistant to temperature at sampling conditions muy
 to used for the prolw; examples of such' material  are
 aluminum, copper, qnarti glass and Teflon.
   l.\..'. I'urnp.  A one-way squeeze bulb, or equivalent,
 Is used lo transport  the gas  sample  to Ihe analyzer.
•   2.2  Integrated Sampling (Figure :t 2).
   2.2.1  Probe. A probe such at thai described In Section
 2.1.1 is suitable.

   i .Mention of  trade names or specific products does not
 constitute endorsement by tlie Environmental Protec-
 tion Agency.
                                                                                            FLEXIBLE TUBING
                                                                                                                                 TO ANALYZER
                                                                          SQUEEZE  BULB
                                                                     Figure 31.  Grab sampling train.
                                                                                             RATE METER
                                AIR-COOLED
                                CONDENSER
                PROBE
                      \
                        \
                            FILTER
                        (GLASS WOOL)
                                                                            RIGID CONTAINER
                                                          Figure 3-2.  Integrated gas-sampling train.
                                                                     111-63

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   2.2.2  Condenser. An air-cooled or water-oooled con-
. denser,  or  other  condenser  that will not remove Oi.
 CO,. CO. and N>. may be used to remove excess moisture
 which would Interfere with the operation of the pump
 and flow meter.
   2.2.3  Valve. A needle valve Is used to adjust sample
 gas flow rat*.
   2.2.4  Pump. A teak-free,  diaphragm-type pump, or
 equivalent, Is use'1 to transport sample gas to the flexible
 bag.  Install a small surge  tank between the pump and
 rate meter  to eliminate the pulsation effect of the dia-
 phragm pump on the rotameter.
   2.2.6  Rat* Meter. The  rolamotcr, or equivalent rate
 meter, used should be capable of measuring; flow rate
 to within ±2 percent of the selected  flow rate. A flow
 rate range of 500 to 1000 cm'/mln is suggested.
   2.2.0  Flciible Bag. Any leak-free plastic (e.g., Tedlar,
 Mylar, Teflon) or plastic-coated aluminum (e.g., alumi-
 nlzed Mylar) bag, or equivalent,  having  a  capacity
 consistent with the selected flow rate and time length
 of the test run, may bo used. A capacity In the range of
 60 to 00 HUTS is suggested.
   To leak-check the hag. connect It to a water manometer
 and pressurize the bag to 6 to 10 cm IliO (2 to 4 In. HK».
 Allow to stand for 10 minutes. Any displacement In the
 water manometer Indicates a leak.  An alternative leak-
 check method Is to pressurUe the hag to 6 to 10 cm IljO
 (2 to 4 In. H>O) and allow to stand overnight. A deflated
 bag Indicates a leak.
   2.2.7  Pressure UaiiRe. A water-filled U-tube manom-
 eter, or equivalent, of about 28 cm  (12 In.) Is used  for
 the flexible bag leak-check.
   2.2.8  Vacuum Gauge.  A mercury manometer,  or
 equivalent, of at least 760 mm Hg (30 In. Hg) is used tor
 the sampling train leak-check.
   2.3  Analysts. For Great and Fyrtte analyter main-
 tenance and operation procedures, follow the Instructions
 recommended by the manufacturer, unless  otherwise
 specified herein.                                _
   2.S.1  Dry Molecular Weight Determination. An  Orsat
 analyter or Fyrite type combustion gas analyter may be

   2.3.2  Emission Hate Correction Factor or Excess Ah-
 Determination.  An Orsat analyter  must be used. For
 low COi (less than 4.0 percent) or high Ot (greater than
 15.0 percent) concentrations, the measuring burette of
 the Orsat must have at least 0.1 percent subdivisions.

 3. Dry Molecular Weight Determination

    Any of the three sampling and analytical procedures
 described below  may be used tor determining the dry
 molecular weight.
    3.1   Single-Point, Grab  Sampling  and  Analytical

    3 1 1   The sampling point In the  duct shall either bo
 at the centrold of the cross section or at a point no closer
 to the walls than 1.00m (3.3 ft), unless otherwise specified
 by the Administrator.
    312   Set up the equipment as shown in Flgnre 8-1.
 making sure all  connections ahead of the analytor  aro
 tight and  leak-free. If an Great analyter la  used. It Is
 recommended that the analyter be leaked-chec-ked by
 following the procedure in Section 6; however, the leak-

    313° Place the probe In the stack, with the tip of the
 prol>e positioned at the sampling point; purge the sampl-
 ing HneT Draw a sample  Into the analyter and imme-
 diately analyse It for percent COiond percent Oi. Deter-
 mine the percentage of the gas tliat 6 N, and CO by
 subtracting the sum of the percent  COi and percent Oi
 from 100 percent. Calculate the dry molecular weight as
 Indicated in Section 8.3.
    3 1 4   Repeat the sampling, analysis, and calculation
 procedures, until the dry molecular weights of any throe
 grab samples differ from  their mean by no more than
 0 3 g/g-mole (0.3 Ib/lb-mole). Average these three molec-
 ular  weights,  and report  the results to the nearest
 0.1 g/g-molc (ll>/lb-mole).            ,                .
    3.2  Singlo-I'oint, Integrated Sampling and Analytical

    3.2.1 "rhe sampling point U1 tho duct slia11 *"* locale(1
  asspecinodinSoctionS.l.l.   .........       ,
    322  Leak-check (optional) the flexible  bag as In
  Section 2.2.6. Set up the equipment as shown in Figure
  3-2  Just prior  to  sampling,  leak-check (optional)  the
  train by placing a vacuum gauge at the condenser inlet,
  pulling a vacuum  of at least 250 mm Hg  (10 in. llg),
  plugging the outlet at the quick disconnect, and then
  turning off the pump. The vacuum should remain stable
  for at Icast0.5 minute. Evacuate the flexible bag. Connect
  tho probe and place it in the stack, with the tip of the
  probe positioned at the sampling point; purge the samp -
  ing  line. Next, connect the bag and make stiro that all
  connections arc light and  leak free.
    323  Sample at a constant rain. The sampling  run
  should  bo simultaneous  with, and lor the same lotiU
  length of time as Hie |x>Hulanl emission rate determina-
  tion Collection of at Inast 30 liters (I.OOft')of sample gas
  is recommended:  however, smaller volumes may 1»
  collected,  if desired.                              .
    Hi! 4  Obtain  one integrated flue gas sample during
  each pollutant omission  rote deUirinlnaUnn. Within H
  hours after the sample Li taken, analyte it for percent
  CO. and percent O, using either on Orsat analyw.r or n
  Kyrite-typo combustion gas analyser. U an  Orsut ana-
   ytor Is used, it Is recommended  that the Orsat leak-
   •hock described In Section 5 be performed  before this
   loterminatlon; however, the check  is optional.  Deter-
  mine the percentage of the gas that Is Nt and CO by sub-
  tracting the sum  of the percent CO. and  percent Oi
from luo percent. Calculate the dry molecular weight ai
radicated In Section n.3.
  3.2.6  Repeat the analysis and calculation procedures
until the individual dry molecular weights for any three
analyses differ from  their mean by no more than 0.3
g/g-raole (0.31b/lb-mole). Average these three melecular
weights, and report the results to the nearest 0.1 g/g-mole '
(0.1 Ib/lb-mole).
  3.3  Multi-Point, Integrated Sampling and Analytical
Procedure.
  3.3.1  Unless otherwise specified by  the Adminis-
trator, a minimum of eight traverse points shall be used
for circular stackb having diameters less  then 0.61 m
(24 In.), a minimum of nine shall be used for rectangular
stacks having equivalent diameters less than 0.61 m
(24 In.), and a minimum of twelve traverse points shall
be used for all other cases. The traverse points shall be
located according to  Method 1. The use of fewer points
Is subject to approval of the Administrator.
  3.3.2  Follow the procedures outlined In Sections 3.2.2
through 3.2.5, except for tho following: traverse all sam-
pling points and sample at each point for an equal length
of time. Record sampling  data as shown In Figure 3-3.
4. Kmlwltm Rate Correction Factor or Kcetn Air fielcr-
"'mfnallon

  NOTE.—A Fyrllo-type combustion gas analyzer Li not
acceptable for ucess air or emission rale correction factor
determination, unless approved by the Administrator.
If hot h percent COt and  percent Ot are measured. Ilia
analytical  results of any of the three procedures glvc.it
below may also be used for calculating the dry molecular
weight.
  Each of the three procedures below shall bo used only
when specified in an applicable suopart of the standards.
The use of these procedures for other purposes must have
specific prior approval of the Administrator.
  4.1  Single-Point,  Urab  Sampling  and  Analytical
 Procedure.
  4.1.1  The sampling point In the duct shall either  be
at tho controld of the cross-section or at a point no closrr
 to the walls than 1.00 m (3.3 ft), unless otherwise specified
 by the Administrator.
  4.1.2  Set up  the equipment as shown in Figure 3-1,
making sure all connections ahead of the analyzer oru
 tight and  leak-free. Leak-check the Orsat  analyzer ac-
 cording to the  procedure described  In Section 5.  This
 leak-chock Is mandatory.
TIME




TRAVERSE
FT.




AVERAGE
Q
1pm





% DEV.a


i


                                  avg
                                        ')100        (MUST  BE < 10%)
                   Figure 3-3.   Sampling rate data.
   4.1.3  Place the probe In the stack, with the Up of the
 probe positioned at the sampling point; imrge the sam-
 pling line. Draw a sample Into Ihe analyter. For emission
 rate correction factor determination,  immediately ana-
 lyze the sample, as outlined in Sections 4.1.4 and 4.1.f>,
 for percent COi or percent O,. If excess air is desired,
 proceed as follows: (1) Immediately analyte the sample.
 as In Sections 4.1.4 and 4.1.5, for percent  COi. O>, and
 CO; (2) determine the percentage of  the gas that Is  Ni
 by subtracting the sum of tho percent CO*  percent Oi,
 and percent CO from  100  iwrcent;  ami (3) calculate
 percent excess air as outlined In Section 0.2.
   4 1.4  To ensure complete absorption  of the CO:, Oj,
 or If applicable, CO, make repeated passes through each.
 absorbing solution until two consecutive readings are
 tho same. Several passes (three or four)  should be made
 between  readings.  (If  constant  readings  cannot  be
 obtained after threw  consccuUve..readlngs,  replace the
 absorbing solution.)
   4.1.5 After  the analysis  Is  completed,   leak-chock
 (mandatory) tho Orsat analyzer once again, as described
 In Section 6. For the results of the analysis to ho valid.
 the Orsat analyter must pass this leak tost before and
 after tho analysis. NOTE.—Since this single-point,  grab
 sampling and analytical procedure is normally conducted
 in conjunction with a single-mint, grab sampling and
 analytical procedure  for a pollutant,  only one  analysis
 Is ordinarily conducted. Therefore, great  care must be
 taken to obtain a valid sample and analysis. Although
 in most cases only COi or Oi Is required, It Is recom-
 mended that both CO, and O, be measured, and that
 Citation 5 in the Bibliography be used to validate the
 analytical data.
   4.2  Kinglo-l'oinl, Inlegraleil Sampling :md Aimlyli'-iil
 Procedure.
   4.2.1  The. sampling |minl in Iho duel shall be located
 as specified in Section 4.1.1.
   4.2.2  Ixaik-check (mandatory) thn fleiible bag on in
 Section 2.2.  through 4.2.7). Tim
  Orsat analyier must  be leak-chocked  (see Section  r,)
  before tho analysis.  If excess ah" is desired, proceed  us
  follows: (I)  within 4 hours nfter the sample is taken.
  analyze it (as in Sections 4.2.5 through  4.2.7) for perce.nl
  COi  Oi, and CO; (2) determine the percentage of tlio
  gas that is N» by subtracting ttie sum of the iwrce.nl VI >i.
  percent Oi.  and percent CO from  100 percent; (3) cal-
  culot.c percent excess air, as outlined in Section 6.2.
    4.2.5 To ensure complete absorption of the C()>, Oi,
  or If applicable, CO, make re|>ealed passes through eocli
  absorbing solution untl I two consecutive readings arc tho
  same. Several passes (three or four) should be made be-
  tween readings. (I f constant readings cannot bo obtained
  after three coiisecutlvo readings, replace Iho absorbing

    4.2.0 Repeal the analysis until  the following criteria

    4.2.H.1  For percent CO», repeul lhi> analytical itrn-
  cndur". until the rr.snlls of any thr™ analyses illlfer by  no
  more than (a) (U |x-.rci>nl by vnlumn when < :<>, is greater
  lhan 4.0 percent or (b) 0.2 percent by volume when COi
  Is lews lhan or wjunl to 4.0 pereent.  Average the three  ac-
  ceptable values of percent COi and report the results to
  tho nearest 0.1 percent.
    4.2.6.2  For percent Oi, repeat the analytical procedure
  until loo  results of any three analyses differ by no more
                                                                            .111-64

-------
than (ft) o.:t |>creent by volume wbi-n O: is i-.«:s than lfi.0
|n*m--nt or tb) 0.2 percent by volume, when <>j Itt greater
than 15.0 p-rn-nt. Average the threw acceptable values of
Ih'i.tnii  i). nnd  report the results to the nearest 0.1

  4.2.6.:*  Fur jM>rcrnt CO, repeat  the  analytical proce-
dure, until Urn results of any three, analyses differ by no
hioro than O.*'l iwrccnt. Average  the  limn* acceptable
valutas of jvercent CO and report the. results to the, nearest
O.I porceut.
  4.2.7   A (I or  I he  analysis  is  roinpl«-|ed.  leak-check
(mandatory) the Orsat analy/.or once again, as described
in Her I. ion '.',. for the results of the amilysis to be. valid, the
Orsat anaiyxe.r must  pass tills leak lest before and after
thcanalyKi*. Note: Although in most instances only COj
or <>i is required, it is rcrornimmded that both CO» and
<>,!>•• measured, and that ClialionA in the Itjbliography
be used to validate thr. analytical data.
  4.:i   Multi-Point, Integrated Siimpling nnd Analytical

  4.3.1   (loth the minimum number of sampling points
,itid the sampling point locution shall  be as s|>ecillcd in
H'«:lion 3.3.1 of this method. The use of fewer points than
specified w aubjisct  to the approval of the Administrator.
  4.:t.2   Follow the procedure.*-- outlined in Sections 4.2.2
through 4.2.7, except  for the following: Truver.su oil
samnlitig (joint:;  and  sant|ile at enrh point for an wiunl
kim Hi of time. Itecord sampling datii ;is slum n in Figure


.r». l.(nk-(.1nct( /Yo«rfur«*/«r Ortol Anttlij:tn>

  Moving :in Orsat analyzer frequently ••;tu:.i-f- il to leak.
Therefore., ;in Orsat anuly/,er almuld be thoroughly taak-
rhecked on site, before  the Hue yas sample is intrrd the meniscus |K.sili«m.
  />.l.4   Obsi-rvn the meniscus in the burrltn  and the
Ilifiild lovct in the pipette, for jnoveinent over the next 4
rnlnuUis.
  5.1.6   For the  Orsat analyzer to |>as.s the. leuk-cncck,
two comllMous must he mrt.
  rf.l.fi.l  Tbt: lirjuid level In e.ach plpi*tte must not fall
below the bottom of the capillary tubing during Una

  .ri.l..V2  The meniscus In the bure.ite must not chan^t
by morn than 0.2 ml dm Ing this 4-ininuti: interval.
  .ri.l.O  If thu analyzer fails thn li*4ik-check proiN^lure. all
rublHT comu*clioi)M and *itopi:ot;ks should bo  c.hockiMl
untilthocaiisoofthelrak Is Idv.nLillrd.  Ixvikhig HtO|)c4>
re|M-uled.
             6. Calculation*

               6.1  Nomenclature.
                  Mr-= f)ry molecular weight, g/R-nioh: (lb,!b-mole.).
                %KA~ Percent excess air.
               %COj=J*ercentCOi by volume (dry basis).
                 %Oj= Percent Oi by volume (dry basis).
                %<:<)- Percent (JO by volume (dry basis).
                 %Na= Percent Nt by volume (dry basis).
                 0.264= Ratio of Oj to Ni in air, v/v.
                 0.2XO~Mo!ocular weight of NiorCO, divided by 100.
                 0.320- MnU-culur weight of Oj divided by 100.
                 0.44(1-^Mohiciilar weight of COj divided by 1'X).
               fi.2  IVn-.cint Kxci'^s Air. f'alr.utate thr |n-re,ent 1-xc-es.s
             nir  (if  applicable),  by substituting  the  appropriate
             vahie,sof |te.n:entO/, CO,and Ni(obl:tincd from Krclinn
             4.1.3 or 4.2.-I) inlo K* %N»(%Oa--0..ri%CO)
                                                                  "
                                                   l^juntioii .'I  1

                NOTK. — The.  e(|U:'Hon above. ns.sumea that ambient
              nir Is used ;vs the source, of < h nnd that Die fm.'l do)
                NmK.   ') b«- -.iliiiv-: "(ualion dors not consider ar^on
              in air  (about O.!l pctc.imt, molecular  weight of 37.7).
              A  nexutivi: error  of  about 0.4 prrcetit  !s introductxl.
              The Uytor may opt tuin;il of Air and  Water
              Pollution. C:75 HI. I!HW.
                2. Conner, William \). and J. R. Nader. Air Sampling
              J' las tic,  Itugs. J
-------
MKTIIOII  1  • DtThRMivATinN  or MOIHTURK (?ONTKNT
                   IN HTACK  (JAHMI

t.  I'rlurliitt antt AriitllfttliUllg

  I.I   I'rlniviplc  \ (/tin nmiplc is oitrautwl at ft WHISMWU
ruin from I Im .VHIP-I'; moisture is removed from Iho sum-
pi" stream   nti'l 'IH"i mined  c.illic.r  voluinntrlcully  or
Kianm.-lrlc.ally.
  1.1'   Ap|,ljr.ut>ilitY.  This  method  iti apl>licuhle  for
di-ti-M Mining 11 ii- moisture, content of Khu:k Kas.
  Two iiroccilnniH uiii Kivf.n. The hr::l. in u reforene,o
mrlhiiil. fur ru-i-iirule ili^iiMiilniilliiiiM ut inoisluro Ronl«uil
(Nilch n>;  urn MI-I-«|I*<|  lo  riilrnlnln HiiiLs.-;!'}!! tluln).  Tlio
> uti :i|i|)iii\iiiiuii-
otctly wil.lt u fKilliil.nnl i-inissioii iiiriisiiii-iin'ill run; wlh-ii
it. is, ciilriilnlKiii or |M>n:<>nl isnkiiKHic,  tHi]hil:\nt emission
Milo,  c.lc., for (In; run shall l>o htusnil U[H>II  l.ho results of
I hi! Mifi;riuii;o. tii^lliod or its iMiuivulrnl.; Ihixsuuitculallons
shall  not Im liasi:nii (.tip ii'sults ol ilm unproximnllnn
iiif.lluitl, unless (lit: approxiiiiul.ioii rnf.lhou nt shown, to
Mm sal isfurl ion of I In: Ailiniiiistralor,  0.8.  Bnvironmon-
lal  I'rniiK'.lion Atitutfy, lo lie rapalilt) of yi<:l(lint( rnsnlLs
within I piinmii Hit) ol llm rt:f<*rnn<:i! nrlhod.
  NIITE.—Tlics ri'fi-rRiiiT. method mny yield tineslionahlo
n-MilLs when nppliixl  to .saturated givs streams  or lo
stn-anis that i-onUiin wntor droplet*. Thcreltore,  when
tlii'sn roudilions exist or arc  siisn«'tcd, a second dislpr-
ininullon  of  Ilin inoislitri: content shall ho made simul-
taneously with the refermire inothod, as follows: Assume
that tin- Kas Nirrain Is  saltinilud. Attafh a tomperatiiro
srii-or It-npahlf of  innasiirinu  to  ="•!" (; (2° K)| to tho
nsfiTfiici) inrtlioil prohc. Mt:asiire the stuck gait tcmpcia-
lure at oath  Inivisrs" |K)int (aco Section 2.2.1) duriiiK the
roffrenco  method Iruvorsc: calciilato  tho avoraco stack
Kas ti-niixMnunc. Next, dclrrinino the moisture  percent-
anc.  niUmr  by: (I)  using  a  psychroinctrie chart and
niukini;  ap|jri'|iriate  cnrructinn.s  if  stack  pressure is
dill'crctit from that of the chart, or (2) uslun saturation
viiixjr pressure lahl<\s. In caww where the paychrometrlo
chart or the saturation  vapor pressure tables  are  not
appUrablc (baiwd on evaiuatlon of the praoen). alternate
methods,  siibjii-i to Iho approval of the Administrator.
shall  I— —-•
              2. Rffrrmce Mtthod

                The proeedure dcst-riU-d in Method 5 for determining
              moisture i-ontant Is a.-e..r,t,ttble as a mfeniuHi method
                 J .APJ*rat'«- A  selininatjr of tho «ampllng train
              iiwd In this raferpiioo method is shown in Flfftu^ 4-1
              All eomp.m«i.ts shall  lw maintained and calibrated
              weordhiR tii tho procedure, outlin.^d in Method ft.
                2.1.1  Prob«.  The probo f.i ainstrut-.teil  of stainhw
              vtnM or Rla-w tultlnvr, siilllrionlly  honf-l  to  prrveni
              wulor oondniiMallon. nud Is nI Inserted  into the "ml
              of the nrobo) or lnmt»«l mil-slivk (O.K.. a.1  described In
              Moihod .')), U> rmnovn  purli<;iiliile nmtti-r.
                Whnn stuck conditions permit, otlmr nietuls or plfttUc
              til Id up may t>eiised for lltr probe. siit>Jo<:ltrovitl
              of the Adntlnistrnlor.
                2.1.2  ('ondmiser. The  condenser  consisl.i  of  four
              hnpbiRors «x)niiectod In snnr-H v.'it.h ground i-.ltuw, leak-
              fron nttlng.s or any similarly l«-:iK froti noiM-onlamLimlliu;
              liLlinca. The lirsl. Ihinl, ancl dmil.l» itnpiiii-.cni nhnll b"
              of the (JrvonlntrK-Stnilli design, modiUed  by replacing
              tin* lip with u  1.3 eriiijnii'ti'.r fj£ ine.li) U> i:laH8 Itibn
              extentling  lo nlxml 1.3 c.m (Vt in.)  from UP- hot.tout of
              th« (liwk. Thesocoiul impiIIRIT shall  brof the. Orcc-nburn-
              Hniitti draii^n with the standard lip. Modifications (o.t;.,
              usiriE flexible uonneeiions  hctwnut tho impiiiRcrs, usiiiR
              materials other Ihun •il;is?f or usins llexible viu-uum linns
              to connect the  liltor holdur to Iho condenser) may bo
              usod, subject lo the approval of Iho Administrator.
                The first two i in pincers slmll contain known volumes
              of water, the third shall be empty,  and the fourth shall
              contain a known wp.iRhi of 6- to Hi-mesh in'licalinp type
              silica pel,  or equivalent desiccaht.  If the silica pel has
              been previously used,  dry at 175U  (J (VHP F) for 2 hours.
              New silica gel may be used as received. A ibormomo.lRr,
              caf>able of mervsurinK temperature to within 1° C  (2° K),
              Blmll be placed at Ihe outlet of the  fourth implngcr, for
              rnonitorlnc purposes.
                Alternatively,  any  system  may  bo used. (subject to
              the approval of the Administrator) that cools tho sample
              p'os stream and allows  ne.asuremont  of both tho water
              that has been condensed and the mnistnrc leaving tho
              Condenser, each lo within  1 ml or I K.  Acceptable means
              ure  to measure  Iho  condensed water,  either  (rravi-
              melrioaUy or volumetrically, and to measure the mois-
              ture  leaving the condenser  by:  (1)  monitoring the
              temperature and pressure at the eilt of tho condenser
              *nd using Dal ton'a law of partial pressures, or (2) peaslng
                                  the samplo  gas  stream through a tared silica gel (or
                                  equivalent destceant) trap, with rill gases kept below
                                  2(r C (fifi° F), and detorminfnc the weight gain.
                                    If means other than silleaRel are used to determine the
                                  amount of m "is turn leaving the condenser, it is ree.om-
                                  mend<-d Mint silica  r<*1 (or etmlvulenl) si ill be used be-
                                  IWIHMI  the  ciuirleiiser system and  pump, to  pre.venl
                                  iiintsluro cnndch:iiiiioii  in  (bo  putup  and   niedirint;
                                  diwlres tmd lo iivnUI the need  to nmku et'iTiH-iloiis for
                                  niotsline In  the nieterei] volume
                                    2.l.:t  ('..')lln«  Hv''t<-m  An Jen bulb  container nnd
                                  crushed Ico (ur («|iilvalent) are. used to uld In eoudeirUn^
                                  inolsliire.
                                    2.M  Meli-rlng Myste.m. This sysU-m  Includes n v:i"--
                                  iiiiin  ^unc.e., le.uk-fre*1  pump,  thermometer:! capable of
                                  nieasurliiK U'liip'-raturn to within :t" C (ft.4" K), dry K:W
                                  me.icr <-upah!e of nicti^iirliig  volume,  lo within 'J percent.
                                  and  related rnpilpnie.nl HS shown in Kl^iirn 4-1. Otli< i
                                  metc-rin^ syst/sms,  cupublo  of ni'ilntiiinimf a connl-aiti
                                  suinptinH rule and dfU-rininiin1; sample KUS  volume, may
                                  be used, subject to the approval m tho Adminislrat >i.
                                    2.1.r>  Haronic.ter. M'Tcury, aneroid, or  oilier uaruin-
                                  filer capable of meiismiiiK atninsplu-rir pressure to wilhin
                                  2.6 nun HK  (0.1 In.  11^) may IK* used. In  nmny c,n.s4>.«, tho
                                  barometric  reading may be  obtained  from  a nearby
                                  national weather sorvieo  station, in which case the sta-
                                  tion value  (which  is tho absolute barometric pn^ssnn-)
                                  Shall bo requested and  an  adjustment  fur  elevation
                                  differences  betwppn the weallier station and the sam-
                                  pling p')int  shall  be applied nt a rate  >>f minus 2.5 mm H^
                                  (0.1  In. llg) per  30 m (100 ft) elevation  increase or viuo
                                  vprsa for elevaiion  decrease.
                                    2.1.6  Graduated Cylinder  and/or  Dalance.  Those
                                  Items are used to measure condensed water and m?ii>lure.
                                  caught in tho silica  gel to within 1 ml or 0.5 g. Graduated
                                  cylinders shall have subdivisions no greater than 2 ml.
                                  Most laboratory  balances arc capable of  weighing to tho
                                  nearest OJS  g or less. These  balances ore suitable  for
                                  use here.
                                     2.2  Procedure. Tho following procedure Is written for
                                  a eoiidcnpor system (such as the impiugcr system de-
                                  scribed In Section 2.1.21 Incorpora'ing volumetric analy-
                                  sis to measure the condensed moisture, and silica gel and
                                  gravimetric analysis to measure'the moisture leaving thn
                                  condenser.
          FILTER
  (EITHER IN STACK
 OR OUT OF STACK)
STACK
 WALL
CONDENSER-ICE BATH SYSTEM  INCLUDING
                           SILICA GEL TUBE —7
                                                                                AIR-TIGHT
                                                                                   PUMP
  Figure 4-1.   Moisture  sampling train-reference  method.
                            111-66

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               olh"rwi*"*'pt*<-inYf1 l.y lh«» Administrator.
             ••( i-ii'ht  l.ravfrjw  |K>mls shall  >>r> n:.«-d  (nr
r'fiilarsl-irlf . LHVIIIU diameters less Limn (Mil in (2-1 in.).
n iiii'iiiiiuin nl nine poiol.s shall be iis-'il fix rectangular
•I'll-:;- h.iviiti; equivalent dlameliTS le,ss Hum (Mil in
IVM in.). iiM-l :i mi..inium  of twelve Lraviis  | MM lit:; slmll
I..-  US.--I in  all otln-i »-:LS*-S. The Inivi-rst: points shall Im
l.wal.'-l uicMi'luiK I" MHhod I. The,  use of fewer  |Miinl,l
is sni'Jeel I.* lli«-. approval of the Administrator. He.lerl a
suHaMe pii.lie uinl probe length  such thai all  IniviTSn
points e;tn In- sampled. Consider HamptInn from opposite
:;tili-s uf Lin* stack 'four total sampling \vn U'O Tor liirun
slacks, lo permit use of shorter proho IriiuLhs. Mark thn
proln- willi lirut n-siaUint tnp<: or  liy  SI.IM.-. ullii-r im-llnMl
In 'l.'iiutr I In: |'ii.|>.-r ilislhuiT. into Lhr sliu-k or 'lili L Inr
fiich .%iinp!in^ point. I'liirf known volumes of water in
thn liisl iwn inipiiiKor.s. Wfif.h nn.l n-cnnl UIR wrijiljt of
Llir silim KI-| li» tin- nr:in-sl o.A jt. and tnitisfrr lln' silicu
^•\  In Ihr.  fuiutii impinKvr; :illi>rniil.ivi-ly, Lhr silii'OKcl
inity lirsl, IT l.i.iiisf.-rT'i'l  l<> Ihn iinpinu'«-r, uiul Lhr. wi-JKlil
 of Ihnsilira K''> pl'in inipi'i^rr n>rorilnl.
  2.2.'2 KHccL 11 L'ltnl sampling HUM-  snrh (.hat n mini-
mum total vats volume  nl (Mil) sum CJI  s«l) will ho i,-«l-
l.-ctod, at a ruLi1 no unml'T than O.OV1 ttiV")i'> «'-"•'' c lo ho ilrhTiniiuHl. tlm rnnlstnrc ili't^nnlnnlion si ml I
1m simultaneous willi, und fur the y
thn  AdniinisLialor. l-'or  enrh run, rwoid. tho dnl.n  m-
ipiired on the tixutnple data sheet shown in Kufure 4 2.
He siiri- to record the. dry p;iks  mnUv reading at tfip l>cglli-
ning and end of each santpling lime Increment and when-
*w sampttiiK Li halted. Takn othw approprlaln readluio
at wu'.h sample point,  at  least once  during nach  time
Irirremonl
  'J.'.i..r)  Tfi lipt:in sntnpliitR, position the prnhv lip nl. tltc
I:i .1 tiuvi-rse iMtinl. Imniodiatftly start the pump mid
fi'dnst  the Mow lo  ihit  decdred rate. Trnve.r.'v* tlu* fin^s
.vrljfui, sJitnpliiiR ill rairh travttrsn p^tinl for fin etpinl
length  of limn. Add more lee and, if neee,ssnry.  salt u>
main Lain a tr-nijMirature of less limn 2U° C OiH° i1') ut thn
silica pnl outlet.
  2,2.A  A flJir eollocling the samplft, disconncH't l.he prnhn
from Die lilUir holder (or horn th(> first impin^nrjuiid .-on-
duct a leak chock (mandatory) as described in Section

2.2.3. Uncord the leak rate. If HIP leakage raterxeoed.s the
allowable  rale, the tester shall eithc
suits or shall correct the sample vnln
of Method ft. No.xt, measure the vo!u
condensed lo Lite nearwil ml.  Untcrn
weight of the silica unl (or silica KI-I i>l
m-anvst O.S R.  Utx-ord this Informatior
reject the test ro-
10 as in .Section *i,3
10 of the rnoHurn
no thn intTea.se in
s impincor) lo tho
(sen example dala
islnrr iM-ice.nt.afjo,
   «;l.  KiRiirc-l :i)nndrale,ulaU; the ii
a-; d.'.Hi-rihml In 2.3 hclow.
  'A.'A   CalciilalioiiH. (>arry oul the following oalt-ulations,
retaining at Iwwt onn eitra dwimal ftgnro bpyoud that of
tin) aetjulred dala. Hound ail figure*} after final  calr-.ulu-
lion.
      PLANT	

      rOCATION_

      OPERATOR.

      DATE	
      RUN NO	

      AMBIENT TEMPERATUR&.

      BAROMETRIC PRESSURE.

      PROBE LENGTH n(ft)	
                                                                     SCHEMATIC OF STACK CROSS SECTION
TRAVERSE POINT
• UMBER







.







TOTAL
SAMHING
TIME
(9).«n.












•
.


AVERAGE
STACK
TEMPERATURE
•tPH












. .




PRESSURE
DIFFERENTIAL
ACROSS
ORIFICE METER
UN).
nnlnj HjO

















METER
READING
GAS SAMPLE
VOLUME
«J(hJ)













»



AV.
«J(ftJ)

















GAS SAMPLE TEMPERATURE
AT DRV GAS METER
INLET
rr-ij.occo















A«9.
A^..
OUTLET
(Tw0ut).°CPF)















A*

TEMPERATURE
OF GAS
LEAVING
CONDENSER OR
LAST IMPINGER.
•C («F)














^


                                                          Figure 4-2.  Field moisture determination-reference method.
                                                                           111-67

-------

FINAL
INITIAL
nirrERENCi
WINGER
VOLUME.
ml

	 . .
M.ICAGEI
•EIGHT.
a

	 	 	
            Fiyorc 4 It. Anjlylicnl iljta . iefcicm.e inuthod.
        2.3.1  Nomenclature.
            J*B.- • rio|Kirtli»n of water  xapoi, by  volume,  in
                  llmgoa stream.
             M » •- Molecular  wejiglil  of  water. 18.0 g/g-mole
                  (IK.OIb/lb-inole).
             7'.. - Absolute pressure (f"f this mctho'l, same
                  us barometric, pressure) at Ihu dry gas meter,
                  mm Ilg (In. ll«).
            t'.n  Slainlurd  absolute |>iessiire,  700 mm  Ifg
                  (2!l.!i2in. UK).
              /(  Ideal gas conslant, Oi»iL':tO (mm UK) (in')/
                  ill-mole) (°K) for melric units and 21. RO (In.
                  Ilg) (ft')/(lb-mole) (°H)  for English  units.
             '/'»•= Absolute tomiK-raturc at meter, *K <" U).
            T.u -Hlonuard   absolute  t-niiivrature,  ZWI"  K
                  V,W R).
             Vm=* Dry gas volume measured by dry gas meter,
                  dcm (dcf).
            AV.'- Incremental  dry gas  volume  measured by
                  dry gas meter at each traverse  point, dcm
                  (del).
          V^tn)- Dry gas volume measured by the dry gas
                  meter,  corrected  to  .•.l.aiulurd  conditions,
                  dscm (dscf).
         Vw,t,u)~ Volume of water va|ior condensed corrected
                  lo standard conditions, scm (set).
        V., ,(, id) = Volume of wator  vapor collected in silica
                  gel corrected to standard conditions, scm
                  (set).
              V> = KinBl volume of condenser water, nil.
              Vi— lullial volume, if any, of condenser water,
                  nil.
              (f, = l''inal weight of silica i;el or silica gel plus
                  implngcr, g.
              If, = Initial welghl of silica gel or silica c<-l plua
                  impinger, g.
              V'^Dry gas mi;ler c.ulil^ralion factor.
              !'.= Density of  water,  O.'JUH^ g/m|  io.(X)220l
                  Ib/ml).
        2.3.2  Volume, of water  vapor condens-d.
                           (V,
                                 ,- V,)
                                            Kquation 4  I
       rhore:
        Ki=O.OOI3M mi/ml for metric uniUs
           =0.04707 fl]/ml for English runts
        2.8.8  Volume of wator vapor  collected in silica gel.
       rhere:
        Jfi=0.001336 mVg for metric units
           -0.04716 ff/gfor English anils
        1.8.4  Sample gas volume.
                                             Equation 42
                                                                                          '/'„
                                                              Wll'T' .
                                                                                                    Ki|il:il.lun I 3
                                                                    i':ihf,H "K/niNi  UK tor metric unils
                                                                    17.04 " It/In. Ilg for Kngli.sli units
                             NOTK.—If tlm |Kist-tost leak  rule
                                                    lorrccl  II
                                                    tn Sccllon II :i of Method 5.
        -If tlm  iKist-tost leak  rule (.Section  V.'.'.rt ei-
n«d« tlm  allowable rate, correct llui  v:ilnn  of Vm III
                                                              K«tiiit), to dry the sitmplc. Ran and to pro-
liwl I he meter ami pump.
  s.l.S  Valve. Needle valve, lo regulate I he sample gas
flow rule.
  3.l.e,  or equiva-
lent., to pull tlu> (!ILS Aainple through the Train.
  :t.l.7 Voliiinn. inrtor.  Dry v.na nmlcr, sllflleienl.ly ac.-
rurate u> moasiirc Iho sample volume within 2%, and
calibrated over the range of (low ratrc and  conditions
actually encouiitered during sinnpllng.
  3.1.K  Kale Meter.  Hotameli'.r, to nu-nsurc the How
range from U to 31 pm  (0  to 0.11 e.fin).
  .1.1.0  Graduated Cylinder. 2.r> ml.
  3.1.10  Barometer.  Mercury, aneroid, or oilier barom-
eter, as described In Section 2.1.6 alx>v«.
  3.1.11   Vacuum Gauge. At Inast 760 mm Ilg (30  in.
Hg) gauge, to be used (or the sampling leak check.
  3.2  1'rocedure.
  3.2.1  Place eiactly 6 ml distilled wator in each im-
pinger. Assemble tho apparatus without the probe as
shown in Figure 4-4.  Leak check the train by placing a
vacuum  gauge at the Inlet to the first tmplnger and
drawing a vacuum ot at least 250 mm Ilg (10 In.  Hg),
plugging the outlet of the rotameter, and then turning
off the pump. The vacuum shall remain constant tor at
east one minute.  Carefully release the vacuum gauge
Ibcforc unplugging the rotameter end.
    HEATED PROBE
SILICA GEL TUBE
          RATE METER (

                  VALVE
FILTER
(GLASS  WOOL)



     ICE BATH
                                                                                                          DRY  GAS )
                                                                                                           JSETER   /
       MIDGET  IMPINGERS
                      PUMP
               Figure 4-4.   Moisture-sampling train  -  approximation method.
                                                    111-6$

-------
LOCATION.

TEST
                             COMMENTS
DATE
OPERATOR
BAROMETRIC PRESSURE
CLOCK TIME

•



GAS VOLUME THROUGH
METER, (Vm),
m3 (ft3)



•

RATE METER SETTING
m3/min. (ft3/min.)





