&EPA
            United States
            Environmental Protection
            Agency
Office of Air Quality
Planning and Standards
Research Triangle Park NC 27711
EPA-450/2-81 -080
November 1981
            Air
            Analysis of  State
            and Federal Particulate
            and Visible  Emission
            Combustion Sources

-------
                                     EPA-450/2-81-080
Analysis of State and  Federal Particulate
     and Visible  Emission  Regulations
           for Combustion  Sources
                          by

                    PEDCo Environmental, Inc.
                      11499 Chester Road
                     Cincinnati, Ohio 45246
                    Contract No. 68-02-3512
                    Work Assignment No. 12
                        PN 3525-12
                 Project Officer: Kenneth R. Woodsrd

               U.S. ENVIRONMENTAL PROTECTION AGENCY
                Control Programs Development Division
               Research Triangle Park, North Carolina 27711

                       November 1981

-------
This report is issued by the Environmental Protection Agency to report
technical data of interest to a limited number of readers.  Copies are
available - in limited quantities - from the Library Services Office  (MD-35) ,
U.S. Environmental Protection Agency, Research Triangle Park, North
Carolina 27711; or, for a fee,  from the National Technical Information
Service, 5285 Port Royal Road,  Springfield,  Virginia 22161.
                                 Publication No. EPA-450/2-81-080

-------
                                  CONTENTS
Figures                                                                 iv
Tables                                                                   y
Acknowledgment                                                          vi

1.   Introduction                                                        1

2.   Nationwide Summary of Mass Emission Rates                           3

3.   Regulation of Particulate Emissions from Fuel Combustion           13

          3.1  Regulation under the Clean Air Act                       13
          3.2  State Implementation Plans                               14
          3.3  Federal Standards of Performance for New Sources         20

4.   Boiler Emissions and Control Techniques                            24

          4.1  Control of Particulate Emissions                         24
          4.2  Relationship Between Allowable Emissions and Other
                Parameters                                              32

5.   Compilation of Particulate Mass and Visible Emission Limits        35

          5.1  Summary of Mass and Visible Emission Regulations
                by State or Territory                                   35
          5.2  Summary of Continuous Monitoring Requirements for
                Opacity                                                 37
          5.3  State and Territory Specific Summaries                   38

References                                                             109

Appendix A     Reference figures for allowable emission rates          113
Appendix B     Conversion factors                                      170
Appendix C     Method 5—Determination of particulate emissions
                from stationary sources                                173
                                     iii

-------
                                   FIGURES

Number                                                                   Page

  1       Histogram of Emission Limits for Selected Boiler Sizes            9

  2       Typical Mass Rate Regulation Applicable to Solid
            Fuel-fired Boilers Based on Equipment Capacity                 15

  3       Typical Mass Rate Regulation Applicable to Solid Fuel-Fired
            Boilers Based on Firing Rate                                   16

  4       Range of Boiler Sizes by Use                                     25

  5       Relative Uncontrolled Particulate Emissions from Various
            Fuel/Boiler Combinations                                       26

  6       Control Efficiency vs. Particle Size for Mechanical
            Collectors                                                     29

  7       Relationship between Collection Efficiency and SCA for
            Various Coal Sulfur Contents                                   30

  8       Nomograph for Relating Allowable Emissions and Overall
            Control Efficiency                                             33

  9       Particulate Emission Rates for a Typical Pulverized
            Coal-Fired Boiler                                              34
                                       IV

-------
                                   TABLES

Number                                                                   Page

  1       Summary of Allowable Mass Emission Rates for Indirect
            Heat Exchangers                                                 4

  2       Conversion Factors for Particulate Emission Regulations          10


  3       Comparison of Allowable Particulate Emissions under Various
            Interpretations of the Regulations for Two Co-Fired
            Furnaces Rated at 200 x 106 Btu/h Each                         17

  4       Comparison of Light Extinction Terms                             19

-------
                               ACKNOWLEDGEMENT
     This report was prepared for the U.S.  Environmental Protection Agency by
PEDCo  Environmental,  Inc.,  Cincinnati,  Ohio.   Mr.  Kenneth Woodard  was  the
Project  Officer.   Mr.  Donald  Henz  served  as  the  Project  Director  and
Mr.  David  Dunbar  was  the  Project  Manager.    The  principal  authors  were
Ms.  Barbara Blagun, Mr. David  Dunbar,  and  Mr.  Donald Henz.   The authors wish
to  thank Mr. Kenneth  Woodard for  his  overall  guidance  and  direction  and
Mr.  John Calcagni for his comments and suggestions.   The authors also wish to
thank Mr. Willis Beal  for  his assistance in locating  the  files on the State
Implementation Plan requirements.