METER TEMPERATURE.
°C (°F)





    Figure 4-5.  Field moisture determination •  approximation method.
 of
Hie
      .122  Connect thr; probe, Insert it Into the stack, and
    sample at a constani rale ..» 2 Ipm (0.071 cfm). Oonlinue.
    sampling unlll the dry gas moter registers about SO
    lilers (1.1 ft«) or unlil visible liquid droplets arc carried
    over  (roin  the  first lm|iinB«r to the second.  Kccord
    temiwralurc, pressure, and  dry  gas motor readings as
    remiired by Figure. 4-5.                  .
      •12.1  Alter collecting the wimple,  combine the con-
    l..nWof the two iinpingerK.nid measure Uii: volume to the
    ni'iiresl n./i ml.                                   . .
      •| 3 Cnlcnlalinns. Tli ...... Iriili'lion method presented is
    designed to eslimiile I.I..  moisture  in  Iho stuck gas;
    therefore, other diila, wha-li lire, only necessary ['" nc-
    enrule moisture determinations.  are nol collected. Iho
    following «|ll!itiuns ml ..... i:il'-lv  estimate the moisluru
    eonlKiil . for tin- |MN|Kisr. ..I di-l-rlinnnr.  niklnelh: «»"-
    pling nile s«!lliii;'>.
      :i:i I  NoiMi-ni-UiMire.
         JI...-A|iprn»iiii!ilf.  |.rn|«,ili"ii,  liy  vnln
              wilier vn|Kir in thn Rus .slnaim leuvi
              SIT. ..... 1 impinrrr, (UKS.
          /!..=Waler vi.iwr  in the Kns stream. pro|x)rli..n liy
              volume.
          yi/.=Molecnlar weight  of  water,  18.0 c/K-molo
              (IK.O'b/lh-molc I
          y.=Ahsolnte pressure (for this method, same as
              barometric prwsurc) at the dry gas meter
         l'.n= Standard  absolute pressure, 760 Dim Jig

           R^ Ideal gas conslnnt, 0.06236  (mm  Hg)  (m1)/
              (g-molo) (°K) for metric units  and  21.85
              (in.  Hg)  (fl')/lb-roolc)  (°K) tor  l.nghsb

          T.= Absolute temperature at meter, °K (°R)
          7'.u=8tandard  absolute  temporaturo,  2U3  K
              (528° K)
          V/=Final volume of Impinger contents, ml.
          V,-=Initlal volume of Impinger contents, ml.
          V«=Dry gas volume measured by dry gas meter,
              dcm (dcf).
      V.(.n>=Dry gas volume measured by dry gas meter,
              corrected  to  standard  conditions,   dscm

      Vr.(«u>=volume of water vapor condensed, corrected
              to standard conditions, scm (scf).
          «.=Densityof wal.T, O.U982 g/ml (0.002201 Hi/ml).
      3.3.2  Volume of water vai»r coUectiJ.

                       ( V, -•- V.)P.«T.«,,

                    ''-"   ~"
                                 K)
        where:
          Ki=O.I»ISM in'.'ml fnr mntric nulls
            =0.(M7U7 fl'/ml for Knglish ii'iils.
          3.3.3
                    volume.
                                                    i 4-0
where:

    = 17.61 "It/in. II); l'ir Kngli: !i nulls

  3.3.4  Approximate mo'iHlure content.


            V"»
 Hfl~~ I/   f ,r '" ~ "T" "»•"•
        Va,e-\-Vmf,,,u
                                               + (0.025)
          : Ciililirulion
          4.1
                                          Equation 4-7
           .   For the ref'-ivnce method, cfllilu-aio. eqiiiiinient as
         sjtccificd in the. following se.r.iiom of Method .'»: Heel ion f».3
         (meterinc sysle.m); t't'clion  5..'» (leni[)erature pnuge^i;
         and Seel ion  5,7 (barometer). The recommended leak
         check  of the metering system (Section 5.6 of Method 6)
         also applies to the reference method. For the approxima-
         tion method.^isc the. procedures outlined in Section S.I.I
         of Method 6 to calibrate the meiering system, and ihe
         procedure of  Method 5, Section  5.7 to cniiiirjle the
         barometer.
                                       K(|iiiili«ii 4- 5
           1. Air Pollution F.njiiuvring Manual (See/mil Kdiiion).
         l>anielson, J. A. (ed.). U.S. Knvironniental I'rolectlon
         Agency, tXTice of Air yuality rianning and Standards.
         Research Triangle I'ark, N.C. Publication No. AF-40.
         l'.)73.
           2. JJiivurlfin, Tlownrd, ct al. Air follulion SOIHO: Test-
         ing Manual. Air 1'ollin ion (Join ml District, Ixis Angeles,
         Calif. November, luc;;.
           3. Methods for Determination of Velocity, Volume,
         Bast and Mist Content of (lasi--. Western Precipitation
         Division of Joy Manufacturing Co., Ix» Angeles'. Calif.
         Uullctin WP-50. 11163.
                                                   111-69

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JJLTKOn  s— DtTC»i.i).»Tir.v  or  Srtn «  HIUIH i
        ElllUIOM FaOtt eJTAllOMtn BuVK. L>

». frifei
  1.1   Principle  A gas sample  U •itn«-ii-d  froui th»
sampling  point In tbe sues.. Tbe sulfurir s»:id  mix
Uacluajag sulfur  tnoilde) and tbe sulfur  dioxide are
•eparated. Tbi niUar  dioxide freriion u measured by
UM bej-lum-tborm utreuon method.
  1.3   Appueel'0ji)-. i-hit metbod U applicable lor UK
•sier initiation ol sulltu diniide emissions from stationary
source,-.. The minimum detectsMe limit ol  the method
but b»u determined u> bf 3.4 DJilhf run- (rog> ol SOt'm1
(J.12X10-' Ib'li >).  Although no  upper limit tat been
established. lest*  have shewn that  concentrations e>
high u 80.000 Dig's' ol 6Ui can be roDeoied e ft c Irmly
io uro midget  ImplnKrrs,  eaeh containing IS ruilliliieri
of 3 percent h>drogen peroxide . at e rale ol 10 Ipm lor
JO minute;. Boaed on ibeorrtiv-al calculations. Uie upper
concentration limit ID a 20-liter sample is about U.lut
Bc'ru'.
  Possible InterlerenU ere free ammonis. water-soluble
cations, and fluoride;.  Tbe cationr.  and fiuortdvs are
remove j by glaj5 » oo) flli  UK  option of •abstltutlnf aamplint eqnlp-
Baot described In Method 8 ID place ol Ibe midfet 1m
Mnfer equipment  of Method 6. Bowrrer. the Method 8
train moit be modified to Include a baatco filter between
the probe and laoptopanol Iroplnjf r, and tbe operation
ft toe aampUnt train and aamplr analyilj mnn be at
tba flow ratal and Mlulion Tolnmo denned In Method 8.
  The Utter also  baa  tor option of delermlnlnt. 8O>
•InulUncoutly with paniculate  matUr  and moisture
datcrmlnatloni by (1) replacing the water In a Method 5
Implntfr  ijiUrn .with » percent  perloUde aolntlon. or
(ft  by replactni the Method i water Implnter ntum
with a Method  8 laopropanol-llltcr-paroilde lyitetn. Tbe
aaaJyxlt for 8Oi mint be coniiiunt  with  the prooedurr
to Method 8.
  1.1.1  Probe.  Boroellicau (lug. 01 lUlnhat fuel (other
intertill  of ooutrucllon  may be oaed, iob|ect to the
•pproTal  of the Admlniiumtor).  approilmately  6-mm
malde djametcr, with a beating lystem to  preTent water
MOdeuailon and a fljter (either ln«tack  or heated out-
atack)  to remove partlcnlavr matter, Including lulturic
add mlit. A plot of glass wool ti a (ttlslaclory filter.
  J.1.J  Bubbler and  unplncen.  One mldtet bubbler,
with medlunxoane flaaa Irlt and borotiucau or qoaru
fkB wool packed In top (aee Flfure 6-1) to prevent
anlfurlc add mut carryover, and three  JO-ml midget
|]Dpln|en. Tbe bubbler and midget Implngen most be
emuieclrd In eerlee with leck^ree  (Ian connector*. BID-
too* mut may be tued. U nereiaary, t« prevent H*kac e.
  Al tbe option of tbe tester, a midget tmplnter may be
BMd In {ilace of the mtdiet bubbler.
  Other collection abwrben and flow r»Uo may b« u»d,
bat are nbject to tbe  approval of the Admlniftrmtor.
Alao, eollertlozi efficiency mtut be thown to be at leaat
M peioent (or eacb test run and mult be documented In
tbe report. It tbe efficiency Is found to be acceptable alur
a acnes of three torts, further documental Ion  Is not
required.  To conduct tbe efficiency test, an extra »t>
•orbcr must be added  and analyted separately. This
extra absorber  must not contain more than 1 percent ol
Ike total BOt.
  1.1 J Olais Wool. Borostllcat* or quarti.
  t.1.4 Btopcock   Orease.  Acetone-Insoluble,  beat-
atoble sUlcone  (rease may be used. If necesaary.
  1.1.6 Temperature   Gauge.  Dial  UMrmomater, or
•qolvalent, to measure temperature ol gas leaving Un-
•bxer trmlc to within 1* C (J* F.)
" Vl.« Drying Tube. Tube pecked wttb «- to l«-m«»h
todlcettng type ttllca gel, or equivalent,  to dry UM gas
 •ample and to protect tbe met«r and pump. If tbe sillac
eel has been used previously, dry at 176» C (aSP F) lor
I boun. New silica gel may be used as received. AJUms-
ttvely, other types of desircants  (equivalent or better)
•ay be used, subject to approval of the Administrator.
  1.1.7 Value. Needle value, to nculale sample gas flow
res*.
  S.U Pump. Leak-tree disphragm pump, or equiv-
alent. to poll gas through the train. Install a small tank
between  tbe  pump and rate meter to eliminate  the
 pulsation eflect of the diaphragm pump on tbe nrUmeler.
  J.1.8 Rate Meter.  Rotaroeur, or equivalent, capable
•f measuring flow rate to wlthlo t percent of UM (elected
 •ow rate of about 1000 ee/mln.
  11.10 Volume  M»te>.  Dry  gai  metoi, infflclently
•ecurate to measure the sample volume within 2 percent.
ctllbnud at  tbe  selected  flow rate  aod  conditions
actually encountered  durins. sampllos. and  equipped
wile a umperature gauge (dial thermometer, or equiv-
alent)  oapablt of  measuring  temperature  to  within
rc ti.4*F ).
  1.1 II barometer. Mercury, amerold, or other barom-
eter oapablr of measuring atmospheric pressure to within
14 mm H| (0 1 In. B«). In many easrs. the barometric
ratdliif may be obtained (rum a nearby national weather
eerTto« sUUon, ID which our the station value (which
I* thf absolute barometric pressure) shall  be requested
and  an adjustment for  elevation  dlfTerenres between
Ut» weather station and sampllns point shall be  tppli*d
sjtarauofmlnus2.9mm Hg (0.1 In. Hg) peraOm 000ft)
aiaTaUoo Increase or  vice vena for elevation decrease.
  1.1.U Vacuum Otuge. At least 760 mm Hg (30 In.
Hg)  gaugr, to be used lor leak cback  of tbe sampling
train.
  1.2  Sample Recovery.
  tl.l  Wash  bottles. Polyethylene or glass, 800 ml,
two.
  1.2.2  Storage Bottles. Polyethylene, 100 ml, to store
implnger samples (one per sample).
  I.I  Analysis.
  14.1  Pipettes. Volumetric type, S-ml, »ml (one per
•ample), and 54-ml slses.
  IS J  Volumetric Flasks. 100-ml slse (one per sample)
and 100-ml slse.
  SJ.Ji  Burettes. &• and SO-ml sites.
  1.1 t  Krl^nmeyer Flasks  IX znl4lse (cae for each
•ample, blank, and standard!.
  1.1.6  Dropping Bottle. 126-mi slse, to add Indicator.
  SJ.d  Onduated CyUnder. 100-ml site.
  U 7  BpectropbotomeUr. To measure abaorbance a.
8tt nanometers

*•*?*!«•
   Unless otherwise Indicated, all reagrats must conform
to tbe  specifications established by tbe Committee on
Analytics! Reagents of tbe American Chemical  Soclet).
Where such specifications are not available, use the best
available grade.              ,
   (.1   Sampling.
   1.1.1 WaterTDtlonlsed, distilled to conform to A8TM
apeclflcation D1193- 7J. Type 2. At tbe option of  the
analyst, the KMnC< ten for oildltable organic matter
may be omitted  wb-.n high ooncentretlons of organii
matter are not expected to oe present.
   1.1.2 Isopropanol, 80 percent. Mil SO ml of Isopropanol
with 20ml of delonlied. distilled water.  Check each lot of
Isopropanol for peroiloe Impurities as  follows.: sbakr 10
ml of  Isopropanol with  10  ml of freshly prepared  10
percent potassium Iodide solution. Prepare a blank by
similarly treating 10ml of distilled water. After 1 minute.
read thf  absorhance  at tol nanometers on  a  spectro-
pbotometer. U absorbance exceeds 0.1,  reject alcohol tor
oae.
   PeroiMn may be removed from Isopropanol by redis-
tilling or by  panage through  a  column of activated
alumina;  however,  reagent  grade laonropano! with
soltably  low peroxide levels may be obtained from com-
mercial sources. Rejection  of  contaminated  lots may,
therefore, be a more eftV.lenl procedure
   S.I.I Hydrogen Peroxide, • Percent.  Dilute SO percent
bydroien peroside 1:9  (v/v) with deionltrd.  distilled
water  (to ml Is needed per sample). Prepare fresh dally
   J.I 4 Potassium Iodide Solution, 10  Percent. Dissolve
10.0 grams Kl In delonised, distilled water and dilute to
100 ml. Prepare when needed.
   S.2  Sample Recover)-.
   I.J.I Water. Deionlted, distilled, a?  In 1.1.1.
   S.2.1 Isopropanol. 80 Percent. Mil 80 ml of Isopropanol
with 20 rol of delonlted, distilled water.
   S.I  Analysis.
   Ml Water. Delonlied, distilled, as  In I.I.I.
   SJ.2 Isopropanol, 100 percent.
   11} Thorin    Indicator    Ho-arsonopnenylato)-2
napbibo]-3.f~duul(onlc acid, dlsodium salt, or equiva-
lent. Dissolve 0.20 g In 100 ml of delonised,  distilled
water
   SJ4 Barium Perchlorate Solution, 0.0100  K  Div
•Olre I.Ug of borlum perchlorate tribydrate |Ba(riO.)i
SBiO| In 200 ml distilled water and dilute to I liter with
  •opropanol. Alurnatlvely. I 22 g of |B»Clr2H,0| ma>
be tued  Instead of the poicbJonie  Sundardiu as In
 Section 6.6.

   J.35  Bulfuric Acid Standard, 00100 N. Pturhai*  or
  standardize to »0 00n2 N against 0.0100 N NaOH which
  has  previously been standardlted anlnst potassium
  acid phthalate (primary tundard grade).

  4. Pnadun.

   4.1  Sampling.
   4.1.1  Preparation of collection tr«ln Measure 15 ml of
  10 percent uoprope.no! Utto the rnidnet bubbler and  16
  ml of J percent hydrogen peroildr Into each of the first
  two midget Implngers Leave the Anal midget Implncer
  dry Auemble the train  as shown In Figure 6-1. Adjust
  probe heater to a temperature lufflclent to prevent water
  condensation. Plan crushed ice and  water around tbe
  tmplngen.
  4 I 2  Leak-check procedure A leak rhsrk prior to the
sampling run Is optional  however, a leak rherk after tb*
sampling run Is mandatory. Thi leak -check procedure is
as follows:
  With the probe disconnected, place a vacuum gauge at
tbe Inlet to the bubbler  and  pull a vacuum of 2tt mm
(10 In ) Hg: plug or nlnch off the outlet of the flow meter.
and then turn  off the pump  The vacuum shall remain
stable  (or at  least  30  seconds  Carefully release the
vacuum game before releasing tbe flow meler end to
prevent bark flow of the Implnger fluid.
  Other leak check procedures may be used, subject to
the approval of the Administrator. U R. Environmental
Protection Aienry. The procedure used In Method J U
not mutable for diaphragm pump*
  41.1  Sample collection  Record  the Initial dry gas
meter reading and barometric pressure  To begin sam-
pling. position  the tip of the probe at the sampling point,
connect the probe to the bubbler, and rUrt the pi imp
Adjust  the  sample flow  to a constant  rate  of ap-
proximately I 0 llter'mln as Indicated by tbe rotaroeter
Maintain this  constant rate  («IO percent) during the
entire  sampling  run. Take  readings  (dry gas  meter.
temperatures at dry gas meter and at Implnger outlet
and rate meter) at least  every 6 minutes Add more Ice
during the run to keep the temperature of the gases
leaving the last Implnger at 20* C (M° F) or less. At the
conclusion of each run, turn ofl the pump, remove probe
from tbe *ts>ck. and record tbe final readings  Conduct  a
leak check as In Section 4.1.2.  (This leak check li manda-
tory ) If a leak Is found, void tbe teat run.  Drain the Ice
bath, and purge the remaining part of the train by draw-
Ing clean ambient air through tbe system for IS minutes
at the sampling rate.
  Clean ambient air can be provided by passing  air
through a charcoal filter or  through an extra midget
Implnger with  19 ml of S percent HrOi. Tbe teeter may
opt to simply use ambient air, without purification
  4.2  Sample  Recovery. Disconnect the Implngers after
purflng. Discard the contents of tbe mldgst bubbler. Pour
tbe contents of the midget  Impingen Into a leak-free
polyethylene bottle for shipment Rinse the three midget
Impingen and  tbe  connecting  tubes with delonlxed.
distilled water, and add the washings to the same storage
container. Mark  the fluid level. Seal and Identify the
sample container.
  4.1  Sample Analysts. Note level of liquid In container,
and confirm whether any sample was  lost during ship-
ment; note this on analytical data sheet. If • noticeable
amount of leakage bis occurred, either void tbe sample
or use methods, subject to the approval of tbe Adminis-
trator, to correct the final results.
  Transfer  the contents of tbe storage container to  a
100-ml volumetric flask and dilute to exactly  100 ml
with delonlied. distilled water. Pipette • 20-ml aliquot of
this solution into a 240-ml Erlenmeyer flask, add SO ml
of 100 percent Isopropanol and two to four drops of thortn
Indicator, and  titrate to  a pink endpoint using 0 0100 N
barium perch Ion. te  Repeat and average tbe Utration
volumes Run a blank with each series of samples. Repli-
cate tltratlons must agree within I percent or 0.2 ml,
whichever Is larger.
  (NoTk.— Protect tbe 0.0100 N barium
solution from evaporation at sjl tunes.)
                                        parcnlomte
  S.I  Metering System.
  S.I.I  Initial Calibration. Before Its Initial use in tbe
 field, first leak check the metering system (drying tube.
 needle valve,  pump, rotametor, ana dry gas meter) as
 follows: place a vacuum gauge at tbe inlet to the drying
 tube and pull a vacuum of 230 """ (10 In.) Hg: plug oe
  anch off the outlet or the flow meter, and then turn ofl
  e pump. Tbe vacuum shall remain stable tor at lean
 SO seconds.  Carefully release the vacuum gauge before
 releasing the flow meter end.
  Neit, calibrate the metering system (at the sampling
 flow rate specified by the method) as follow*: connect
 an appropriately sited wet (e*t meter (04., 1 liter par
 revolution)  to the Inlet of the drying tube. Make three
 Independent calibration runs, using at least five revolu-
 tions of the dry gas meter per run. Calculate the calibra-
 tion factor, Y (wet test meter calibration volume divided
 by the dry gas meter volume, both volumes adjusted to
 trie same reference temperature and .pressure), tor  each
 run, and average the results. If any r vUue deviates by
 more than  2  percent from the average, the metering
 system Is unacceptable for use. Otherwise, use tbe aver-
 age  •• the calibration  factor for subsequent test runs.
  S.1.2  Post Te
-------
  6.3  TlMnnotMUn.  Callbrala  tfOaii ntnanMa-
ftea thermomeun.
  6.J  Rotameter. The rotameter n*ad not b* eallbraUd
bat ibould be cteaned and malotalnad aooordlnt to lb«
manuBKiurti'i Instruction.
  1.4  Barometer. Calibrate afttnrt • mercury bwam-
•Ur.
  tJ  Barium  Penhlorat*  Solution. Sundardlu  UM
barium percblorale lalDUon acalnjl tt ml of lundkrd
•ulfurtc tcld to wbleb 100 m) 0} 100 percent Uopropaool
b«i baan added.
  Carry oat calculations, retaining at lean on* eiua
daelma) figure beyond thai of the acquired data. Round
off figures after Anal calculation.
  a, I  Nomenclature.

    Cm -Concentration of  fulfill dioxide,  dry  bads
       '   corrected to ttandard conditions, mi/dscm
       .   (Ib/dncf).
      JV-Normality of  barium parcbJorate tltnnt,
          mllllequlvaltnts/ml.
    >%..-Barometric pressure at the exit ortftoB of the
          dry gas meter, mm H| (In. Hf).
    />«<« Standard  absolute pressure. 760  mm Hf
          (29.92 In. H|).
     7".- Average dry ta> mettr abaolute temperature.
          •K CR).
     7*>u—Standard  absolute  temperature,  SI*  K
          (»»•  R).
      V.-Volume of sample aliquot titrated, ml.      *
     V.-Dry fk> volume w measured by Ibe dry ne
               , dem (dcf).
  V.U^J-Dry fis  volume n>eaeiirii<1 by  the dry fat
         malar,  eorreelad la ilandard eondltlons.
         daon (dsef).
    V.i.-Total volume of solotion In which Ibe enllur
         dioxide sample Is contained. 100 ml.
      V,-Volume of barium perch torn* tltrant used
         far  the sample, ml (average  of repllcau
         tllrWtons)
     V,.-Volume of barium psrcblonU Utrant used
         lor the blank, ml.
      V- Dry gas meter calibration factor.
    H 03- Equivalent weight of sulfur dloilde.
  ftj  Dry (ample gai  volume, eorrected  to standard
oondiuons.       ._.._.
                                  S7  v  "  **'
                                 A'r~r.r

                                    Kquatton e-1
                                                     ri-OJUS «K/Bn B( far BMrte onlu.
                                                       -IT.M'RAn. 84 lor Entllib unit*.
                                                     M   Sulfur dioxide oonoratmlon.
                                                                             '•(•M
                                                                                       Zquadoo *-J
                                                     ITi-K.OO ml/meq. far metric unlu
                                                       -r.06IX10-« Ib/moq. far Bnfllib unlu.
                                                                                               7

                                                                                                 1. Atmospheric Emtalon* from Bolfurlc Add Mtno-
                                                                                               tecturtni Vroontf*  U.S. DHEW. pMH. DI»Ulon of Air
                                                                                               Pollution.  Public  Health  Berrloe  Publlcmllon  No.
                                                                                               W»-AP-11. Clndnnail. Ohio. I8W.
                                                                                                 J Corbetl. P. F. The Determination of BOi and BOi
                                                                                               In Pin* Qaaea. Journal of the. Innltnuof Fnel.ti in-
                                                                                               to. 19*1.
                                                                                                 I. Matty. R. E. and B. K. Dlehl. Mnanrlnf Flue-Ota
                                                                                               SOi and BO.. Por«r. 101: M-vr. Novembrr IW7.
                                                                                                 4. Patton. W. F. and J. A. Brink. Jr. New Equipment
                                                                                               and Twbnlquw for Bampllnf fhemJoal Procew Hun.
                                                                                               I. Air Pollution Control Aitoclatton. 13  162. IM1.
                                                                                                 t. Rom.J.J.MalnUnanof.CaUbrallon.andOprrallon
                                                                                               of Itoklnetlc  aouree-Bamplinf  Equipment. Omot  o(
                                                                                               Air  Protrranu.  Enrlranmental Protection  Aiency.
                                                                                                R«a>arcti TrUn«l. Park. N.C. APTD-067B. Marcb 1977.
                                                                                                 ». Hamll. H.  F. and D. B Camann. CollaboratlTe
                                                                                                Study of Method for the DeUrmlnalton of Sulfur Dloilde.
                                                                                                EmlBloru tram Biallonary Bouret* (FoBll-Fuel Fired
                                                                                                Steam Ueneraton). Environmental Protection Agency.
                                                                                                Reaearch  Ttlanflc  Park,  N.C.  KPA-4M/4-74-024.
                                                                                                Decuobcr 1971.
                                                                                                 7. Annual Book of A8TM Btandarda. Part It; Waur.
                                                                                                Almoapherlc  AnalyfU. American Society  for
                                                                                               and Materials. Philadelphia.  Pa. 1774. pp. 40-tt
                                                                                                 S. Knoll. J. E. and M. R. Midfett. The Application of
                                                                                                EPA Method 6 to Hlfh Bulnir Dloiide Concentration!.
                                                                                                Environment*) Protection Ateoey. Retaanh Trianfle
                                                                                                Park. N.C. BPA-400/4-76-OIB. July 1976.
                                                                                                                     THERMOMETER
PROBE (END PACKED
  WITH QUARTZ OR
    PYREX WOOL)
                                                                                                                                   SILICA GEL
                                                                                                                                  DRYING TUBE
                                                                                                                                     PUMP
                                               Figure 6-1.  SC>2 sampling  train.
                                                                                                SURGE TANK
                                                                         HI-71

-------
MBTBOD  7—DmainvAisoM or Nmoatv. bznn
       Kntssnin PMH BTATIOIUIT Soon*

1. frtudpb «iM XpgHesWt
  I.I  Principle. A grab sample Is collected In an evacu-
ated flaak containing a dilute suUurtc  eeld-bydroten
peroxide absorbing solution, and the nitrogen oxides,
axoe.pt nitrous onde. are measured  eolorimeterloaUy
using tb* pbenoldlsullonlc add (PD8) procedure.
  U  Applicability. This method Is applicable to the
saauurement ot nitrogen oildes emitted from stationary
•Borcee. The range of the mttbod has bean determined
to be t to 400 mUflgnuLj NO. (as NOi) per dry standard
eabie meter, without having to dilute the sample.
  11  "t^r""! <"» Figure 7-1). Other grab ewnpllnj
liateint or equipment,  capable of measuring  sample
volume to within ±10 percent and collecting a sufficient
sample volume  to allow analytical reproauclblUty to
within ±S percent, will  b* eooiidend ccrfpUble «Jt«-
D*tlTd. iub)ect to ipprorml ot the Administrator. U.S.
KnTlroameaUl  ProteclloD  A^met- The  foUowlni
eqnlpmeot U med In •mpUof:
  1.1.1  Probe. Boradlleete flaa tublnj. nfflcleotly
beMed to prevent wmler oondeojeUon end  equipped
with u In-elack or oot-«Uck filter to remove pvtlcuUte
       (» plug  of  |le*  wool 1» mlbttcUHj tor thli
    r __ >). Sulnlea fUel or Teftoo ' tubing CUT ilio be
    i lor the probe. Bekttnt li not n*eee»rj U ue probe
renuklni dry dortnf the por|in( period.
  • Mention of trede namet or (peeUte prodocU doe> not
eoo(Utate endaneateat by the  KortronmenUl  Pro-
Uettoo Annoy.
                                                  LU  Collection Plwk. Two-Uur boraillokte. round
                                                 bottom Bert, with ihort nerk end 14/40 iundvd uper
                                                 Opmlng. prol»rl»d Mlilnsl Itnplcnion or bre»ke?r
                                                  1.1.3  Fluk Valvr. T-bort  itopoock eonnected to •
                                                 M/40 lundvd Uprr lolni
                                                  S.1.4  Temprreturt Oui(t. DUl-type tbarmometer. or
                                                 olbrr tempmturr fmw.  oemblf of meuurlng I* C
                                                 (T DlnUrveOtlrom -iloMT C OivoUS'F).   .
                                                  1.1.i  Vecuum Lint Tubing oepebU o( wtibjuadlu
                                                 • vecuuni of 7J mni Hi (S In. H() tbtolut* pnvun. with
                                                 "T" connection end T-bort noprock.
                                                  11.6  Vkcuurc O»u»f  TJ-tubf nunotneter, I meter
                                                 (K lu.), will) l-mai (O.Mn.)  dlvlilona. or  other (*uf»
                                                 espstilr of meMurlDf preisun to within ±2.!i mm Hi
                                                 (0.10 in. Ilg).
                                                  11.7  Pump.  Cepebt* of  •TecruUnj  the collection
                                                 fluk to » preeeurc equal to or lee than ?> mm HI (I In.
                                                 Hi; ebtolutc.
                                                  5.1 »  Equretr Bulb. One-way.
                                                  1.1.9  Volumetric PipeUc. 21 ml.
                                                  11.10  Btoprock and Ground Joint Qreaar. A high-
                                                 vacuum, bign-umprraturr chlorofluorocvooo frreec It
                                                 reqoirrd. Ha)ocarbonZV^B has t*»n found lobeeflrcllvf.
                                                  ll.ll  Baromrtfr. Mercury, aneroid, or other barom
                                                 Mar capable of measuring atmospheric pressure to within
                                                 J.I mm Ht (0.1  in. U;). ID many caan. the barometric
                                                 reading may be obtained from a nearby national weather
                                                 earvirr siauon. In which cate the Helton value (which It
                                                 the absolute barometric preasurr) ihall be requested and
                                                 an ad]uitmeni  loi elevation dlflirrncee between the
                                                 weaibfj utation and sampling point ihall be applied at a
                                                 rate of minus 2.5 mm H| (0.1 In. H(> net 80 m (100 ft)
                                                 elevation tnrreaar. of vice vena for elevation decreaK.
                                                  12 Sarnpl* Recovery. Tbe following equipment It
                                                 required for aarnple'^ecovery:
                                                  SJ.l  Graduated Cylinder. 50 ml with 1-ml dlvtilonj.
                                                  >^2  Storage  Containers.   Leak (ne  polyetbylene
                                                 bottles.
   2:2.1  Wash Bottle  Polyethylene or glat*
   12.4  Olats Burring Rod.
   12.*  Test Paper lor Indicating pB. To eovar the pB
 mote of 7 tn 14.
   IJ  Analvslb. For the analysts, the tollowlng eqolp-
 •ent Is neaded.
   is.i  Votumetrlr Pipettes. Two 1 ml. two 2 ml, one
 I ml, ont 4 ml, two 10 ml, and one  28 ml tor each sample
 and standard
      \.
   JJ.5  Porcelain Evaporating Dishes. 17fr-  to 260-ml
  oaparllt with Up (or pouring, one lor each sample and
  each standard. The Coon No. UOW (shallow-form. 196
  ml)  ha* been toond to be satisfactory.  Alternatively,
  polymethyl pentene beakers (Nalg* No. 1203. ISC ml), or
  glace bees en (110 ml) may be used. When glass beaken
  are used, etching of the beakers may raiw solid matter
  to be preanit In the analytical sun. the solids should be
  removed by filtration (set Section 4.3).
   2.*.*  Steam Bath. Low-temperature ovens or thermo-
  statically control!*) hot plates kept below 70° C (190° F)
  •re acceptable alternatives.
   li. 4  Dropping Pipette or Droppet. Three required.
   2J.i  Polyethylene Policeman.  One tor each temple
  and  each standard
   2.8.0  Graduated Cylinder. 100ml with l-tnldivisions.
   2.3.7  Volumetric Flasks. M) ml  (one for each sample).
  100 ml (one for each sample and aarb standard, and one
  tor the working standard KNOi solution), and 1000 ml
  (onr).
   2.1.8  Spectropbotometer. To measure abaorbance at
  410 nm.
   2.8.0  Graduated Pipette. 10 ml  with 0.1-ml divisions.
*  11.10  Trrt Paper tor Indicating pH. To  cover the
  pH range of 7 to 14.
   2.».11   Analytical Batanoc. To measure U within O.I
  mg.
          WO6E
          r
        FILTER
GROUND-GLASS SOCKET.
       § NO. 12/6


                      f&"
                 110mm
 3-WAV STOPCOCK:
 T-BORE.  i PTREX.
 2«mn BORE. 8-rnm OO
                                                 FLASK
                                                                                                                       SQUEEZE BULB

                                                                                                                     MP VALVE

                                                                                                                             PUMP
                                                                            THERMOMETER
              GROUND-GLASS CONE.

               STANDARD TAPER.           GROUND-GLASS
              I SLEEVE NO. 24/40           SOCKET. § NO. U*
                                              rVREX
                                                                                                                 •FOAM ENCASEMENT
                                                                                                         BOILING FLASK -
                                                                                                         2-LITER. ROUND-BOTTOM. SHORT NECK.
                                                                                                         WITH | SLEEVE NO. 24/40
                                      Fiflure 7-1.  Sampling train, flask valve, and flask.
                                                                            111-72

-------
   Unless otherwise  Indicated.  II Is  Intended  that  el)
 reagent* oonlorm to tbe specifications established by the
 Committee on  Analytical Reeeenu ol the Amerto»n
 Chemical Society, where  turh  st>*ciQoalloiu are avail
 •ble: otherwise. UK- thr best available grade.
   a.!  Sampling  To prepare the absorbing  solution.
 awollously tan 2.1 ml  concentrated HiSO. to 1 Ulo of
 4Monlred. dmllled water.  Mil  writ end will 8 JnJ of I
 awnuiit hydrogen peroxide, (rashly  piepared  from  go
 parrent  hydrogen  peroild-  solution  The  absorbing
 •OluUon should be used within I week of lu preparation
 Do not expose to extreme heat or dtnrt sunlight.
   U  Sample Recovery. Two reagents trf required tor
 ample recovery:
   aJ.I  Sodium Hydroxide (IN). Dlasolve 40 g N.OH
 to drtoolied. dlnllM water and d)lut» to I liter.
   U.2  Water. Delonleed.  distilled to oonlorm U) A6TM
 gawclfioaUao DlIM-74. Type 1. At  tbe opUon of the
 analyst, UM DfNO> test  far oxldlsabte organic matter
 nay be omitted when high concentrations of orf»nlc
 matter ire not expected to or present.
   1.1  Analysis. For the. analysis. lb* following reagent*
 an required:
   S.1.1  Fuming Sulfuric Acid. 1» to IB percent by weight
 fret  Kilter Uiosidr. HANDLE  WITH  CAUTION.
   a.t.2  Phenol. White solid.
   l.s.S  Bulfunc Acid. Concentrated, 94 percent mini-
 mum MM). HANDLE WITH CAUTION?
   S.1.4  Potassium Nitrate. Dried at 105  u> 110" C  (WO
 to 2)0° F) lor * minimum of 2 boun |tut prior to prepare
 tton ol standard solution.
   i.J.i Standard KNOi  Solution.   Dissolve  exert))
 S.I9B It of dried potassium nltnir (KNOi) In delonited.
 distill^  viler  and dilute to  1 liter  with deionited.
 distill _, water in • 1,000-ml volumetric flask.
   I.S.6 Working Standard KNOi Solution. Dilute 10
 ml  of v * standard  solution  to 100 ml with deionited
 distilled* water. Ooe mlUiliter of the working standard
 solution 1s equivalent to 100 ft nitrogen dloude (NOi)
   (.3.7 Water.  Deionited, distilled as ID Section 3.2.2
   S.a.8 PbeuoldisulfonJc  Acid  Solution.  Dissolve 26 I
 Ot pure  white phenol  In  190 ml concentrated tulfurir
 •do on • steam bath  Cool, add 76 ml fuming tulfurlc
 •dd. and beat at 100° C  (212*  F) lor 2 noun.  Store In
 • dark, ftopptrad bottle.

 4. Pnatwu

   4.1  Sampling.
   4.1.1  Pipette 2) ml of absorbing solution Into a sample
 flask, retaining a sufficient quantity for UM In preparing
 the calibration standards  Insert the (task valve (topper
 mto tbe flask with the valve In the "purge" position
 Assemble tbe sampling train as shown In Figure 7-1
 and plan the probe at the sampling point Make sure
 that all  fittings are tight  and leak-free,  and  that  all
 •round glass Joints have been properly greased with a
 high-vacuum,    high-temperature  chlorofluorocarbon-
 based  stopcock  (rease.  Turn -tbe flask valve and  the
 pump valve  to tbelr  "evacuate" positions  Evacuate
 tbe flask to 7S mm Hg (3 In. Bg) absolute pressure, or
 lest  Evacuation to a  pressure  approaching the vapor
 pressure of water at tbe  existing temperature is desirable
 Turn tbe pump valve  to Its "vent"  position and turn
 00 tbe pump  Check for leakage by observing tbe ma
 nometar  lor any pressure  fluctuation (Any variation
  greater than  10 *•"" Hg  (0.4 In Hf) over a period of
  1 minute It not arceptable.  and tbe Back If not to be
.' Died  until the leakage problem U corrected.  Prenure
  In tbe flask is not to exceed 75 mm Hg (3 In. Hg)absolute
  at tbe time aunnling Is commenced.) Record the volume
  of tbe flask and valve (V,). tbe fla) Is tbe barometric pressure leas the man
 emeirr reeding  Transfer the content! of'tbe flask u e
 leak (n*  polyethylene  bottle  Rinse the  flask twtoe
 wltb fr-ml portions of delonlted. distilled water and add
 Ibe rinse water to the bolt If Adlust the pB to between
 t and 12 by adding sodium hydroxide  (1 N). dropwlse
 (about  ZJ to 15 drops)  Check  the  pB  by dipping a
 •Urnng rod Into the eolutlon and then touching  the rod
 to the pH test paper Remove as Utlle material as possible
 during  this step Mark tbe height of the liquid  level so
 that thr container can  be checked for leakage after
 transport  Label the container  to clearly  Identify  lu
 emienu  Baal Ibe container for shipping
   4 J  Analysis. Note the level of tbe liquid In container
 and confirm whether or not any  sample was lost during
 ahlpmtnt; note  this on the analytical  data sheet. If a
 noticeable amount of leaksf has occurred, cither void
 the sample or use methods, subject to tbe approval of
 the Administrator, to correct the final results. Immedi-
 ately prior to  analysis, transfer the contents of  the
 ahlpping container to a 60-ml  volumetric flask, and
 ruue the container twice with 6-mJ portions of delonlted,
 distilled water.  Add tbe rinse water to tbe flask and
 dilute to tbe mark wltb deionittd. distilled water; mix
 thoroughly.  Pipette a 25- ml aliquot  into tbe procelaln
 evaporating  dish. Return any  unused  portion ol the
 sample to the polyethylene  storage  bottle. Evaporate
 the 26-ml aliquot to dryness on a steam bath and allow
 to cool. Add 2 ml phenoldisulfonic acid solution to the
 dried residue and triturate thoroughly with a poylethyl-
 eoe policeman.  Make sure the solution contacts all the
 residue. Add. 1  ml deioniEed, distilled water and four
 drops of concentrated sulluric acid.  Heat tbe solution
 oo a steam bsth for t minutes with occasional stinlni .
 Allow tbe solution to cool, add 20 ml deionised, distilled
 water, mix well by stirring, and add concentrated am-
 monium hydroxide, dropwise. with constant stirring.
 until tbe pH Is  10 (as determined by pH paper). If the
 sample  contains aolids, these must  be  removed  by
 filtration (cenlrifugation  Is an  acceptable alternative.
 •object to toe approval of tbe Administrator) , as  fallows
 filter through Whatman No. 41 filter paper Into a lOO-ml
 volumetric flask: rinse the evsporstine dish with three
 6-ml portions of deionlted. distilled  vater; filter tbese
 tare* nnses. Wa?n  the filter with at least three IVml
 portions of delonlted. distilled  water.  Add  tbe filter
 washings to tbe contents  of the volumetric  flask and
 dilute to tbe mark  with deionised, distilled water. U
 solids are absent, tbe solution can be transferred  directly
 to the 100-ml volumetric flask and diluted to tbe mark
 with deiomied.  distilled water. Mix the contents ol the
 flask thoroughly, and measure  tbe absorbanee at tht
 optimum wavelength  used for the standards (Section
 62.1), using the  blank solution as a tero reference. Dilute
 the sample and  the blank with equal volumes of deion-
 ised. distilled water If the absornance exceeds  A«. tbe
 aoaorbance of tbe 400 «g N Oi standard (see Section J.2.2) .
   I.I  Flask Volume. Tbe volume of the collection fUik
 Baak valve combination  must be known prior In aun-
 pilng Assemble  tbe  Bask and flask valve and fill wn)
 water, to tbe stopcock Measure the volume of water to
 *10 ml  Record this volume on tbe flask.
   (.2 Spectropbotometer Calibration.
   1.2.1  Optimum Wavelength Determination. For both
 fixed and  variable  wavelength spectrophotometers.
 calibrate  against standard  certified wavelength of  410
 nm. every 6 months. Alternatively, for variable wave
 length spectrophotometers.  scan the spectrum between
 400 and 416 nm using a 20n«g NOi standard solution (see
 Section 6.2.2).  If a peak  does not occur, tbe spectropho-
 IOmeter Is probably  malfunctlonlnn. and should be re-
 paired. When a peak Is obtained within the 400 to 416 nm
 range, the wavelength at which this peak occurs shall be
 the optimum wavelength for the measurement  of ab-
 sorbanee for both the standards and samples.
   e.2.2 Determination of Bpectrophotometer Calibre
 Ucm Factor E.. Add 0.0. 1.0. 2.0, 1.0. and 4.0 ml of toe
 KNOi working standard solution (I m)-100«f NOi) to
 a series of five porcelain evaporating dishes. To each, add
 > ml of absorbing aolution. 10 ml deionlted, distilled
 water, and sodium hydroxide (IN), dropwtse, until the
 pB Is between t and 12 (abour*2S to U drop  each).
 Bef inninz with the evaporation step, follow the analy-
 sis procedure of Section 4.S  until tbe solution has been
 ttansferred to the 100 ml volumetric flask and diluted to
 the mark  Measure the absorbance of »«ch solution, at the
 optimum wavelength, as determined  in Section 6.2.1.
 This calibration procedure must be repeated on each day
 that samples are analysed Calculate the spectrophotom-
 rter calibration (actor as follows:
  i.S  Vacuum Gauge  Calibrate mechanical gauges. II
need, against a mercury manometer such as that sperl-
Bed In 2.1.6.
  6.6  Analytical Balance.  Calibrate  afelnxl standard
weights.
  Carry out the calculations, retaining at least one extra
decimal figure beyond that of the acquired data. Round
off figures after final calculations
  6.1  Nomenclature.
    A -AbKrbanc* of sample
    C-Concentrailon ol NO. as NOi. dry basis, cor-
       reeled  to   standard   conditions,  mg/dscm
       Oh/dvO
    /•-Dilution (actor  (It. nil. 28/10. etc.,  required
       only  If sample dilution wa< needed to redurr
       the absorbance Into the rang*- of calibration).
   Kr—Bperlrbphotometer calibration (actor
    wi-Hsss nf NO. as NOi In gas sample. *s
    /"/-Final absolute pressure of fltsk. mm Hr (in Bit
    Pi- Initial absolute  pressure of flask, mm Hg (in
       HE)
  Pnt -Standard sbaototr pressure, 780 mm Bg (20.92 in
       Hi).
    Tr-Flnal absolute temperature of flask  .*K PR)
    Ti-lnltial absolute temperature ol flask. °K <°R)
  T.,« - Standard absolute temperature, 293' E ((28* R)
   t'..- Sample volume  at  standard  conditions (dry
       basb). ml
    V/— Volume of flask and valve, ml
   V.- Volume of absorbing solution. 26 ml
     2-60/25, the aliquot (actor.  (II other than a 2S-ml
       aliquot we* used for analysis  tbe correspond-
       Ing IV tor must be substituted!.
  6.2  Sample volume, dry be." is. corrected to standard
condition*
                                   Equation 7-1
where:
  K. - CaHbraUon factor
  Ai-Absorbent* of the lOO-i* NOi standard
  A i - A bsorbence of the ZOO-* NO, standard
  Xi-Absorbance of the SOO>« NOi standard
  X4-Abeorbance of the 400(4 NOi standard
  (.1  Barometer. Calibrate against a mercury  barom-
eter.
  (.4  Temperature Oauge. Calibrate dial thermome^ri
•gainst mercury-4n^laei thermometers.
where:
                    K,(V,-25 ml)      -


                                   Equation 7-2
   A'i = 0.3858
                    CK
                 mm  Hg
for metric units
       -^17.64 :—rr- for English units


  6.S  Total »t NOi per sample.
                                   Equation 7-3

  Non.—If other than a2i-ml aliquot Is used for analy-
sli. tbe factor 2 must be replaced by a corresponding
sactor.
  6.4  Sample concentration, dry  bails,  corrected to
standard conditions.
                   C-K,i
                                  Equation 7-4
  K,- IV         for metric units
            jig/ml
     -6.243X 10-« -.— for English units
                      stg/ml

T. KUiotrtfkw

  1. Standard Methods of Chemical  Analysis. 6tb ad.
New  York. D. Vna Nostrand  Co..  Inc. 1M2. Vol. 1,
p. S2»-330.
  1. Standard Method of Test for Oxides of Nitrogen In
Osseous Combustion  Products  (Phenoldisulionic Arid
Procedure). In: 1968 Book of ABTM Standards. Pan K.
Philadelphia. Pa. 1968. ASTM Designation D-160S-60.
p. T1S-728.
  I. Jacob, MB. The Chemical Analysis of Air Pollut-
ants.  New York.  Interscience Publishers,  Inc. 1960.
Vol. 10. p. 151-156.
  4. Beatty.  R. L., L. B. Berger, and B. H. Bchrenk.
Determination of Oxides of Nitrogen by the Pbenoldisul-
lonlc  Acid Method. Bureau  of Mines.  U.6. Dept. of
Interior. R. I. K8T. February 1MJ
  6. Hamll, H. P. and D.  K. Camann. Collaborative
Study of Method  lor tbe Determination  of Nitrogen
Oxide Emissions from Stationary Sources (Fossil Fuel-
Fired Steam Generators). Southwest Research Institute
report (or Environmental Protection Agency. Research
Triangle Park, N.C. October  6. 1973.
  6. Hamll, H. F. and R. E. Thomas. Collaborative
Study of Method  tor the Drtermlnation  of Nitrogen
Oxide Emissions (ram Stationary Sources (Nitric Acid
Plants).  Southwest Research Institute  report for En-
vironmental  Protection  Agency.  Research  Triangle
Park, N.C. May t, 1074.
                                                                                  111-73

-------
MITHOO »— D«T«RMIH»TIOII o»  Boirvuc AOB  Mist
  AMD Sui.ru« DIOIIDI Euusiom FaoM SttnoitiaT
  Souacu
1. Prlndplt ei
           nf A

           '?''_*
  1.1  Principle. A gas sample Is estrarlMl Isoklnatleally
(rein Ihe slack. The sulfunc acid mist (Including lutlui
trtoiidr) Mid (he .luKur dioiide are. separated, and botb
fractions are measured separately by (be bariuJU-thorio
Utnlion method.
  1.2  Applicability.  This method ii »ppllc»ble for tbe
determination of sulfurlc acid  ntlit  (Including  sulfur
tftoside. and In the abvnre of other paniculate matter)
and  sulfur  dloilde emissions from stationery iouree«.
Collaborative lull  hive ihown that  Ihe minimum
detectable limns of Ihr method «ie 0 OS milligr«m»/cubic
meter (0.03> 10-' pounds/cubic  fool) lot sulfur Irtoside
and  1.2 mg,m> (0.74   10-' IMP) for  sulfur dioiide. No
opper linuu have- been established. Dated on Ihcontlcd
calculation] fur  20U  nuUiliirn  of 3  percent  hydrogen
p*roiide  tolution, the  upper  concentration  limit lor
Mlfur dioiid* in a 1 u m> lU.) 1C) gas sample la about
1J.JOO rrn'm'  (77X10-'  Ili.-fi'). The upper limit can be
ettrndrd t>y incrrasins Ihe iiunntity 01 prruiide solution
ID the impnuers
  Poviblr Intrrtrnng a|ent> of thU method are fluondet,
(r«  ammonia, and dimethyl aniline. If any of thcw
Interfenni ageiits arc prrsrnt (this can be determined by
knowledge  of  the nrocru), altemall*e methods, tubjrrt
to DM approTal of  lh«  Administrator, an required.
                                                      Filterable paniculate matter mar he determined tlnni
                                                    with SO i and SOt (subject to the approTal of the Ad-
                                                    mlnlttratorl: however, tbe procedure used for paniculate
                                                    matter must be comment with the iptclnratloni and
                                                    procedures (1*eo In attthod i.
                                                      2.1  Pampllnf.  A schematic of  the  sampUnf  tralo
                                                    liird la Ihli mrlhod Is shown In Flpire  H. It Is simitar
                                                    to thr .Mrthod S train rtrcpt thai  the nlirr position b
                                                    dllfirrnl and the filirr hold, r Jwj not have lobe helled.
                                                    t'ommnrlal DiMl'li of this train are available. For those
                                                    who desire to build their own. howrvr-r, complete eon-
                                                    Itrurilon drtalls arr d.vrllM-d In AI'TI)-n*l  I'hanid
                                                    from the AI'TIUI'^I  dutumrnl Hid allowkMc modl-
                                                    fkatlons  to Kluure 9-1 are  disctuard In the following
                                                    subvv Uons.
                                                      Tin* operallng and maintenance  procrdures for the
                                                    sampling train are dnscilWd In AI'TI>-Oo78 Since comet
                                                    UMitii1 U lni|»urtant In obliuiung valid results,  all  usen
                                                    ahuulil  r, jd I ho ArTD-a',78 il» un.. m and adopt tbe
                                                    oprratlng tnd nialnirnunce  finx-Mutcs  outlined In It,
                                                    unless oili«rwlM.> si^Tiftrd hLTrin.  Funhcr details and
                                                    gute metal probe liners.
  i 1.3  fitot Tubr. Same as Method 'j. tfecUon 2.1.3.

  S.1.4  DI9«f»nUa) Pnstian Oaujr Same a* Methods.

  t \J>  FlitM Bolder  Baroalll«au gUuc. with a itlasr
frit filter  support and a glllcone rubber gasket. Other
Basket matnals. e.g., Teflon or Vluin, nay be oa«d sub-
feet to  the approval of the Administrator. The holder
dtolgn shall provide a positive atal afalnst leakage from
tbe ouUtde of around tbe filter. The filler holder shall
b» pbxrd between the flm and second Implngers. Note:
Do Dot heat the tllur bolder.
  2.1O  Implngen— Four, at •howTJ In rifui* R-]. The
Int and  third shall be of tbe Ore«nhurg -Smith dmtgn
with standard Up» Tbe  second and founh shall be of
tb» Oreenbnrg-Smlth dealgn, mndlAed by replarlng th*
Insert with an approilmatfly 1) mllllmrur (O.i In.) ID
ilaHt tube,  having an uneorutrlrud tin located 13 mm
(06 In.) from the bottom  of the flaik. Rlmllar coll«eUon
systems,  which have been approved by the Adminis-
trator, may b« used.
  1.1.7  MeUrtOf Biitam. Same as Method 6. Settlor.
ll.t.
  I.1J  Barometer. Same at Method 6. Section 2.1.«.
  2.1.9  Oas Density Determination Equipment. Bane,
M Methods. Section 2.1.10.
  11.10  Temperature Gauge. Thermonwier. or equlva-
   2  Sample Ilat»ivti>.
                                 TEMPERATURE SENSOR
                          >           ^


          £_ZJ'-a*-   .....  .     •*•«£—;
                                                 PROBE
                                                                                                                     THERMOMETER
    PROBE
                                                                                                                                  .CHECK
                                                                                                                                 /VALVE
     REVERSE TYPE
       WOT TUBE
                                                                                                                                          VACUUM
                                                                                                                                             LINE
                                                                                                                                     VACUUM
                                                                                                                                       GAUGE
                                                                                                                        MAIN VALVE
                                          DRY TEST METER

                                                  Figure 8-1.  Sulfuric acid mist sampling train.
                                                                         111-74

-------
  U.I  Wmsb BotOea.  Polyethylene er times. MX) ml.
(two).
  1.2.3  Graduated  Cylinders.  HO  ml,  I Uler.  (Vohr
•ctrlr flasks may also be need )
  U.l  Storage BotUM. Lem*-tre» polyetbylrne boUVsa.
MOO ml slaa (two lor emeb ammpllnf ran).

  1.2.4  Trip Balance SOftfiMi capacity, to tnemmra to
•YOJ I fnniaaai) only U • moisture content analysis to
to be done).
  2.8  Analysts.
  2.1.1  Pipettes. Volumetric 29 ml,  100 ml.
  1.1.2  BurretU.oDml.
  1.3.3  Erleruneyer Flask. HO ml. (en* tor emeb ample
Mink and standard).
  1.1.4  Graduated  Cylinder. 100 ml.
  1.15  Trip Balmner. WO  t  capacity.  to measure to
aYOJf.
  2.1.4  Dropping  Bonk. To  add  Indlomlor  aoraUon.
129-mIalsa.
  Unless otherwise Indicated. all rea* t nU are to eontorm
to the specifications established by the Commute* on
Analytical Rutrnli of Ibf Amorlmn Chrmltml Society.
• brrr nich iprrlfkalloiu tr» tTtlltble. OlbarwiM, mr
tb* but trtlltble fndc.
  1.1  8»mplln».
  1.1.1  Fllun Rune u Mf thod 5. Bretlon 3.1 .1 .
  l.l.I  BlUa Del. Bunt u Method 6. Section 3.1.2.
  3.1 >  »'»ttr. Drlonlied. dtnllM U> eonlbrm to A8TM
tp*ctfle*tlon DllW-74, Typr 3. At  the option  of Uu
•nalyn, tbr KMnOi Wat for ozldlubto orttnlc mMtrr
•my be omltud  when bit b eoneentntlonj at eifmnlc
•»tU> we not eipeclvd to M pment.
  1.1 « boprepemol. 10 Peramt. MU »> ml of bopto-
PIDOI with 100 ml of delonlud, dwtilled w»ter.
  MOTI.— Eipf.rt»n«e hucbown thel only A.C.B.fude
•Bpropenol  U •tldu-tory. TriU b«»«  rtiown  tbtt
taoproptaol  obUlnod train  eommereltl  •oarers oee>-
eutoDdly bu peroildt ImpariUe* tb»t will emote m-
iWMOusly hljh folfurlc meld mist  measurement.  Dm>
U)i followlnf tett lor deUrtlnj prroildu In emcb lot of
hoBronuiol.  Bbmkr 10 ml of Ibf liopropmool wltb 10 ml
of tnuhly pnpmrrd I0perr*nt poUnlura lojlde eolotton
fnpmn • btenk by •ImlUrly tnmtlni 10 ml ol dlitllled
wmtai . A IKr I mlnuU, nmd the ehini b«nf» on t tp*clio-
DbotomrUr it IS2 nmaomften. II thr mbfoibmooe eiemo>
0.1. tbr liopropmnol Iball not b* uwd. Peroxides m»y be
     tfid from Isopromnol by rKHsUIUnf. or by pmmimft
               n of mrtlve
thcoufih m column of
                                   .
                      veud mlumlni However, re-
                                            ,
 tenUf rtd< liopromnol with sulubly low pcroilde level*
b remnlly eTelfthlr (ram oonunMrlml SOUTOH; tbemlon,
rtJerUon  of eont&mlniUd loU m*y be more efficient
Uimn lollowlnf the prroildr retnoTml procedure.
  (.1.0 Bydrocen Peroxide. 1 Percent. DUale 100  ml
•f n percent hydrogen peroilde to I Uter wltb delonlMd,
distilled weutr. Prepmre rremh dally.
  1.1 • Cruibed Ice.
  S.2  Beroplt Rerovrry.
  U.I WeUr.Bmme ma 3.1.8.
  t-J.Z Isopropmnol, lOPiraot. Bmmemsl.1.4.
  1.8  Aoeljfls.
  U.I Wet«r. Btmru S.1.3.
  1.1.2 Isopropmnol. 100 Percent.
  1.1.9 Thortn Indlcmur. l-(o-*noooprieiiylmso)-l«mpb-
thol-1, «-dlsu1lonlc acid, dlsodlum eeJt. or «rolTmleDt.
DUeoUe 0 »f In 100 ml of delonlted. dntllM weter
  1.14 • Btrtuin Perchloraie (0.0100 Norm*)). DtseoUe
I.MlorbkrluiB perehlortu trlhydretr (BelCIO.)rlUiO)
ID 200 ml delonlud dlitllled wem, »j,d dlluu to I UUT
with isopropuiol.  1.23 | of bmrlDm ehlorlrte dlhydrmie
(BeCU JHeO) mey b* uard Instep of the bmnnm per
•tilonte Btmnderdlw wM (oUurlc meld Mln SetUon 8.7
This solution most b* protected mfilost trmponUon et
•U times.
  J 3 5  Bulfurte Add Btmndmrd  (0.0100 N). Purchmee or
slendtrdlte to ±0.0002 N mfmlnsi 0.0100 N NeOH that
has  previously been standardised acmlnat primary
standard rrtasnlnm acid phthalate.

4. Prxrdurt
  4.1  ftampUnf.
  4.1.1   I'releal Prepanlion. Follow the procedure, out-
lined in Method S. Seriion 4.1.1. niters should  be.  In-
•peeled, but nerd not be dealceaied, wei|hed, or Identl-
lied. If t he effluent fas ran be corulde rxl dry ,!.«., mois-
ture free  the silica |el need not be weighed.
  4.1.2   Preliminary l>eierminanons  Kollow the pro-
cedure outlined in  Method J, Section 4.1.2.
  4.1.3  Preparation of Collection Train. Follow the pro-
cedure outlined in  Method  5. EWtlon 4.1.3 (eirept lor
the aecond paragraph  and other  obvtou&ly inapplicable
parts) and use Firure 8-1 instead of Figure VI Replace
the aecond parmttiiph  with: Place 100 ml of 80 percent
tmopropsnol in the first Implnfer. 100 ml of 3 percent
bydroctn prroiide In both  the  second and  third Im-
plnfcrs: retain a portion of each remfent lor urns a< a
blank solution. Place about 200 tofaUlcapl In tbslaonb
Implncer.
   LOCATION.

   OPERATOR.

   DATE	

   RUN NO. _
   SAMPLE BOX NO.

   METER BOX NO._

   METER A Hf	

   CFACTOR	
  P1TOT TUBE COEFFICIENT, Cm.
                                      HA TIC PREKURE. •• H| (im, H|).

                                      AMBIENT TEMPERATURE	

                                      BAROMETRIC PRESSURE	

                                      ASSUMED MOISTURE. %	

                                      PROBE LENGTH, m (ft)	
                                                SCHEMATIC OF STACK CROSS SECTION
                                      NOZ2LE IDENTIFICATION NO	

                                      AVERAGE CALIBRATED NOZZLE DIAMETER. cm(iflj.

                                      PROBE HEATER SETTING	

                                      LEAK RATE. mJ/min,(cfm)	

                                      PROBE LINER MATERIAL	

                                      FILTER MO.  	
TRAVERSE POINT
NUMBER












TOTAL
SAMPLING
TIME
.
••HID
OfcHjO)














PRESSURE
DIFFERENTIAL
ACROSS
ORIFICE
METER.
•»H20
(hLH^OI














6 AS SAMPLE
VOLUME.
•1 (h'l














GAS SAMPLE TEMPERATURE
AT DRY GAS METER
INLET.
•CI'FJ












Avg
OUTLET.
H(»F)












A»B
Av»
TEMPERATURE
OF GAS
LEAVING
CONDENSER OR
LAST IMPINGER.
•C (»FJ














                                                               Flgur* 8-2.  Fl«ld d«U.
                                                                               111-75

-------
  Norg —It moisture contest to to be determined by
tmplnger analysis, weigh each o( the Bret three Implngen
(plus ebsorblngiolutlon) to tbe neons* 0.6 | and roord
then weight*. The weight of the illlca gel (or silica («)
plus eonuiner) must also b* determined to lb* nearest
0.1 g and recorded.
  4.1.4  Pnteet  Leak-Cbeck  Procedure.  Follow tbe
boek procedun outlined  In Method 5. Section 4.1.4.1,
notinc th»i tht probe hector shell  be adjusted  to UM
minimum temperature required to pnvenl  oondensa-
Uoo. and al*o that verbac nich as. ''* • •  plugging UM
UiM to tbe Alter bolder  ' • V shall be  replaced by.
	plugging the Inlet to tbe first Impinfer • • V"
Tbe pretest leak-check I* optional.
  4.1.4  Train  Operation.  Follow tbe boric procedure*
euUlmd In  Method J. Section 4.1 J. In conjunction with
tbe fallowing special Instruction*. Data shall be raoordrd
eo »sheet similar to tbe ens la injure B-B. Tbe sampling
ret* shall not  raceed O.ojo m>/mln (1.0 dm) during tbe
run. Periodically during tho test, oborve tbe caonocttna
Une between the probe end first Implnier tor signs of
condensation.  If It does occur. adjust the  probe beater
setting upward to tbe minimum Ltmpt»ture required
to prevent  condensation. K component change* become
oeevBorr durlnf e run. a leak-check (ball be done Im-
mediate ly before each change, according to the procedure
outlined In Section 4.1.4.2 ol Method 5 (with appropriate
modifications,  a* mentioned ID  Section  4.1.4 at tbl*
method); record *ll  lea*  rotes. I' tbe  leakage  rate(i)
exceed the specified rale, tbe teeter shall either void tbe
ran or shall plan to correct the ample volume a* out-
lined In Section 6.9 of Method S. Immediately alter com-
ponent  changes,  leak-checks are  optional.  II  these
leak-check* an done, tbe  procedure outlined  In Section
4.1.4.1  of Method 5  (with appropriate modification*)
•teUbeuwd.

  After turning ofl tbe pump and recording tbe final
readings at the conclusion of each run. remove the probe
from the stack. Conduct  a post-test (mondotory) leak-
check as In Section 4.1.4.3 of Method S (with appropriate
modification)  and record  the leak rat*. If the pott-test
la&kane rate exceeds tbe  specified acceptable rate, the
tester shall either correct the sample volume, as outlined
In Section 6.3 of Metbod 5. or shall void tht run.
   Drain the Ice bath and. with the probe disconnected.
purge the remaining pan ol the train, by drawing clean
ambient air through the  system lor 15 minutes at tbe
average flow rate uvd for sampling.
   NOTE.—Clean unbienl air can be provided by passing
air through a charcoal filter. At the option of tbe tester,
ambient air (without cleaning) may be used.
  4.1.6  Calculation of Percent  Isoklnetlc. Follow tbe
procedure outlined in Method i. Section 4.1.0.
   4-S  Sample Recovery.
  4J.1  Container No. I. If a moisture content analysis
if to be dose, weigh tbe tint implnger plus content! to
tbe nearest O.S g and record this weight.
  Transfer the contents of tbe first tmplnger to a SJO-ml
graduated  cylinder. Rinse the probe, first Implnger all
connecting glassware before the filter, and tbe front bait
of tbe filter bolder with K percent Isopropanol. Add the
rinse solution to the  cylinder. Dilute to MO ml with SO
percent Isopropanol. Add the Alter to tbe solution, mil,
and transfer to the storage container. Protect the solution
•gainst evaporation,  nark the level of liquid  on bet
container and  Identity the sample container.
  4 J J  Container No. I. II a moisture content •Mir*'*
I* to be done, weigh the second and third Imptngen
 (plus contents) to tbe Dearest OJ> g and record  these
weights. Also, weigh tbe spent silica gel (or silica gel
pluakmplnger) to the neoreetO-Sg.
   Transfer tbe solutions trom  tbe second  and  third
Implngen  to  a 1000-ml graduated cylinder.  Ulnae all
connecting glassware (Including back half of filter bolder)
between toe Biter and silica gel Implnger with delooUed,
 distilled water, and add tbls rime water to the erUBdar.
 Dilute to a volume ol 1000 ml with delooUed, distilled
 water. Transfer the solution to a storage container. Mark
 tbe level of liquid on tbe container. Seal and Identify tbe
 •ample container.
   4.8  Analysis.
   Note the level of liquid In containers 1 and S, and con-
 firm whether or not any sample was loft during ship-
 ment; note this on the analytical data sheet. If a notice-
 able amount  of leakage  has occurred, either void tbe
 •ample or  UK methods, subject to the  approval of the
 Administrator, to correct tbe final reaulta.  •
   4J.1  Container No. 1. Shake the container holding
 tbe Uopropanol solution and  tbe  Alter. If tbe filter
 breaks up, allow tbe fragments to settle lor a few minute*
 before removing a cample. Pipette a 100-ml  aliquot  of
this solution Into » MO-ml Erlenmeyer Book, add 1 to 4
 drops of thortn Indicator, and titrate to a pink endpolnt
 using 0.0100 N barium perchlorate.  Repeat tbe tltratlon
 with a second aliquot of sample and avenge UM Utratton

 values, BopUcate UtraUoni moat acre* within I parast
 OTOJml. whichever Is greater.
  4JJ  Container No. 3. Thoroughly mix tbe solution
la the container holding the content* of the second and
third Impingers- Pipette a lO-mJ aliquot of sample Into a
VO-ml  Srlenmeyer flask. Add  ml of toopropanol. 1 to
4drop* oftberln Indicator, and trtroteto a pink endpolnt
W U ml, whichever Is greater
  U-* Blanks. Prepare blanks by adding 1 to 4 drop*
•* tbortn Indicator to 100 ml of go percent lanprepanal-
Titrate tbe blanks In the some manner as the •ample*.
  a.)  Calibrate oqulpment using tbe procedure* sped-
ted In the fallowing sections of Method 6: Section U
(metering system); Section  6.6 (temperature gauges):
•eaUan J.7 (barometer). Note that the recommended
leak-check of tbe metering system, described In Section
M of Method 5, also applies to this method.
  1J  Standardise tbe barium perchlorate solution with
IS ml of standard  sulfuric acid, to which 100 ml of 100
Bwnaot laoproponoi has been added.

e. Oticvlatem

  Note.—Carry  out calculations retaining at ktoit OB*
extra decimal figure beyond that of tbe acquired data.
Round of} figure* after final calculation.
  (.1  Nomenclature.
       ^t.-Croat-sectional area of noule.m> (n1).
      B.-Water vapor In tbe ga* stream,  proportion
             by volume.
  CBj80i»8uUuric acid (Including BOi) concentration.
             1/dJcmnb/dscO.
     CSOi-BuUur dioxide concentration, g/dscm (lb/
             dec/).
        /•Percent of Uoklnettc sampling.
        sV-Normality 0f barium perchlorat* tltnnt,  g
             equl valenti/uter;
     /•bar-Barometric  pressure at the sampling Me,
             mm Bg (In. Bg).
        /•.-Absolute Mack gas nresmre, mm Bg On.

     Atd-Standard  absolute prawn, TtO mm Bg
             (SS.KlD.Hi).
       T.- Average absolute dry gas meter temperature
             <*ee>lgureB-2),'KCR).
       r.-Average absolnu stock gas temperature (see
             Figure 8-2),' K f R).
     Tttd-Standard  absolute temperature, Kf  K
             (628° B)
       V.-Volame of sample aliquot titrated,  100 ml
             far B»80i ana 10 ml for SOi.
       V,,-Total volume of liquid collected In Impingers
             and silica gel. ml.
       V.-Volume of gas sample as measured by dry
          gai meter, acm (del).
  V»(ltd) - Volume of ga* sample measured by tbe dry
          gu mtter corrected to standard conditions,
          dscm (dscf).
        (.•Avenge stock ga* velocity, calculated by
          Metbod 2. Equation J-*. using daU obtained
          from Metbod8, m/sec (ft/sec).
    Veoln-Total  volume of  solution In which tbe
          eulfurir acid or mlfur dioxide  sample  is
          contained. IV) ml or 1,000 ml, respectively.
       Vc-Volume of barium perchlorate tltnnt n*ed
          tor tbe sample, ml.
       V«-Volume of barium perchlorate tltnnt mod
          far the blank, ml.
        r"- Dry gas meter calibration factor.
      A/Y-Averue pressure drop across orifice meter,
          mm (In.) BrO.
        6-Total sampling tlm«, mln.
      11.6-Speclflc gravity of mercury.
       W-sec/mln.
       100-Converslon to percent.
  t.2  Average dry gas meW temperature and avenge
•rifle* pressure drop. Set data sheet (Figure (-2).
  U  Dry Oat Volume. Correct tbe sample volume
measured by tbe dry gas meter to runderd conditions
O0> C and 760 mm Bg or 68° F and ».«In. Bg) by using
Equation 6-1.
 eo*ou the motetun content of the stork gas. using Eaua-
 Mao »-» of Method t. Tbe "Note" In Section 6.»ofMetbod
 I obo applies to this method. Note that If tbe effluent gas
 stream can be considered dry, tbe volume of water vapor
 SBd moUtare content need not be calculated.
  o-J  auUurtc odd milt (Including 8O.) concentration.
                                                                                      Equation 8-2
                                                      *ti»aoU(M g/mUlleqalvalent tor metric unit*.
                                                         -LOBlXIfr-Mb/Bieql  ~
                                                      e.6 Sulfur dioxide oooo
     -1.0BlXIO- described In Section «J of Method A), or shall
Invalidate the ten run.


   4U  Volume of Water Vapor and Moirtnre Content.
 Colculste the  volume of water vapor using Equation
 *-l of Method t.  tbe weight of water collected IB the
 taBplpgen and  silica gel con be directly converted to
 affllllten (the specific gravity of water fa 1 g/ml). Col-
                                 Equfttion 8-5
where:
  ft-UU) lor metric unit*.
     •O.OMSO for BngUsh unit*.
  U Acceptable H
eant, the ntults an i   .        	„
eomparlson to the standards and I If beyond tbe accept-
able range, tbe Administrator may opt to accept the
twnilb. Os* Citation 4 in the Bibliography of Method &
to make  Judgments. Otherwise, reject the noutu and
repeat tbe test.

T. BftHetnrt.

  1.  Atmospheric Emissions from tuUaric Aeld Manu-
fccturtng Pncessee  0.6. DBEW.  PBS. DlvWon of
Air  PoUotlon  PnbUc  Bealth Service fnbUcotton No.
wN-AP-U. Cincinnati, Ohio. 1M5.
  >.  Corbttt. P. F. Tbe Determination of BOi and BOi
to Flue Oases. Journal of tbe Institute of Fuel. i«v237-34J.
1M1.
  g. Martin. Robert U. Cotutruction Details of Iioklnetic
Bourse Sampling Equipment. Environmental Protection
Agency-  Research Triangle Park, N.C. Air PoUotlon
Control Office Publication No. APTD-OM1. April, 1971.
  4. Patton, W. F. and 1.  A. Brink, Jr. New Equipment
wad  Techniques lor Sampling Chemical Process Oases
Journal of Air Pollution Control Association. l» 163.1M3.
  6. Rom, 1-1. Maintenance. Calibration, and Operation
of boMoctlc  Souree-Sampung Equipment. Office of
Air  Programs,  Environmental  Protection  Agency.
leeearchTMangle Park, N.C. APTD-W6. March, 19TJ.
  t.  Bamll. B.  F. and D. E. Ctmonn. Collaborative
Study of Metbod lor Determination of Sulfur Dioxide
Emission* from stationary Sources  (Foamil  Fuel-Fired
Steam Generators). Environmental Protection Agency.
Research  Triangle  Park,  N.C.  EPA-4JO/4-74-OJ4.
December, 1978.
  T. Annual Book of ABTM Standards. Pert II: Water.
Atmpipheric AnalyHs. pp. 40-43.  American Society
nr Testing and Mourtals. Philadelphia, Pa. 1974.
                                                                             111-76

-------
 aiXTHOD  S  VISUAL  IU1 UBOIlaTTOlf  OF TH*
   oraorr ce>  XKHSXOMS  imoic  *T»TIO»A»T
         stationary sources discharge visible
 •missions Into the atmosphere; these emis-
 sions are usually In to* shape of a plum*.
 TtO* method involves the determination of
 plum*  opacity  by qualified utnunun. The
 method include* procedure* tar the tnlnlng
 and certification of observer*, and procedures
 to be uMd  in the field for determination of
 plum* opacity. Hi* appearance of a plum* M
 viewed by an ulisai i»r depends upon a num-
 ber of variables, com* of which may be con-
 trollable and  scene  of  which may not  b»
 controllable In the field. Variables which can
 be eontroUaA to an  extent to which they no
 longer  exert a significant  Influence  upon
 plume appearance Include: Angle of the ob-
 •erver with respect to the plume; angle of the
 obeeiver with reepect to  tn*  sun;  point of
 observation of attached and detached (team
 plume:  and angle of the obeiner  with re-
 epect to a plume emitted from a rectangular
 •tack with a Urge length to width ratio. The
 «~t*ti~< includes epedflc  criteria applicable
 to thea* variable*.
   Other vatlablr  which may not be control-
 lable In the fle>u are luminescence and color
 contract betwet • the plume and the back-
 ground against valcb the plume Is viewed.
 These variable* exert an influence upon the
 appearance of a plume  as viewed by an ob-
 aerrer. and can affect the ability of the ob-
 eerver  to accurately assign opacity values
 to the observed plume. Studies of the theory
 of plume opacity and field studies have dem-
 onstrated that a plume is most Ttolble and
 present* the greatest apparent opacity when
 viewed  against a contrasting background. It
 follow*  from this, and Is confirmed by field
 trials, that the opacity of a plume, viewed
 under conditions where a contrasting back-
 ground Is present can be assigned  with the
 greatest degree of accuracy. However, the po-
"tentlal for a positive error Is also the greatest
 when a plume Is viewed under such contrast-
 Ing conditions. Cndcr conditions presenting
 a lea* contrasting background, the  apparent
 opacity of a plume Is  less  and approaches
 cero as the color and luminescence contrast
 decrease toward zero. As a result, significant
 negative bias and  negative  errors can  be
 tnade when a  plume Is viewed  under less
 contrasting conditions.  A negative  bias de-
 creases rather than Increases the possibility
 that a plant operator win be cited for a vio-
 lation  of opacity standards due to observer
 error.
   Studies have been undertaken to determine
 the magnitude of positive errors which can
 be made by qualified observer* 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 76B sets of
 3ft readings each are a* follows:
    (I) For black plumes (133 seta at a smoke
 generator). 100 percent  of  the sets were
 read with a positive error1 of less  than 7.6
 percent.opaclty; M percent were read with
 a positive error of less than 8 percent opacity.
    (3) For white plumes (170 sets at a smoke
 generator, 188 sets at a coal-fired power plant.
 298 sets at a sulfurle add plant). 99 percent
 of the set* were read with a poslUvs error of
 less than 7.8 percent opacity; 95 percent were
 read with a positive error ofless than 0 per*
 cent opacity.
   The positive observational error associated
 •with an average  of twenty-five readings is
 therefor* established. The accuracy of- the
 metbod must be taken Into account-when
  determining possible  violations of  appli-
 cable opacity standards..

   > For  a as*, positive error =«ev*raf* opacity
 determined b? observers' SB obeervattons-
 averag* opacity determined .from transmls-
 •ometerli 36 iwumdlnga, •
  1. Principle and oppHoabCUy.

  I.I  Principle. The opacity of emissions
trom  stationary source* Is determined vis-
ually  by a qualified observer. -
  1.3  Applicability.  This method I*  appll-
oabl* for  th* determination  of  the opacity
of emissions from stationary sources pur-
suant to  190.11 (b)  and for  qualifying ob-
server*  for visually  determining opacity of
•missions.                      -
  t,  Procedures.  The observer qualified IB
accordance with paragraph S  of this method
•ban  us*  the following procedures for vis-
ually determining the opacity of emissions:
  t.l  Position.. The qualified observer shall
stand at a distance  sufficient to provide a
clear  view of the emissions with the sun
oriented In the 140* sector to his back. Con-
sistent with maintaining the above require-
ment, the observer shall, as much as possible.
make his  observation* from a position such
that  his  line  of vision ls  approximately
perpendicular to the plume  direction, and
when observing opacity of emissions from
rectangular outlets (e.g. roof  monitors, open
bagnouses,  nonclrcular   stacks), approxi-
mately  perpendicular to the longer axis of
the outlet. The observer's line of sight should
not include more than one plume at a time
when multiple stacks are Involved, and tn
any case the observer should make his ob-
servations with bis line  of sight  perpendicu-
lar to the longer axis of such a set of multi-
ple stacks (eg. stub stacks on  baghouae*).
  23  Field records.  The  observer shall  re-
cord the name of the plant, emission loca-
tion,  type  facility,   observer's  .name  and
affiliation, and the date  on a field data sheet
(Figure 0-1). The time, estimated  distance
to the emission location, approximate wind
direction, estimated  wind speed, description
of the sky condition (presence and color of
clouds), and  plume background are recorded
on a field data sheet at the time opacity read-
Ings are Initiated and completed.
  2.3  Observations.   Opacity  observations
shall  be made at the point of greatest opacity
In that portion  of  the plume  where con-
densed  watet vapor  I* not present. The ob-
server shall  not look continuously at the
plume,  but Instead shall  observe the plume
momentarily a* 18-sseond Intervals.
  2.3.1  Attached steam plumes. When con-
densed  water vapor  la  present within the
plume as  It emerges from the emission out-
let, opacity observations  shall 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-
tance from the emission outlet to the point
In the.plume at which  the observations are
made.
  333  Detached steam plume.  When water
vapor In the plume  condenses and becomes
visible at a distinct distance  from the emis-
sion outlet, the opacity of emissions should
be evaluated at the  emission outlet prlnr to
the condensation of water vapor  and the for-
mation of the steam plume.      • •
  3.4  Recording observations. Opacity ob-
servations shall be recorded to the nearest  8
percent at IV-second Intervals on  an  ob-
servational record sheet. (See Figure 0-3 for
an example.) A minimum of  34  observations
shall be recorded. Each  momentary observa-
tion  recorded shall  bo  deemed  to represent
the avenge  opacity of emission* for a 18-
aecond period.
  3.8  Data Reduction.  Opacity  shall be de-
termined  as an  average of  34  consecutive
observations recorded at IB-eecond intervals.
Divide the observations recorded on the rec-
ord sheet Into sete of 24 consecutive obser-
vations. A set Is composed of any 34 con-
secutive observations. Bets need not be con-
secutive In time and-In no case shall two
sets overlap.  For each set of 34 observations,
calculate the average by summing the opacity
of the 24  observation* and dividing this nun
by 24. If an applicable standard specifies an
averaging time requiring more than 24 ob-
servations, calculate the average for all ob-
servations made during the *peelfl*d time
period. Record the average opacity on a record
sheet. (See Figure 0-1 for an example.)
   8. Qualification* and tttttna.    -
   8.1  Certification requirement*. To receive
certification a* a qualified observer, a can-
didate must b*  tested and demonstrate the
ability to assign opacity reading* tn B percent
Increments to 38 different black plumes and
M different  white plume*,  wtth an  error
not to sa-eeed  IB percent opacity on any one
me fllnc and an  average error not to exceed
7.8 percent opacity In each category. Candi-
dates shall be tested according to  the pro-
cedures described In paragraph  83. Smoke
generators ueed pursuant to paragraph 8.2
•hall be equipped with a smoke meter which
meets the requirements of paragraph 3.3.   '
  The certification shall be valid for a period
of 6 month*, at which tune the qualification
procedure must  be repeated by any observer
In order to retain certification,          _   :
•  8.2  Certification procedure. The certifica-
tion test consists of showing the candidate a
complete run of 80 plumes—36 black plumes
and 38 white plumes—generated by a smoke
generator. Plume* within each aet of 28 black
and 28 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 60 reading*
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 shown black and white plumes of known
opacity.            .  •
. sj  Bmoke  generator  specifications.  Any
•moke generator used for the purposes  of
paragraph 33 shall be equipped with a smoke
meter Installed  to measure opacity  across
the diameter of the smoke generator stack.
The smoke meter output shall display In-
atack opacity based upon a pattuengtb equal
to the stack exit diameter, on a full 0 to 100
percent chart recorder  scale. The  smoke
meter  optlcaJ  design and performance shall
meet the specifications shown In Table 9-1.
The smoke meter shall be calibrated as pre-
scribed In  paragraph 83.1 prior to the con-
duet  of  each smoke reading test.  At the
completion of each teat, the eero and span
drift shall be checked and  If the drift ex-
ceeds 2J percent opacity, the condition shall
be corrected prior to conducting  any subse-
quent teat runs.  The smoke meter shall  be
demonstrated, at the time of Installation,  to
meet the  specifications listed In Table 0-1.
This  demonstration shall  bo repeated fol-
lowing any subsequent repair or replacement
of the photocell or associated electronic cir-
cuitry Including the chart recorder or output
meter, or •very 6 months, whichever occur*
first.
   8.8.1  Calibration. Th* amok* meter  ls
calibrated  after allowing a minimum of  80
minute* warmup by alternately producing
simulated opacity of 0 percent and 100 per-
cent. When stable response at  0 percent  or
100 percent Is noted, the smoke meter Is ad-
Justed to produce an output of 0 percent  or
100 percent, as appropriate. This  calibration
•hall b* repeated until stable 0 percent and
100 percent readings  are produced without
adjustment. Simulated  0 percent and 100
percent opacity values may be  produced by
alternately switching th* power to the light
source on and off while the smoke generator
is not producing amoke.
                                                           111-77

-------
a. Ug&t •owse.. —  Incandescent   Ump
                       operated at nominal.
                       rated voltage.
b. Spectral response  Photopto    (daylight
    of photocell.       epeotral response of
o. Angle of view. ___

d. Angle  c* projec-
                     .  reference 4.8).
                     18*" maximum  total
                       angle.
                     IB* rna»tirmm  total
                       angl*.
•. Calibration error.  as%  opacity, maxl-
S. Zero   and   span  aa*   opacity,   to
    •drift.              minutes.
m jgespoB** Ume..^  *CB seconds.