-------
                                  SECTION 1
                                INTRODUCTION

     The purpose  of this  report  is to  compile the  particulate  and visible
emission  limits  from  the  State  Implementation  Plans  (SIP's) and  Federal
standards of  performance for  new stationary sources that  are  applicable to
fuel combustion  sources.   This  report  was developed to serve  as  a starting
point  for  broad  control  strategy evaluations  and  is not  intended to  be  a
precise  reference for  individual compliance determinations.  Users are cau-
tioned  to  contact  the  appropriate State and/or local air pollution control
agency  and  EPA  Regional  Office to verify the specific emission limits appli-
cable to an individual  source.  The definition of fuel combustion varies from
State to State,  but in all cases, fuel  combustion regulations apply to util-
ity and industrial boilers that burn fuel to generate steam.  The regulations
compiled in this  report  generally do not apply to particulate emissions from
incineration or industrial processes.
     The SIP's  are designed  to  ensure  that all areas within a State attain
and maintain  the  National  Ambient Air Quality Standards  (NAAQS's).  Although
most regulations  in an SIP are State regulations,  there  are some cases where
a State  has  chosen to  include a  local regulation as part of the SIP.  There-
fore, this  report  includes  not  only those  State  regulations that represent
the SIP for an individual State or territory but also those local regulations
that are considered to be part of the SIP as well.
     The basic  references for this report are a  series  of reports prepared
for the U.S.  Environmental  Protection  Agency  (EPA)1-55  as  a  result of the
Clean Air  Act Amendments  of  1977.   The 1977 Act  amendments  required EPA to
prepare  an  official  SIP  compilation  for  each State  or  territory.   These
compilations  represented  all  the  regulations  contained  in the SIP's  as of
July 1, 1979.   However,  because  some regulatory actions have been  taken  over
the past several years  to revise the SIP's to comply with the 1977  Act amend-
ments,   PEDCo  reviewed  all  Federal Register notices published between July 1,

-------
1979, and April 1,  1981,  to determine if  any  revisions  to the SIP fuel com-
bustion regulations  were made  since July 1, 1979.   In  addition,  PEDCo also
reviewed the current  State  regulations published in the Environment Reporter
as of April  1,  1981, to ensure that the SIP regulations contained in this re-
port represent the most current SIP regulations applicable to fuel combustion
sources.  As a  final  check, the compilation of regulations contained in this
report  was  compared to  the summary  of  SIP regulations  for fuel combustion
sources  published by  EPA  in  August  1976.56   During this  comparison, some
questions arose regarding  the  form or applicability of the equations used in
the  regulations.   As a  result,  contacts  were  made  to  individual  States to
clarify these questions.
     In  this  report, Section  2.0  summarizes and  compares the mass emission
rates  for all  50  States, the District of Columbia, and the four territories.
Section  3.0 discusses regulation of  particulate  emissions from fuel combus-
tion  sources.   Section 4.0  discusses emissions  from and control techniques
used  for boilers.   Section 5.0  compiles  the  particulate mass  and visible
emission regulations by State and political jurisdiction.
     Appendix A contains  figures  referred to in the compilation of the  State
and  local  regulations (Section 5.0);  these  are  graphical representations of
the  equations  or  tables used to calculate  the  allowable emissions for  indi-
vidual  fuel combustion  sources.   Appendix  B  lists  some conversion factors
commonly associated with fuel combustion sources and their applicable regula-
tions.  Appendix  C contains a copy of  EPA Reference Method 5.

-------
                                  SECTION 2
                  NATIONWIDE SUMMARY OF MASS EMISSION RATES

     Table 1 summarizes  the mass  emission rates for all  50  States,  the Dis-
trict of  Columbia,  and  the four  territories.   This table indicates  how the
allowable emissions  are  to  be  applied,  such as entire plant,  an  individual
boiler or an individual stack.   This table also presents the  allowable limits
in lb/106 Btu for typical sizes of new and existing boilers.   Because all the
State regulations  are not  expressed  in  terms  of  lb/106  Btu  some  conversion
was  necessary  in order  to  compare typical size boiler or combustion units.
Table 2  lists  the  conversion factors and the assumptions used to convert the
emission limits of the individual  regulations to lb/106 Btu.
     All of the new source emission limits listed in Table 1  do not represent
the  New Source Performance  Standard  (NSPS) limits  in all cases.   Although
                                      •
some States  have adopted the NSPS limits  as promulgated  by  EPA, others have
developed their  own more stringent  limits especially  for sources  less than
250 x 106 Btu/h,  because the NSPS  limits  do not apply to these  size units.
Additionally, some  States do not  require new sources  to  meet any limit more
stringent than that required of existing sources.   In those  cases, no number
is presented in Table 1.
     Table 1 indicates for  small  units (10 x 106 Btu or less) that allowable
emission  limits  vary from  0.10 to 1.2  lb/106  Btu and that  most  limits are
between 0.4  and  0.8 lb/106  Btu.  For  existing  250 x io6  Btu/h units, allow-
able emission limits vary from 0.05 to 0.8 lb/106 Btu with most States having
a  limit between  0.1  and 0.5 lb/106  Btu.   Finally, for  the  existing larger
units,  i.e., 10,000 x io6 Btu/h or more, the allowable limits vary from 0.01
to 0.8  lb/106  Btu,  with over half  of the States  having  a limit between 0.1
and 0.20 lb/106 Btu. Figure I is a histogram of emission limits for 250 x io6
Btu/h,  1000 x  io6  Btu/h,   and  10,000 x IO6 Btu/h  units.   With  respect  to
applicability,  over half the  States  apply the  regulations  on an individual
stack basis  with the  remainder of the States  almost  evenly  divided between
applying the regulations  to the individual unit or the entire plant.

-------
            TABLE  1.   SUMMARY  OF  ALLOWABLE MASS EMISSION RATES FOR INDIRECT HEAT EXCHANGERS
















State

Alabama
Class 1
Class II
Alaska
Arizona
Arkansas
California0
Colorado
Connecticut
Delaware
District of
Columbia
Florida
Georgia
Hawa 1 1
At lowabTe
emissions
based on:




*j
c


0.