  •4J  emoke meter evaluation. The smoke
meter  design  and  performance are to be
evaluated as follows:
  8.3.2.1 Light source.  Verify from manu-
facturer's data and frotr voltage measure-
ments made at the lamp, a* Installed, that
the lamp to operated withui ±8 percent of
the nominal rated voltage.
  8.3.2.2 Spectral  response  of  pbotooell.
Verify from manufacturer's  data that the
photocell has  a pbotople response;  Ije, the
•pectrml sensitivity of the cell  shall closely
Approximate the standard spectral-luminos-
ity curve for photoplc vision which  Is refer-
enced in (b) of Table 9-1.
  3.3.2.3 Angle of view. Check  construction
geometry to ensure that the total  angl* of
view  of the smoke plume,  as  seen by the
photocell,  does not exceed  IB*. Tb*  total
angle of view may  b* oalraiiatert from: »=1
tan-* d/2L, where »=total angle of view:
d=th* nan of the photocell dlsmeter+the
diameter  of  the  Hunting  aperture;  and
Lsthe distance from tb* photocell to the
limiting aperture. The  limiting aperture  is
the point In the path between the photocell
and tb* smoke plum*  where the  angle of
view I* most restricted, to amok* generator
•moke  meters thai Is  normally «n orifice
plate.
          Angl* of projection.  Cheek oon-
         i geometry to ensure that tb* total
angle of  projection of tb*  lamp  OB tb*
•moke plume doe* not *zo»*d 16*. Tb* total
•agle of projection may be calculated from:
*=3 tan-> d/2L. where Is: total angle of pro-
jection: ds the sum of tb*  length of the
lamp filament + tb* diam*t-*ir of ***** iiiyyi^)y»y
apenur*: and Ic the dtttanee from the lamp
to the '"•"•'"g aperture.
  8.8.34  Calibration error.  Using aeutral-
denclty fiitars of known opacity,  eback the
error between the actual response and tb*
theoretical  linear rsapons* of tb* smoke
meter. This check Is accomplished  by first
calibrating  the amok* meter according  to
8.8.1  and  then  Inserting a  series of  three
neutral-density filter* of nominal opacity of
SO, BO. and 76  percent In tb* amok* meter
pathlengtb. niters oallbarted within ttfl per-
cent shall be used. Oar* should be taken
wben Inserting  the Alter* to prevent stray
light from affecting the meter. Uak* a total
of  five nonoonsecutlve t*sfllnti for each
filter. The »•».«»
-------
                                                                       FIGURE 9-1
                                                        RECORD OF VISUAL DETERMINATION OF OPACITY
                                                                                                 PAGE	of
                   COMPAHY
                   LOCATIOM	
                   TEST NUMBER.
                   DATE	
                  TYPE FACILITY^
                  CONTROL DEVICE.
                                                                             HOURS OF OBSERVATION.
                                                                             OBSERVER	
                                                                             OBSERVER CERTIFICATION DATE.
                                                                             OBSERVER AFFILIATION	
                                                                             POINT OF EMISSIONS	
                                                                             HEIGKT OP DISCHARGE POINT
H
H
H
 I
-J
VO
CLOCK TIME
OBSERVER LOCATION
  Distance to Discharge
  "Direction from Discharge
  Height of Observation Point
BACKGROUND DESCRIPTION
HEATHER CONDITIONS
  Wind Direction
  Wind Speed
    •
  Ambient Temperature
SKY CONDITIONS (clear.
  overcast* X clouds, etc.) .
PLUME DESCRIPTION
  Color
  Distance Visible
 OTIIW IHFORMTIOtl
                              Initial
Final
SUMMARY OF AVERAGE OPACITY
Set
Number









•' -
Tiny.
Start—End










Opaclti • .
Sum










Average










                                                                                          Readings ranged from	to _	I opacity
                                                                                          The source was/was not 1n compliance with
                                                                                          the time evaluation was made.

-------
                    FIGURE 9-2  OBSERVATION RECORD
                   PAGE
.OF
     COMPANY
     LOCATION
     TEST NUMBtTT
     MTE	
OBSERVER 	
TYPE FAClLITV
POINT OF EMISSTJHT
H
H
H
 I
00
o
Mr.














.















Mln.
0
1
2
3
4
5
6
7
8
9
10
1*
12
13
' 4
'5
16
17
18
19
20
21
22
23
24
25
26
27
28
29

0






























Seconds
15






























JO






























*b






























STEAM PLUME
(check If applicable)
Attached"






























Detached































COMMENTS






























FIGURE 9-2 C
(Cor
COMPANY
LOCATION" "
TEST
DATE
Hr.































NUMBER



Mln.
in
31
32
33
34
35
36
' 3?
38
39
40
41
42
43
44
45
46
47
48
49
50
M
52
S3
54
55
'S6
... ^
68
59

Seconds
IT































lb






























30






























in
45






























(eli
At






























3DOC.74
OBSERVATION RECORD
PAGE	OF _
                                               OBSERVER	
                                               TYPE FACILITY
                                               POINT OF EMISSTCHT

-------
 Method 20— IJelerminaliiin nl
 Oxides, Sulfur Dioxide, and Oxygen
 Emissions from Stationary' Gas Turbines
 1. Applicability ani
   1.1  Applicability. This method is
 Hpplicable for the determination of nitrogen
 oxides (NO,), sulfur dioxide (SOj). and
 oxygen (O,) emissions from stationary gas
 turbines. For the NO, and Oi 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
 OO, determination, a separate measurement
 of SO» emissions is made, using Method 6, or
 it equivalent. The O, determination is used to
 adjust the NO. and SOt  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 the following major
 subsystems:
   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 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   O, Analyzer. That portion of the
 system that senses O> and generates an
 output proportional to the gas concentration.
  2.2 Span Value. The upper limit  of a gas
 concentration measurement range  that is
specified for affected sourc« categories in the
applicable part of the regulations.
SIM N

•Vf.ll
      I /.I IIMIA f ION
   2.3  Calibration Gas. A known
 conoMilrjtion of a gas in an appropriate
 diluent gas.
   2.4  Calibration Krrur. The differenci.1
 Iwtwern the gas concentration indicated by
 tin measurement system and the known
 concentration of the calibration gas.
   2.S  Zero Drift. The difference In the
 measurement system output rending!) before
 unit alter n stati.'d period of operation during
 which no unscheduled maintenance, repair.
 or adjustment took place and the input
 concentration at the time of the
 mtdsurements was ZIMO.
   2.8  Calibration Drift. The difference in llio
 measurement system output readings before
 end after a slated 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
 reached the analyzer inlet.
   2.0  Response Time. The amount of time
 required for the continuous monitoring
 system to display on the data output 05
 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. I-ess 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 spun vnlue.

4. Apparatus and Reagents
  4.1  Measurement System. Use any
measurement system for NO, and O, that is
expected to meet the specifications in this
method. A schematic of an acceptable
measurement system is shown in Figure 20-1.
Th« exsential components of the
measurement system are described below:
                                                                   NlllllllilN
                                                                    OX II ll %
                                                                   HUM V/l II
           t/l-L, ,„«., 1-1 j;;~' L-l     ,« I/UM>!	1 L
                   rrzT  L_'~L.n.	r
               CALIBRATION
                   GAS
                                                   SAMPLE OAS
                                                    MANIFOLD
             Figure 20-1.  Measurement system design tot stalmnaty gas turbines.
                                                                          EXCESS
                                                                      SAMPLE TO VENT
   4.1.1  Sample Probe. Heated Kluinlcss
 Htr-el. or equivalent, opun-endnd. straight tube
 of sufficient length to traverse lliu sample
 points.
   4.1.2  Sample Lino. Heated (>fl.S'C)
 Hlulnless steel or Teflon •» bing to transport
 the sample gas to the sample conditioners
 and analyzers.
   4.1.3  Calibration Valvo Aiiscmhly. A
 lliree-wiiy valve aHScmhly io direct tin icro
 anil calibration gases to the sample
 conditioners and to the iin.ilyzns. The
 calibration valve assembly r.hall he i:;ipiible
 of blocking the sample f,a« flow and of
 introducing calibration gases to the
 measurement system when in Ihi: calibration
 mode.
   4.1.4   NO, to NO Conv«rl( r. Tliat portion
 of the system that converts the nitrogen
 dioxide (NO,) in the sample ijan to nitrogen
 oxide (NO). Some analyzers are designed to
 measure NO, as NO, 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 addition, an NO, to
 NO converter is not necessai y if the NO,
 portion of the exhaust gas ib less than S
 percent of the total NO, concentration. As a
 guideline, an NO, to NO converter is not
 necessary if the gun turbine is operated at 90
 percent or more of peak loaH capacity. A
 converter is necessary undtv lower load
 conditions.
   4.1.5  Moisture Removal Trap. A
 refrigerator-type condenser designed  to
 continuously remove condciisiiti; from the
 sample gas. The moisture ri mcviil Imp is not
 necessary for analyzers Ihul cun men sure
 NO. concentrations on a we! basis: for these
 analyzers, (a) heal the nample line up to the
 inlet of the analyzers, (b) determine the
 moisture content using methods subject to tht
 approval of the Administrator, mid (c) correct
 the NO. and O, concentrations to a dry basis
   4.1.6  Particulale Filter. An in-stack or an
 out-of-stack glass fiber filter, of the type
 specified in EPA Referent''; Method 5:
 however, an out-of-Htack liller is
 recommended when the stuck cas
 temperature exceeds 250 to 300'C.
   4.1.7  Sample Pump. A nonreaclive leak-
 free sample pump to pull the sample gas
 through the system at a flow rate sufficient Ic
 minimize transport delay. The pump shall be
 made from stainless steel or coated with
 Teflon or equivalent.
  4.1.8  Sample Gas Mnnifold A sample gas
manifold to divert portions of the tmmple gna
a I run m to tha an*ly/.«m The multifold  inny be
connlniclrd of glnHH, THIon. lyjut 315
nlnllilftftn nlfinl. or nnilvulflnt.
  4.1.0  <>xyK«!M mid Aimlyzi-r. An uiinlyxnr
to dnlerniine Ilia pprc«;ni O, concentration of
the fmmple gat slrnam.
  4.1.10  Nitrogen Oxides Analyznr. An
anulyzer to determine the ppm NO,    \
concnntrHtlon In the sample gut stream.'
  4.1.11   Data Output. A strip-churl recorder.
analog computer, or digital recorder for i
recording measurement data.
  4.2  Sulfur Dioxide Analysis. F.PA
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.
                                                              111-81

-------
in N.-. For NO. measurement analyzers lhat
require oxidation of NO to NO». the
calibration gases must be in the form of NO
in N;. Uut; four calibration gas mixtures us
specified below:
 . 4.3.1  High-level Gas. A gas concentration
that is equivalent to 80 to 90 percent of the
span value.
 i 4.X2  Mid-level Gas. A gas concentration
truit is equivalent to 45 to 55 percent of the
span value.
  4.3.3  Low-level Gas. A gas concentration
that is equivalent to 20 to 30 percent of the
span wilue.
  4.3.4  Zero Gas. A gas concentration of
less than (1.25 percent of the span value.
Ambient ;iir may be used for the NO, zero
gas.
  4.4   O> Calibration Gases. Use ambient air
:it 20.9 percent as the high-level Ot gas. Use a
gas concentration that is equivalent to 11-14
percent O, for the mid-level gas. Use purified
nitrogen for the zero gas.
  4.5   NO>/NO Gns Mixture. For
(li.'tennining the  conversion efficiency of the
NO, to NO r. inverter, use a calibration gns
mixture of NO, and NO in N«. The mixture
\v.';i !;t; ;..-umu i:»,ic<;Mlralions of 40 tu htl ppm
NO, ami 510 to ill) ppm NO and certified dy
the gii.-j manufacturer. This certification of gas
r.om.fMilra'ion must include a brief
description nf the procedure followed in
            the  concentrations.
5. Mfa-nin-ini.'i:! Syateni Porfarmuncc Tost
f'l(>i:i'i!uri'ii
  Perform HIM following procedures prior to
meHSun:nit!iil of umitfHions (Section 0) and
only oni.fc lot each text program, i.e., the
serins of nil t.Ml rnriH for n given gun turbintt
Oligine.
  5.1  Calibration Gas Checks. There are
two allttrnHtiviif) fur checking the
conci.Titrnrions of the calibration gases, (a)
The firHl U to use calibration gases that are
documented Iruccable to National Bureau of
Standards Reference Materials. Use
Tractiability Protocol for Establishing True
Concentrations of Gases Used fur
Calibrations and Audits nf Continuous
Source Emission Monitors (Protocol Number
1} that is available from the Environmental
Monitoring and Support Laboratory. Quality
Assurance Branch, Mail Drop 77.
Environmental Protection Agency, Research
Triangle Park. North Carolina 27711. Obtain n
certification from the gas manufacturer that
the protocol was followed. These calibration
gases an; not to be analyzed with the
Reference Methods, (b) The second
alternative is to use calibration gases not
prepared according to the protocol. If this
alternative is chosen, within 1 month prior to
the emission test, analyze each of the
calibration gas  mixtures in triplicate using
Reference Method 7 or the procedure outlined
in Citation 8.1 for NO, and use Reference
Method 3 for O,. Record the results on a data
sheet (example is shown in Figure 20-2). For
the low-level, mid-level, or high-level gas
mixtures, each of the individual NO,
analytical results must be within 10 percent
(or 10 ppm. whichever is greater) of the
triplicate set average (Oi tost results must be
within 0..1 jn.Tuinl O3): otherwise, discard the
entire si.-t  gas of
the calibration gas manufacturer's tag value.
use the  tag value: otherwise, conduct at least
three ndditinnal reference method Ic.st
analyses until the results of six individual
NO. runs (Ihe three original plus three
additional) agree within 10 percent (or 10
ppm, whichever is greater) of the average (Ot
test results must be within 0.5 percent O,)
Then use  this average for the cylinder value.
  S.2 Measurement System Preparation.
Prior to Ihe emission lest, assemble Ihe
measurement system following the
manufacturer's  written instructions in
preparing find operating the NO, to NO
converter, Ihe NO, analyzer, the O» analyzer.
and other components.
   Date	(Must be within 1 month prior to the test period)
   Reference method used.
Sample run
1
2
3
Avei.iuK
Maximum % deviation1'
Gas concentration, ppm
Low level3





Mid levelb





High Ieve1c





8 Average must be 20 to 30% of span value.

° Average must be 45 to 55% of span value.

c Average must be 80 to 90% of span value.
d Must be Js ± 10% of applicable average Of 10 ppm,
  whichever is greater.

              Figure 20-2. Analysis of calibration gases.
                                                         111-82

-------
   5.3  Calihiation Check. Conduct the
 calibration checks for both the NO, and the
 O, annhvers as follows:
   5.3.1  After the measurement system has
 been prepared for use (Section 5.2). introduce
 7«ro gasps end the mid-level calibration
 gases; get the analyzer output responses to
 the appropriate le\-els. Then introduce each
 of Ihi? remainder of the calibration gases
 described in Sections 4.3 or 4.4. one at 8 time.
 to the measurement system. Record the
 responses on a form similar to Figure 20-3.
   5.3.2 If the linear curve determined from
 the zt-ro and mid-level calibration gas
 responses dot's not predict the arliul
 response of the low-level (nut applicable for
 tin? Oj analyzer) and high-level Rases 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 the
 gaseous components listed in Table 2(M into
 the measurement system separately, or as gus
 mixtures. Determine the total interference
 output response of the system to these
 components in concentration units; record the
 values on a form similar to Figure 2O-4. If the
 sum of the interference responses of the test
       gases for either the NO. or O, analy/crs is
       greater than 2 percent of (he applicable sp;in
       value, tnke corrective measure on the
       measurement system.
        TaMe 20-1.—Interference Test Gas Concentration

       CO..	  500-W) ppm.
       SO,		  ?00,-.?0 ppm.
       CO,				  10 •; 1 percent
       O.	_	  n.S • 1
  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 tiie
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 test gases of Table
20-1 the interference performance
       specification is not 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
                                                           111-83

-------
 calibration valve until all readings arc; stable;
 tl:nn. switch to monitor tin; stack effluent
 i.ntil a stable miiding ran be obtained.
 Kccord the upscale response lime. Nex.t.
 introduce high-level calibration }$as into (hi:
 system. Once |he system lias stabilized nt the
 hij'.h level concentration, switch to monitor
 Itif stuck effluent and wait uctil a stable
 value 13 rcuchfcd. Record the duwnscale
 response time.  Repeat the procedure three
 times. A stable value is equivalent to a
                change nf less than 1 percent of span value
                for 'JO seconds or less than 5 percent of the
                measured average concentration for 2
                minutes. Record lh« response time diita on a
                lorm similar to Figure 20-5, the readings of
                Ihr upscale or downscale reponse time, nnd
                rejxirt tli» (jreuter lime us the "response time"
                for thi: analyzer. Conduct a response time
                test prior to the initial field use of the
                measurement system, and repeat if changes
                ore madi: in the measurement system.
   Date of test.
   Analyzer type.
   Span gas concentration.

   Analyzer span setting	
   Upscale
1.

2

3.
.     S/N.

-Ppm

. ppm

.seconds

.seconds

.seconds
          Average upscale response.

                             1	

   Downscale            2	

                            3	
                                .seconds
                       .seconds

                       .seconds

                       . seconds
         Average tlovvnscale response.
                                .seconds
   System response time = slower average time =.
                                         .seconds.
                         Figure 20-5.    Response time
  5.0  NO, NO Conversion r.ff-.ciency.
Introduce !<> 'hi- «;y:h:Mi. al llie calibration
valve assembly, the NO=/NO fj.is mixture
(Section 4.5). Kecord Ihr response of the NO,
an::l\ •  -  rf ' th:' instrument ie-uioiise indicates
l'j:;s l.i.iii "n'i p :'c ei'-t NO- !•.> NM converse.!!!.
make cuiTi'cIinns  to the raiNisurement system
arid repeat tho check. Alteni;,!ively. the NO,
to NO converter rhcck described in Title 40
J'.irt CO: Ccr!:f:cc::i:::i anil Trat Pror.ffdurun fur
Hiiavy-Uaty Engines fur J'J7,iJ and Later
Model Years may be used. Other alternate
procedures may be used with approval of the
Administrator.
                6. Eminsion. Measurement Test Procedure

                  6.1   1'reliminaries.
                  6.1.1  Selection of a Sampl:ng Site. Select a
                samplr;;: sire as close os practical Ki i!:e
                exhaust of the turbine. Turbine geometry,
                stack cuili^uration. internul liciffling. ar.d
                point of introduction of dilution air will vary
                f'.ir difterent 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 sir into
the duct. Sample purls may be located before
or after the upturn elbow, in order to
accommodate the r.ofifi^unilion of the turning
vune.H nnd liatTles imd to permil a compMn,
unobstructed traverse of the stuck. The
sample  ports shall not be located within 5
feet or 2 diameters (whichever is less) of the
gas discharge to atmosphere. For
supplementary-iircd, combined-cycle plants.
the sampling site shall be located between
the gas  turbine and the boiler. The diameter
of the sample ports shall be sufficient to
allow entry of the sample probe".
  6.1.2  A preliminary O, traverse is made
for the purpose of selecting low O> 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 m3(l6.1 ft5): (2) one sample point
for each 0.2 m'tZ^ ft1 of areas, for stacks of
1.5 m' to 10.0 m1 (16.1-107.6 ft''1) in cross-
sectional ;tre:i: and (3) one snmple point for
each 0.4 m- (4.4 ft-1) of area, for slacks greater
than 10.0 m J (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 oil 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 O1
sampling has been determined, use Method 1
to located the traverse points.
  6.1.2.3 Preliminary O2 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 first 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 O1 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 O1 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 di.-sired.

     Table 20-2.—Cross-sectional Layout lor
             FlacMngutar Slacks
                                    No. 01 uavetse f.
                                        9	
                                       12
                                       15	.._
                                       ?0	_
                                       2S.._
                                       30	
                                       36	
                                       42....
                                     3.3
                                     « • 3
                                     4x4
                                     S>4
                                     b<5
                                     6<5
                                     6x8
                                     7«S
                                     7x7
                                                            111-84

-------
   Location:

        Pljnt
                 Date.
        City, State.
   Turbine identrtication:

        Manufacturer	
        Model, serial number.

           Sample point
Oxygen concentration, ppm
               Figure 20-6.  Preliminary oxygen traverse.
  C.2  NO, and Oi Measurement. This lest is
to In; conducted at ench of the specified load
conditions. Three test runs at each load
condition constitute a complete test.
  6.2.1  At the beginning of each NO. test
run und. as applicable, during the run. record
turbine dxta as indicated in Figure 20-7. Also.
record the location and number of the
traverse points on a diagram.
BILLING CODE 6S60-01-M
    6.2.2  Position the probe at the first point
  determined in the preceding section and
  begin sampling. The minimum sampling time
  at each point shall be at least 1 minute plus
  the averse system response time. Determine
  the averapr; steady-slate concentration of O»
  end NO, at each point and record the data on
  Figure 2O-8.
                                                          111-85

-------
 Test operator	
        t
 Turbine identification:
     Ty fie	
     Serial IMo	
 Location:
     Plant	
     City	
                TURBINE OPERATION RECORD

                	  Da»e_	
                                    Ultimate fuel
                                     Analysis  C
                                              H
                                              O
                                              N
 Ambient temperature.

 Ambient humidity	

 Test time start	
                                              Ash
                                              H2O
                                    Trace Metals
                                             Na
 Test time finish	

 Fuel flow ntoa	
                                             Va
                                              K
 Water or ste.im	
     Flow rai«a
                                             ntc'J
                                    Operating load.
 Ambient Pressure,
 aDescribe measurement method, i.e., continuous flow meter.
  Start finish volumes. «tc.

 bi.e.. additional t-lemfcnts added for smoke suppression.
                                                    instrument type.
                                                      Serial No	
                                                NOX instrument type.
                                                      Serial No	
             FKjure 20-7.  Stationary gas turbine.data.
                                                  \
Turbine identification:                             Test operator name

  Manufacturer	

  Model, serial No	

Location:

  Plant	

  City. State	

Ambient temperature

Ambient pr«sMiie	

Date	

Test time start	

Test time - finish	
Sample
point





Time,
min.





02-
%





NO;.
ppm





                                                 aAverage steady-state value from recorder or
                                                  instrument readout.
                     Figure 20-8.  Stationary gas turbine sample point record.
BILLING CODE 6iSO-OI-C
                                                   HI-86

-------
  0.2.3   After sampling the last point.
conclude the test run by recording the final
turbine operating parameters and by
determining the zero and calibration drift, as
follows:
  Immediately following the test run at each
lo.id condition, or if adjustments are
necessary for the measurement system  during
llir tests, reintroduce the zero and mid-level
c;ilib:..!:ongdses as described in Sections 4.3.
am! 4.4. ore at n time, to  tlie measurement
syslirr. at the calibration valve usfcmHy.
(Make no adjustments to the measurement
system until after the drift checks are madej.
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 eyttem. Alternatively, the test
results  may be accepted provided the
measurement system is recalibrated and the
calibration data thai result in the highest
corrected emission rale are used.
  6.3  SOa Measurement This test is
conducted only at the 100 percent peak load
condition. Determine SOf using Method 6. or
equivalent, during the test. 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 10minutes. Average the O>
readings taken during the NO, test runs at
sample  points corresponding to the SO>
traverse points (see Section 6.2.2) and use
this average O, concentration to correct the
integrated SO, concentration obtained by
Method 0 to IS percent O, (see Equation 20-
1).
  If the applicable regulation allows fuel
sampling and analysis for fuel sulfur content
to demonstrate compliance with sulfur
emission unit, emission sampling with
Reference MtJiodeis not required, provided
 the fuel sulfur content meets the limits of the
 regulation.

 7. E:nissiou Calculations
   7.1  Correction to 15 Percent Oxygen.
 Using Equation 20-1. calculate the NO, and
 SOj concentrations (adjusted to 15 percent
 O:). The correction  to 15 percent Ot is
 ser.sitivi: to the accuracy of the O>
 nit'.isiiri'nicnl. At the level of mi;ily::cr drift
 specified in the method (±2  percent of full
 seal'-), the ch.mgi' in the O; conLcntriitinn
 correction can exceed 10 percent when ihe O,
 content of the exhaust is above 10 percent O,.
 Therefore O, analyzer stability and careful
 calibration are necessary.
                  5.!.
                   -
(fquatIon 20-1)
Where:
  C. percent O> (ppin)
  Cn,,«,= Pollutant concentration measured.
    dry basis !ppm)
  5.9=20.9 percent O.-15 percent O,. the
    defined Oa 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.

A 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
197B.
|FR Doc. 79-27M3 Filed 9-7-78; 845 urn)
WLLINO CODE 6560-01-M
                                                             111-87

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           B—PoroKMANcr SPECIFICATIONS

  Performance Specification  1—Performance
apecincatloi.s  and  specification  Vest proce-
dures for transmLssometer systems for con-
Unuous meuurfTnent of the opacity of
•tack emissions .
  1.  Principle and Applicability.
  I.I Principle  The  opacity 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 B
direct  measurement  of the attenuation cf
visible  radiation  (opacity)  by  paniculate
matter  In a stack effluent. Light  having spe-
cie  spectral characteristics Is 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 partlcul&te
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 tbe visible  light  will have a  tranamlttance
of 0 or  an opacity of 100 percent. The trane-
ml£someter Is evaluated by use of  neutral
density niters vo determine  the  precisian of
the  continuous monitoring  system. Tests of
the  system  are performed to determine aero
drift, calibration  drift. sJid  response  time
characteristics of the system.
   1.2 Applicability. This  performance  spe-
cification  Is  applicable to  the  continuous
monitoring systems speclSed In the subparts
tor  measuring opacity cf  emissions.  Specifi-
cations for  continuous measurement of vis-
ible emissions are elven In terms  of design.
performance,   and   Installation  parameters
These specifications contain vest procedures.
Installation requirements, and data compu-
tation procedures for evaluating the accept-
ability of the continuous monitoring systems
subject to approval by tbe Administrator.
   2. Apparatus
   2.1  Calibrated Filters. Optical niters with
neutral spectrsJ characteristics  and known
optical  densities to risible  light or screens
known  to produce specified optical densities.
Calibrated filters with accuracies certified by
the  manufacturer  to  within  i3  percent
opacity shii! be used  Filters required are
low, mid, and hlp,h-range filters with nom-
inal optical densities  as  follows  when the
transmlssometer Is tptnned  at opacity levels
specified by applicable subparts:
    Bptn valuf
 (percent opacity)
Calibrated 01!*- optical densities
  with equlTnleni opscltr In
        ptrrnthesis

 Low-      Mid-  .   Hlch-
 ranre     range     ranpf
&0...
W...
TO...
to...
W...
100..
                   o.
     (20)
     (20)
     (20)
     (20)
     (20)
  .1 (20)
o.i (37)  as )
 .2 '87)  .» (.SO)
 .8 «*)  !e CM
        .7 (SO.
        .» (67y,>
.4 (60)
-4 (60)
  It is recommended that filter calibrations
be checked with a wrll-colllm&ted  photoplc
transmlssometer of known linearity prior to
use. The filters shall  be of sufficient clze
to attenuate  the entire  light  beam of the
transmlssometer.
  12 Data  Recorder. Analog chart recorder
or other suitable device  with Input voltage
range compatible with tbe analyzer system
output.  The  resolution  of  the  recorder's
data output shall be sufficient to allou- com-
pletion  of the  test procedures -within this
specification.
  2.3 Opacity measurement System. An In-
rtack  transmlssometer  (folded or  single
path) with the optical design specifications
                 designated balow. associated  control  units
                 and apparatus to keep optical surfaces clean.
                   3. Definitions.
                   3.1  Continuous Monitoring  System. The
                 total equipment required for the determlnfc-
                 Uon of pollutant opacity In s source effluent
                 Continuous monitoring  systems consist  of
                 major subsystems as follows:
                   3.1.1  Sampllnc Interlace. The portion of a
                 continuous  monitoring system for opacity
                 that protects tbe analyzer  from the effluent.
                   3.15 Analyzer  That portion ol  the  con-
                 tinuous monitoring system which senses the
                 pollutant and generates a signal output tbav
                 Is a function of tbe pollutant opacity.
                   3.13 Data  Recorder. That portion o' the
                 continuous monltorinp system that processes
                 tbe analyzer output  and provides  a nmm-
                 nent record of  tne output signal In terms of
                 pollutant opacity.
                   3.2  Transmlsscrmeter.  The  portions  of  £
                 continuous  monitoring system lor opacity
                 that Include the sampling  interface and the
                 analyzer.
                   33  Span. The value of  opacity  at which
                 the continuous monitoring system Is set to
                 produce the  maximum data  display output.
                 Tbe span shall be set at  an opacity specified
                 In each applicable subpart.
                   3.4  Calibration Error.  Tbe  difference be-
                 tween  tbe opacity reading Indicated by the
                 continuous  monitoring  system   and  the
                 known values of a veries of tert standards
                 For this  method tbe test standards are a
                 aeries of calibrated optical filters or screens.
                   3.5  Zero DrUt. The change In continuous
                 monitoring system  output over a stated pe-
                 riod of time  of normal continuous  operation
                 when  tbe pollutant concentration at the
                 ttme of tbe measurement* Is aero.
                   S.«  Calibration Drift. Tne 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 Ls  the same
                 known upscale value.
                   3.7  System Response.  The  time Interval
                 from  a step  change In opacity In the stack
                 at the Input to  the continuous monitoring
                 system to the  time at which 95 percent of
                 tbe corresponding final value  U reached  as
                 displayed on ohe continuous monitoring sys-
                 tem data recorder.
                   3.8 Operational Test  Period. A minimum
                 pertod of time  over which  a continuous
                 monitoring system  Is expected  to operate
                 within certain  performance  specifications
                 without   unscheduled maintenance, repair.
                 or adjustment.
                   3.9 Transmlttance Tbe fraction of Incident
                 light  that l> 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)
                 are related as'follows:
 . 3.11  Optical Density.  A logarithmic meas-
ure of the amount of light that It attenuated
by  an optical  medium of Interest. Optical
density (D) Is related to the tranamlttance
and  opacity as follows:
  D=-log10T
  D=-log,. (1-0)
  8.12  Peak . Optical  Response. The  wave-
tongth of maximum sensitivity of the Instru-
ment.
  8.13  Mean Spectral  Response. The wave-
length which bisects the  total area under
the  curve  obtained  pursuant  to paragraph
t.2.1
  8.14  Angle of View. The maximum (total)
angle of radiation  detection by the photo-
detector assembly of the analyzer.
  8.16  Angle of  Projection.  The maximum
(total)  angle that contains 95 percent of
tbe radiation projected from tbe lamp assem-
bly of the analyser.


                   111-88
  8.16 Pathlength  The depth of •fluent In
Ote light beam between the receiver and the
transmitter of tbe single-pass transmlssom-
9t*r, or the depth of effluent between the
transceiver  awl  reflector  of a double-pass
transmlssometer. Two pathlengths  are refer-
enced by this specification:
  8.18.1  Monitor Pathlength. The  depth of
effluent  at the Installed location of tbe con-
tinuous monitoring system.
  3.165 Emission  Outlet  Pathlerugth.  The
depth of effluent at the location emissions are
released to the atmosphere
  4. Installation Specification.
  4.1 Location  The transmlssometer  must
be located  acroos  a section of duct or  stack
that will provide a paniculate matter flow
through  the optical  volume  of the  trans-
missometer that Is representative of the par-
tlculate matter  flow  through  the duct or
•tack. It Is  recommended  that the monitor
pathlength or depth of effluent for the trans-
mlssometer  include the entire diameter of
the duct or stack. In Installations using a
shorter  pathlength. extra caution must be
used In determining the measurement loca-
tion representative of tbe paniculate matter
flow through tbe duct or stack.
  4.1.1 Tbe  transmlseometer  location  shall
be downstream from  all  paniculate control
equipment.
  4.1.2 The  transmlsaometer shall be located
OLE far from bends and obstructions as prac-
tical.
  4.1.3  A  transmlssometer  that Is  located
In the duct or stock  following a bend shall
be  Installed In the  plane  defined  by the
bend  where possible
  4.1.4  The truitmluaometer should be In-
stalled In an accessible location.
  4.1.5 When required by tbe Administrator.
tbe  owner  or  operator  of  a  source  must
demonstrate that tbe tranamlsaometer tc lo-
cated In a  aectlon of duct  or stack where
a representative paniculate matter distribu-
tion exists  The determination shall  be ac-
complished by examining  tbe opacity profile
of the effluent at a series  of  positions across
tbe duct or stack while the plant Is In oper-
ation at maximum or reduced operating rates
or by other tests, acceptable to tbe Adminis-
trator  .
  42 Slotted Tube. Installations that require
the use 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 tbe entire optical  volume  of  the
transmlsaometer  or  reflect  light Into  the
 transmlscometer  photodetector.  Light  re-
flections may be prevented by using black-
ened  baffles within the slotted tube to pre-
vent tbe lamp radiation from Impinging upon
the tube walls, by restricting tbe angle or
projection of the light and the angle of view
of the photodetector assembly to less than
tbe cross-sectional area of tbe 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
oystems using slotted tubes.
  4.3 Data Recorder Output. The continuous
monitoring system output shall permit ex-
panded display of the span opacity on  a
standard  0 to 100 percent  scale. Since all
opacity standards are baaed on the opacity
of the effluent exhausted to the atmosphere.
the system output shall be  based upon the
emission outlet pathlength and permanently
recorded. For affected facilities whose moni-
tor pathlength Is different from tbe facility's
emission outlet pathlength. a graph shall be
provided with tbe Installation.to show the
relationships between the continuous moni-
toring system recorded opacity based upon
the emission outlet pathlength and tbe opac-
ity of'the effluent at tbe  analyzer location
.(monitor pathlength.). Tests for measure-
ment of opacity thai are required  by this
performance specification are based upon tbe

-------
monitor pathlengtb. The graph necessary to
convert the  data  recorder output so  the
SBOBltor pathlength -bans snail be MtakUahed
•a follows:

  tec (1-0.) «"(U/i.> tat 
-------
             Values for t.975
n
J 	
a
4 . .
5
e 	
7 	
e
t

-.875
1! 7W'
4.3TO
». is:
2 776
2. 571
5.447
2.S&S
2.SOO

n
10 	
II 	
IS 	
13 	
U 	
15 	 	
16 	


«.«7S
z. ye
2.278
5. 201
2. >7«
2. 160
2 141
2.JS1


  93 Data Analysis and Reporting.
  9.2.1  Bpeetrml   Response.  Combine  the
spectral data  obtained In accordance with
paragraph 8.3.1 to develop the effective spec-
tral response curve of the transmlssometer.
Report  the  wavelength at which the peak
response occurs, the wavelength at which the
mean response occurs, and  the maximum
response at any  wavelength  below 400 nm
aud above 700 nm expressed as a percentage
Date of Test
     of the peak response ac required under para-
     graph 6.2.
      B.2.2 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 in tbe  horizontal  and vertical
     directions   (26 centimeters  of  arc with  a
     radius of 3 meters equal 6 degrees). Report
     relative angle of  view curves as required un-
     der paragraph 6.2.
      8.2.3 Angle of  Projection. Using  tbe  data
     obtained In accordance  with paragraph 6.3.3.
     calculate the response  of the photoelectric
     detector as a Junction of projection angle in
     tbe horizontal and vertical directions. Report
     relative angle of projection curves ac required
     under paragraph  6.2.
      8.2.4 Calibration Error. Using the data from
     paragraph  B.I  (Figure  1-1). subtract  the
     known filter opacity  value from  the va'ue
     shown by tbe measurement system for each
     of tbe'15 readings. Calculate  the mean and
     85 percent confidence  Interval of tbe five dif-
     ferent values at each test filter value accord-
Low
Range  	i opacity
Span Value 	X  opacity
                                  Hid
                                  Range  	X opacity
                        High
                        Range 	X opacity
 Location of Test
           Calibrated Filter
                              1
Analyzer Reading
   X Opacity
                                                              Differences
                                                               X Opacity
  2_

  3_

  4_

  5_

  6_

  T_

  8_

  2_

 10

 n
 14
 15
 Mean difference

 Confidence Interval


 Calibration error  »  Mean Difference  * C.I.
                                                          Low      Hid
                                    High
  Low. mid or high  range
 ^Calibration filter  opacity - analyzer reading
  Absolute value
                   Figure 1-1.  Cal'tratlor. Error Test
                                                                                    Ing to equations <-.	     «vejjurt me sum
                                                                                    of tbe absolute mean difference and  the  95
                                                                                    percent confidence Interval for each  of tbe
                                                                                   'three test filters.
                                                                                           MM 9t |MI_