41
l_

*J
C
IAJ



X


X









c
*3


n
3
-a

>

TD
C


X





X


X
X
X

xt
u
•9
*>
in


•a
3
t7

>

tJ
cr

X

X


X



X














t-
«
.c
*J
o













ExTstTng SOUTCP
1 f mi ts for typicfl 1
units, 1b/10* Btu



£
- —
3
4-1
00

«
o


X
0
r- 1
.50
.80
-2°h
.21b
.60
1.2

.27
.20
.30

.10
.10
.70



jr
\
3
«J
to


O
r-l

X

8
•-"
.18
.21
.20?
.21b
.35
.75

.16
.20
.30

.06
.10
.44



/=
\
3
*J
al

«
0


X

O
in
C-J
.12
.12
X
.21b
.28
.56

.14
.20
.30

.05
.10
.37


JC
^.
3
en

«
0
.-H

X

0
o
a
r-*
.12
.12
.ZO?
.21b
.21
.24

.10
.20
.30

.03
.10
.2B

c
3

CD

0


X

0
o
o
o
l->
.12
.12
.20'
.21b
.09
.07

.10
.20
.30

.02
.10
.24

New source 1 units
for typical units.
lb/10" Btu



£
^
3
«J
oa

«
o
r-*

M
O
rH
.5
.5
•K
.llb




.10



.10
.50



JZ

«-»
da

«
o
i-»

X

o
o
r4
-18
.18
X
.nb




.10



.10
.16



.c
^v.
3
«-»
CO

«
^
•-4

x

s
CM
.12
.12
.lOJJ
.llb



.10
.10



.10
.10


f
**^
3
4-t
m

«
o
r^

X

^
o
o
f-1
.12
.12
X
.nb



. .10
.10



.10
.10

-C.
"***
3
4_»
CO
0
o
r-*

X

o
^
o
o
—«
.12
.12
.10»
.llb



.10
.10



.10
.10



Footnotes















Existing .10 gr/scf, new .05 gr/scf
assuming 50t excess air - coal.
Existing .10 gr/scT. new .05 gr/scf
assuming 501 excess air - oil.

cHo Statewide regulations.









(continued)
 Note:   New source performance standards (40 CFR 60.40 and 60.40a)  supersede  less
        stringent State emission limits where applicable.

-------
TABLE 1 (continued)










State
Idaho
Illinois'*
Illinois'"
f
Indiana
Indiana9
lowah
Iowa
Kansas
Kentucky J
Kentucky1
Kentucky
Louisiana
Maine
Maryland

Allowable
•missions
based on:

—
c
"a.



c
UJ



X
X






X




5

I



•o
c








X
X
X




J,
99
*t
«i
^_
3
•o



c

X
X


X
X
X




X
X






L
V
5
O
X














Existing source
Units for typical
units, lb/10* Btu

JE
n
O
t-i

K
S
.60
1.0
.10
.80
.60
.60
.80
.60
.56
.75
.80
.60
.60
.60


JC
5
ID
S

K

O
O
.36
.19
.10
.80
.40
.60
.80
.35
.33
.44
.49
.60
.34
.35


JC
a
ID
W
O
1-t

X

o
„
.10
.10
.80
.35
.60
.80
.28
.26
.35
.34
.60
.30
. 28

f
3
ID

3
K

O
O
O
.20
.10
.10

.28


.21
.19
.26
.30
.60
.30
.21

|
CO
o
r-4
X
O
O

O
.12
.10
.10

.20


.12
.11
.15
.18
.60
.30
.12

New source limits
for typical units.
lb/10* Btu

JZ
*J
CD
O


X
O

.10
.10
.60

.60
.60

.56
.56
.56


.4


*
to
f.

K

1

.10
.10


.60
.60

.33
.33
.33


.22


|
CD
S

X

o
3

.10
.10

.10
.60
.60

.10
.10
.10


.10

c.
3
CD

S
X


o
o
1-t

.10
.10

.10



.10
.10
.10


.10

JC
at
o
K



o

.10
.10

.10



.10
.10
.10


.10



Footnotes








Chicago metropolitan area.
eOuts1de major Metropolitan Chicago.
All areas except lake and Porter Counties
and Indianapolis AQCR - Missing values
dependent upon stack height.
'lake and Porter Counties and
Indianapolis AQCR.
hlns1de SMSA - Missing values dependent
upon stack height.
'outside SMSA - Missing values dependent
upon stack height.
•'Priority I areas.
""Priority 11 areas.
i
'Priority III areas.
  (continued)
  Note:   New source performance standards (40 CFR 60.40 and 60.40a) supersede less
          stringent State emission limits where applicable.

-------
TABLE 1 (continued)










State
Massachusetts
Michigan

Minnesota
Mississippi
Missouri
Montana
Nebraska
Nevada
New Hampshire
New Jersey
New Mexico
New York5'1

North Carolina

Allowable
emissions
based on:


|
"a.

c

c
UJ




X

X
X








c
_
3
TJ
"^

C

X








X




*
S
^.
^
•O
"£

£
X


X
X
X


X
X

X

X






t.
V
o















Existing source
Km Us for typical
units. lb/10fi Btu

^
OD
w
O
r-t
X
o
r-t
.15m
.38°
.35"
.60"
.60
.60
.60
.60
.60
.60
.60
.70
.60

.60,,
.70"

~3
en
o
.-t
X

I
.15
•38°
.35P
.60"
.40
.40
.40
.35
.35
.40
.15
.50
.37

.33
.41"
e-
3
CD
*
o

X

o
m
tM
.15
•33°
.30"
.60"
.35
.36
.35
.28
.28
.35
.10
.50
.30

.26,,
.34"
f.
5
«
o

X
o
o
o
.15
2^O
"21P
.60"
.28
.26
.20
.21
.21
.28
.10
.50
.23

.18
.25"
.C
3
GO
O


O
0
o
o
.15
.23°
.21P
.60"
.19
.18
.19
.15
.09
.19
.10
.50
.14

.10,,
.15"
New source limits
for typical units,
lb/10s Blu

.c
oa

0
i-l
X
rH
.10


.40r
.60
.60


.60

.56
.60




|
01
*
S
X

o
3
.10


.40r
.275
.35


.35

.33
.37




|
CD
«0
^
x

O
m
.10


.40r
.232
.10


.10

.27
.10



^
3
m
0

X

o
0
.05"


.40r
.126
.10


.10

.19
.10



.C
^
CD
«

**
g

C3
.05"


.40r
.10
.10


.10

.14
.10





Footnotes








""Critical areas limit Is 0.12 Berkshire,
Central Mass., Merrlmack Valley, Metro.
Boston Pioneer Valley, S.E. Mass Air
Pollution Control Districts.
n0.10 allowed If equipment Is used to con-
trol or reduce SO^ at the same time.
"Conversion from lb/1000 1b stack gas coal.
"Conversion from lb/1000 Ib stack gas oil.
''Also applies to sources located outside
the Mlnneapolls-St. Paul AQCR and the
City of Ouluth.
rAlso applies to sources located within
the Mlnneapolls-St. Paul AQCR and the
City of Duluth.
5 Ho handflred bituminous coal units.
t K
lNo oil units <_ 10 lb/10 Btu.

"Wood burning.
(continued)
 Note:   New source performance standards (40 CFR 60.40 and 60.40a)  supersede  less
        stringent State emission limits where applicable.

-------
TABLE 1 (continued)










State
North Dakota
Ohio


Oklahoma

Oregon

Pennsylvania
Rhode Island
South Carolina
South Dakota
Tennessee
Texas
Utah
Vermont
Virginia
Allowable
emissions
based on:

—
c
IV
OL



C
UJ











X





c
3
_
TJ



£




X



X



X
X


^
V*
__
Mi
•o



i
X
X




X


X
X

X

X
X





I.

5
o
















Existing source
limits for typical
units, lb/10* Btu

£
CO
?>
t-l

X
o
r-t
.80
.40V
.60"

.60

.46
.43*
.40
.20
.80
.30
.60
.30bb
.60
.50
.40dd

£
m
3

X

O
o
i-H
.80
.20"
.60"

.35

.46
.43*
.27
.20
.60
.30
.33
.30bb
.42
.18
.29

|
CO
o

X

o
.80
.15*
!30*

.28

.46
.43*
.16
.10
.60
.30
.26
.30bb
.36
.10
.23
c.
^
m
•9
S
X

o
g
r-4
.80
.10"
.15"

.20

.46
.43*
.10
.10
.60
.30
.18
.30bb
.29
.10
.17
£
«J
01
•a
3
X

O
CD
O
r-l
.BO
-10*
.15"

.10
.,x
.46
.43*
.10
.10
.16
.30
.10
.30bb
.20
.06
.01
New source limits
for typical units.
lta/10* Btu

JC
to



X

.60




y
• 41
.21


.60

.60
.10"



|
a
3

X

§
.44




y
"•41
• 21


.60

.17
.10"



£
aa
3

X

a
CM
.10




!•&
* ••
. 21


.60
.10
.10
.10"


£
«J
a

3


o
O
3
.10




y
a a
.21


.60
.10
.10
.10"


£
ID
3
M



s"
.10




*f
' aa
.21


.16
.10
.10
.10"




Footnotes








v Priority 1 Regions.
" Priority II » III Regions.
" .2 gr/scf assuming SOX excess air - coal
fired.

y .2 gr/scf assuming SOX excess air - oil
fired.

1 .1 gr/scf assuming SOX excess air - coal
fired.
".1 gr/scf assuming SOX excess air - oil
fired.
bbSo11d fossil fuel fired steam generators
only.
"Men fossil-fuel fired steam generators
only.
ddValue Is for AQCR fI-6 value for AQCR
11 Is .30. All other values are the
same as AQCR 1-6.
 (continued)
  Note:  New source performance standards  (40 CFR  60.40  and  60.40a)  supersede less
         stringent State emission limits where applicable.

-------
      TABLE 1 (continued)














State

Washington
West Virginia
Wisconsin

Wyoming

American Samoa

Guam
Puerto Rico
Virgin Islands
Allowable
emissions
based on:




c

a.




c
UJ
X
X




X






c



1
TJ



C
^^










X
^
u
2
in


•O
TJ



•o
c
•— t


X

X




X










u

.c
o







11
X


Existing source
limits for typical
units, lb/10* Btu


^


03
„
o


K
O
f— *
.,ee
.46ff
.43ff
.34
.60
"l5hh
.60

.10


.30
.60

.c


CO

o


K

O
0
t— <
.46"
.43ff
.17
.60
]l5hh
.40

.10


.30
.35


~5

CD

0


K

0
01
rsi
Xf
.09
'^aa
'l5hh
.31

.10


.30
.33
-C

13
1X3

(0
O
.-«

K

O
o
0
•— '
!43ff
.09
.25
'l5hh
.27

.10


.30
.21
^

CO
<0
o

X

o
o
o
0
r— *
'ffi
.09
.15
'l5hh
.20

.10


.30
.09
New source 1 imits
for typical units,
lb/10« Btu


*;