                                                                                           **•• rnt*r	

                                                                                           JbMl/ttr ifM

                                                                                           •«•«
  8.2.6  Zero Drift  Using  the cero opacity
 values measured every  24  hours  during the
 field test (paragraph 62).  calculate the de-
 ferences between the zero  point after clean-
 ing. aligning, and adjustment, and the zero
 value 24 hours  later Just  prior to  cleaning.
 aligning.  and   adjustment.   Calculate  the
 mean value  of  these points  B J tbe confi-
 dence Interval using equations 1-1 end 1-2
 Report  tbe sum of the  absoluu mean value
 and the 95 percent confidence Interval.
  9.2.6  Calibration Drift.  Using  the  spa:,
 value measured every  24 hours during the
 field test, calculate the differences betweer.
 the span value after cleaning, aligning, and
 adjustment of zero and span, and  tbe  spcn
 value 24 hours later  Just  after  clearJr.g
 aligning, and adjustment of zero and before
 adjustment  of  span.  Calculate  tbe  mecn
 value of  these  points  and  tbe  conf.der.ro
 Interval using equations 1-1 and 1-2. Report
 the sum of the absolute mean value and the
 confidence Interval.
  8.2.7 Response Time.  Using  the data from
 paragraph  8.1. calculate the  time interval
 from filter Intertlon to 85 percent of the fir.al
 stable value for all upscale  and downscale
 traverses. Report tbe mean of tbe 10 upscale
 and downscale test times.
  8.2.8 Operational Ts*t Period. During the
 168-hour operational  test  period, tbe  con-
 tinuous monitoring system (ball not require
 any corrective maintenance, repair, replace-
 ment, or adjustment other than that clearer
 specified as  required In tbe manufacturer's
 operation end maintenance manuals as rou-
 tine and expected during a one-week period.
 If the continuous monitoring system U oper-
 ated within  the specified  performance pa-
 rameters and doe;  not require  corrective
 maintenance, repair, replacement, or adjust-
 ment other  than as specified above during
 tbe  168-hour test period, the operational
 test period shall have been successfully con-
 cluded  Failure  of the continuous monitor-
 ing system to meet these requirements shall
call  for  a  repetition  of the  168-hour test
 period. Pontons  of the testa which were sat-
 isfactorily completed need  not be repeated.
 Failure  to meet any performance specifica-
tion (s)  shall call for  a repetition of the
 one-week  oneratlonal test  period and  that
specific  portion  of .the tests required bv
paragraph 6  related to  demonstrating com-
pliance  with  the failed  specification.  All
maintenance and adjustments required shall
be recorded.  Output readings shall be re-
corded before and after all adjustments.
                                                  10.1 "Btoerunental Statistics." Department
                                                of Commerce. National Bureau of Standards
                                                Handbook PI. 1863.  pp. 8-31. paragraphs

                                                  10.2 "Performance Specifications  for Sta-
                                                tionary-Source Monitoring Systems for Oases
                                                and Visible Emissions." Environmental Pro-
                                                tection  Agency.  Research  Triangle Park.
                                                N.C., EFA-650/2-74-018. January 1074.
                                                                 111-90

-------
   Ttro Stttlftj

   Son Uttln*
                                                   of
   CUtc
  I«r»
(ttfor«
**4 tdjvtucnt)
                           Itre Drift
                             \tltn)
(»ftrr clwln? ind lero ttjulUirnt
   hut teforc ipm idjutuvnt)
Ciltbrtllon
  Drift
 (*S»e  difference between the paired
                                   concentration measurement*  expressed as a
                                   percentage of tbe  mean  reference value.
    1.4 Calibration Crror. Tbe  difference  be-
  tween  the pollutant  concentration  Indi-
  cated by the continuous monitoring system
  and the known  concentration  of  the test
  fee mixture.
    S.6 Zero Drift. The change in the continu-
  ous monitoring system  output over a stated
  period of time of normal continuous opera-
  tion when tbe  pollutant  concentration  al
  tbe time for tbe measurements Is zero
    8.8 Calibration Drift. Tbe change In  the
  continuous monitoring system output over
  a Mated tune period of normal continuous
  operations when the  pollutant  concentra-
  tion at  the time of the  measurements Is the
  Mme known upscale value.
    87 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 95 per-
  cent of the   corresponding  final  value  Is
  reached  as displayed  on  tbe  continuous
  monitoring system data  recorder.
    8.8 Operational Period. A minimum period
  of tune over  which a measurement system
  Is 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 tbe average concentration  in the due:
  or stack and the concentration at any point
  more than 1.0  meter from the  duct or stack
  wall.
   «. Installation   Specifications   Pollutant
  continuous monitoring  systems  (SO,  and
  NO.) shall be  Installed  at a sampling  loca-
  tion where measurements can 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
  •hall be accomplished as follows:
   4.1 Effluent  gases may be assumed to  be
  nonstratlfled 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 4.3.1 may  not
  be applied to sampling  locations upstream
  of an air prebeater in a (team  generating
  facllltv  under Subpart D of this part. For
  •ampllng locations where affluent gases are
 either demonstrated  (45)  or  may be  as-
  sumed to be nonstratlfled (eight diameters).
  a point (extractive systems)  or path  (In-situ
 systems) of average concentration  may be
  monitored.
   4.3  For sampling locations where  effluent
 fates cannot be assumed to be  nonstratl-
 fled (leas than eight diameters)  or have been
 ahown under paragraph  44  to  be stratified.
 results obtained must be consistently repre-
 sentative (e.g. a point of average  concentra-
 tion  may shirt with  load changes)  or tbe
 data  generated  by sampling at  a  point (ex-
 tractive systems)  or across  a path (In-situ
 systems)  must be corrected (4.2.1  and 4.2.2)
 ao as to be representative of the total emls-
 rtons  from the affected  facility.  Conform-
 ance  with this requirement  may  be  accom-
 plished In either of the following ways:
  4.2.1 Installation of a  diluent continuous
 monitoring system  (O. or CO. as applicable)
 In  accordance  with  the procedures under
 paragraph 4.2 of Performance Specification
 S of  this appendix. If the  pollutant and
 diluent monitoring  systems  are not of  the
 same  type (both extractive or both In-altu)
 tbe extractive system must use a multipoint
 probe.
  4.1.3 Installation • of  extractive  pollutant
 monitoring  systems using multipoint sam-
pling  probes or In-sltu pollutant monitoring
•Tttems that sample or view emlsalons which
are consistently representative of tbe total
emlsalons  for tbe  entire  cross section. The
Administrator may require date to bs «ub-
                                                         111-91

-------
  mltted to demonstrate that  the  emission*
  sampled  or  viewed an consistently repre-
  sentative for several typical facility proce**
  operating conditions.
    4.3 Tbe owner or operator may perform a
  traverse to characterize any stratification of
  effluent gases that might exist In a stack or
  duct. If no stratification La present, sampling
  procedures \ rider paragraph 4.1  may be ap-
  plied even though the eight diameter criteria
  Is not met.
    4.4 When single point sampling probes for
  extractive systems are  Installed within  the
  stack or duct under paragraphs 4.1 and 4.2.1.
  th* sample may not be extracted at any point
  less than 1.0 meter from the -stack or duct
  vail. Multipoint sampling  probes  Installed
  under paragraph 4.2.2 may be located at  any
  polnta necessary to obtain consistently rep-
  resentative samples.

  5. Continuous  Monitoring System  Perform-
  ance Speclncatlons.
   The continuous  monitoring system shall
  meet the performance specifications In Table
  3-1  to be considered acceptable  under "this
  method.
                         TABLE 2-1.—Performance tpeciflcationa
                    ParaaulfT
                                                              Specification
 \. Accuracy'	 <20 pet of tht mean value ol the reference method leal
                                                 dais.
 ?. Calibration error'	 £ Spctoftacb (50 pet, 90 pet) calibration gas minor*
                                                 value.
 1. Zero drift (2 b) i			 Spctofipan
 4. Zero drift (24 h) i	    Do.
 5. Calibration drill (2h)'	    Do.
 e. Cali oration drift (24 h)'	 2.S pet. of span
 7. Response time	 IS mln maiimum.
 8. Operational period	 168 h minimum.


  1 Eipnesad u «*"" of absolute mean value plus U pet confidence Interval of a series of lesu.
   6. Performance  Specification Test Proce-
 dures. Tbe following test procedures shall be
 used  to determine conformance  with the
 requirements  of  paragraph 5. For NO, an-
 requlrements  of  paragraph S. For NOi an-
 alyzers  tbst oxidize  nitric oxide  (NO)  to
 nitrogen dioxide  (NO,), the  response  time
 test under paragraph 6 J 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 subpart.
   6.1  Calibration Error Test Procedure. Set
 up  and  calibrate  the complete  continuous
 monitoring  system according  to the manu-
 facturer's writen Instructions. This may be
 accomplished either In  the laboratory  or In
 the field.
   6.1.1 Calibration  Oas 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 NOa.
 Analyze each calibration gas mixture (50%.
 S0<"o) and record the results on the example
 sheet shown In Figure 2-1. Each sample test
 result must be within 20 percent of the  aver-
 aged result  or the tests shall be  repeated.
 This step may be omitted for non-extractive
 monitors where dynamic calibration gas mix-
 tures are not used  (6.1.2).
   6.1.2  Calibration Error  Test  Procedure.
 Make a  total of IS nonconsecutlve measure-
 ments by alternately using zero gas and each
 :iliberatlon  gas mixture concentration  (e.g..
 3<-r.  50%. 0%. 90%.  50%, 80%, 50%, 0%.
 •tc.). For nonextractlve continuous monitor-.
 Ing  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  Test  for  Accuracy (Relative).
 Zero Drift, and Calibration Drift. Install and
 operate the continuous monitoring system In
 accordance with the manufacturer's written
 Instructions  and  drawings as follows:
   0.2.1 Conditioning Period. Offset the  zero
setting at least 10 percent  of the span so
 that negative zero drift can be quantified.
 Operate  the  system Tor  an Initial 108-hour
conditioning  period In  normal  operating
  6.2.3 Operational Tost Period. Operate the
continuous monitoring system for an addi-
 tional  168-hour  period  retaining the  zero
 offset.  The system shall  monitor the source
 effluent  at  all  tunes except  when  being
 zeroed, calibrated, or backpurged.
   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 and tbe probe
 tip for the Reference Method sampling train
 should be placed at adjacent locations in the
 duct. For NO, continuous monitoring sys-
 tems, make  27 NOX 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  hour. 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 tbe example data sheet shown In Figure
 3-3.
   6.2.22 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 systenu, tbe  zero
 value may be determined by mechanically
 producing a  zero  condition that provides a
 system check of the analyzer Internal mirrors
 and  all electronic  circuitry  including  tbe
 radiation source and  detector assembly or
 by inserting three or more  calibration gas
 cells and  computing the zero point from tbe
 upscale measurements. If this latter tech-
 nique Is used, a graph(s) must be retained
 by tbe  owner or operator for each measure-
 ment system  that shows the relationship be-
 tween tbe upscale  measurements and  tbe
 zero point. Tbe span of the system shall be
 checked by using  a  calibration gas cell cer-
 tified by  the manufacturer to be function-
 ally equivalent to 50 percent of span concen-
 tration. Record the zero and span measure-
 ments (or the computed  zero drift) on  the
 example data sheet shown In Figure 3-4.
 Tbe two-hour periods over which measure-
 ments are conducted need  not be consecutive
 but may not overlap. All  measurements re-
quired under this paragraph  may be eon-
ducted  concurrent with  testa under  para-
graph e.a.a.1.
    6.3.3.3 Adjustment*. Zero  and calibration
  corrections and adjustment*  are allowed only
  at 34-hour intervals or  at such shorter In-
  tervals as the  manufacturer's writ!en in-
  struction*  specify.   Automatic  corrections
  made  by tbe measurement  system without
  operator Intervention or  Initiation are allow-
  able at any time. During tbe entire 168-houi i
  operational test  period, record on the ex-
  ample sheet shown tn Figure 2-6 the values
  given  by zero and span gaa pollutant con-
  centrations before and after adjustment at
  24-hour intervals.
    63 Field Test for Response Time.
    6.3.1 Scope of Test. Dae tbe entire continu-
  ous monitoring system as Installed,  including
  sample transport  lines if  used. Flow rates.
  line diameters, pumping rates, pressures (do
  not allow tbe pressurized calibration gas to
  change tbe normal operating pressure In Uie
  sample line),  etc., shall  be at the nominal
  values for normal operation as specified In
  tbe manufacturer's  written  instructions. I/
  tbe analyzer Is used to sample more than one
  pollutant source (stack), repeat this test for
  each sampling point.
    6.35 Response  Time Test  Procedure. In-
  troduce zero gas Into the continuous moni-
  toring system  sampling Interface or as  close
  to tbe 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 tbe
 sample path and  response times  recorded.
  Perform  this test  sequence three (3) times.
•  Record  the results  of  each  test  on  the
 example  sheet shown  In Figure 2-0.
   7- Calculations. Date Analysis and Rcrort-
  Ing.        •
   7.1 Procedure  for  determination  of mean
  values and confidence Intervals.
   7.1.1 The mean value of  a  date set Is
 calculated according to equation 2-1.



                   n 1-1     Equation ?.-•}
 where:
   x, = absolute value of the measurements.
    : = sum of the Individual values,
    x*=mean value, and
    n = number of date points.

   7.1.2 The  85 percent confidence  Interval
  (two-sided) is calculated according to equa-
 tion 2-2:
                             Equation 2-2
where:
    £x, » sum of all data points,
    t.»?j=t| — or/2, and
   C.I.»j=9.V percent  confidence  interval
          estimate  of  tbe  average  mean
          value.
              Values for  '.975
n
,....
4 	
?-

!„...
TO**"

12
ID
14....
14
M-...
«.»7»
	 „ 12.708
	 4. (03
	 	 1182
i 	 Z.T78
	 	 	 2.471
, 	 Z447
...-. 	 2.3W
	 Z382
	 2,128
	 2.JB1
	 	 2. MB
	 	 2,160
	 2.146
	 2. ill
  Tbe value* In this table are already cor-
rected  for n-1 degree* of freedom.  Use n
                                                          111-92

-------
 equal to the  number of samples  a* cut*
 points.
   13  Date Analysis and Exporting.
   7.2.1  Accuracy (Relative). For etch of the
 oine reference method test polnU. determine
 the avenge pollutant concentration reported
 by the contlnuoui monitoring system. These
 average  concentration* ahail be  determined
 from the continuous monitoring system data
 recorded under 123 by Integrating or aver-
 aging the pollutant concentrations over each
 at the time Intervals concurrent with each
 reference method testing period. Before pro-
 ceeding  to the next step, determine the basts
 (wet or  dry)  of the continuous  monitoring
 system data and reference method test data
 concentrations. 11 the bases ire not  con-
 sistent, apply * moisture correction to either
 reference method concentrations or the con-
 tinuous  monitoring system  concentrations
 as  appropriate.  Determine  the   correction
 factor by moisture test* concurrent with the
 reference method testing period*. 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  tost concentration* (use average of
 each set of three znr  .urements for NO.)
 from the continuous monitoring system inte-
 grated  or  averaged  c. >eentraUons. Using
 these data, compute  the mean difference and
 the 95 percent confidence Interval of the dif-
 ferences  (equations  9-1 and  9-2). Accuracy
 Is reported aj the sum of the absolute value
 of  the mean difference and  the  95  percent
 confidence  Interval  of  the differences  ex-
 pressed as a percentage of the mean refer-
 ence method value.  Use the exuaple sheet
 shown in Figure 3-3.
   7.2.2   Calibration  Error. Using the data
 from paragraph 6.1. subtract the measured
 pollutant concentration determined  under
 psTfcprnph 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 6.1.3 (Figure 3-2).
 Calculate the mean of these difference values
 and the  OS  percent confidence Intervals ac-
 cording to equations 3-1 aod 3-3. Eeport the
 calibration error (the cum 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 examplt sheet shown In Figure 3-2.
  7.3.3  Zero Drift (3-hour). Using the sere
 concentration values measured  each  two
 hours during the field test, calculate the dif-
 ferences between consecutive two-hour read-
ings expressed In ppm. Calculate  the mean
difference aod the confidence Interval using
 equations 8-1 and 3-3. Report the uro drift
 as the sum of the absolute mean value and
 the confidence Interval as a  percentage of
 span. Use  example sheet shown In Figure
 3-4.
   7.3.4  Zero Drill (24-hour). Using the zero
 concentration  values  measured  every  24
 hours during the field test, calculate the dif-
 ferences  between the cero point alter zero
 adjustment and the aero value 34 hours later
 Just prior to eero adjustment. -Calculate the
 mean value of these  points and the confi-
 dence Interval using equations 3-1 and 3-3.
 Report the Eero drift  (the sum of the abso-
 lute mean and confidence  Interval) as a per-
 centage of span. Use example sheet shown in
 Figure 3-6.
   7.25  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 be  corrected for  the corresponding
 tero drift during that two-hour period. Cal-
 culate  the  mean and  confidence Interval of
 these corrected difference values using equa-
 tions 2-1 and 3-2. Do not use the differences
 between  non-oonaecutlve  readings.  Report
 the calibration drift as the sum of the abso-
 lute mean and confidence  Interval as a per-
 centage of span. Use the example sheet shown
 10 Figure 3-4.
   7.2.6  C-llbratlon  Drift   (34-hour). .Using
 the calibration  values measured  every  24
 hours durlne 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 tero 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 aad confidence Interval)
 as a percentage of span.  Use  the example
 sheet shown IB Figure 2-5.
   7.2.7  Response  Time. Using  the  charts
 from paragraph 6.3. calculate toe time inter-
 val from concentration switching to 95 per-
 cent to the  Anal stable value for all upscale
 and downicale 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 tune. Use the ex-
 ample sheet shown In  Figure 2-6.
   7.3.8 Operational Test Period. During the
 108-hour  performance  and operational test
 period, 'the  continuous monitoring system
 shall not require any corrective maintenance.
repair, replacement, or adjustment other than
 that c'early specified as required In the op-
 eration toad maintenance manuals as routine
 and expected during a  one-week period. If
 the continuous monitoring system operates
 within the specified performance parameters
 and does noi require corrective maintenance.
 repair, replacement or adjustment other than
 as  specified above during the  168-hour teet
 period, the operational period will be success-
 fully  concluded. Failure of the  continuous
 monitoring system  to meet tats requirement
 shall call for a repetition of the 168-bour test
 period. Portions 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-
 week  performance test period and that por-
 tion of the testing  which is  related to the
 failed specification. All maintenance and ad-
 justments  required  shall be recorded.  Out-
 put readings  shall be  recorded  before  and
 after all adjustments.
  8. References.
  8.1 "Monitoring Instrumentation  for the
 Measurement of Sulfur Dioxide In Stationary
 Source Emissions." Environmental Protection
 Agency. Research Triangle Park. N.C..  Feb-
 ruary 1973.
  82 "Instrumentation for  the Determina-
 tion of  Nitrogen Oxides Content  of Station-
 ary Source Emissions." Environmental Pro-
 tection Agency, Research Triangle Park. N.C..
 Volume 1. APTD-0847.  October  1671:  Vol-
 ume 2.  AFTD-0943. January 1973.
  3.3 "Expertmentil Statistics." Department
 of Commerce, Handbook 91. 1963. pp.  3-31.
 paragraphs 3-3.1.4.
  8.4 "Performance  Specifications  for  Sta-
 tionary-Source Monitoring Systems for Cases
 and Visible Emissions." Environmental  Pro-
 tection Agency. Research Triangle Park, N.C.,
EPA-450/3-74-013. January 1974.
                  Hjp> Ul H*Hm«
                       tH. «.! .Hit...
                                                                                             r«t»> M.  im\rtit *> utiMttw an
                                                          111-93

-------
            Calibration G«s  Mixture OaU  {From Figure 2-1)
            Mid (505) 	ppn       High (901) 	ppm
Run t
          Calibration Gas
         Conccntration.ppm
Measurement Systen
  Reading, ppn
Differences,   ppm
4
5
6
7
8
9
10
11
12
13
14
15
                                                                Hid    High
Mean difference
Confidence Interval
Calibration error =         Calibration  r,as  Concent raTfbrT
                            Pear Difference   +  C.I.
                                                           x 100
 Calibration gas concentration - measurement system  reading
"Absolute value
                    Figure 2-2.  Calibration Error Determination
'tit
Ho.
1
J
J
«
tra

•ffcrtnct NftriM Wnpltt
•&'

i
i
I
~f
tnpft 1
(K")



i
$ ! • i
«• i !
7
f
t
bin
fit
U (
ttor
'Up
'


rtf«r«nci •
Mlut (SO.
AlfIMM* 1


• UM





•o. ; w,
tewft t ! twit J
!










j

j


V tMpll





«Mlyt«r l-MHr
«rrtr<«« (pp.)-





i
1
i

HMn rvftmct MBtlnri
tMt n)M 1«3 )
• ••
(10.) • •










(Hffimct
(PV)
10, «,













NHn of
UK «ltr.r»«tl
tm
•IM» »f tkt «(fltr»BC«l . Hs (o«flwiKt"lllt*r> .
*'" * Nun rtftrtnct Mtkml Mint • — _
Uli «M r»port MtMd KtM U Hltrmtm lnt*gr»IM Illitjl'
	 • >~1





) • 	 I «».)
                     ri««n t-).  Jkuraqr OtumtMtlw (10, «M Ht)
                                    111-94

-------
KU
Ml         TIM
Co.       tnli  lid
                            I*r>  .    Drift
                                                       Drift
                                                                    Grift
irr« ?rift • (H«n Zero >m*
Ctllbrttlon Orlft • [HMn Sp«n Drift'
•Absolute Vtluf.
                                  * CI (ifo)
                                 "  « CI (SrS
                                                      l [Sptn] i 10
                       ?-4.  2cro 
-------
       Data of Tast
       Span Gas Concentration

       Analyzer Span Setting _




       Upscale
                                    pps
                                   _tecondi

                                    seconds
                                       seconds
                     Average upscale response
                                       seconds
                                                  seconds
       Downjctie
                                       seconds
                                    ^seconds

                  Average downscale response

SyJtcn average response -tine (slower time) • _

Zdevlation  from slower
system average response
                                                    _seconds

                                                     seconds.
                            average upscale ciinus average downscale
                                           slower tine
x 1001 -
                          Figure 2-6.  Response Time
      ^	       Performance
 specifications and  specification test proce-
 dures (or monitor* ot CO, and O, from sta-
 tionary sources.
   1. Principle and Appllcablllty.
   1.1 Principle. EMuent gases are continu-
 ously sampled and are analyzed (or carbon
 dioxide or oxygen by a 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.
   1.3 Applicability. This performance speci-
 fication is applicable  to evaluation of  con-
 tinuous monitoring systems for measurement
 ot carbon dioxide or oxygen. These specifica-
 tion* contain test procedures, installation re-
 quirements,  and data computation proce-
 dures for evaluating the acceptability of the
 continuous monitoring  systems  eubjoct to
 approval  by  the Administrator.  Sampling
 may  include either extractive or non-extrac-
 tive (in-sltu) procedures.
  2. Apparatus.
  2.1 Continuous  Monitoring  System  for
 Carbon Dioxide or Oxygen.
  2.3 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 eat and
 check the  analyzer span and is referred to
 01 span  gas. For oxygen  analyzers. If the
 span Is higher than 31 percent O,, ambient
 air may be used in place of the 90 percent of
 span calibration  gai  mixture.  Triplicate
 analyses of the gas mixture (except omblant
 air)  shall  bo performed within  two weeks
 prior to  use using Reference  Method 3 of
 this pan.
  2.3 Zero Oas. A gas containing lew than 100
 ppm of carbon dioxide or oxygen.
  2.4 Data Recorder.  Analog chart recorder
 or other  suitable device with input voltage
range compatible with analyzer system out-
 put.  The resolution of tho recorder's data
 output shall be sufficient to allow completion
 of the test procedures within this caeciaca-
 tlon.
  3. PoflnUrons.
  0.1  Continuous  Honltorlng Oydtem Tha
 total equipment required for the datennlna-
 tlon of carbon diaslda or caytjon IB a (jlvon
                                         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  of the
                                         source effluent or protection of the analyzer
                                         from  the hostile aspects  of  the sample or
                                         source 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  pollutant 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.
                                           32 Span. The value of oxygen or carbon di-
                                         oxide concentration at which  the continuous
                                         monitoring system Is  sat that produces the
                                         maximum data display output. For the pur-
                                         poses  of this method, the span shall  ba cat
                                         no less than 1.S to 2.S times the normal cor-.
                                         bon dioxide or normal oxygen concentration
                                         In the stack gas of the affected facility.
                                           3.3 Midrange. The value of oxygen or car-
                                         bon dioxide concentration that Is representa-
                                         tive of the normal  conditions In the stock
                                         B»s of. the affected facility at  typtczJ 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 toro.
                                           3.8 Calibration Drift. Tho  cbanga In  tho
                                        'continuous monitoring system output over a
                                         stated time period of normal continuous op-
                                         eration when the carbon dioxide or oxygon
                                         continuous monitoring system la measuring
                                         the concentration of span gas.   . •
                                           3.0 Operational Test Period. A minimum
                                         period of time over which tho  continuous
                                         monitoring system  la expected  to" operate
                                         within certain  performance  specifications
                                         without unscheduled maintenance, repair, or
                                         adjustment.        .   • .  •
                                        .   0.7 Response time. The ttma Interval from
                                         o ctop change  In concentration ot tho  Input
                                         to tho continuous monitoring cTotom to tho
                                        .ttrno ot which  05 percent of tho ecrrejpossl-
 Ing anal value la displayed ea O»o esattnuoos
 Gonltorlna system data rceordor.
   4. Installation Qpcctflcotton.
   Oxygon or carbon dioxide continuous mon-
 itoring systems' shall -to Installed at a loca-
 tion where measurements oro directly repre-
 oantatlve  of  tho total  effluent from  the
 affected facility or roprcMntatlvo of the aame
 effluent sampled by a SO, or NO. continuous
 monitoring system.  TnU requirement aball
 bo compiled with by  usa of  applicable re-
 quirements in Porformanej Specification 3 of
 this appendix ea follows:
   4.1 Installation of Oxygon  or  Carbon Di-
 oxide  Continuous Monitoring Systems Not
 Used to Convert Pollutant Data. A campling
 location shall ba selected In accordance with
 the procedures under • paragraphs  4J.I  or
. 4.2.2. or Performance Specification 3 of this
 appendix.
   42 Installation  of Oxygon  or  Carbon Di-
 oxide  Continuous Monitoring Systems Used
 to Convert Pollutant Continuous Monitoring
 System Data to TJnlta of Applicable Stand-
 ards. The diluent continuous monitoring sys-
 tem (oxygen or carbon dioxide) oholl be In-
 stalled at a sampling location whore measure-
 ments that ra« ba made oro representative of
 the effluent gases sampled by the pollutant
 continuous monitoring system (a). Conform-
 once with  this requirement may be  accom-
 plished In  any of tho following ways:
   4.2.1  The sampling location  for tho diluent
 system shalfbe near the sampling location for
 the pollutant continuous monitoring system
 such that  the  same approximate point (o)
 (extractive systems) or path (In-sltu sys-
 tems)   In  the cross osction  is campled  or
 viewed.
   42.2  The diluent and pollutant continuous
 monitoring systems may ba Installed at dif-
 ferent locations If the effluent gases at both
 sampling locations ore nonstrauflod as deter-
 mined under paragraphs 4.1 or 4.3, Perform-
 ance  Specification 3 of  this  appendix and
 there is no in-leakoge occurring between the
 two sampling locations. It the effluent gases
 are stratified  at either location, tho proce-
 dures  under  paragraph  422, Performance
 Specification 3 of this appendix shall bo used
 for installing continuous monitoring systems
 at that location.
   6. Continuous Monltortnrc STtitem Perform-
 ance Specifications.
   The continuous monitoring system shall
 meet the performance specifications in Table
 3-1 to  be  considered accsptablo  under this
 method.
   e. Performance  Specification Test Procs.
     10 following tost procedures shall bo used
 to determine conformance with the require-
 ments of paragraph 4. Due to tho wide varia-
 tion existing in analyzer designs and princi-
 ples of  operation, these- procedures  oro not
 applicable to all analyzers. Whore this occurs.
 alternative  procedures, subject to the ap-
 proval  of the  Administrator,  may  be em-
 ployed.  Any such alternative procedures must
 fulfill the same  purposes (verify raponse,
 drift, and aecurscy) as the following proce-
 dures, and  must  clearly demonstrate eon-
 formance  with specifications In  Tobla 0-1.
  6.1 Calibration Check. Establish a cali-
 bration curve for the continuous  moni-
 toring  system using zero, midransc. and
 span concentration tjas mixtures. Verify
 that the resultant curve of analyzer read-
 Ing  compared with the calibration BOS
 value la consistent with the expected re-
 sponse  curve as described by the analyzer
 manufacturer. If the expected response
 curve Is  not produced, additional cali-
 bration ana meaaurcmenta chall to mode,
or additional otcja undarb&cn to
                                                            TTT-Q6

-------
 the accuracy of the response curve of the
 analyzer.
   6.2 Field Test for Zero Drift and Cali-
 bration  Drift.  Install  and  operate  the
 continuous monitoring system in accord-
 ance with the manufacturer's written In-
 structions and  drawings as  follows:
  TABLE 8-1.—Performance tpecificalinm
       ftrnuttr
                           Specification
 1. Zerodrill (?M '	  <0.4 pel Oior COi.
 2. Zero drill (74 h»	  <0-i pel Oior COi.
 i. Calibration drill CM'..  §0.4 pel O: o: COt
 4. Calibration rtrtfi 124 b)'.  <0-4 pel O; or COj.
 .V Operational period	  18S b minimum.
 0. Response use	  lOmin.

  > Eipmvd at nun of absolute nun value plus W pel
 confidence Inwrral o! • eerie* of Usu.
  6.2.1  Conditioning  Period  OCset tbe zero
 tettlug at least 10 percent ol (pan to that
 negative cero drift may be quantified. Oper-
 ate  the continuous  monitoring system for
 an InlUal  168-hour conditioning period In a
 normal operational manner.
  6.2.2 "Operational Test  Period. Operate the
 continuous monitoring system  for an  addi-
 tional 168-hour period  maintaining tbe eera
 onset  The system ahull  monitor the source
 effluent  at ail times  except  when-being
 zeroed, calibrated, or backpurged.
  6.2.3 Field Test for Zero Drift and Calibra-
 tion  Drift. Determine  the  values given by
 rero and mldrange gas concentrations at t»-o-
 hour inteivals until  19 acts  of  data are ob-
 tained. For non-extractive continuous moni-
 toring  systems, determine  the aero   value
 given  by a mechanically  produced cero con-
 dition cr by computing the  zero value from
 upscale  measurements  using calibrated gas
 cells certified by tbe manufacturer. The mid-
 range  checks shall  be performed by  using
 certified  calibration  gas cells  functionally
 equivalent to less than 50  percent o?  spun.
 Record these readings on tbe example  sheet
 shown In Figure 3-1. These two-hour periods
 need not be consecutive.but may not overlap.
 In-sltu CO. or O, analyzers which cannot be
 fitted with "a calibration pus cell may be cali-
 brated by alternative procedures acceptable
 to tbe Administrator. Zero  and calibration
 correction* and adjustments  are  allowed
 only at 24-hour Intervals or at  such shorter
 Intervals  as tbe manufacturer's written In-
 structions  specify.   Automatic  corrections
 made  by tbe continuous  monitoring  system
 without operator  intervention  or Initiation
 arc allowable  at any time. During the en-
 tire  168-hour  test period, record  the values
 given by  cero and span  gas concentrations
 before and alter adjustment at 24-hour In-
 terval* In tbe example sheet shown In Figure
 3-2.
  63 Field Tost for Response Time.
  6J.I Scope of Test.
  This test shall be accomplished using the
 continuous monitoring  system  as Installed.
 Including  sample  transport lines If  used.
 Flow  rates, line diameters, pumping  rates,
 pressures (do not allow the pressurized  cali-
 bration gas to change the normal operating
 pressure la tbe  sample line). etc., shall be
 at tbe nominal values.for normal operation
 as specified In tbe manufacturer's written
 Instructions. If the analyzer Is used to sample
 more than one source (stack), this test  shall
 be repeated for each sampling point.
  8.3.2 Response Time Test Procedure.
  Introduce zero  gas  Into  tbe  continuous
 monitoring system sampling  Interface or as
elos* to tbe sampling interface as possible.
When the system output  reading has stabi-
    1. switch quickly to a known concentra-
 tion of gas at 90 percent of apan. Record tbe
 Urne from  concentration switching  to  96
 percent of  final stable response. After the
 system response has stabilized at tbe upper
 level, switch quickly to a zero gas.  Record
 the time from concentration switching to 95
 percent of  final  stable  response  Alterna-
 tively, for nonextractlve continuous monitor-
 Ing systems, the hlghe-t available calibration
 gas concentration shall be switched Into and
 out of  the  eiimple path  and responne times
 recorded. Perform thlc test sequence  three
 (3) times. For each  test, record the  results
 on the  data sheet  shown In Figure  3-3.
   7. Calculations,  Data Analysis, end Report-

 '7.1 Procedure for determination of mean
 values  and  confidence Intervals.
   7.1.1  The mean value of a data set Is cal-
 culated according to equation 3-1.
                   i
                   n  '••     Equation  3-1
 where:
   x, = absolute value of the measurements.
   I- :sum of the Individual values.
   x = mean value, and "
   n ^number of data points.

   7.2.1 The 95  percent  confidence  Interval
 (two-elded) is calculated according to equa-
 tion 3-2:
            nyn — 1
                             Equation 3-2
 where:
    2X = sum of all data points,
   '.975 = t,-o/2.and
   C.I.»=85  percent  confidence   interval
     estimates of the average mean  value
              Values tor «.975
                                      '.975
                                      .
 2  ................................ 12.706
 8  ................................  4.303
 *  ................................  3.182
 5  ................................  2.776
 6  ................................  2.671
 *  - ...............................  2.447
 8  ................................  2.S65
 9  ................................  2.308
'0  ................................  2.282
11  ................................  2.228
12  ......... •• ......................  2.201
13  .................. . .............  2.179
1*  ................................  2.160
18-- ..............................  2.145
18  ................................  2.131

Tbe values In this table are already corrected
for n-1 degrees of  freedom. Use  n equal  to
the number of samples as data  points.
  12  Data Analysis and Reporting.
  7.2.1 Zero Drift (2-hour).  Using the zero
concentration   values  measured   each two
hours during the field test, calculate the dif-
ferences  between tbe consecutive two-hour
readings expressed In  ppm.  Calculate the
mean difference and tbe confidence  Interval
using equations 3-1 and 3-2. Record the sum
of the absolute mean value  and  tbe  confi-
dence Interval  on tbe data sheet shown  In
Figure 8-1.
  122 Zero Drift (24-hour). Using tbe zero
concentration   values  measured  every   94
hours during tbe field test, calculate the dif-
ferences  between the zero point  after zero
adjustment and tbe zero value 24  hours
later Just prior  to zero adjustment. Calculate
the mean value of these points and tbe con-
fidence interval using equations 8-1 and 8-4.
Record the zero drift (the sum of the  ab-
solute mean and confidence Interval) on the
data sheet shown In Figure 3-2.
   12 J Calibration Drift (2-hour). Using the
calibration values obtained at two-hour In-
tervals during tbe field  test,  calculate  the
differences  between  consecutive   two-hour
readings  expressed  as ppm.  These values
should be  corrected  for  tbe corresponding
zero drift during that two-hour period. Cal-
culate the mean and  confidence Interval of
these corrected difference values uslnp equa-
tions 3-1 and 3-2. Do not use the differences
between non-consecutive readings.  Record
the  sum  of the absolute mean and  confi-
dence interval upon  the data sheet shon-n
In Flrure 3-1.
   7.2.4 Calibration Drift (24-hour).  Using the
calibration  values measured every  24 hours
during the field  test,  calculate the dlfer-
ences  between the calibration concentration
reading after zero and calibration actjutt-
men't end the calibration concentration read-
ing 24 hours later after zero adjustment but
before calibration adjustment.  Calculate the
mean  value of these differences and tbe con-
fidence Interval  using equations 3-1 and 3-2.
Record the sum of the absolute mean and
confidence interval on the data sheet Ehov.-n
In Flg\rre 3-2.
   7.2.5 Operational Test Period. During  ihe
168-hour  performance and operational test
period, the continuous monitoring  systrm
shall 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 manuals r»s  rojtlne and  expected
during a one-week period. If tbe continuous
monitoring system operates within the speci-
fied performance parameters and does net re-
quire corrective maintenance, repair, replace-
ment  or adjustment other than as speciStd
above  during the 168-hour test period,  the
operational period win be successfully con-
cluded. Failure of the continuous monitoring
system to  meet this  requirement shall call
for a repetition  of the IPS hour test period.
Portions of tbe test which were satisfactorily
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 tbe test-
Ing which  Is related to tbe failed specifica-
tion.  All maintenance and adjustments re-
quired shall be  recorded. Output  readings
shall  be resorded 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 tbe final stable value for all  up-
scale and downscale tests. Report the mean of
tbe three upscale test times and tbe mean o:
tbe three downscale test times. Tbe two av-
erage times should not differ by more than
15 percent of the slower time. Report  the
slower time as the system response time. Re-
cord the results on Figure 8-8.
   8.  References.
   S.I   "Performance  Specifications  for  Sta-
tionary Source'Monitoring Systems  for Oases
and Visible Emissions." Environmental Pro-
tection Agency. Research Triangle Park, N.C.,
EPA-650/2-74-013. January 1974.
   62 "Experimental Statistics," Department
of Commerce. National Bureau of Standards
Handbook  91, 1983.  pp.  3-31, paragraphs
8-3.1.4.
(Bees.  Ill and 114 of tbe Clean Air Act. as
amended by sec. 4(a)  of  Pub.  L. 91-804. 84
Btat. 1878 (43  U.8.C. 1867C-0. by sec. 16(c) (2)
of Pub. L. 91-004. 8fi Btat.  1718 (42 U.S.C.
l«57g)).
                                                             111-97

-------
teU
*t
M.
          Ttat
                    DlU
                            Itn
                                      Z*ro
                                      Drift
                                              Sptu
                                                        Drift
                                                                    Dr Drif
   Ctllbritlon Drift • [H«»n Spin Dri
   •Abtolutt Vilu».
                                    « Cl \ MB
                              Flgurt >•!. bra and bllintleo Drift (1 Hour).
Date
and            Zero
Mine        Reading
                           Zero                 Span            Calibration
                          Drift               Reading              Drift
                         (iZero)      (After zero adjustment)    (iSpan)
Zero Drift  •  [Mean Zero  Drift*
                                          * C.I.  (Zero)
Calibration Drift • [Mean  Span Drift*
                                                   * C.I. (Span)
k Absolute value
                Figure 3-2.   Zero and Calibration Drift (24-hour)
                                    111-98

-------
Cau of Test
Span Gas Concentration
Analyzer Span Setting
1.
Upscale 2.
3.
Average
1.
Domscjle 2.
3.
Average
pom
ppm .
. seconds
seconds
seconds
upscale response seconds
seconds
seconds
seconds
downscale response seconds
System averege response time (slower tiire) » seconds
                                              ,, ,.,
system average resp
onse slower tune
a

Figure 3-3. Response
(B«e. 114 of th» Qe^n Air Act u
(OU.SC. »tS7c-«).).
               111-99

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                                                    AM© GI©U!LATtS>NS
    Tttto 4Q—Protection of Emdronmant
     CHAPTER I—ENVIRONMENTAL
         PROTECTION AGENCY'
      8UBCHAPTER C—AIR PfWOHAfcSa
PART  SO—STANDARDS  O?  PERFORM-
 ANCE FOR NEW  STATIONARY SOURCES

Additions cm! Mloo2)loncjwta Amendmonto
  It is evident from comments received
that an Inadequate explanation was given
for applying both an enforceable opacity
standard and  an enforceable concentra-
tion standard to the same source and that
the relationship between the concentra-
tion standard and the opacity standard
was not clearly presented. Because all
but one of the regulations Include these
dual standards, this subject is dealt with
here from the general viewpoint. Specific
changes  made to the regulations  pro-
posed for a specific source are described
in the discussions of each source.
  A discussion of the major points raised
by the comments on the opacity standard
follows:
  1. Several   commentators  felt  that
opacity limits should be only guidelines
for  determining when to conduct  the
stack tests needed to determine compli-
ance with concentration/mass standards.
Several other commentators expressed
the  opinion that  the opacity standard
was more stringent than the concentra-
tion/mass standard.
  As promulgated  below, the  opacity
standards  are regulatory  requirements.
just like the concentration/mass stand-
ards. It is not necessary to show that the
concentration/mass  standard  is  being
violated in order to support enforcement
of the opacity standard. Where opacity
tuid concentration/mass  standards  are
applicable to the same source, the opacity
standard to not more restrictive thaa the
concentration/mass standard. The  con-
centration/mass standard is  established
at a level which will result In the design.
Installation, and operation of  the best
adequately demonstrated system of emis-
sion reduction  (taking  costs into  ac-
count)  for each  source. The  opacity
standard is established at a level which
will require proper operation and mainte-
nance of such control systems on a day-
to-day basis, but not require the design
and installation of a control system more
efficient or expensive than that required
by the concentration/mass standard.
  Opacity standards are a necessary sup-
plement to concentration/mass  stand-
ards. Opacity standards help ensure that
sources and   emission  control systems
continue to be properly maintained and
operated so as to comply with concen-
tration/mass standards. Participate test-
Ing by EPA method  5 and most other
techniques requires an  expenditure  of
$3.000 to $10,000 per test including about
300  man-hours of technical and semi-
technical personnel. Furthermore, sched-
uling and preparation are required such
that It is seldom possible to conduct  a
test with less than 9 weeks notice. There-
fore, method  5 particular teste can be
conducted only on an infrequent basis.
  If there were no standards other them
concentration/mass standards, it would
be possible to  inadequately operate or
maintain pollution control equipment at
all Umee except during periods  of per-
formance  testing.  It takes 2 weeks or
longer to schedule & typical stack test.
If only small repairs were required, e.g.,
pump or fan repair or replacement of
fabric niter bags, such remedial action
could be delayed until shortly before the
test  la conducted. For some  types of
equipment such as scrubbers, the energy
input could be reduced (the pressure drop
through the  system)  when stack tests
weren't being conducted, which would
result in the release of significantly more
paniculate matter than normal. There-
fore, EPA  has  required  that operators
properly maintain air  pollution control
equipment  at all times  (40 CFK> 60.11
(d)) and meet  opacity standards- at all
times except  during periods of startup,
shutdown,  and  malfunction (40  CPR
dO.ll(c)), and  during  other periods of
exemption  aa  specified  In  Individual
regulations.
  Opacity of emissions is Indicative of
whether control equipment is properly
maintained and operated. However, it is
established as an Independent enforce-
able standard, rather than an Indicator
of maintenance and operating conditions
because information concerning the lat-
ter is peculiarly within  the control of
the  plant  operator. Furthermore, the
time and expense required to prove that
proper procedures nave not been  fol-
lowed are so great that the provisions of
40 CFR 60.Hid) by themselves (without
opacity standards) would not provide on
economically sensible means of ensuring
on a day-to-day basis that emissions of
pollutants  are  within  allowable limits.
Opacity standards require nothing more
than B trained  observer and can be per-
formed with  no prior notice. NarmaQy,
it is not even necessary for the  observer
to be admitted  to the plant to determine
properly the  opacity of stack emissions.
Where observed opacities are within al-
lowable limits,  It is not normally neces-
sary for enforcement personnel to enter
the  plant  or contact  plant  personnel.
However, in some cases, Including times
when  opacity  standards may  not be
violated, a full investigation of operating
and maintenance conditions will be de-
sirable. Accordingly, EPA  has  require-
ments for -both  opacity limits and proper
operating and  maintenance procedures.
  2. Some commentators suggested that
the regulatory  opacity limits should be
lowered to be consistent with the opacity
observed at existing plants; others felt
that the opacity limits were too strin-
gent. The regTjlatbry opacity limits are
sufficiently close to observed opacity to
ensure proper operation and  mainte-
nance of control systems  on a continuing
basis but still allow some room for minor
variations  from the conditions  existing
at the time opacity readings were made.
  3. There are specified periods during
which opacity  standards do not apply.
Commentators  questioned  the rationale
for these  time  exemptions, as proposed.
some pointing  out that  the exemptions
were not  justified and some that  they
were inadequate. Time exemptions fur-
ther reflect the stated purpose of opacity
otandnrda by providing relief from such
standards during periods -sfren  accept-
able systems of emission reduction are
judged to be Incapable of meeting pre-
scribed opacity limits. Opacity standards
do not apply to emissions during periods
of startup,  shutdown, and malfunction
(see FEDERAL  Rgcisren  of October  15.
1973, 38 FR 28564). nor do opacity stand-
ards apply during periods judged neces-
sary to permit the observed excess emis-
sions caused by soot-blowing and  un-
stable process conditions. Some confu-
sion resulted  from  the  fact that  the
startup-shutdown-malfunction   regula-
tions were proposed separately (see FED-
ERAL REGISTER of May  2,  1073, 38 FR
10820) from the regultions for this'sroup
of new sources. Although this was point-
ed out hi the preamble (see FEDERAL REG-
ISTER of June  11, 1973. 38 FR 15406) to
this  group of new  source performance
standards, it appears to have escaped the
notice of several commentators.
  4.  Other  comments, along with • re-
study of  sources and additional  opacity
observations, have led to definition of
specific time exemptions, where  needed.
to account for excess emissions resulting
from soot-blowing  and  process varia-
tions. These specific  actions replace the
generalized  approach to  time  exemp-
tions, 2 minutes per hour, contained in
all  but  one of the proposed  opacity
standards. The intent of the 2.minutes
was  to prevent the  opacity standards
from being  unfairly  stringent  and re-
flected an arbitrary  selection of a time
exemption to (serve this  purpose. Com-
ments noted that observed opacity and
operating conditions did not support this
approach. Some pointed  out  that these
exemptions were not warranted: others.
that they were inadequate. The  cyclical
basic oxygen steel-making process, for
example,  does  not  operate  in hourly
cycles and  the  Inappropri&teness  of 2
minutes per hour in  this case would ap-
ply to other cyclical processes which ex-
ist both In sources now subject to stand-
ards  of  performance and sources for
which standards will be developed in the
future. The time exemptions now pro-
vide for circumstances specific to the
sources  and. coupled with the startup-
shutdown-malfunction  provisions  and
the hlgher-than-observed opacity limits,
provide much better assurance that the
opacity   standards  are  not  unfairly
stringent.
   Dated: February 22. X97«.
                  RUSSELL E. Turo.
                       Administrator.
    FTOSBAl W6ISYS9, VOL J», WO. 47-

               MA«CH «. 1974
                                                      III-100

-------
                                             tUlES AND •EMULATIONS
 THta 40—Protection of the Environment
     CHAPTER I—ENVIRONMENTAL
         PROTECTION AGENCY
     SUBCHAFTER C—AIR MOONMIS
              IFRL 991-0)
PART 60—STANDARDS OF  PERFORM-
ANCE FOR NEW STATIONARY  SOURCES
           Opacity Provision*
  On June 29. 1973. the United  States
Court of Appeals for the  District of
Columbia In "Portland Cement Associa-
tion T. Ruckelshaus." 486 F. 2d 375  (1973)
remanded to EPA the  standard of per-
formance for Portland cement plants (40
CFR 60.60 et seq.) promulgated by EPA
under section  111 of the Clean Air Act.
In the remand, the Court directed EPA to
reconsider among other things the use
of the opacity standards. EPA has pre-
pared a response to the remand.  Copies
of this response are available from the
Emission  Standards  and  Engineering
Division,   Environmental   Protection
Agency,  Research Triangle Park, N.C.
27711. Attn: Mr. Don R. Goodwin. In de-
veloping the response, EPA collected and
evaluated a substantial amount  of In-
formation which Is summarized and ref-
erenced In the response. Copies of this
Information are  available  for Inspection
during normal office hours at EPA's Office
Of  Public Affairs.  401  M Street SW.,
Washington. D.C. EPA determined that
the  Portland  cement  plant  standards
generally did not require revision but did
not find that certain revisions are ap-
propriate to the opacity  provisions  of
the standards. The  provisions promul-
gated herein Include a revision to { 60.11,
Compliance with Standards and Mainte-
nance Requirements, a revision  to the
opacity  standard  for  Portland cement
plants, and revisions to Reference Meth-
od 9. The bases for the revisions are dis-
cussed In detail in the Agency's response
to  the  remand. They are  summarized
below.
  The revisions to  I 60.11  Include the
modification of  paragraph  (b) and the
addition of paragraph 
-------
reading opacity In this manner and will
propose this revision to Method 9 as soon
as this analysis is completed. The Agency
•elicits comments and recommendations
on the need for this additional revision to
Method 9 and would welcome any sug-
gestions particularly from  air pollution
control agencies on how we might make
Method 9 more responsive to the needs of
these agencies.
  These actions are effective on Novem-
ber 12,1974. The Agency finds good cause
exists  for  not publishing these actions
as a notice of proposed rulemaklng and
for making them  effective Immediately
upon  publication  for  the  following
reasons:
   (1)  Only minor amendments are  be-
ing made to the opacity standards which
were remanded.
   (2)  The  T7JB. Court of Appeals  for
the District of Columbia Instructed EPA
to complete the remand proceeding with
respect to the Portland cement plant
standards by November S, 1974.
   (3) Because opacity standards are the
subject of other litigation, it is necessary
to reach a final determination with re-
spect to the basic issues involving opacity
at this time In order to properly respond
to this issue with  respect to such other
litigation.
  These regulations are Issued under the
authority of sections 111 and 114 of the
Clean  Air Act.  as amended (42 UJS.C.
1857C-4 and 9).
  Dated: November 1.1974.
                    JOHN  QtTARLES,
                Acting Administrator.


   HDftAl MWSTH. VOL -»*, NO. tl*-

     -niUOAY. «OVEMM* It,
     IULES  AND 1EGULATKM4S

   Title 40  Protection of Environment

     CHAPTER I—ENVIRONMENTAL
         PROTECTION AGENCY
             [FRL 392-7)

 PART 6O—STANDARDS OF  PERFORM-
ANCE FOR  NEW STATIONARY SOURCES

     Five Categories of Sources In the
      Phosphate Fertilizer Industry
          OPACTTT STANDARDS

  Many  commentators  challenged  the
proposed  opacity  standards  on  the
grounds that EPA had shown no correla-
tion between  fluoride  emissions  and
plume  opacity, and that no data were
presented which showed that a violation
of the  proposed opacity standard would
indicate  simultaneous violation  of  the
proposed  fluoride  standard.  For  the
opacity standard to be used as  an  en-
forcement tool to indicate  possible  vio-
lation  of the fluoride standard,  such  a
correlation  must  be established.  The
Agency has  reevaluated the opacity  test
data and determined that the correlation
is insufficient  to  support  a standard.
Therefore, standards for visible emissions
for diammonium phosphate plants, triple
superphosphate plants,  and  granular
triple  superphosphate storage facilities
have been deleted. This action, however.
is not  meant  to set a precedent re-
garding promulgation of visible emission
standards. The situation which necessi-
tates this decision relates only to  fluoride
emissions. In the future, the Agency will
continue  to set opacity standards for
affected facilities where such standards
are desirable and warranted based on
test data.
   In place of the opacity standard, a  pro-
vision  has been added which requires an
owner or operator to monitor the total
pressure drop across an affected facility's
scrubbing system. This requirement will
provide an  affected facility's scrubbing
system. This requirement will provide for
a record  of the operating  conditions  of
the control  system, and will serve as an
effective method for monitoring  compli-
ance with the  fluoride standards.
      MOMITOUMO RMtnanmcrs
  Several comments' were received with
regard to the sections requiring a flow
measuring device which has an accuracy
of ± 6 percent over its operating range.
The commentators  felt that  this accu-
racy could not  be met and that the
capital and operating  costs outweighed
anticipated utility. First of all, "weigh-
belts" are common devices in the phos-
phate fertilizer industry as raw material
feeds  are  routinely  measured.  EPA
felt there would be no economic Impact
resulting from this  requirement because
plants  would have  normally Installed
weighing  devices anyway. Second, con-
tacts with the Industry led EPA to be-
lieve that the ± 6 percent accuracy re-
quirement would be easily met, and a
search of pertinent literature showed
that weighing devices with i 1 percent
accuracy  are commercially available.
  Effective date. In accordance with sec-
tion 111 of the Act, these regulations pre-
scribing  standards of  performance for
the selected stationary sources are effec-
tive on  August 4. 1975, and apply to
sources at which construction or modifi-
cation commenced after October 22.1974.
                 RUSSELL E. Tunr,
                      Administrator.

  JOT.Y 25. 1975.


    ftDOAl UOISTIt, VOL 40, NO. 1M-
      -WEDNESDAY, AUOUn 6. 1t7S
                                                    III-102

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 PART 60—STANDARDS OF PERFORM-
ANCE FOR NEW STATIONARY SOURCES

Emotion  Monitoring Requirement*  and
  Revisions   to  fltrfortMi     ~
  Methods
•nee  Testing
  On September 11. 1974 (39 FR 32852).
the  Environmental  Protection  Agency
(EPA) proposed revisions to 40 CFR Part
60. Standards of Performance for New
Stationary Sources, to establish  specific
requirements pertaining to continuous
emission monitoring system performance
specifications, operating procedures, data
These requirements would apply to new
and modified facilities  covered  under
Part 60.  but would not apply  to existing
facilities.
  Simultaneously  (39  FR 32871).  the
Agency proposed revisions to 40 CFR
Part 51.  Requirements for the Prepara-
tion. Adoption,  and Submlttal of Imple-
mentation  Plans, which would  require
States to revise their State Implementa-
tion Plans (SIP's) to  include legal en-
forceable procedures requiring  certain
specified stationary  sources to monitor
emissions on a continuous basis. These
requirements would apply to existing fa-
cilities, which are not covered under Part
60.
  Interested parties  participated in the
rulemaking by sending comments to EPA
A  total of 105 comment letters were re-
ceived on the proposed revisions  to Part
60 from monitoring equipment manufac-
turers, data processing equipment manu-
facturers, industrial users of monitoring
equipment, air pollution control agencies
Including State, local, and EPA regional
offices, other Federal agencies, and con-
sultants. Copies of the comment letters
received and a summary of the issues and
EPA's responses are available for Inspec-
tion and copying at the U.S. Environ-
mental Protection Agency, Public Infor-
mation Reference Unit, Room 2922 (EPA
Library). 401 M Street. S.W., Washing-
ton. D.C. In addition, copies of the issue
summary and EPA responses may be ob-
tained upon written request  from  the
EPA  Public Information Center (PM-
2l5i,  401 M Street,  8.W..  Washington.
D.C.  20460  (specify Public  Comment
Summary: Emission Monitoring Require-
ments). The comments have been care-
fully considered, additional Information
has  been collected  and assessed, and
where determined by Ihe Administrator
to be appropriate,  changes have been
made to the proposed regulations. These
changes are Incorporated In the regula-
tions promulgated herein.

             BACKGROUND
  At the time the regulations were pro-
posed (September  11,  1974). EPA had
promulgated  12 standards of perform-
ance for new stationary sources under
section.Ill  of the  Clean Air Act,  as
amended, four of which required  the af-
fected facilities to  install  and operate
systems which continuously monitor the
levels of pollutant emissions,  where the
technical feasibility exists using cur-
rently available continuous monitoring
technology, and where  the cost of  the
     RULES  AND REGULATIONS

systems Is reasonable. When the four
standards that require monitoring sys-
tems were promulgated. EPA had limited
knowledge about the operation of such
systems because only a few systems had
been installed:  thus,  the requirements
were specified  in general terms. EPA
Initiated a program to develop perform-
ance specifications and obtain informa-
tion on the operation  of continuous
monitoring systems. The program was
designed to assess the systems' accuracy.
reliability, costs, and problems related
to installation,  operation, maintenance.
and data  handling. The proposed regu-
lations (39 FR 32852) were based on the
results of this program.
  The  purpose  of regulations promul-
gated herein is to establish minimum
performance  specifications for cdntinu-
ous monitoring systems, minimum data
reduction  requirements, operating pro-
cedures, and  reporting requirements for
those affected facilities  required  to In-
stall  continuous  monitoring systems.
The specifications and  procedures are
designed to assure that the data obtained
from continuous monitoring systems will
be accurate and reliable and provide the
necessary  Information  for determining
whether an owner or operator is follow-
ing proper operation and  maintenance
procedures.
  SIGNIFICANT COMMENTS AND CHANCES
    MADE  To PROPOSED REGULATIONS
  Many of the comment letters received
by  EPA contained multiple  comments.
The most  significant comments and the
differences between  the proposed and
final regulations are discussed below.
  (1)  Subpart  A—General Provisions.
The greatest number of comments re-
ceived pertained to the methodology and
expense of obtaining and reporting con-
tinuous monitoring  system  emission
data. Both air pollution control agencies
and affected  users of monitoring equip-
ment presented  the view  that the pro-
posed  regulations  requiring  that  all
emission data be reported were  exces-
sive, and  that  reports  of only  excess
emissions and retention of all the data for
two  years on  the affected facility's
premises Is sufficient. Twenty-five com-
mentators suggested that the effective-
ness of the operation and maintenance of
an affected facility and its air pollution
control  system  could be  determined  by
reporting only excess emissions. Fifteen
others recommended deleting the report-
Ing requirements entirely.
  EPA' has reviewed these comments and
has contacted vendors of monitoring and
data acquisition equipment  for  addi-
tional information to more fully  assess
the Impact of  the proposed reporting
requirements. Consideration was also
given to the resources that would  be re-
quired  of  EPA  to enforce the proposed
requirement,  the costs  that would  be
Incurred by an  affected source, and the
effectiveness  of  the proposed require-
ment In comparison with a requirement
to report  only  excess  emissions. EPA
concluded   that  reporting  only  excess
emissions would  assure proper operation
and maintenance  of the air pollution
 control equipment and would result  In
 lower costs to the source and allow more
 effective use of EPA resources by elimi-
 nating  the need for handling and stor-
 ing large  amounts of data  Therefore.
 the regulation promulgated herein re-
 quires owners or operators to report only
 excess  emissions  and  to  maintain  a
 permanent record  of all  emission data
 for a period of two years.
   In addition, the proposed specification
 of  minimum data reduction procedures
 has been changed. Rather than requiring
 Integrated averages as proposed, the reg-
 ulations promulgated herein also spec-
 ify a method by which a minimum num-
 ber of data points may be used to com-
 pute average emission rates. For exam-
 ple, average opacity emissions over a six-
 mlnute period may be calculated from a
 minimum  of  24  data  points  equally
 spaced over each six-minute period. Any
 number of equally spaced data points in
 excess  of 24 or continuously integrated
 data may  also be used to compute six-
 minute  averages.  This specification  of
 minimum   computation   requirements
 combined with the requirement to report
 only excess  emissions  provides  source
 owners  and operators  with maximum
 flexibility to select from a wide choice of
 optional  data  reduction  procedures.
 Sources which monitor only opacity and
 which  Infrequently  experience  excess
 emissions  may  choose  to  utilize. strip
 chart recorders, with or without contin-
 uous six-minute  Integrators;  whereas
 sources monitoring two or more pollut-
 ants plus other parameters necessary  to
 convert to units of the emission  stand-
 ard may choose to utilize existing com-
 puters  or  electronic data processes In-
 corporated with the monitoring system.
 All data must be retained for two years,
 but only excess emissions need  be re-
 duced to units of the standard. However.
 in order to report excess emissions, ade-
 quate procedures must be utilized to In-
 sure that excess emissions are identified.
 Here again, certain sources with minimal
 excess  emissions can determine  excess
 emissions by review of strip charts, while
'sources with varying emission and ex-
 cess air rates will most  likely need  to
 reduce all data to units of the standard to
 Identify any excess emissions. The regu-
 lations promulgated herein allow the use
 of extractive, gaseous monitoring systems
 on a time sharing basis by Installing sam-
 pling probes at several locations, provided
 the minimum  number of  data  points
 (four per hour) are obtained.
  Several commentators stated that the
 averaging periods for reduction of moni-
 toring data, especially opacity, were too
 short and  would result in an excessive
 amount of data that must be reduced and
 recorded. EPA evaluated these comments
 and concluded that to be useful to source
 owners and operators as well as enforce-
 ment agencies, the averaging time for the
 continuous  monitoring  data should  be
 reasonably consistent with  the averag-
 ing time for the reference methods used
 during  performance tests. The data re-
 duction  requirements for opacity have
 been substantially reduced because the
 averaging period was changed from one
                                                 III-103

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                                             RULES AND  REGULATIONS
minute, which was proposed, to six min-
utes to be consistent with revisions made
to Method 9 (39 FR 39872).
  Numerous comments were received on
proposed ( 60.13 which resulted In several
changes. The proposed section has been
reorganized and  revised In several  re-
spects to accommodate the comments
and provide ch-.ity.  to more specifically
delineate the equipment subject to Per-
formance Specifications in Appendix B.
and to more specifically define require-
ments for equipment purchased  prior to
September 11,  1974.  The provisions In
I 60.13 are not intended to prevent  the
use of any equipment that can be demon-
strated  to  be  reliable  and  accurate;
therefore, the performance  of monitor-
Ing systems i£ specified in general terms
with minimal references to specific equip-
ment types. The  provisions  in § 60.13(1)
are included to  allow owners or operators
and equipment vendors to apply to  the
Administrator for approval  to use alter-
native equipment or procedures  when
equipment capable of producing accurate
results may not. be commercially avail-
able (e.g. condensed water  vapor Inter-
feres with  measurement  of  opacity),
when unusual circumstances may justify
less costly procedures, or when the owner
or  operator or  equipment  vendor may
•Imply prefer to use other equipment or
procedures that are consistent with his
current practices.
  Several  paragraphs  In  i 60.13  have
been changed on the basis  of the com-
ments received. In response to comments
that the monitor operating frequency re-
quirements did not consider periods when
the monitor Is inoperative  or undergo-
ing maintenance, calibration, and adjust-
ment, the operating frequency  require-
ments have been changed. Also  the fre-
quency of cycling requirement for opacity
monitors has been changed to  be con-
sistent with the  response time  require-
ment In  Performance  Specification   1,
which reflects the capability of commer-
cially available equipment.
  A second area  that received comment
concerns maintenance  performed upon
continuous  monitoring  systems.   Six
commentators noted that the proposed
regulation  requiring extensive retestlng
of continuous monitoring systems for all
minor failures  would discourage proper
maintenance of the  systems. Two  other
commentators noted the difficulty of de-
termining a general list of critical com-
ponents, the replacement of  which would
automatically require a retest of the sys-
tem.  Nevertheless,  it is EPA's  opinion
that some control must be  exercised to
Insure that a suitable monitoring system
is not rendered unsuitable by substantial
alteration or a lack of needed  mainte-
nance. Accordingly, the regulations pro-
mulgated herein  require that owners or
operators submit with the quarterly re-
port information on any repairs or modi-
fications made to the system during the
reporting period. Based  upon this Infor-
mation, the Administrator  may review
the status of the monitoring system with
the owner or operator and, if determined
to be necessary, require retesting of  the
continuous monitoring system (•).
   Several commentators noted that the
 proposed reporting requirements are un-
 necessary for affected facilities not re-
 quired to Install continuous  monitoring
^ystems. Consequently, the  regulations
 promulgated herein do not contain the
 requirements.
   Numerous comments  were received
 which indicated that some  monitoring
 systems may not be compatible with the
 proposed  test  procedures  and require-
 ments.  The comments were evaluated
 and, where appropriate, the  proposed
 test procedures and  requirements  were
 changed.  The  procedures  and require-
 ments promulgated herein are applicable
 to the majority  of acceptable systems:
 however, EPA recognizes that there may
 be  some  acceptable  systems  available
 now or in  the  future which could not
 meet the  requirements. Because of this,
 the regulations promulgated herein In-
 clude a provision which allows the Ad-
 ministrator to approve alternative testing
 procedures. Eleven commentators noted
 that adjustment of the monitoring in-
 struments may not be necessary as  a re-
 sult of dally zero and span checks. Ac-
 cordingly, the  regulations promulgated
 herein require  adjustments  only when
 applicable 24-hour drift limits are ex-
 ceeded. Pour commentators  stated that
 it Is not necessary to introduce calibra-
 tion gases near the probe tips. EPA has
 demonstrated in  fleld evaluations that
 this requirement is necessary in order to
 assure accurate  results; therefore, the
 requirement has been retained. The re-
 quirement enables detection of any dilu-
 tion or absorption of pollutant gas by the
 plumbing and conditioning systems prior
 to the  pollutant  gas entering the gas
 analyzer.
   Provisions have been  added to these
 regulations to require that the gas  mix-
 tures used for the daily calibration check
 of extractive continuous monitoring sys-
 tems be traceable to National Bureau of
 Standards  (NBS) reference gases.  Cali-
 bration  gases  used to conduct  system
 evaluations  under  Appendix  B  must
 either be  analyzed prior to use or shown
 to be traceable to NBS materials. This
 traceablllty requirement will assure the
 accuracy  of the calibration gas mixtures
 and the comparability of data from sys-
 tems at all locations. These  traceability
 requirements will not be applied when-
 ever the NBS materials are not available.
 A list of available NBS Standard Refer-
 ence Materials  may be obtained from the
 Office of Standard Reference Materials,
 Room B311. Chemistry Building,  Na-
 tional Bureau of Standards, Washington,
 D.C. 20234.
   Recertincatlon  of  the continued ac-
 curacy of the calibration gas mixtures Is
 also necessary  and should be performed
 at Intervals recommended by  the  cali-
 bration gas mixture manufacturer. The
 .NBS materials and calibration gas  mix-
 tures traceable to these materials should
 not be used after expiration of  their
 stated shelf-life. Manufacturers of cali-
 bration gas mixtures generally use NBS
 materials   for   traceability   purposes,
 therefore, these amendments to the reg-
ulations will  not Impose additional re-
quirements upon most manufacturers.
  (2)  Subpart  - D—Fossil-Fuel  Fired
Steam Generators. Eighteen commenta-
tors  had questions or remarks concern-
Ing the proposed revisions dealing with
fuel  analysis. The  evaluation of these
comments and discussions with coal sup-
pliers and electric utility companies led
the  Agency to conclude that the pro-
posed -provisions for fuel analysis are not
adequate or consistent with the  current
fuel  situation. An attempt was made to
revise the proposed provisions; however,
it became apparent  that  an in-depth
study would be necessary before mean-
ingful provisions could be developed. The
Agency has decided to promulgate all of
the regulations except those dealing with
fuel  analysis. The  fuel analysis provi-
sions of Subpart D have been reserved
in the regulations promulgated  herein.
The Agency has initiated a study to ob-
tain the necessary Information  on the
variability of sulfur content in fuels, and
the capability of fossil fuel fired steam
generators to  use  fuel analysis and
blending to prevent excess sulfur dioxide
emissions. The results of this study will
be used to determine whether fuel anal-
ysis  should  be allowed as a means of
measuring  excess emissions,  and if al-
lowed, what procedure  should  be re-
quired.  It  should be pointed out that
this  action does not afiect facilities which
use  flue gas desulfurizatlon as a means
of complying with  the  sulfur  dioxide
standard; these  facilities are still re-
quired  to  Install continuous emission
monitoring systems for  sulfur  dioxide.
Facilities which  use low sulfur fuel as a
means of complying with the sulfur di-
oxide standard  may use a  continuous
sulfur dioxide monitor or fuel analysis.
For  facilities that elect to use fuel anal-
ysis  procedures, fuels  are not required
to be sampled or analyzed  for prepara-
tion of reports of excess emissions until
the Agency finalizes the procedures and
requirements.
  Three   commentators  recommended
that carbon dioxide continuous monitor-
ing systems be allowed as an alternative
for oxygen monitoring for measurement
of the amount of diluents in flue gases
from steam   generators.  The  Agency
agrees with this recommendation  and has
Included a provision which allows the use
of carbon  dioxide monitors. This -pro-
vision allows  the use of pollutant moni-
tors that produce data on a wet  basis
without requiring additional equipment
or procedures for correction of data to a
dry basis. Where CO, or O, data  are not
collected on a consistent basis  (wet or
dry)  with the pollutant data, or where
oxygen is measured  on a wet basis, al-
ternative procedures to provide  correc-
tions for stack moisture and excess air
must be approved by the Administrator,
Similarly, use of a carbon  dioxide con-
tinuous monitoring system downstream
of a flue gas desulf urization system is not
permitted without  the Administrator's
prior approval due to  the potential for
absorption of CO, within the  control
device. It should be noted that when any
fuel  is fired directly in the stack gases
                                                    III-104

-------
                                             «ULES AND IEOULATIONS
for reheating, the T and F,  factors
promulgated herein must be prorated
based upon the total  heat Input of the
fuels fired within the facility regardless
of the locations of fuel firing. Therefore.
any facility using a flue gas desulfuriza-
Uon system may be limited to dry basis
monitoring  Instrumentation due to the
restrictions on use of a CO diluent moni-
tor unless water vapor Is also measured
subject to the Administrator's approval.
  Two commentators  requested  that an
additional factor (F •) be developed for
use with oxygen continuous monitoring
systems that measure flue gas diluents on
a wet basis. A factor of this  type was
evaluated by EPA. but is not being pro-
mulgated with  the regulations  herein.
The error in the accuracy of the factor
may exceed  ±5 percent without  addi-
tional measurements to correct  for va-
riations in flue gas moisture content due
to fluctuations In ambient humidity or
fuel moisture content. However. EPA will
approve installation of wet basis oxygen
systems on  a case-by-case basis If the
owner or operator will proposed use of
additional measurements and procedures
to control the accuracy of the P.. factor
within acceptable limits. Applications for
approval of such systems should include
the frequency  and type  of  additional
measurements proposed and the resulting
accuracy of the  F« factor under the ex-
tremes    of    operating    conditions
anticipated.
 •r One commentator stated that the pro-
posed requirements for recording heat
input are superfluous because this infor-
mation Is not needed to convert monitor-
Ing data to units of the applicable stand-
ard. EPA has reevaluated  this require-
ment and has determined that the con-
version of excess emissions into  units of
the standards  will be based  upon the
P factors and that measurement of the
rates of fuel firing will not be needed ex-
cept when combinations of fuels are fired.
Accordingly, the regulations promulgated
herein require such measurements only
when multiple fuels are fired.
  Thirteen commentators questioned the
rationale for the proposed Increased op-
erating temperature  of  the Method 5
sampling train for fossil-fuel-fired steam
generator  particulate  testing and the
basis  for raising rather than lowering
the temperature. A brief discussion of the
rationale behind this revision was pro-
vided In the preamble to  the proposed
regulations, and a more detailed discus-
sion is provided  here. Several factors are
of primary importance In developing the
data base for a standard of performance
and in specifying the reference  method
for use in conducting a performance test.
Including:
  a. The method used for data gathering
to  establish a  standard  must  be the
aame as. or must have a known relation-
ship to. the method subsequently estab-
lished as the reference method.
  b. The method should measure pollut-
ant emissions indicative of  the perform-
ance of the best systems of emission re-
duction. A method meeting this criterion
will not  necessarily measure  emissions
as they would exist after  dilution and
 cooling to ambient temperature and pres-
 sure, as would occur upon release to the
 atmosphere. As such, an emission factor
 obtained through use of such a method
 would, for example, not necessarily be of
. use in an ambient dispersion model. This
 seeming inconsistency results from the
 fact that standards of performance are
 intended to result In Installation of sys-
 tems of emission  reduction which  are
 consistent with best demonstrated tech-
 nology, considering cost. The Adminis-
 trator, in establishing such standards, is
 required to  Identify best  demonstrated
 technology and to develop  standards
 which reflect such technology. In order
 for these  standards  to  be meaningful.
 and for the required control technology
 to be predictable, the compliance meth-
'ods must  measure emissions which are
 indicative  of the performance  of such
 systems.
   c. The method should include sufficient
 detail as needed  to produce  consistent
 and reliable test results.
   EPA relies primarily upon Method 5
 for gathering a consistent data base  for
 particulate matter standards. Method 5
 meets the above criteria by providing de-
 tailed  sampling methodology  and  in-
 cludes an out-of-stack filter to facilitate
 temperature control. The latter is needed
 to define particulate matter on a com-
 mon basis since it is a function of tem-
 perature and is not an absolute quantity.
'If temperature is not controlled, and/or
 if the effect of temperature upon particu-
 late formation is unknown, the effect on
 an emission control limitation for partic-
 ulate matter may be  variable and un-
 predictable.
   Although selection of temperature can
 be varied from industry to industry, EPA
 specifies a nominal sampling tempera-
 ture of 120" C for most source categories
 subject to standards of  performance.
 Reasons for selection of 120° C  Include
 the following:
   a.  Filter temperature  must  be held
 above 100° C at sources where moist gas
 streams are present. Below 100° C, con-
 densation can occur with resultant plug-
 ging of filters and possible gas/liquid  re-
 actions. A temperature of 120" C allows
 for  expected  temperature  variation
 within the train, without dropping below
 100° C.
   b. Matter existing in particulate form
 at 120° C is indicative'of the perform-
 ance of the best particulate emission  re-
 duction systems for most industrial proc-
 esses. These Include systems of emission
 reduction that may involve-not only the
 final control device, but also the process
 and stack  gas conditioning systems.
   c. Adherence to one established tem-
 perature  (even though  some variation
 may be needed  for some source categor-
 ies) allows comparison of emissions from
 source category to source category. This
 limited standardization used in the de-
 velopment of standards of performance
 is a benefit to equipment vendors and to
 source owners by providing a consistent
 basis for comparing test results and pre-
 dicting control system performance. In
 comparison,   In-stack  filtration  takes
 place at stack temperature, which usually
 Is not constant from one source to the
 next. Since the temperature varies, in-
 stack filtration does not necessarily pro-
 vide a consistent definition of particulate
 matter and does not allow for compari-
 son of  various  systems of control. On
 these bases. Method 5  with a sampling
'filter temperature controlled at approxi-
 mately 120* C was promulgated as the
 applicable test method for new fossil-fuel
 fired steam generators.
   Subsequent to the promulgation of the
 standards  of  performance for steam
 generators, data became available  indi-
 cating that certain combustion products
 which do not exist as particulate matter
 at the elevated temperatures existing in
 steam generator stacks may be collected
 by Method 5 at lower temperatures (be-
 low 160°  C). Such material, existing In
 gaseous  form  at  stack   temperature,
 would not be controllable by emission re-
 duction systems involving  electrostatic
 preclpltators    (ESP).   Consequently,
 measurement of such condensible matter
 would not be indicative of the  control
 system performance. Studies conducted
 in the past two years have confirmed that
 such condensation can  occur. At sources
 where fuels containing 0.3 to 0.85 percent
 sulfur were burned, the incremental in-
 crease in particulate matter concentra-
 tion resulting from sampling at 120' C
 as compared to about 150°  C was found
 to be variable, ranging  from 0.001 to
 0.008 gr/scf. The variability Is not neces-
 sarily predictable, since total sulfur  oxide
 concentration, boiler design and opera-
 tion, and  fuel additives each appear to
 have a potential effect.  Based upon  these
 data, it Is concluded that the potential
 increase In particulate  concentration at
 sources meeting the standard of per-
 formance  for sulfur oxides is not a seri-
 ous problem in comparison with the par-
 ticulate standard which is approximately
 0.07 gr/scf. Nevertheless, to insure that
 an unusual case will not occur where a
 high concentration of  condensible  mat-
 ter, not controllable with an ESP. would
 prevent attainment of the particulate
 standard,  the sampling temperature al-
 lowed at fossil-fuel fired steam boilers is
 being raised to 160° C. Since  this  tem-
 perature is attainable at new steam gen-
 erator stacks, sampling at temperatures
 above 160° C would not yield results nec-
 essarily representative of the capabilities
 of the best systems of emission reduction.
 .  In evaluating  particulate  sampling
 techniques and the effect  of sampling
 temperature, particular  attention has
 also been given  to the possibility that
 SO, may  react In the front half of the
 Method 5 train to form particulate mat-
 ter.- Based upon a series of comprehen-
 sive tests involving both source and con-
 trolled environments, EPA has developed
 data that show such reactions do not oc-
 cur to a significant degree.
   Several control agencies commented on
 the increase in sampling  temperature
 and suggested that the need Is for  sam-
 pling at lower, not higher, temperatures.
 This is a  relevant comment and is one
 which must be considered in terms of the
 basis upon which  standards are estab-
 lished.
                                                      III-105

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  For existing boilers which are not sub-
ject to  this standard, the existence  of
higher stack  temperatures and/or the
use of higher sulfur fuels may result  in
significant condensation  and resultant
high  indicated  participate  concentra-
tions when sampling  is  conducted  at
120° C. At one r.oal fired steam generator
burning coal  containing  approximately
three percent sulfur, EPA  measurements
at 120° C showed an Increase of 0.05 gr/
dscf over an average of seven runs com-
pared to samples collected at approxi-
mately 150° C. It is believed that this In-
crease  resulted,  in  large part.  If not
totally,  from  SO]  condensation  which
would occur also when the stack emis-
sions are released into the atmosphere.
Therefore, where standards are based
upon emission reduction to achieve am-
bient air quality standards rather than
on  control technology (as is  the  case
with the standards promulgated herein),
a lower sampling temperature may  be
appropriate.
  Seven commentators questioned the
need for  traversing for  oxygen at  12
points within a duct during performance
tests. This requirement, which is being
revised  to  apply only  when  partlculate
sampling is performed  (no more than  12
points are required) is Included  to in-
sure that potential stratification  result-
Ing  from  air in-leakage  will not ad-
versely  affect  the accuracy of  the
paniculate test.
  Eight commentators stated  that the
requirement for  continuous  monitoring
of nitrogen oxides should  be deleted be-
cause only two air quality control re-
gions have ambient levels of nitrogen
dioxide that exceed the national ambient
air quality standard for nitrogen dioxide.
Standards of  performance Issued under-
section 111 of the Act are designed to re-
quire affected  facilities to  design and in-
stall the best systems of emission reduc-
tion (taking into account the cost of such
reduction). Continuous emission mon-
itoring  systems are required to  insure
that the  emission control systems are
operated and  maintained properly. Be-
cause of this, the Agency does not 'feel
that it is  appropriate to delete the  con-
tinuous emission monitoring system re-
quirements for nitrogen oxides; however.
In evaluating these comments the Agency
found  that some situations may exist
where the nitrogen oxides monitor is not
necessary  to  insure  proper operation
and maintenance. The quantity of nitro-
gen oxides emitted from certain types Of
furnaces Is considerably below the nitro-
gen oxides emission limitation. The low
emission level is  achieved through the
design of the  furnace  and does not re-
quire specific  operating  procedures  or
maintenance  on a continuous basis  to
keep the nitrogen oxides emissions below
the  applicable standard.  Therefore,  In
this situation,  a  continuous  emission
monitoring system for nitrogen oxides is
unnecessary.  The  regulations promul-
gated herein do  not require continuous
emission monitoring systems for nitrogen
oxides on facilities whose emissions are
30 percent or  more below the applicable
standard.
     AULES AND KEGULATIONS