CO
V

r-f

X
o

2,ee
21ff

.15

.10








"5

CO

o


K

O
O

:""

.15

.10







.C
3

CO

V


x

o
CM
21ff

.15

.10








3
ta

«
o

X


o
rH
:""

.10

.10






JC

to

o

K

o


o

?,ee
•'Jff
.21ff

.10

.10








Footnotes













"Existing .20 gr/dscf. new .10 gr/dscf
assuming 501 excess air - coal.
ff Existing .20 gr/dscf, new .10 gr/dscf
assuming 501 excess air - oil.
q9Subreg1on of Lake Michigan AQCR.
Sources In S.E. Wisconsin AQCR.
Did not specify.





00
         Note:
New source performance standards (40 CFR 60.40 and  60.40a)  supersede  less
stringent State emission limits where applicable.

-------
t/>
uj to
t— UJ
 o

u.t  10
o a:
  cz
on LU
UJ h-
CQ
x: cc
=> o
Zl
                    10,000 x 106 Btu/h
                          BOILER
                          Elt
ro
o
oo
UJ 00
h— LU
«t —
h- a:
oo O


U. i—•
O Qi
  OL
on uj
UJ H-
CO
2: Qi
rj o
H-"
o
o
                         1,000 x 106 Btu/h

                               BOILER
20 ,.
NUMBER OF STATES
OR TERRITORIES
i— •
0 0
.






250 x 106 Btu/h
BOILER

1 	 1
      0.1   0.2   0.3   0.4   0.5   0.6   0.7   0.8

                     EMISSION RATE, lb/106 Btu
                                                           0.9
1.0
Figure 1.  Histogram of emission limits for selected boiler sizes,

-------
  TABLE  2.   CONVERSION  FACTORS  FOR  PARTICULATE  EMISSION REGULATIONS56
Units of the regulation (A)
grains/SCF (assuming X is known)
Coal
Oil
grains/SCF (assuming X = 50%)
Coal
Oil
grains/SCFD (assuming X is known)
Coal
Oil
grains/SCFD (assuming X = 50%)
Coal
Oil
Ib/h
Coal
Oil
lb/103 Ib stack gas
Coal
Oil
E(lb/10b Btu)
(1.99
(2.094
2.905
3.091
(1.96
(2.094
2.905
3.091
A/Q
A/Q
1.596
1.668
x 104 + 1
x 105 +
x 104 A/H
x 105 A/H
x 104 + 1
x 105 +
x 104 A/H
x 105 A/H

x 104 A/H
x 105 A/H
.89 x 102X) A/H
1.993 x 103X) A/H

.89 x 102X) A/H
1.993 x 103) A/H



 A     SIP value in given units
 H     Heat content of fuel  in Btu/lb for coal  or Btu/gal  for oil
 E     Emission of particulates  in units  of lb/106 Btu
 X     Excess air in units of %  excess
 Q     Heat input rate in units  of 106 Btu/h

 Assumptions:

 1.     Density of fuel oil is assumed to  be 7.88 Ib oil/gal  oil.
 2.     In the conversion from units of grains/SCF, grains/SCFD,  and Ib
       particulate/103 Ib stack  gas,  it is assumed that coal  contains
       72%C, 5%H2, 1%S, and 10%  moisture.
 3.     In the conversion from units of grains/SCF, grains/SCFD,  and Ib
       particulate/103 Ib stack  gas,  it is assumed that oil  contains
       88%C, 9.5%H2, and 0.5% moisture.
 4.     Air fed to the boiler is  assumed to contain no moisture.
 5.     Molecular weight of the stack gas  is assumed to  be 29.5 Ib/lb mole.
 6.     Complete combustion is assumed.
 7.     Standard conditions for stack gas  is taken as 1  atmosphere and
       60°F.
 8.     Stack gas is assumed to be an ideal gas.
 9.     Heat content of coal  is assumed to be 1.25 x 104 Btu/lb.
10.     Heat content of oil is assumed to  be 1.45 x 105  Btu/gal.
                                    10