  Three  commentators  requested  that
owners or operators of steam generators
be permitted to use NO, continuous mon-
itoring systems  capable of measuring
only nitric oxide (NO) since the amount
of nitrogen  dioxide  (NO:) in the flue
gases is comparatively small. The reg-
ulations proposed and those promulgated
herein allow use of such systems or any .
system meeting all of the requirements
of Performance  Specification 2  of Ap-
pendix B. A system that measures only
nitric oxide (NO) may meet these specifi-
cations including the relative accuracy
requirement (relative to the reference
method tests which measure NO + NO,)
without modification. However,  in the
Interests of maximizing  the accuracy of
the system and creating conditions favor-
able to acceptance of such systems (the
cost of  systems  measuring only NO is
less). the owner or operator may deter-
mine the proportion of  NO: relative to
NO in the flue gases and use a factor to
adjust the continuous monitoring system
emission data (e.g.  1.03 x  NO = NO,)
provided that  the factor is applied not
only to the performance  evaluation data,
but also applied consistently to all data
generated by the continuous monitoring
system thereafter. This procedure Is lim-
ited to facilities that have less than 10
percent NO,  (greater than 90 percent
NO) in order to not seriously Impair the
accuracy of the system due to NOi to NO
proportion fluctuations.
  Section 60.45(g) (1) has been reserved
for the future  specification of the excess
emissions for opacity that must be re-
ported. On November 12,  1974  (39 FR
39872).  the Administrator  promulgated
revisions to Subpart A, General Provi-
sions, pertaining to the opacity provi-
sions and to Reference Method 9. Visual
Determination of the Opacity of Emis-
sions  from  Stationary  Sources.  On
April 22,1975 (40 PR 17778), the Agency
issued a notice soliciting comments on
the  opacity provisions  and Reference
Method 9. The Agency Intends to  eval-
uate  the comments  received and make
any  appropriate revision to the  opacity
provisions and Reference Method  9. In
addition,  the Agency is evaluating the
opacity standards  for  fossil-fuel  fired
steam generators under -i 60.42(a) (2) to
determine if changes are needed because
of the new Reference Method 9. The pro-
visions on excess emissions for  opacity
will be issued after the Agency completes
Its evaluation of the opacity standard.
   (3)  Subpart O—Nitric  Acid  Plants.
Two commentators questioned the long-
term validity of the proposed conversion'
procedures for reducing data to units of
the standard.  They  suggested that the
conversion could  be accomplished  by
monitoring the flue gas  volumetric rate.
EPA reevaluated the proposed procedures
and  found that monitoring the flue gas
vplume would be the most direct  method
and would also be an accurate method of
converting monitoring data,  but would
require the Installation of an additional
continuous monitoring system. Although
this option is available and would be ac-
ceptable  subject to the Administrator's
approval, EPA does not believe that the
additional expense this method  (moni-
toring volumetric rate) would entail is
warranted. Since nitric acid plants, for
economic  and technical reasons, typi-
cally  operate  within  a fairly  narrow
range of  conversion efficiencies (90-96
percent) and tail gas diluents (2-5 per-
cent oxygen), the flue gas volumetric
rates are reasonably  proportional to the
acid production  rate.  The error that
would be Introduced  into the data from
the maximum variation of these param-
eters  is  approximately 15  percent  and
would usually be much less. It is expected
that the tail gas oxygen concentration
(an indication of the degree of tail gas
dilution) will be rigidly controlled at fa-
cilities using catalytic  converter control
equipment.  Accordingly, the  proposed
procedures for data conversion have been
retained due to the small  benefit that
would result from requiring additional
monitoring equipment.  Other procedures
may be approved by the Administrator
under 160.13(1).
   (4) Subpart H—Sulfurlc Acid Plants.
Two commentators stated that the pro-
posed procedure for conversion of moni-
toring data  to  units  of the standard
would  result  in large data  reduction
errors. EPA has evaluated  more closely
the operations of sulf uric acid plants and
agrees that the proposed procedure is in-
adequate. The proposed conversion pro-
cedure assumes  that the operating con-
ditions  of the affected facility  will re-
main approximately the same as during
the continuous monitoring system eval-
uation tests. For sulfuric acid plants this
assumption is  invalid. A  sulfuric  acid
plant is typically designed  to operate at
a  constant   volumetric   throughput
(scfm). Acid production rates are altered
by by-passing portions of the process air
around the furnace or  combustor to vary
the concentration of  the  gas entering
the converter. This  procedure produces
widely varying amounts of  tail gas dilu-
tion relative to the production rate. Ac-
cordingly, EPA  has  developed new con-
version procedures whereby the appro-
priate  conversion  factor  is  computed
from en analysis of the SO: concentra-
tion entering the converter. Air injection
plants must make additional corrections
for the diluent  air added.  Measurement
of the inlet 8O: is a  normal quality con-
trol procedure used by  most sulfuric acid
plants and does not represent an addi-
tional  cost  burden.  The Reich test or
other suitable procedures may be used.
   (5) Subpart J—Petroleum Refineries.
One commentator stated  that the re-
quirements for Installation  of continuous
monitoring systems for oxygen and fire-
box temperature  are  unnecessary  and
that installation of a flame detection de-
vice would be superior for process con-
trol purposes. Also, EPA  has obtained
data  which show no  identifiable rela-
tionship between furnace  temperature,
percent oxygen in the  flue  gas, and car-
bon monoxide emissions when the facil-
ity is operated'in compliance with the
applicable standard. Since firebox tem-»
perature and oxygen measurements may
not be  preferred by source owners and
operators for process control,  and no
                                                     III-106

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                                            tULES  AND REGULATIONS
known method Is available for transla-
tion of these measurements into quanti-
tative reports of excess carbon monoxide
emissions, this requirement appears to
be of little use to the affected  facilities
or to EPA. Accordingly, requirements for
Installation  of continuous  monitoring
systems  for  measurements  of firebox
temperature and oxygen are deleted from
the regulations.
  Since EPA has  not yet developed per-
formance specifications for carbon mon-
oxide or  hydrogen  sulflde  continuous
monitoring systems, the  type of equip-
ment that may be Installed by an owner
or operator in compliance with EPA re-
quirements Is  undefined.  Without con-
ducting performance evaluations of such
equipment, little reliance can be placed
upon the value of any data such systems
would generate. Therefore, the sections
of the regulation requiring these systems
are being reserved  until  EPA  proposes
performance specifications applicable to
HrS and CO  monitoring systems.  The
provisions of 5 60.l05(a) (3) do not apply
to an owner or operator electing to moni-
tor H;S. In that case, an H;S monitor
should not be installed until specific HrS
monitoring  requirements are  promul-
gated. At the time specifications are pro-
posed, all owners or operators who have
not entered into binding contractual ob-
ligations to purchase continuous moni-
toring equipment by [date of publication!
will be  required  to Install  a carbon
monoxide continuous monitoring system
and a hydrogen sulflde continuous moni-
toring system  (unless a  sulfur dioxide
continuous monitoring system has been
Installed) as applicable.
   Section 60.105(a)(2). which specifies
the excess emissions for capacity  that
must be reported, has been reserved for
the same reasons discussed under  fossil
fuel-fired steam generators.
   (6) Appendix B—Performance Speci-
fications. A large number of comments
were  received  in reference to specific
technical and  editorial changes needed
in the specifications. Each of these com-
ments  has  been reviewed  and several
changes in format and procedures have
been  made. These include adding  align-
ment  procedures for opacity  monitors
and more specific instructions for select-
ing a location for installing the monitor-
Ing equipment. Span requirements have
been specified so that commercially pro-
duced equipment may be standardized
where possible. The format of the  speci-
fications was simplified by redefining the
requirements in terms of percent opacity.
or oxygen, or carbon dioxide, or percent
of span. The proposed requirements were
in terms  of  percent of the emission
standard which is less convenient  or too
 vague  since reference to the emission
 standards would have  represented  a
 range  of pollutant  concentrations de-
 pending upon the amount of diluents (i.e.
 excess  air and water vapor)  that are
 present in the effluent. In order to cali-
 brate  gaseous monitors  In  terms of a
'specific concentration, the requirements
 were revised  to  delete reference to the
 emission standards.
   Four commentators noted that the ref-
•erence methods used to evaluate con-
tinuous monitoring system performance
may be less accurate than the systems
themselves.  Five  other  commentators
questioned the need for 27 nitrogen ox-
ides reference  method tests. The ac-
curacy specification for gaseous monitor-
ing systems was specified at 20 percent, a
value in excess  of the actual accuracy
of monitoring systems that provides tol-
erance for reference method Inaccuracy.
Commercially   available   monitoring
equipment has been evaluated using these
procedures and the combined errors (i.e.
relative accuracy)  in the reference meth-
ods  and the monitoring  systems have
been shown not to exceed 20 percent after
the  data  are averaged by the specified
procedures.
  Twenty commentators noted that the
cost, estimates contained in the proposal
did  not  fully reflect installation costs.
data reduction and recording costs, and
the  costs of evaluating the  continuous
monitoring  systems. As  a result, EPA
reevaluated the  cost analysis. For opac-
ity  monitoring  alone.  Investment costs
including data reduction equipment and
performance tests  are   approximately
$20.000. and annual operating costs are
approximately $8.500. The same location
on the stack used for conducting per-
formance tests with Reference Method 5
(participate) may  be used by Installing
a separate set of ports for the monitoring
system so that no additional expense for
access is required. For power plants that
are  required to  install opacity, nitrogen
oxides, sulfur dioxide, and diluent  (Or
or CO,)  monitoring systems, the  Invest-
ment cost is approximately $55,000, and
the operating cost is approximately $30,-
000. These are significant costs but are
not unreasonable in comparison to the
approximately  seven million dollar In-
vestment cost  for the smallest steam
-generation facility affected by these regu-
lations.
   Effective  date.  These regulations are
 promulgated under the authority of sec-
 tions  111. 114 and 301 (a) of the Clean
 Air Act as amended [42 U.S.C. 1857c-fl",
 1857c-9, and 1857g(a) ] and become ef-
 fective October  6. 1975.
   Dated: September 23,1975.
                    JOHN OVARIES.
                Acting Administrator.
    FEDHAl KOtSTR. VOL 40. NO. 1*4-

        -MONDAY, OCTOMI «,  <*7S
                                                          III-107

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                                              RULES AND REGULATIONS
    Title 40—Protection of Environment
      CHAPTER  I—ENVIRONMENTAL
          PROTECTION AGENCY
       SUBCHAPTER C—AIR  PROGRAMS
               |FRL 423-6)

 JART  51—REQUIREMENTS  FOR  THE
   PREPARATION.  ADOPTION  AND SUB
   MITTAL OF  IMPLEMENTATION  PLANS
 Cmission Monitoring of Stationary Sources
   On September  11,  1974.  the  Environ-
 mental Protection  Agency  (EPA)  pro-
 posed revisions to 40 CFR Part 51. Re-
 quirements for the  Preparation. Adop-
 tion,  and Subinittal of  Implementation
 Plans. EPA proposed to expand  5 51.19 to
 require  Stales 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-
 posed 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 contfnuous emission monitor-
 ing instruments.  (5>  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  of
 nitrogen and oxygen);
   (b) Oil-fired steam generators of more
 than 250 million BTU per hour heat In-
 put (sulfur dioxide, oxides of  nitrogen
 and oxygen). An opacity monitor was re-
 quired only if an emission control device
 is needed to  meet  partlculate  emission
 regulations,  or if violations of  visible
 emission regulations are noted;
   (c)  Nitric  acid  plants  (oxides   of
 nitrogen);
   (d) Sulfuric  acid plants (sulfur 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-
po^ed regulation* for Part 51 (|.c.._those
relating to SIP's and existing  sources i
included by .reloronrc many specific tech-
nical details set lorth 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-
making 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
comments 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  com-
mcntors suggested that a determination
of the sources which should install con-
tinuous monitors should be made on a
case-by-case basjs. Almost all objected to
the data reporting requirements stating
that  the proposed requirement of sub-
mission of all collected data was excessive
ami 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 5l.ll(a)(6». This requirement
was designed to partially implement the
requirements of Sections 110(a) (2) (F)
Mi) and (HI)  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  (ill)  should
now be more fully implemented.
  The  Administrator believes that  a
sound program of continuous emission
monitoring and reporting wUl 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
                               FtDHAt UOISTII. VOL. 40. NO.  1»4—MONDAY, OCTOKI 4, WS
                                                        III-108

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                                              RULES AND REGULATIONS
 once per year, and In some case*, affected
 sources probably have never been tested.
 Manual stark  tests are generally  per-
 formed under  optimum  operating  con-
 ditions, and as such, do not reflect the
 lull-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
 conducted for a relatively short  period
 of time (e.g.. one to three hours*,  they
 cannot be 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 a 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-mtnimize emissions
 to the  atmosphere  and  to assure that
 full-time control  efforts, 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
 •ources on  a case-by-case basis were  left
 to the States,  that  some States would
 probably  not undertake an  adequate
 emission  monitoring  program.   Some
 State Agencies who  commented on  the
 proposed  regulations  questioned   the
 •tete-of-the-art of emission monitoring
 ww stated their opinion that the pro-
 P«««d   requirement* were   premature
 TlwrtloTft.  K  u the  Administrator's
           (bat. In order to assure  an
 adequate  nationwide  emission  monl-
 torini: procnirn. minimum emission mon-
 itoring requirements must be established.
   Thr source categories  affected by the
 regulations  were selected because  they
 are significant sources of emissions and
 because the  Agency's work at the time of
 the proposal of these regulations In the
 field of continuous omission  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-
 ment', 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 o/ Major Comments. Many
 eommentors 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.  $20.000; for  sulfur  dioxide
 and oxygen  or  oxides  of nitrogen  and
 oxygen,  $30.000:  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 10? :or 8 years arc: $8.500: $16.000:
 and $30.000  respectively  for  the cases
 described above.(l)
  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 ran
 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 monitoring equipment can
be incorporated at the time of plant de-
sign. This feature is not available for ex-
 isting sources, hence higher costs gei
 rrally result.  Actual costs of Installalir
 at existing sources may  vary from 01
 to five times the cost of normal installs
 tion at  new sources, and in some casi
 even higher costs can result. For exam
 pic. discussions with instrument suppli
 ers indicate that a typical cost of instal
 latlon of an opacity monitor on an exist
 Ing source may be two to three times tlv
 purchase price of the monitor. Difficul
 tics also exist for Installation of gaseou
 monitors nt existing sources.
   It should be noted that these instal In
 tion costs Include material costs for seal
 folding, ladders,  sampling  ports  an'
 other items necessary to provide acces
 to a lo:atlon  where source emissions cai
 be measured. It  is the Agency's oplnio:
 that such  costs cannot be solely attrib
 uted to these continuous emission moni
 toring  regulations.  Access  to samplini
 locations Is generally necessary to dc
 termlne compliance with applicable stat>
 or local emission limitations  by routln<
 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 commentors
 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 n
 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
 proposed 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 commentors 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-
                              HDfl^l If Omit, VOL  40, NO. 1*4—MONDAY. OCTOIII *,  WS
                                                 III-109

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                                             RULES AND REGULATIONS
nlflcant  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 somf 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) 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
• 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
atmosphere.  Since many control  agen-
cies prior  to that  announcement had
adopted emission regulations  that were
determined to  be needed based  upon
these erroneous data, and since new data.
collected by  other  measurement tech-
niques, indicated  that 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.  1974. 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
Anceles Intrastatc  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 suggested that
smaller  sized units, particularly steam -
generating unite 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 unite are operated
to supply electricity during  periods of
maximum system demand. Unite  which
are  operated  for intermediate service
between the extremes of baseload and
peaking are termed cycling unite.
  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 unite are
older,  smaller, of lower efficiency, and
more costly to operate than base load or
cycling unite. Cycling unite are also gen-
erally  older, smaller and  less efficient
than base load unite. Since the expected
life of peaking unite is relatively short
and total emissions from such unite 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 unite at the upper  end of
the capacity factor range  Hence, the
final regulations do not affect any boiler
that has an annual boiler capacity factor
of less  than 30%. Monitoring require-
ments  will thus be more cost effectively
applied to the newer, larger, and more
efficient  units  that  burn  a  relatively
larner 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-
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                                              RULES AND  REGULATIONS
 ply  with  the proposed regulations. For
 fossil fuel-fired steflm generating units.
 the  exemption  relating to  the  annual
 boiler capacity  fnctor  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 regulations allow thnt any
 source that  Is  scheduled  to be  retired
 within five years of the Inclusion of mon-
 itoring requirements 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 rease
 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 f2) 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
regulationsvr.equlred 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 particular 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 smallcr-
 sizod 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  lamer-sized units.  '2>
 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 si7.e and
 the type  of  unit.  In general, the larner
 units produce  more oxides  of nitroRcn
 emissions. The Agency  therefore finds
 that the minimum size of a unit affected
 by the final regulatioas 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,  have the effect of exempt-
 ing  approximately 567r  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 78r.r
 of the potential oxides of nitroccn emis-
 sions from such sources.'2 >  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 50T
 of the steam generators greater than 250
 million  BTU per  hour heat Input,  yet
 they  emit 80 <5 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 monltorinc and rcportinq require-
 ments. Specifically, for nitric arid 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 797*  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 467.-.
 (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 been 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 acid plants at the present
 time will be affected by these monitoring
 requirements.
   Similarly, evaluations of sulfuric acid
 plants 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 377' and  39% respectively
 of such plants on a  national basis from
 these emission  monitoring and reporting
 rcauirements.  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
 such 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-
                              FIOIIAl U6ISTII, VOL.  40. NO. 194—MONDAY. OCTOIfl 6. 1t75
                                                          Ill-Ill

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                                               RULES AND  REGULATIONS
  ted  to  the State. It was generally indi-
  cated by the commentors that the datn
  reportinp  requirements were excessive.
  Commentors  questioned the purpose of
  reporting all  measured data while some
  State agencies indicated they hnve lim-
  ited resources t"1 handle such informa-
  tion. EPA believes that, in some cases.
  the  commentors misconstrued the data
  reporting  reouirements  for  existing
  sources. In light of each of these com-
  ments, the final regulations, with respect
  to the  data  reporting  requirements for
  gaseous 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-
  atnined 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
  for oil noted violations of applicable reg-
  ulations.
   The proposed data reporting require-
  ments for opacity have also been modi-
  fied.  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  cither by
 arithmetically avcraping 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 States  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 iastalled. 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  durine  each quarter
to the  State. Further,  the State  must
have procedures 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  legally enforceable procedures  to
reouire a source to conduct a new per-
formance test whenever,  on the basis  of
available information, the -State deems
such test is necessary.
  The  time period proposed for the In-
stillation  of the  reauired monltorine
system, i.e.. one vpar after plan apnroval.
wns thought, hv 21 commentors to be too
hrjpf. orlmarilv because of lack  of avail-
able instruments, the lack of trained ner-
snnnrl and  the  time available for Instal-
lation of the required monitors. Eauip-
ment  suoolicrs  were  contacted by the
Agency and thev confirmed the avail-
ability  of emission  monitors. However.
                               FIDMAl MCISTEI. VOL. 40, NO. 1»4—MONDAY, OCTOUI », 197S
                                                         III-112

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                                             RULES  AND REGULATIONS
 the  Administrator has determined that
 the  time necessary for purchase. Inslal-
 lation and  performance tr.Miiu: of .such
 monitors may require morr than  one
 year for rcrtnin  installations, especially
 where gaseous monitors nre required. In
 order to provide sources with n in pic time.
 the Agency has modified the final reputa-
 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 monitoring regula-
 tions. A provision is also included  to al-
 low, on a case-by-cnse bnsis. additional
 extensions for sources where good 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  agencies
 also commented on the lack of time pro-
 vided sources to Install the monitors re-
 quired  by  the  proposed  regulations.
 These agencies 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 submittnl of plan
 revisions to require emission monitoring
 and  reporting  is  Justified  and prudent.
 Hence. States must submit plan revisions
 to satisfy the requirements of  this sec-
 tion  within  one year of promulgation 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 Unit this lime period
will  provide aclcciuntr  time to  amortize
the  cosl  of such equipment.  In  cases
where  existing  emission monitors are
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 specifically 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.  Stales should use
their  judgment  In Implementing  these
reciulicmcnts 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-
porting' by more routine methods, such
ns  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. Stales 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. Com-
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 suggestion and an ex-
emption for such sources burning oil and
gas 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 n fleeted by Part 60.
Many of the comments received on the
proposed regulations 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-
Inn techniques: requirements for report-
ing repairs and replacement parts  used;
location  of   monitoring   Instruments:
changes to  span  requirements, operating
                              HOIIAl MOUTH, VOL 40. NO. 1*4—MONDAY, OCTOBEI *, 1975
                                                              III-113

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                                              RULES AND REGULATIONS
 frequency requirements, sulfuric ncld and
 nitric  acid  plant conversion  factors:
 and. for opacity monitoring equipment.
 chances in the cycling time and in allcn-
 mcnt  procedures. The  reader  is cau-
 tioned, however, that specific reference
 to regulations In  the Part 60 Preamble
 IK strictly to federal ..ew Source Perform-
 ance Regulations rather than SUile 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 number of legal
 issues  were raised. Several  commentors
 questioned EPA's  statutory  authority .to
 promulcate 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(a) (2(H>
 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 cognizance of Section
 110 (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
 301 fa) 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 rrtiuirements in order to
carry out its function of assuring that the
Act is properly implemented.
  In EPA's  Judcnicnt, the  requirements
set forth  in ? 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 oxypon 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 i!  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 Clori/ica-
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
arc 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 five years of the inclusion of moni-
torinc requirements for the source in
Appendix P.
  <4> Revisions to exempt smaller-sized
sources  t»nd  infrequently used  sources
within the specified source cateRories
  <5> A  revision  to the data reporting
requirements to-requlre the submillal by
tlir source of the State, emission data in
excess of the applicable  emission limita-
tion for  both opacity and  gaspous  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.
  (1) 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.
  '8i A  revision  to delete the require-
ments of new performance tests each
time  the continuous monitorlne  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
                              PSBSIAl OieiiTSB, VOl. «0, WO 194—MONDAY, OCTOBER 6,  1*75
                                                   III-114

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                                               RULES  AND  REGULATIONS
were proposed (September II. 1974 > prior
to the effective date for rcquirinc volun-
tary  environmental  Impact statements
on  EPA's regulatory actions (see 39 FR
16186. May 7. 1974 >.
  The  regulations set  forth  below  are
promulgntcd under the  authority of sec-
tions 110 and 301
of  the  Clean Air  Act.  as  amended  142
U.S.C. 1857c-5iai(2KF>iii»-(IU>. 1857g
 1 and are  effective November 5. 1975.
  Dated: September 23.1975.
                     JOHN QUARLES.
                 Acting Administrator.
               Rcrntr.NCcs
  1. Jenkins. R E . Strategies and Air Stand-
ards Division. OAQPS. .EPA. Memo to R L.
AJax. Emlsxlon Standards and Engineering
Division. OAQPS.  EPA. Emission  Monitoring
Costs. February 37. 1975
  2. Young, D.  E.. Control  Programs Develop-
ment Division. OAQPS.  EPA. Memo to E. J.
Llllls. Control  Programs  Development  Di-
vision. 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   Definition*.
     •       •       •       •      •
  (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 Ume 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 sulfuric  acid by  the
contact process by burning elemental sul-
fur, alkylation acid, hydrogen sulflde. 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:

| 51.19  Source surveillance.
   (e)  Legally enforceable procedures to
 require  stationary sources  subject  to
 emission standards as part of an appli-
 cable plan to Install, calibrate, maintain.
 and operate equipment for continuously
 Monitoring and recording emissions: and
 IP 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  flic 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
t 5l.l9(e) (2) of  this section shall have
installed  all  necessary  equipment  and
shall have begun monitoring and record-
ing within 18 months of d) the approval
of a State plan requiring monitoring  for
that source or <2i promulgation by the
Agency of monitoring  requirements  for
that source. However, sources that have
made 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.
  < 61 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
              REOtnttCMCNTS

  1.0 Purpone. 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 Sl.lO(e). These requirements Include
the source categories to be affected: emission
monitoring,  recording, and  reporting re-
quirements !or these  sources: performance
specification* for  accuracy, reliability, and
durability of acceptable monitoring systems:
and techniques to convert emission datn  to
units of the applicable State emission stand-
ard Such data must be reported to the State
as an Indication of whether proper mainte-
nance and operating  procedures arc  beftig
utilized by  nourco operators to maintain
emission levels at or  below emission stand*
ards Such data may be used directly or In-
directly for rompltnnre determination or any
other purpose deemed  appropriate by the
State TlimiRh the monitoring requirement*
are specified In detail. States are given some
flexibility  to resolvn difficulties  that may
arise  during  the  Implementation of these
regulations
  11  XppHcabJIItj/
  The State plan (.hall require the owner or
operator of an emli>slon source In a category
listed In this Appendix  to: (I)  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-Tired  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, shall 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
  1.2.3  scheduled for retirement within  5
years after Inclusion of monitoring require-
ments for  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-
scribed tlmeframe.
  1.4  Monitoring System Mai/unction.
  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 State, that
the  malfunction  was  unavoidable and  Is
being repaired as expedltlously as practicable.
  2.0  .Minimum Monitoring Requirement
  States must, as a minimum,  require the
sources listed in paragraph 1.1 of this appen-
dix to meet the following basic requirements.
  2.1  Fossil furl-flred tteam generators.
  Each fnmll  fuel-fired  steam generator, ex-
cept as  provided In  the following subpara-
graphs. with an annual average capacity fac-
tor of greater than 30 percent, as reported in
the Federal Power Commission  for calendar
year lf>74. or as otherwise demonstrated to
the State 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 for
the pollutant in question.
                                HDflAl MOUTH.  VOL. 40. NO. 194—MONDAY.  OCTOMI «.  t*7S


                                                       III-115

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                                                   RULES AND  REGULATIONS
   211   A continuous monitoring system for
 the measurement of opacity which meete tho
 performance  specifications  of  paragraph
 3.1.1 of thin appendix shall  be Installed, cali-
 brated, maintained, and operated In accord-
 ance with the procedure* of thin appendix b)
 the owner or  operator of  any sucli steam
 generator of greater t:.an  250  million  BTU
 per hour heat  Input except where:
   a.1.1.1 gaseous fuel In the  only fuel burned.
 or
  3.1.1.2 oil or a mixture of gas and oil are
 the only fuels burned and the source Is able
 to  comply with  the applicable partlculale
 matter and opacity regulations without -utili-
 zation   of  participate  matter   collection
 equipment, and where  the  source  has  never
 been found,  through any administrative or
 Judicial proceedings, to be In violation of any
 visible 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
 than 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-
 sil  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
 source 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 of this appendix shall be Installed, cali-
 brated,  operated, and maintained  on  fossil
 fuel-fired itteam  generators where  measure-
 ments of oxygen or carbon dioxide In the flue
 gas 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 arid 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 has 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
specifications  of paragraph 3.12  for  each
nitric acid producing  facility  within  such
plant.
9.3 Sulfuric arid plants.
  Each  Sulfurlc acid plant of greater  than
300 tons  per day production capacity, the
production being expressed as 100  percent
•eld. shall Install,  calibrate,  maintain  and
operate a continuous monitoring system for
the measurement of sulfur dioxide which
meet* the performance specifications of 3.1.3
 for each sulfurlc  acid  producing  facility
within such plant.
  2.4 Fluid bed catalytic cracking «n<(  cata-
lyst regenerators at petroleum refineries
   Each catalyst  regenerator  for  fluid  bed
catalytic cracking units of greater than  20.-
OOO barrels per day fresh feed capacity shall
lnM.all. calibrate, maintain, and  operate  a
continuous monitoring system for the meas-
urement of  opacity  which meets  the  per-
formance specifications of 3.1.1.
   30 Minimum specifications.
   All Stale plans 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.
   3.1  Performance specifications.
   The performance  specifications set forth
In Appendix B of Part 60  arc 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 (e.g.. In
Performance Specification 1, 1.2. "  . . moni-
toring systems subject to  approval by  the
Xdmim.ttrafor,"  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.
   3.1.2  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-
formance 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, may 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 dioxide (NO.). These
gases  shall also be used for dally checks under
paragraph 3.7 of this  appendix as applicable.
For sulfur dioxide monitoring systems In-
stalled on fossil  fuel-fired  steam generators
or stilfurlc acid plants the pollutant gas used
to prepare calibration gas mixtures (Section
2.1. Performance Specification 2. Appendix B.
Part 60 of this Chapter) shall be sullur di-
oxide (SO,).  Span and zero gases should be
traceable to  National Bureau of  Standards
reference  gases  whenever  these  reference
gases  are  available.  Every  six months  from
date of manufacture, span  and  zero gases
shall  be reanalyzed by conducting  triplicate
analyses using the reference methods In Ap-
pendix A. Part 60 of this chapter as follows:
for sulfur dioxide, use Reference Method 6:
for nitrogen oxides, use Reference Method 7:
and for carbon dioxide or oxygen,  use  Ref-
erence Method 3  The gases may Lf  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  system  requires   to   sample.
analyze and record an emission 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 ID-second period.
  3.4 2 Continuous  monitoring  systems for
measuring  oxides of nitrogen,  carbon diox-
ide, oxygen, or nulfur 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) from 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 60 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 ana 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 zero and
spnn  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 adjustment*  at
shorter Intervals. In which ease 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 specification!; In
Appendix B of Part 60 are exceeded:  and to
adjust continuous monitoring systems refer-
enced  by paragraph 32  of this Appendix
whenever the 24-hour  zero drift or 24-hour
calibration drift  exceed  10  percent  of the
emission  standard.
  3.8  Spnn.
  Instrument span  should be approximately
200 ner cent of the  expected Instrument data
display output corresponding to the emission
standard for the  source.
  3.9  Alternative  procedures and  require-
ments
  In cases where States wish to utlllte differ-
ent, but equivalent, procedures and require-
ments for  continuous monitoring systems.
the State plan must provide a description of
such  nltrmative  proceduers  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 thnt require corrections for stack mois-
ture conditions (e.g.. an Instrument measur-
ing steam generator SO., emissions  on a wet
basis could be used  with"an Instrument mea-
suring oxygen concentration on a  dry  basis
If  acceptable  methods of measuring stack
moisture conditions are  used  to allow ac-
                                          IIOISTH. VOL. 40. NO.  1*4—MONDAY, OCTOttR «, WS
                                                            III-116

-------
                                                  •ULES AND IEGULATIONS
 curate adjustment of the measured SO. con-
 centration to dry basis )
   39.2  Alternative  locations for Installing
 continuous monitoring systems or monltor-
 Jng devices when the owner or oper«tor cm
 demonstrate that  Insinuation at alternative
 locations will enable occurale and represent-
 ative measurements
   3.9.3 .Alternative  procedures for perform-
 ing calibration check* (e.g . «ome Instruments
 may demonstrate  superior drift characteris-
 tics that require  checking at less frequent
 Intervals).
   3.9.4 Alternative  monitoring requirement*
 when the effluent from one affected facility or
 the  combined  effluent  from two or  more
 Identical affected facilities Is released to the
 atmosphere  through more than  one -point
 te g  an extractive,  gaseous monitoring sys-
 tem used at several points  may be approved
 If the procedures recommended are suitable
 for generating  accurate emission averages).
   395 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
 and the opacity  measurement* of a system
 complying  with  the requirements  In  Per-
 formance Specification  1  The State may  re-
 quire that such demonstration be performed
 for each affected facility.
   4.0 Minimum data Tf.quiremrnts
   The following paragraphs set forth  the
 minimum data reporting requirements neces-
 sary to comply with »5l.l9
-------
                LIST OF SUMMARY TABLES
               OF  MONITORING  INFORMATION
Table No.               Subject                          Page

    1         NSPS Source Categories Required
                to Monitor Continuously	III-119

    2         Operational Monitoring Requirements   .  III-123

    3         Emission Limitations 	  III-126

    4         Proposal and Promulgation Dates for
                NSPS Source Categories 	  III-133

    5         NSPS Continuous Monitoring Require-
                ments   	  III-135

    6         Quarterly Reporting Requirements . .  .  III-136

    7         Definitions of Excess Emissions  . .  .  III-137

    8         Spanning and Zeroing 	  III-139

    9         Span Specifications  .... 	  III-140

   10         Notifications Requirements 	  III-142

   11         Subpart Da Emission Limitations  . .  .  III-143

   12         Performance Specifications ......  Ill-ISO

   13         When To Run Monitor Performance
                Test	III-151

   14         Requirements for SIP Revisions ....  III-152

   15         Existing Sources Required to
                Continuously Monitor Emissions . .  .  III-153
                        III-118

-------
Subpart

   D
   Da
   G

   H

   J
                    0       Table 01

                  SOURCE  CATEGORIES WHICH  ARE

               REQUIRED TO MONITOR CONTINUOUSLY
Source Category

STEAM GENI-RATORS

   Solid Fossil Fuel



   Liquid Fossil Fuel



   Gaseous Fossil Fuel

ELECTRIC UTILITY STEAM
   GENERATING UNITS

   Solid Fossil Fuel
                Liquid Fossil Fuel
   Gaseous Fossil Fuel

NITRIC ACID PLANTS

SULFURIC ACID PLANTS

PETROLEUM REFINERIES

   FCCU
                Combustion of Fuel
                  Gases
Pollutant
                                      Opacity
                                      S02
                                      NOx

                                      Opacity
                                      S02
                                      NOx

                                      NOx
Process




02 or C02




02 or C02




02 or CO?
 *"      £*
                                      Opacity        02 or COo
                                      S02 (at inlet
                                      and outlet of
                                      control device)
                                      NOX
Opacity        i
SO? (at inlet
ana outlet of
control device)
NOX
                                           or CO-
NOX

NOX

S02
Opacity
CO

S02 or
H2S
                                                     02 or C02
                                III.-119

-------
Table #1, continued
Subpart
(cont'd)
   N
Source Category
Pollutant
Process
   P


   Q


   R


TUVWX
  AA
             PETROLEUM REFINERIES  (cont'd)
   Sulfur Recovery
     Plant

IRON AND STEEL PLANTS
                                      S02a
                                      TRSb
      H2SD,
PRIMARY COPPER SMELTERS  Opacity
                         S02

PRIMARY ZINC SMELTERS    Opacity
                         S02

PRIMARY LEAD SMELTERS    Opacity
                         S02

PHOSPHATE FERTILIZER
   PLANTS
             COAL  PREPARATION  PLANTS
              FERROALLOY  PRODUCTION     Opacity
                 FACILITIES
STEEL PLANTS:            Opacity
   ELECTRIC ARC FURNACES
               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 in-
               side the electric
               are furnace.
a  For oxidation control systems
b  For reduction control systems not followed by
     incineration
                                III-120

-------
Table #1,  continued
Subpart


  BB
Source Category
KRAFT PULP MILLS
                Recovery Furnace
                Lime kiln, digester
                  system, brown
                  stock washer sys-
                  tem, multiple ef-
                  fect evaporator
                  system, black
                  liquor oxidation
                  system, or con-
                  densatc stripper
                  system

                Point of incinera-
                  tion of effluent
                  gases, brown stock
                  washer system,
                  multiple effect
                  evaporator system,
                  black liquor oxi-
                  dation system, or
                  condensate strip-
                  per system

                Lime kiln or smelt
                  dissolving tank
                  using a scrubber
  HH
LIME MANUFACTURING
   PLANTS

   Rotary Lime Kilns
Pollutant
                         Opacity
                         TRS (dry basis)

                         TRS (dry basis)
Process
                     (dry basis)

                     (dry basis)
                                           Temperature
                                      Opacity3
                                           Pressure loss
                                           of the gas
                                           stream through
                                           the control
                                           equipment

                                           Scrubbing liquid
                                           supply pressure
                  Pressure loss
                  of steam through
                  the scrubber

                  Scrubbing liquid
                  supply pressure
a Does not apply when there is a wet
    scrubbing emission control device.
                                III-121

-------
Table fl1, continued
Subpart      Source Category          Pollutant         Process


  HH         LIME MANUFACTURING
                PLANTS (cont'd)

                Lime Hydrator                           Scrubbing li-
                                                        quid flow rate

                                                        Measurement of
                                                        the electric
                                                        current (am-
                                                        peres) used by
                                                        the scrubber
                               III-122

-------
                          Table # 2

            OPERATIONAL MONITORING REQUIREMENTS (NSPS)

                      (Non-continuous)
     Subpart
                                    Requirement
E.


F.


G.


H.
Incinerators
Portland Cement
Plants

Nitric Acid Plants
Sulfuric Acid Plants
    Petroleum Refineries
K.
Storage Vessels for
Petroleum Liquids
                      III-123
Daily charging rates and hours
of operation.

Daily production 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
concentration of sulfur dioxide
entering the converter.

Record daily the average coke     ,
burn-off rate and hours of
operation for any fluid catalyt
cracking unit catalyst regenerate •
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 pe-
troleum liquid stored if :        I
(1) the petroleum liquid, as      *
stored, has a vapor pressure      j,
greater than 26 mm Hg but less thr^
78 mm and is stored in a storage  •;
vessel other than one equipped    ['
with a floating roof, a vapor    -,•
recovery system or their equiva-  I
lents; or                         ?
(2) the petroleum liquid has a trt!
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.

-------
     Subpart
                                    Requirement
0.  Sewage Treatment
    Plants
T.
U.
V.
w.
X.
    Primary Copper
    Smelter
    Primary Aluminum
    Reduction Plants
Phosphate Fertilizer
Industry:  Wet-Process
Phosphoric Acid Plants
Phosphate Fertilizer
Industry:  Superphosphoric
Acid Plants
Phosphate Fertilizer
Industry:  Diammonium
Phosphate Plants
Phosphate Fertilizer
Industry:  Triple
Superphosphate Plants
Phosphate Fertilizer
Industry
                     III-124
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.

Determine the mass flow of
phosphorus-bearing feed
material to the process.
Maintain a daily record of
equivalent P?^c feed.

Determine the mass flow of
phosphorus-bearing feed material
to the process.
Record daily the equivalent
P205 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 P2°c feed.

Maintain an accurate account
of triple superphosphate in
storage.
Maintain a daily record of
                               total equivalent
                                                         stored.

-------
      Subpart
     Requirement
 Z.   Ferroalloy Production
     Facilities
AA.  Steel Plants:
     Electric Arc Furnaces
                       III-125
Maintain daily records of (1)
the product; (2) description
of constituents of furnace
charge, including the quantity,
by weight;  (3) the time and
duration of each tapping period
arid 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 consump-
tion 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.