-------
     For new sources, the allowable emission limits for units less than 250 x
106  Btu/h  vary  from 0.1  to 0.6  lb/106  Btu.   For  new  sources with  units
greater than  250 x  106  Btu/h,  the  limits are generally  0.1 lb/106  Btu  or
less; however, some  limits  are  above 0.1 lb/106 Btu.   In  cases where an NSPS
source would  be  involved,  State  emission  limits  above 0.1  lb/106  Btu  would
not be applicable  because  the  NSPS limits  require sources to meet 0.1 lb/106
Btu  or  less  (0.03  lb/106  for steam  electric  generating  units  greater than
250 x 106 Btu/h).
     In addition to  Table  1,  which compares selected  unit sizes,  Appendix A
contains a series  of reference  figures that provide  a graphical  representa-
tion of the  allowable  limits  for the full  size range of units covered by the
various State regulations.  Although  the general  shape of the figures is the
same, the emission  limits  associated with  certain size units  vary.   In some
cases, the  stringency of  the  limit,  i.e.,  lb/106 Btu,  is the  same  for all
units  less  than  10  x  106  Btu/h.   In  other cases, however, the  size  of the
unit  where  the  stringency of  the  limit  remains constant  is 100  or  250 x
106 Btu/h.   On the  other end of the scale, the size of the unit beyond which
the  stringency of  the  limit remains constant  is  usually  10,000  x 106 Btu/h;
although in  some cases,  the  size of  the  unit where the stringency  of the
limit remains constant is 1000 or 3000 x 106 Btu/h.  Therefore, the reference
figures provide  an  additional  method for comparing the overall  SIP require-
ments for fuel combustion sources.
     It is difficult to draw absolute conclusions  regarding the stringency of
one  State's  requirements as  compared  to another.   In some  cases,  one State
may  be  more stringent  than another with  respect to  smaller  units but less
stringent with respect to larger units, or vice versa.  In other cases, there
are  exemptions  for  certain  size  sources  or  for  particular  fuel  types that
make it difficult  to compare the emission limits.   Since not all regulations
are  in  the  same units,  assumptions  were made to  convert  the  emission limit
units to  lb/106  Btu.   Although  these  assumptions  are reasonable,  they are
only estimates and  the  absolute  number  in  lb/106  Btu can only be calculated
on a case-by-case  basis with specific  source  information.   Finally, because
the air quality  problems across  the country vary  from region to region, the
relative stringencies  of the  requirements vary.   In  some cases, the States
are concerned with reducing air quality levels which are far in excess of the

                                       11

-------
NAAQS's; while  in cases,  the States are concerned with  maintaining current
air  quality  levels,  and therefore  do  not  have to require the  same  level  of
control  from  all  sources  in all areas  of  the State.  Thus, while  there  is
some variability in the overall SIP requirements for fuel  combustion sources,
in  many cases  this  variability can  be  justified based  on  the  air quality
problems that may  exist in a  specific area.
                                        12

-------
                                  SECTION 3
           REGULATION OF PARTICULATE EMISSIONS FROM FUEL COMBUSTION

3.1  REGULATION UNDER THE CLEAN AIR ACT
     The Clean Air  Act  of 1970 gave the EPA the responsibility and authority
to control  air pollution in  the  United States and its territories.   One  of
the responsibilities given  to EPA under Section 109 of  the  Act was the pro-
mulgation of NAAQS's.   In addition to giving  EPA  certain  authority,  the Act
also required  the  States  under Section 110 to  adopt and  submit to EPA their
plans for attaining  and maintaining the NAAQS's in all  regions of the State.
Each  State,  therefore,  decided which  existing emission  sources  should  be
controlled and to what  extent.   Particulate  emissions from  fuel  combustion
sources were one  of the first targets of State air pollution control  regula-
tions.
     In addition,  Section 111 of  the Clean Air Act gave EPA the authority to
develop performance  standards  for new stationary sources.   The NSPS's estab-
lished  at a  national   level  apply  to  both  new  and  modified  sources.   The
NSPS's must  reflect  the degree of emission reduction achievable  through the
application of the best system of continuous emission  reduction which (taking
into  consideration  the cost  of achieving  such  emission  reduction,  and any
nonair quality, health, and environmental impact and energy requirements) the
EPA Administrator  determines  has  been  adequately demonstrated  for a source
category.
     In addition  to limiting  the mass  emission rate,  the opacity of boiler
stack  plumes   is  also   regulated.   Allowable  plume opacities vary with the
jurisdictions.   A  maximum allowable  opacity  of 20 percent  is common.   How-
ever,  nearly all  jurisdictions allow for  periodic  excursions.   For example,
the NSPS  for utility boilers  allows a  plume  opacity greater than 20 percent
for a  period  not  to exceed  six  minutes per  hour.   This type  of provision
originates from the need to periodically remove soot deposits from the boiler
                                       13

-------
tubes by directing  a  jet of steam against the outside tube walls (soot blow-
ing).  Because soot blowing  causes a significant increase in potential emis-
sions, the  early visible  emission regulations allowed for  brief  periods  of
high plume densities.   Although utility boilers often blow soot continuously,
soot  is  only blown one  to  three  times a day  on  industrial  boilers.   Hence,
the  current  provision  for  brief periods of higher  plume  density is designed
to allow for brief,  insignificant, malfunctions in the combustion process or
the control system.

3.2  STATE IMPLEMENTATION PLANS
     Pursuant to the Clean Air Act, each State must adopt and submit to EPA a
plan  that  provides  for attainment and maintenance  of  the NAAQS in all areas
of  the  State.   The  SIP must  include  emission limitations,  schedules, time-
tables  and  other  measures that  may be necessary  to ensure  attainment  and
maintenance  of the  NAAQS.   Each State determines the  mix of emissions limi-
tations that would be applicable to the sources within the State.
3.2.1  Typical Mass Rate Emission Regulations
     Particulate emissions from fossil-fuel-fired combustion sources are most
often  limited by the  heat  input  (capacity) of the  boiler.   A typical regu-
lation based on  equipment  capacity is graphically shown in Figure 2; a typi-
cal  one  based on fuel-firing  rate is shown in Figure 3.   Sometimes the regu-
lation  (abscissa in  Figure  3)  specifies  heat  input rather  than equipment
capacity.  This  raises  a question whether  allowable  emissions  vary with the
firing rate,  or  if  the maximum firing rate (or capacity) establishes a fixed
allowable emission rate.  Other questions raised by typical regulations are:
     0    For multifueled  units  (cofiring), is the energy content of all the
          fuel counted,  or only  that portion of heat input attributable to
          one of the fuels?
     0    For multiunit/one-stack  units,  is the  heat  rate  or capacity based
          on  the sum of all units, or on each  unit separately?
     0    For multiunit/multistack units,   is  the heat  rate or the capacity
          based  on  the  sum  of all  units,  the sum of all  units served by  a
          particular stack, or on each unit separately?
                                       14

-------
CQ
    1.0


    0.8


°o  0.6
 «—i

 £  0.5
  •t
 £  0.4
 o
 GO
 2  0.3
UJ
 DC

 a.

 UJ
 _l
 CO


 |
 _l
 
-------
   lO.OOOr
oo
z:
o
t—i
I/O

~   1,000
a:

a.

UJ
_i
CO

•3.
O

_J
ef
      100
       10
         10
                    100         1,000         10,000     100,000      1,000,000


                            HEAT  INPUT  RATE,  106 Btu/h
      Figure 3.  Typical mass  rate regulation applicable  to  solid fuel-fired
                             boilers based on firing rate.
                                     16

-------
     Table  3  illustrates how  the allowable emissions may  vary  depending on
the  interpretation  of the  regulations.   Application of  a  given particulate
emission  regulation requires  that  the  following  questions  be  answered:
     0    To  what  type  and size of  fuel-burning  unit does  the regulation
          apply?
     0    To what type of fuel  does the regulation apply?
     0    How is unit size calculated?
     0    How is capacity or heat input determined?
     0    For cofired units  is heat input from all fuels considered, or only
          that from specified fuels?
    TABLE 3.  COMPARISON OF ALLOWABLE PARTICULATE EMISSIONS UNDER VARIOUS
            INTERPRETATIONS OF THE REGULATIONS FOR TWO COFIRED3
                   BOILERS RATED AT 200 x 106 Btu/h EACH
Interpretation of regulation
No differentiation regarding fuel;
sum of all units (400 x 106 Btu/h)
No differentiation regarding fuel;
each unit considered separately
Considers heat input of coal only;
sum of all units (400 x 106 Btu/h)
Considers heat input of coal only;
each unit considered separately
Total allowable emissions
Regulation per
Figure 2
lb/106 Btu
0.230
0.276
each unit
0.276
0.330
Ib/h
92.2
110.3
55.2
66.0
Regulation per
Figure 3
Ib/h
102.2
120.0
each unit
60.0
70.4
aEach unit is fired with 100 x 106 Btu/h coal; 100 x 106 Btu/h oil
b
Allowable emissions = 1.0903   capacity rating
                                      106
 Allowable emissions = 1.02   heat inPu]r rate
                                     106
                                                - 0.2594
0.760
                                       17

-------
3.2.2  Typical  Opacity Regulations
     The visible emission  regulations  in most States are  general  in wording
and broad in terms  of overall  applicability.  Although  some  States  or local
agencies  have  identified  specific  source categories  to which  a  particular
opacity standard would apply,  most  States have an  opacity  requirement that
applies to  practically all stationary sources.  The most  common terminology
for applicability  is  "all  existing sources."  Other terms include "existing
equipment,"   "existing  facilities,"   "stationary  sources,"  "process  opera-
tions," and "existing  installations."   The  use of  "all existing  sources"
essentially  makes  all sources subject  to the  requirement.   Although  a  few
States  have opacity  requirements that  specifically  apply  to  fuel-burning
sources, most  States  have  a general  opacity  requirement that  applies to all
sources, including fuel-burning sources.
     A  wide range  of  visible  emission regulations exists across  the United
States.  The specific requirements are  listed in Section 5.0 by State and by
political  jurisdication within  each  State.  The visible emission  or opacity
requirements  are  almost   evenly  divided  between  the  Ringelmann  chart  and
opacity.  Some State   or  local  agencies specify  only  the Ringelman number;
others  specify the Ringelmann number  and an  equivalent opacity  limit;  and
still others only specify an opacity  limit.
     The  visible  emission  system  in  the  United  States is  derived  from the
technical  concept developed in the 1800's by Maxmillian Ringelmann to measure
black  smoke emissions  from coal-fired  boilers.   The  Ringelmann chart  was
adopted in  the early  1900's  by  the  U.S.  Bureau of  the  Mines  and  was used
extensively by State and local  agencies to evaluate emissions from coal-fired
boilers.  Because  the Ringelmann  chart  can only be used for black smoke, the
concept of  opacity  as a measure of all  colors of emissions was introduced in
the early 1950's.   Opacity is  the degree  of  obscuration of  an object behind
the  smoke  plume,  rather  than  the appearance of  the plume  itself.   Light
transmittance  (incident  light  flux/light  flux leaving  the  plume),  opacity,
and Ringelmann are compared in Table  4.
                                       18