-------
                         Table #3

                    EMISSION LIMITATIONS  (NSPS)
SUBPART
                       POLLUTANT
                   EMISSION  LL-VELS
   D  Fossil Fuel-Fired
      Steam Generators

         Liquid fossil
         fuel
         Solid fossil
         fuel
         Gaseous fossil
         fuel
         Mixture of
         fossil fuel
                       Particulate
                            Opacity
                            S()
*x =
 y =
 z =
percentage of total
percentage of total
percentage of total
   Particulate


   Opacity

   SO 2


   N0x


   Particulate


   Opacity

   N0y
     A


   Particulate


   Opacity


   S02

   N0x


heat input from
heat input from
heat input from
                   43 ng/joulefi
                   (0.10 lb/10°BTU)

                   20%,  40%   2 min/hr

                   340 ng/joulc
                   (0.80 lb/10°]
                                                   .b/10 BTU)
                                       130 ng/joule
                                       (0.30 lb/10°BTU)

                                       43 ng/joule,
                                       (0.10 lb/10 BTU)
                                            20%, 40%
                                                   min/hr
                                       520 ng/joule
                                       (1.2 lb/10 BTU)

                                       300 ng/joule
                                       (0,70 lb/10°BTU)

                                       43 ng/jouler
                                       (0.10 lb/10° BTU)

                                       20%, 40%  2 min/hr

                                       86 ng/joule,.
                                       (0.20 lb/10° BTU)

                                       43 ng/joule,-
                                       (0.10 lb/10°BTU)

                                       20%, 40%  2 min/hr

                                       y(540) + z(520)  *
                                            y + z

                                       x(86) + y(130) » z(300)
gaseous fossil fuel
liquid fossil fuel
sol id fossi 1  fuel
                         III-126

-------
Tal>le '/ 3 ,  continued
SIJB!>A_RT

   li  Incinerators
   F  Portland Cement
      Plants

         Kiln
         Clinker cooler
         Other emission
         points

   G  Nitric Acid Plants
   II  Sulfuric Acid
      Plants
   I  Asphalt Concrete
     . Plants
  J  Petroleum
     Refineries

       fluid catalytic
       cracking unit
 POLLUTANT

 Particulate
 Particulate


 Opacity

 Particulate



 Opacity

 Opacity
                            Opacity
 SO
                            H2SO. mist
 Particulate


 Opacity
Particulate


Opacity

CO
EMISSION LEVELS

0.18 g/dscm
(0.08 gr/dscf)
(corrected to 12% C07)
0.15 kg/metric ton
(0.30 Ib/ton)
0.05 kg/metric ton
of feed
(0.10 Ib/ton)

20%

10%
1.5 kg/metric tons
of acid produced
(3.0 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)

90 mg/dscm
(0.04 gr/dscf)

20%
1.0 kg/1000 of
coke burn-off

30%

0.050%
                         III-127

-------
Table #3, continued

SUBPART

   Glaus sulfur
   recovery plant
   POLLUTANT
   S02
   Trs
EMISSION LEVELS
0.025%
0.030%
0.0010%
 K   Storage  Vessels
    for Petroleum
    Liquids
    Hydrocarbons
 L  Secondary Lead
    Smelters

       Reverberatory
       and blast
       furnaces
       Pot furnaces

 M  Secondary Brass
    and Bronze Plants

       Reverberatory
       furnaces
       Blast and elec-
       tric furnaces

N  Iron and Steel Plants

          (BOPF)
 0  Sewage Treatment
    Plants
 P  Primary Copper
    Smelters
    Particulate



    Opacity

    Opacity




    Particulate


    Opacity

    Opacity


   Particulate

   Opacity




    Particulate


    Opacity
       Dryer
    Particulate
III-128
If vapor pressure is
78-570 mm llg the stor-
age vessel shall be
equipped with a float-
ing roof or a vapor
recovery system or thin
equivalents.  If vapor
pressure is greater than
570 mm Hg, the storage
vessel shall be equipped
with a vapor recovery
system
50 mg/dscm
(0.022 gr/dscf)
                                          20?,
105
50 mg/dscm
(0.022 gr/dscf)

20%

101


50 mg/dscm

10%
>10% but <20% may occur
once per steel production
cycle
0.65 g/ku  dry  sludge
input  (1.30  lb/ton)

20%
 50 mg/dscm
 (0.022 gr/dscf)

-------
Table 9 3, continui-d
SUBPART
POLLUTANT

Opacity
         Roaster, smelting  SO
         furnace, copper
         converter
                            Opacity

   Q  Primary Zinc Smelters

         Sintering machine  Particulate
         Roaster
Opacity

SO 2

Opacity
   R  Primary Lead Smelters

         Blast or rever-    Particulate
         beratory furnace,
         sintering ma-
         chine discharge
         end
         Sintering ma-
         chine, electric
         smelting furnace,
         converter
   S  Primary Aluminum
      Reduction Plants

         Soderberg
         plants
         Prebake
         plants
         Anode bake
         plants
Opacity

SO,
                            Opacity
Total
fluorides
Opacity

Total
fluorides
Opacity

Total
f1 anrides

Opacity
EMISSION LEVHLS
                0.0651
                201
50 mg/dscm
(0.022 gr/dscf)

20S

0.065%

20°;
                50 mg/dscm
                (0.022 gr/dscf)
20";

0.065%
                201
1 kg/metric ton of
Al produced
(2 Ib/ton)

IQl

0.95 kg/metric ton
of Al produced
(1.9 Ib/ton)

10%

0.05 kg/metric ton
of Al produced

201;
                          III-129

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Table If 7>,  continued
SUBPART
POLLUTANT
EMISSION LF.VHLS
   f  Phosphate Ferti-
      lizer Industry:
      Wet Process
      Phosphoric Acid
      Plants

   U  Phosphate Ferti-
      lizer Industry:
      Super-phosphoric
      Acid Plants

   V  Phosphate Ferti-
      lizer Industry:
      Diammonium Phos-
      phate

   W  Phosphate Ferti-
      lizer Industry:
      Triple Super-
      Phosphate

   X  Phosphate Ferti-
      lizer Industry:
      Granular Triple
      Superphosphate

   Y  Coal Preparation
      Plants

         Thermal dryer
         Pneumatic
         coal cleaving
         equipment
         Processing and
         conveying equip-
         ment, storage
         systems, trans-
         fer and loading
         systems
Total
f]uorides
Total
fluorides
Total
fluorides
Total
fluorides
Total
fluorides
Particulate


Opacity

Particulate



Opacity

Opacity
10 g/metric ton of
P70r feed
CO.020 Ib/ton)
5 g/metric ton of
P70r feed
(6.020 Ib/ton)
50 g/metric ton of
P70,- feed
(6.060 Ib/ton)
100 g/metric ton of
equivalent P70r feed
(0.20 Ib/ton) 3
0.25 g/hr/metric ton
of equivalent P?0
stored     .    * °
(5.0 x 10"4 Ib/hr/ton)
0.070 g/dscm
(0.031 gr/dscf)

20%

0.040 g/dscm
(0.031 gr/dscf)
                                            lot
20%
                              III-130

-------
Table
           continued
SUBPART
                            POLLUTANT
 EMISSION  LEVELS
   Z  Ferroalloy Produc
      tion Facilities

         Electric sub-
         merged arc
         furnaces
         Dus.-t handling
         equipment

  AA  Steel Plants

         lilectric arc
         furnaces

         Control device

         Shop roof
         Dust handling
         equipment
                            Particulate
                            Opacity

                            CO

                            Opacity




                            Particulate


                            Opacity

                            Opacity



                            Opacity
 BB    Kraft  Pulp  Mills

          Recovery Furnace    Particulate

                             Opacity

          Straight recovery
           furnace          TRS
 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  man
 gariese alloys)

 15%

 2:0%

 10%
 12  mg/dscm
 (0.0052  gr/dscf)

 3%
 0,  except:
 20% -  charging
 40% -  tapping
 10%
         Cross  recovery
            furnace
                             TRS
0.10 g/dscm

35%


5 ppm


25 ppm
                     III-131

-------
Table #3, continued

SUBPART

      Smelt dissolving
       tank
      Lime kiln

       gaseous fuel
       liquid fuel
POLLUTANT


Paniculate

TRS


TRS

Particulate
Particulate
      Digester system,
      brown stock washer
      system, multiple-
      effect evaporation
      system, black li-
      quor oxidation
      system or conden-
      sate stripper      TRS

HH  Lime Manufacturing
    Plants

      Rotary Lime kiln   Particulate
      Lime Hydrator
Opacity

Particulate
EMISSION LEVELS
O.lg/kg black liquor
  (dry out)
0.0084g/kg black liquor
  (dry out)

8 ppm

O.lSg/dscm
0.30g/dscm
                 5 ppm
                 0.15 kg/megagram of
                   limestone feed
0.075 kg/megagram
  of lime feed
                    III-132

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                         Table #4
PROPOSAL AND PROMULGATION DATES FOR NSPS SOURCE CATEGORIES
Subpart
D
Da
E
F
G
H
I
J
K
L
M
N
0
P
Q
R
S
TUVWX
Y
LJ
AA
BB
Source Promulgation
Date
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 Plants
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
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
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
                              III-133

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Table #4, continued
Subpart
          Source
Promulgation
    Date
Proposed
  Date
   DD
   HH
Grain Elevators
Lime Manufacturing
    8/03/78


    3/07/78
 l/03/77a,
 8/03/78

 3/03/77
                               III-134
a Suspended on 6/24/77

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                            Table #5
               CONTINUOUS MONITORING REQUIREMENTS
  I.  Installed and operational prior to conducting performance tests


 II.  Conduct monitoring system performance evaluations during per-
      formance tests or 30 days thereafter


III.  Check zero and span drift at least .dfiily (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 commence.
   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.
                                 III-135

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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.  Occurranccs during startups, shutdowns,  and malfunctions
          2.  Nature and cause of malfunction
          3.  Corrective and preventative action taken
      C.   To be Submitted in Units Same as Standard

 I.I.   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
  "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..."
                              III-136

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                                 Table • • 7

                      DEFINITION OP EXCESS EMISSIONS   (NSPS)
SURPART

   1)
POLLUTANT

opacity




SO,,
            NO.
            NO,
    II
SO.
EXCESS EMISSION

any six-minute period during which the aver-
age opacity of emissions exceeds 20"i opacity,
except that one six-minute average per hour
of up to 27?6 opacity need not be reported,

any three-hour period during which the average
emissions of S02 (arithmetic average of three
contiguous  one-hour periods) exceed the
standard

any three-hour period during which the average
emissions of NOX (arithmetic average of three
contiguous one-hour periods) exceed the
standard

any three-hour period during which the average
nitrogen oxides emissions (arithmetic average
of three contiguous one-hour periods) exceed
the standard

all three hour periods (or the arithmetic
average of three consecutive one hour periods)
during which the integrated average sulfur
dioxide emissions exceed the applicable
standards
             Opacity



             CO


             S02




             S02
                All   one-hour  periods  which contain two or
                more six-minute periods  during which the
                average  opacity exceeds  30 percent.

                All  hourly periods  during  which the average
                CO concentration exceeds the standard.

                Any  three  hour period  during which  the
                average  concentration  of S02 emissions
                from any fuel  gas combustion device exceeds
                the  standard.

                Any  twelve-hour  period  during  which the
                average  concentration  of S02 emissions  from
                any  Glaus  sulfur recovery  plant  exceed  the
                standard.
                              III-137

-------
Table #7, continued
SUBPART

    P
    R
   AA
 POLLUTANT

Opacity


S02



Opacity
             SO
Opacity
             SO,
            Opacity
Opacity
  BB
  Recovery
  furnace     TRS
             ... Opacity
   Lime  kiln   TRS
  Digester
  system, brown
  stock  washer
  system, multiple-
  effect evaporator
  system, black
  liquor oxidation
  system, or
  condensate
  stripper.
       TRS
   HH
 Opacity
EXCESS EMISSION

any six-minute period during which the average
opacity exceeds the standard

any six-hour period during which the average
emissions of S02 (arithmetic mean of six con-
tiguous one-hour periods) exceed the standard

any six minute period during which the average
opacity exceeds the standard

any two hour period during which the average
emissions of S02 (arithmetic mean of two
contiguous one-flour periods) exceed the
standard

 any six minute period during which the
 average opacity exceeds the standard

 any two hour period during which the
 average emissions of SO, (arithmetic 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 opactiy 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 minute periods during which the
average opacity  is greater  than the standard
                               III-138

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                              Table "8

                        SPANNING AND ZEROING

  I.   Hxplanation of Zero and Span ('hecks
      A.   Extractive ^as monitors
          1.   Span gas composition
              a.   S02 - sulfur dioxide/nitrogen or air-gas mixture
              b.   NO - nitric oxide/oxygen-free nitrogen mixture
              c.  . NC>2 - 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 SC>2 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%  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 optical surfaces before adjusting
              zero or span drift
          2.   For opacity systems using automatic zero adjustments,
              the optical surfaces shall be cleaned when the cumu-
              lative 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
                                 III-139

-------
                             Table  # 9
                        SPAN SPECIFICATIONS
 SUBPART

 D   Fossil  Fuel  Fired
    Steam Generators

     liquid fossil  fuel
     solid fossil fuel



     gaseous fuel

     mixtures of fossil fuels



 G  Nitric Acid Plants

 H  Sulfuric Acid Plants

 J  Petroleum Refineries
    Catalytic Cracker

    Glaus Recovery Plant


    Fuel Gas Combustion
POLLUTANT
opacity
S02
NOX

opacity
S02
N0x

NOX

opacity
S0£
NOX

NO 2

SO,
Opacity
CO
SOz
H2S
TRS
S02
H2S
SPAN
80, 90, or 100% opacity
1000 ppm
500 ppm

80, 90, or 100% opacity
1SOO ppm
1000

500 ppm

80,90, or 100% opacity
lOOOy + 1500z 1
500 (x+y) + lOOOz

500 ppm

1000 ppm


 60,70,  or 80%  Opacity
  1000  ppm
  500 ppm
  20 ppm
  600 ppm
  100 ppm
  300 ppm
 P  Primary Copper Smelters
 Q  Primary Zinc Smelters
 R  Primary Lead Smelters
 Z  Ferroalloy Production
    Facilities

AA  Steel Plants
 Opacity
 S02

 Opacity
 Opacity
 S02
 Opacity

 Opacity
 80  to  100% opacity
 0.20%  by volume

 80  to  100% opacity
 0.20%  by volume

 80  to  100% opacity
 0.20%  by volume
not  specified

not  specified
                              III-140

-------
BB  Kraft Pulp Mills
    Recovery Furnace
Opacity
    Lime kiln, recovery furnace
      digester system, brown    02

    Stock washer system,
      multiple effect           TRS
      evaporator system,
      black liquor oxidation
      system, or condensate
      stripper system


HH  Lime Manufacturing Plant    Opacity
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
                              III-141

-------
                            Table #10

                   NOTIFICATION REQUIREMENTS
Requirements

  I.  Date of Commencement of Construction

 II.  Anticipated Date of Initial Startup

III.  Actual Date of Initial Startup

 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
   'Any owner or operator subject to the provisions of this part shall
   furnish the Administrator written notification..."
                                 III-142

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Fuel
Coal
Liquid Fossil Fuel
Gas
                                     Table #11

                          SUBPART DA EMISSION LIMITATIONS

                          AND REQUIRED PERCENT REDUCTIONS
Pollutant
   S02
                           NOx

                       Particulate
                         Matter
                       Particulate
                         Matter
   SO-,
                       Particulate
                         Matter
 Emission Limitation

520ng/,T(1.201b/106Btu)



210ng/J(0.501b/106Btu)


 13ng/J(0.031b/!06Btu)


340ng/J(0.801b/106Btu)
130ng/J(0.301b/!06Btu)


 13ng/J(().031b/106Btu)


340ng/J(0.801b/10&Btu)
Coal-derived gase-
  ous fuel
                86ng/J(0.201b/106Btu)


                13ng/J(0.031b/!06Btu)



               210ng/J(0.501b/106Btu)
     Required
Percent Reduction

       90%
(70% if emissions are
 less than 260ng/J)

       651*
                                                99%*.
                                                90%
                                         (if emissions are be-
                                          low 86ng/J, there is
                                          no reduction require-
                                          ment)

                                                30%*
                                                70%*
       90%
(if emissions are be-
 low 86ng/J, there is
 no reduction require-
 ment)

       25%*
                                 25%*
* Compliance with the emission limitation constitutes compliance with the percent
  reduction requirements.
                                      III-143

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Table #11, continued
Fuel

Lignite mined in N.
  Dakota, S. Dakota,
  or Montana and is
  combusted in a slag
  type furnace
                        Pollutant
                              Required
 Emission Limitation      Percent Reduction
                                       340ng/J(0.8 lb/106Btu)
                                 65%*
Other Lignite
Subbituminous Coal
Bituminous Coal
Anthracite Coal
                           NQx


                           NQx
                           NOX
260ng/J(0.6 lb/106Btu)


210ng/J(0.5 lb/106Btu)


260ng/J(0.6 lb/106Btu)
260ng/J(0.6 lb/106Btu)
65%*


65%*


65%*


65%*
*  Compliance with the emission limitation constitutes compliance with the percent
   reduction requirements.
                                   III-144

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                        Table  K 12
                PERFORMANCE SPECIFICATIONS
                  TRANSMISSOMIiTHRS
Calibration error
Zero drift (24h)
Calibration drift  (24h)
Response time
Operational test period
<_ 3 pet opacity
<_ 2 pet opacity
_f_ 2 pet opacity
10 s maximum
168 hours
                    NO  and S09
Accuracy

Calibration error

Zero drift (2h)
Zero drift (24h)
Calibration drift  (2h)
Calibration drift  (24h)
Response time
Operational period
£20 pet  of the mean, value
 of the reference method test  data
<5  pet of (50 pet, 90 pet)
 calibration gas-mixture value.
 2 pet of sp;m
 2 pet of span
 2 pet of span
 2.5 pet of span
 15 min maximum
 168 h minimum
                    07 and CO-,
                     Z.	i^
Zero drift (2h)
Zero drift (24h)
Calibration drift (2h)
Calibration drift (24h)
Operational period
Response time
<_0.4 pet 02 or C02
£0.5 pet 02 or C0?
<0.4 pet 09 or CO.,
—         ^      L
_<0.5 pet 02 or C02
 168 II minimum
 10 min
                         III-145

-------
                      TABU: »13
          WHEN TO RUN THE MONITOR PERFORMANCE TEST
   INITIAL
   FACILITY
   START-UP
                180
               DAYS
                MAX
MAX
PRODUCTION
FATE
REACHED
PERFORMANCE
TEST & SUBMIT
REPORT FOR
COMPLIANCE
60
DAYS
                    MONITOR
                    PERFORMANCE
                    TEST
                         f
                        30
                        DAYS
                                     60
                                   DAYS
                                         MONITOR PERFOR-
                                         MANCE  TEST
                                         REPORT
                          HI-146

-------
                            Table 014

                 REQUIREMENTS FOR SIP REVISIONS


  I.   Submit SIP Revisions by October 6, 1976

 Us   Contain monitoring requirements for the following
      sources (as a minimum)

      A.  Fossil Fuel-Fired Steam Generators
      B.  Sulfuric Acid Plants
      C.  Nitric Acid Plants
      1).  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 monitoring 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 inoperativeness

 VI.   Require that monitoring begin within 18 months of
      EPA approval of the SIP revision (or within 18
      months of EPA promulgation)
                          III-147

-------
                      TABLE  #15
EXISTING SOURCES REQUIRED TO CONTINUOUSLY MONITOR EMISSIONS
Source

Fossil Fuel-Fired
 Steam Generators
Pollutant
  SO,
                         NO,
                         Opacity
Nitric Acid Plants
  NO.
Sulfuric Acid Plants

Petroleum Refineries
  SO.
  Opacity
          Comments
1.   >250 x 10° Btu/hr
2.   Source that has
    control equipment
    for S02 .

1.   >1000 x 106 Btu/hr
2.   Located in a designated
    non-attainment  area
    for N02.
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 particu-
    late matter and
    opacity standards with-
    out installation of
    control equipment

1.   >300 ton/day
2.   Located in a designated
    non-attainment  area
    for NO-7.
          (^

1.   >300 tons/day

1.   >20,000 barrels/day
                           III-148

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    VENDOR LIST
Acurex Autodata
485 Clyde Avenue
Mountain View, CA  94042
(415) 964-3200
Andersen Samplers, Inc.
4215-C Wendell Drive, SW
Atlanta, Georgia  30336
Astro Ecology/Astro Resource
801 Link Road
League City, Texas  77058
(713) 332-2484
Babcock & Wilcox, Co.
Bailey Meter Co.
29801 Euclid Avenue
Wickliffe, Ohio  44092
Bachrach Instrument Co.
2300 Leghorn Street
Mountain View, CA  94043
(415) 967-7221
Baseline Industries, Inc,
Box 649
Lyons, CO  80540
(303) 823-6661
Beckman Inst. PID
2500 Harbor Boulevard
Fullerton, CA  92634
(714) 871-4848
Bendix Corp. EPID Div.
Box 831
Lewisburg, W. V. 24901
(304) 647-4358
Berkeley Controls
2700 Dupont Drive
Irvine, CA  92715
(714) 833-3300

       IV-1

-------
Bio Marine Industries, Inc
45 Great Valley Center
Malvern, PA  19355
(215) 647-7200
C E A Instruments, Inc
15 Charles Street
Westwood, N. J.  07675
(201)664-2300
Calibrated Instruments, Inc,
731 Saw Mill River Road
Ardsley, New York  10502
(914) 693-9232
Cleveland Controls, Inc
5755 Granger Road
Suite 850
Cleveland, Ohio  44109
Climet Instruments Div. WEHR
1320 West Colton Avenue
Box 151
Redlands, California  92373
(714) 793-2788
Columbia Scientific Inds.
Box 9908
Austin, Texas  78766
(800) 531-5003
Contraves-Goerz Corp.
610 Epsilon Drive
Pittsburgh, PA  15238
Datatest, Inc.
1117 Cedar Avenue
Croydon, PA  19020
(215) 785-5247
Delta F Corporation
One Walnut Hill Park
Woburn, MA  01801
       IV-2

-------
E. I. Du Pont de Nemours & Co
1007 Market Street
Wilmington, Delaware  19898
Dynasciences Env. Prods. Div
Township Line Road
Blue Bell, PA  19422
(215) 643-0250
Dynatron, Inc.
Box 745
Wallingford, CT 06492
(203) 265-7121
Electronics Corp. of America
1 Memorial Drive
Cambridge, Massachusetts 02142
Energetics Science, Inc.
85 Executive Boulevard
Elmsford, New York  10523
(914) 592-3010
Environmental Data Corporation
608 Fig Avenue
Monrovia, California  91016
(213) 359-9176
Esterline Angus Div. Esterline
Box 24000
Indianapolis, Indiana 46224
(317) 244-7611
Foxboro/ICT, Inc.
414 Pendleton Way
Oakland, CA  94621
(408) 998-8720.
General Monitors, Inc.
3019 Enterprise Street
Costa Mesa, CA  92626
(714) 540-4895
H N U Systems, Inc.
30 Ossipee Road
Newton Upper Falls, MA  02164
(617) 964-6690

      IV-3

-------
Horiba Instruments, Inc.
1021 Duryea Avenue
Irvine, California  92714
(714) 540-7874
Houston Atlas, Inc.
9441 Baythorne Street
Houston, Texas  77041
(713) 462-6116
ITT Barton
Box 1882
City of Industry, CA 91744
(213) 961-2547
Infrared Industries, Inc.
Box 989
Santa Barbara, California 93102
(805) 684-4181
InterScan Corporation
9614 Cozycroft Avenue
Chatsworth, California 91311
(213) 882-2331
Jacoby Tarbox Corporation
808 Nepperhan Avenue
Yonkers, New York  10703
(914) 965-8400


K V B Equipment Corporation
17332 Irvine Boulevard
Tustin, California  92680
(714) 832-9020
Lear Seigler, Incorporated
74 Inverness Drive East
Englewood, Colorado  80110
(303) 770-3300
Leeds & Northrup
Sumneytown Pike
North Wales, Pennsylvania  19454
(215) 643-2000  -
       IV-4

-------
Meloy Labs, incorporated
6715 Electronic Drive
Springfield, Virginia  22151
(703) 354-2600
Meteorology Research, Incorporated
Box 637
Altadena, California  91001
(213) 791-1901
Milton Roy Company Hays Republic
4333 South Ohio Street
Michigan City, Indiana  46360
(219) 879-4441
Mine Safety Appliances Company
600 Penn Center Boulevard
Pittsburgh, Pennsylvania  15235
(412) 273-5000
Monitor Labs, Incorporated
10180 Scripps Ranch Boulevard
San Diego, California  92131
(714) 578-5060
Napp, Incorporated
8825 North Lamar
Austin, Texas  78753
Particle Measuring Systems, Incorporated
1855 South 57th Court
Boulder, Colorado  80301
(303) 443-7100
Photomation, Incorporated
270 Polaris Avenue
Mount View, California  94043
Research Appliance Company
Moosehead Lodge Road
P.O. Box 265
Cambridge, Maryland  21613
(301) 228-9505
      IV-5

-------
Sierra Misco, Inc.
1825 East Shore Highway
Berkeley, California   94710
(415) 843-1282
Source Gas Analyzers, Inc.
7251 Garden Grove Boulevard
Garden Grove, California  92641
Systems Science & Software
Box 1620
La Jolla, California  92038
(714)  453-0060
Taylor Instrument Div. Sybron
95 Ames Street
Rochester, New York  14601
(716) 235-5000
Teledyne Analytical Insts.
Box 70
San Gabriel, California 91776
(213) 576-1633
Thermco Instrument Corporation
Box 309
La Porte, Indiana  46350
(219) 362-6258
Thermo Electron Corp. Env. Insts,
108 South Street
Hopkinton, Massachusetts  01748
(617) 435-5321
Thermox Instruments, inc.
6592 Hamilton Avenue
Pittsburgh, Pennsylvania  15206
(412) 361-7107
Theta Sensors
17635 A Rowland Street
City of Industry, California  91748
(213) 965-1539
       IV-6

-------
Tracer, Inc.
6500 Tracor Lane
Austin, Texas 78721
(512) 926-2800
Wallace Fisher Instrument Company
Box 51 Ocean Grove Station
Swansea, Massachusetts 02777
(617) 673-4744
Western Precipitation Division
Joy Manufacturing Company
P. 0. Box 2744 Terminal Annex
Los Angeles, California  90051
Western Research and Development, Ltd
1313 44th Avenue, NE
Calgary, Alta.,
Canada  T2E 6L5
Xonics, Inc.
6862 Hayvenhurst Ave.
Van Nuys, California  91406
(213) 787-7380
      IV-7

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                        BIBLIOGRAPHY
1.  Avetta,  Edward  D.  In-Stack Transmissometer  Evaluation and
        Application  _to  Particulate  Opacity  Measurement.  EPA
        Contract  No.   68-02-0660.   Owens,   Illinois.   NTIS  PB
        242402.  January 1975.

2.  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.

3.  Beeson,   H.   G.    Continuous   Monitoring   Excess   Emission
        Reports;  Evaluation   and  Summary.   Entropy   Environ-
        mentalists,  Inc. EPA  Contract No.  68-01-4148,  Task 59.
        June 1979.

4.  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.

5.  Blosser,  R.  0.,   A.  G.  Kutyna,  R.  A.  Schmall,  M.  E.
        Franklin,  and  K.  Jain. "The  Status of  Source  Emission
        Monitoring and Measurements," presented at the Technical
        Association  of  the   Pulp and  Paper  Industry,  Annual
        Meeting in Miami Beach, Florida.  January 1974.

6.  Bonam,  W.  L.  and  W.  F.  Fuller. "Certification  Experience
        with   Extractive   Emission   Monitoring  Systems,"   in
        Calibration  ^n  Air   Monitoring,   ASTM  Special  Tech.
        Publication 598, Proceedings of Symposium, August 1975.

7.  Brooks,  E.  F.  Guidelines  for Stationary  Source  Continuous
        Gas Monitoring Systems. TRN  Systems Group.  EPA  Contract
        No. 68-02-1412. November 1975.

8.  Brooks, E.  F., C.  A.  Flegal,  L.  N.  Harnett, M.  A.  Kolpin,
        D.   J.   Luciani,  and   R.   L.   Williams.   Continuous
        Measurement of Gas Composition  from Stationary  Sources.
        TRW   Systems   Group.   EPA  Contract   No.   68-02-0636.
        EPA-600/2-75-012.

9.  Chapman, Robert L.  "Instrumentation  for  Stack  Monitoring,"
        Pollution  Engineering, September 1972.
                         V-l

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10.  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.

11.  Cheremisinof f,  P. N.  and  R. A. Young.  "New Developments in
         Air  Quality  Instrumentation,"  Pollution  Engineering,
         vol. 7, no. 2, p. 24, 1975.

12.  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.

13.  Connor,  William  D.  Measurement  of  the  Opacity  and  Mass
         Concentration  of.  Particulate  Emissions  by  Transmis-
         sometry.  Chemistry  and  Physics  Laboratory.  EPA-650/
         2-74-128.   November 1974.

14.  Cross,  F.   L. ,  Jr.  and H.  F.  Scheff. "Continuous  Source
         Monitoring,"  Chemical   Engineering   (Deskbook   Issue),
         p. 125-27,  June 1973.

15.  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.)

16.  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.

17.  Driscoll,  Becker,  McCoy,  Young,  and  Ehrenfeld.  Evaluation
         o_f Monitor  Methods  and  Instrumentation for Hydrocarbons
         and  Carbon  Monoxide  in  Stationary Source  Emissions.
         Walden    Research   Corporation.    EPA   Contract   No.
         68-02-0320.  EPA-R2-72-106.  November 1972.

18.  Elliot,  T.  C.  "Monitoring  Boiler  Stack  Gases,"  Power,
         p. 92-94,  April 1975.

19.  "Environmental  Yearbook   and  Product  Reference   Guide,"
         Pollution Engineering,  vol. 9, no. 1, January 1977.

20.  Fennelly, Paul  F. Development  of  an Implementation Plan for
         a Continuous Monitoring  Program.  GCA Corporation.  March
         1977.
                          V-2

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21.  Green, M. W. ,  R.  L.  Chapman,  S.  C.  Creason, R.  N.  Harvey,
         G.  A.   Heyman,   and   W.  R.  Pearson.   Evaluation  of
         Monitoring Systems  for  Power Plant  and  Sulfur Recovery
         Plant Emissions.  Beckman  Instruments,  Inc.  EPA Contract
         No. 68-02-1743.  EPA 600/2-76-171.  June 1976.

22.  Homolya, J.  B.  "Continuous  Monitoring  Systems  for  Gaseous
         Emissions,"  EPRI  Workshop  Proceedings,  Special  Report
         #41, p. 17, October 1975.

23.  Homolya,  J.   B.   "Coupling  Continuous  Gas   Monitors  to
         Emissions Sources," Chem Tech, p. 426-33, July 1974.

24.  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.

25.  James,  R.   E.  and  C.  D.   Wolback.   "Quality  Assurance  of
         Stationary  Source Emission  Monitoring  Data,"  Inst.  of
         Electrical  and Electronics  Engineers,  Inc., Vol.  36,
         1976.

26.  Jaye,   Frederic   C.   Monitoring  Intrumentation   for   the
         Measurement  oj  Sulfur  Dioxide  in  Stationary  Source
         Emissions.  TRW  Systems Group. EPA  Project  17205,  NTIS
         PB 220202.

27.  Karels, Gale G., Gary R. Kendall, Thomas  E.  Perardi, and A.
         Levaggi. Use of Real-Time  Continuous Monitors in Source
         Testing. Presented  at  APCA Annual Meeting,  June 15-20,
         1975. Paper 75-19.5.  NTIS PB 230934/AS GPO.

28»  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.

29.  Lord,  Harry  C. ,  III. "In-Stack  Monitoring  of  Gaseous  Pol-
         lutants,"  Engineering  Science and Technology,  vol. 12,
         no. 3,  p. 264-69, March 1978.

30.  McRanie, Richard  D. ,  John  M.  Craig, and George  0.  Layman.
         Evaluation of_  Sample  Conditioners and  Continuous  Stack
         Monitors  for  Measurement  of S02, NOx,  and  Opacity  in
         Flue Gas. Southern Services, Inc. February 1975.

31.  McNulty, K.  J.f J.  F. McCoy, J.  H. Becker,  J.  R.  Ehrenfeld,
         and  R.   L.   Goldsmith.   Investigation   of_  Extractive
         Sampling Interface Parameters. Walden  ResearchDivision
         of  Abcor,   Inc.   EPA  Contract  No.  68-02-0742.  EPA  -
         650/2-74-089.  October  1974.
                          V-3

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32.  Nader,   John   S.    "Current   Technology   for   Continuous
         Monitoring of Particulate Emissions," Journal of the Air
         Pollution Control Association,  vol.  25,  no. 8,  p.  814-
         821, August 1975.

33.  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.

34.  Osborne,  Michael  C.   and   M.   Rodney  Midgett.  "Survey  of
         Continuous  Gas  Monitors to  Emissions  Sources,"  Chem
         Tech, p. 426-33, July 1974.

35.  Osborne,  Michael   C.  and   M.  Rodney  Midgett.  Survey  of
         Transmissometers  Used   in Conducting Visible  Emissions
         Training Courses.  EPA  - 600/4-78-023.  May 1978.

36.  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.  68-01-4148,
         Tasks 42 and 57.  February  1979.

37.  "Pollution  Control  Issue,"   Environmental Science  and Tech-
         nology, vol. 10, no. 11, October 1976.

38.  "Product  Guide,"  Journal   ojt  the  Air  Pollution  Control
         Association, vol. 27, no.3,  March 1977.

39.  Quick,  Durle  L.  Field Evaluation  of. S02  Monitoring Systems
         Applied _to  H2S04  Plant  Emissions;  Volumes  1^  and  II.
         Scott   Environmental   Technology.   EPA    Contract   No.
         68-02-1292.   EPA  650/2-75-053a   (Vol.    I)    and   EPA
         650/2-75-053b (Vol.  II). July 1975.

40.  Reisman,  E. ,  W.  D.  Gerber, and  N.  D.  Potter.  In-Stack
         Transmissometer Measurement ^f  Particulate Opacity  and
         Mass   Concentration.    Philco-Ford   Corporation.   EPA
         Contract  No.  68-02-1229.  NTIS  PB  239864/AS.  November
         1974.

41.  Repp,   Mark.  Evaluation  jof   Continuous  Monitors  for CO  J_n
         Stationary Sources.  EPA 600/2-77-063.  March 1977.

42.  Scott  Environmental  Technology, Inc.  Continuous  Monitoring
         of  ^  Copper  Smelter   Acid Plant.  Phelps  Dodge  Ajo.
         Arizona Report No. 73-CUS-2.
                          V-4

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43.  Scott Environmental  Technology,  Inc. Summary  of Continuous
         Monitoring  Opacity   Data,   Refinery  FCC   COBoiler/
         Phi Hips Petroleum.  Avon,  California. EPA  Contract No.
         68-02-1400. Report No. 74-CAT-2.  March  1976.

44.  Scott  Research  Laboratories.  Continuous  Monitoring  of  ^
         Copper Smelter  Double Contact  Process  Acid  Plant.  EPA
         Contract No. 68-02-0233.  Report No. 73-CUS-2. May 1974.

45.  Shigehara, R.  T.  "Sampling  Location  for Gaseous Pollutant
         Monitoring   in   Coal-Fired   Power   Plants,"   Source
         Evaluation Society Newsleter,  July 1978.


46.  Sholtes, R. S.  and  J.  R. Dallar.  Continuous  Measurement of
         Sulfur   Dioxide   Emissions.    Mississippi    Chemical
         Corporation;  Pascagoula, Mississippi.  EPA   Report  No.
         73-SFA-3B.

47.  Snyder,  Arthur  D. ,  Edward  C.  Eimutis,  Michael  G.  Konicek,
         Leo  P. Parts, and  Paul  L.  Sherman.  Instrumentation for
         the   Determination  ojE  Nitrogen  Oxides   Content   of
         Stationary Source  Emissions;  Volumes  1^  and  II.  NTIS PB
         204-877 (Vol. I) and  NTIS PB  209-190  (Vol. II).  January
         1972.

48.  Stanley, Jon  and  Peter  R.  Westlin. "An  Alternative  Method
         for  Stack Gas Moisture Determination," Source Evaluation
         Society Newsletter, November 1978.

49.  Tomaides,  M. Instrumentation for  Monitoring the  Opacity of
         ParticulatiEmissionsContaining Condensed  Water.  EPA
         600/2-77-124.   August 1974.

50.  United  States  Environmental  Protection Agency.  Continuous
         Air   Pollution    Source   Monitoring   Systems.    EPA
         625/6-79-005.   June 1979.

51.  United  States  Environmental  Protection Agency.  "Standards
         of  Performance  for   New Stationary  Sources,"  Federal
         Register 40:46250-70.  October 6, 1975.

52.  Westlin,  Peter   R.   and  John   W.  Brown.   "Methods   for
         Collecting  and  Analyzing Gas Cylinder  Samples,"  Source
         Evaluation Society Newsletter, September 1978.

53.  Roy  Weston,  Inc.  Final  Report   Alan  Wood  Steel  Company,
         Conshohocken Pennsylvania. EPA  Contract No.  68-02-0240.
         Report No.  73-BOF-l.  December  1975.
                          V-5

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54.  Woffinden and  Ensor.  Optical  Method for Measuring  the  Mass
         Concentration  gf  Particulate  Emissions.   Meterology
         Research,   Inc.   EPA   Contract  No.  68-02-1749.   EPA
         600/2-76-062. March 1976.

55.  Wolf,  Philip C.  "Continuous  Stack Gas Monitoring  -  Part
         One: Analyzers,"  Pollution  Engineering,  p.  32-35,  June
         1975.

56.  Wolf,  Philip C.  "Continuous  Stack Gas Monitoring  -  Part
         Two: Gas Handling Components and Accessories," Pollution
         Engineering, p. 26-29, July 1975.

57.  Wolf,  Philip C.  "Continuous  Stack Gas Monitoring  -  Part
         Three:   Systems Design,"  Pollution  Engineering, p.  36-
         37, August 1975.

58.  Zegel, W.  C. and  T.  Lachajczyk.  "The  Value  of  Continuous
         Monitoring  to  the User,"  Journal  of the  Air Pollution
         Control  Association, vol. 25,  no.  8, p.  821-23,  August
         1975.
                           V-6

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                         V-7

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                              TECHNICAL REPORT DATA
I Hi l\*:\ I Nt\
  340/1-79-010
.1. Tl i Li A\'L> SUIU 11 LI.

     Regulations  and  Resource 1:ile of  Continuou
     Monitoring  Information
     William J.  Pate
'.I. Pt RKOHMINU ORGANIZATION NAME AN U ADDRESS
     Entropy Environmentalists,  Inc.
     P.  0.  Box 12291
     Research Triangle Park,  N.  C. 27709
 12. SPONSORING AGENCY NAME AND ADDHtSS
     U.  S.  Environmental  Protection Agency
     Office of Enforcement
     Office of General  Enforcement
     Washington. D. C.  20460	.
                                                   I. HI Cll'li NT'S ACCESSION-NO.
                                                  !). MLI'OFU PA I I
                                                    October,  1979    	
                                                  G. I'bRHORMING ORGANIZATION CODE
                                                  8. PERI-'ORMING ORGANIZATION REPORT NO.
                                                  10. PROGRAM ELEMENT NO.
                                                  11. CONTRACT/GRANT NO.


                                                   68-01-4148
                                                  13. TYPE OP REPORT AND PERIOD COVERED
                                                     Interim
                                                  14.
                                                                 cote
 15. SUPPLEMENTARY NOTES
 16. ABSTRACT
     The  Environmental  Protection Agency  has  promulgated revisions to
     40  CFR Part 60, New  Source Performance   Standards, and  40  CFR
     Part 61, National  Emission Standards  for Hazardous Air  Pollutants
     that require specified categories of  stationary sources  to
     continuously monitor emissions.  The  EPA has also required States
     to  revise their SIP's to include continuous emission monitoring
     regulations.
     This report is a  compilation of the  following continuous emission
     monitoring  information:  EPA  organizations and personnel involved
     with continuous emission monitoring;  continuous emission monitoring
     regulations; vendors of continuous monitoring equipment; and a
     bibliography of continuous monitoring literature.
17.
                           KEY WORDS AND DOCUMENT ANALYSIS
               DESCRIPTORS
      Continuous Emission Monitoring
        Regulations

      New Source Performance Standard
                                       I).IDENTIFIERS/OPEN ENDED TERMS
                                        Continuous  Emission
                                        Monitoring
                                                             c. COSATl Hi'ld/Ciruup
13B


140
;••:. u: :THIUU i M IN si AH MI N i

      Release Unlimited
                                       r.i. sfccuniTY CLA:,S iriiix /<<•/><>;•/,/
                                       .... iJ.!l£JL''is..s_i..f L_cd	
                                       20. SECURITY CLASS "{Tltis iiagc)
                                        Unclassi f i ed
                                                             21. NO. 1)1 I'AC.LS
                                                              22. PRiCI:
EPA Form 2220-1 (9-73)

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