-------
               TABLE 4.   COMPARISON OF LIGHT EXTINCTION TERMS
Light transmittance, %
0
0.20
0.40
0.60
0.80
1.00
Plume opacity, %
100
80
60
40
20
0
Ringelmann
number
5
4
3
2
1
0
     Most States and  local  agencies  allow visible emissions to exceed a pre-
scribed standard for  some  finite period of time;  the  usual  period is 3 to 5
minutes in  any one  hour  but a  few  agencies allow  an excursion for 6  to 8
minutes in  any  one  hour.   A few agencies define the  excursion (or exception)
as the total  minutes  in a day that the standard may  be exceeded.   A very few
agencies do  not allow any period of  excursion above  the prescribed standard.
     The one  exemption that applies  almost universally  to  opacity standards
is the  exclusion of  uncombined  water  vapor  from the  opacity  reading.   The
wording of  this exemption  is usually  as follows "where the  presence  of un-
combined water  is  the  only reason for failure of  an  emission to  meet the
requirements,  such  sections  of  the  opacity  requirements  shall  not apply."
3.2.3  Testing, Monitoring, and Reporting Requirements
     Because  compliance with  the applicable mass  emission  regulation  is de-
termined by  a  source stack  test,  the  associated test procedures  are  very
important.   For  example,  if the  mass emission regulation defines particulate
matter to  include  condensible material, the particulate matter collected in
the  impingers in the  back half of  the sampling train  (Appendix  C) must be
considered.    The measured  particulate  matter is also affected by the operat-
ing  temperature of  the filter—the  lower the  temperature,  the  higher the
catch of condensible  matter.   Thus an  in-stack filter, such as the type used
in American  Society  of Mechanical  Engineers  (ASME's) Power  Test  Code  27
(PTC-27) method, would probably capture less than an  EPA Method 5 (40 CFR 60,
                                       19

-------
Appendix A)  filter  maintained at 250°F.  The specified test procedure should
delineate:
     1.   the applicable traversing method;
     2.   the method of determining gas velocity and flow rate;
     3.   the method  of  analyzing for moisture, carbon monoxide, oxygen, and
          excess  air,  and for  determining the dry  molecular weight  of the
          gas; and
     4.   the method of determining particulate emissions.
The most widely used particulate sampling methods are EPA Method 5 and ASME's
PTC-27.  The latter  generally  delineates the  above  items while  the former
only  specifies  how the  particulate matter  is  determined.   The  other items
critical to  calculating  the  emissions are delineated  in great detail in EPA
Methods  1,  2,  3,  and 4  (40  CFR 60 Appendix A).  Because  Method  5 cannot be
properly implemented  without Methods  1 through 4, the requirement for Method
5  infers the use  of Methods  1 through 4.
     In  the case of  visible  emissions,  many control  agencies  use visual
observations by  field inspectors to certify compliance.  Other jurisdictions
require  continuous  in-stack opacity  monitors.   These monitors may  be  used
with  or without  ancilliary   recording  equipment.   The recorder  generates a
strip  chart that provides  a permanent  record  of the  flue  gas opacity.  If
continuous  monitoring is specified, periodic reports are generally required,
and  immediate  notification   of  any  excursion  is  usually  mandated.   Some
agencies  require  periodic source  tests  and formal  test  reports.   These  re-
quirements vary with  the jurisdiction.

3.3  FEDERAL STANDARDS OF PERFORMANCE FOR  NEW SOURCES
     The Clean Air Act requires  that EPA  develop  standards of  performance  for
new  stationary  sources of significant  air pollution.   These  standards, com-
monly  known as NSPS's,  are  based on the  best  system of continuous  emission
reduction  that has  been adequately  demonstrated,  taking  into account such
nonair  quality impacts  as  economics  and energy.   It should  be  noted that
these  regulations  take   the form  of  standards—not just  emission   limits.
Thus,  an NSPS  regulation may  require  monitoring,  process  modification, or
even specific emission reduction methods.

                                        20

-------
3.3.1  Participate Emissions from Fuel-Burning Installations

     There is no  NSPS  applicable to fuel-burning units with heat input rates

less than 250 x  io6 Btu/h.   However, particulate emissions from units larger

than 250 x io6 Btu/h--both utility and industrial boilers—are subject to the

following NSPS limits:
     Source category and
      affected facility


Electric Utility Steam Generating Units:
>250 x io6 Btu/h input rate (size standard
applies to each unit, not to aggregate;
see § 60.330 et seq. for stationary gas
turbines) for which construction is
commenced after September 18, 1978.
(Boilers and combined cycle gas turbines
that exhaust >250 x io6 Btu/h to a steam
generating unit.)
  Emission limits


0.03 Ib particulate matter/
million Btu heat input (40
CFR 60 Subpart Da)
     Source category and
      affected facility


Fossil-fuel-fired Steam Generator:
>250 x io6 Btu/h input rate (size stan-
dards applies to each unit, not to
aggregate; applies to all units firing
any form of fossil fuel or wood residue)
for which construction is commenced after
August 17, 1971
  Emission limits


0.10 Ib particulate matter/
million Btu heat input (40
CFR 60 Subpart D)
     For electric utility steam generating units, the standard applies to any

steam  electric generating  unit  capable  of  combusting more  than 250 x io6

Btu/h  of  heat  input  of  fossil   fuel  and  constructed for  the  purpose  of

supplying more  than  one-third of its potential  electric  output capacity and

more than 25  megawatts of electrical output  for sale to any utility distri-

bution  system.   Fossil fuel  by definition is  natural  gas,  petroleum, coal,

and any  alternate  form of fuel derived from  any of these fuels for the pur-

pose of  creating  useful  heat.  For  nonutility  boilers,  the  standard applies

to  each fossil  fuel  steam generating  unit combusting  more  than 250  x io6

Btu/h and to  each  fossil  fuel and wood residue  steam generating unit capable
                                       21

-------
of firing  fossil  fuel  at  a heat  input of  more  than 250 x io6  Btu/h.   For
units capable  of  cofiring wood  residue,  the emission limit is based  on the
heat  input  of both  the fossil  fuel  and the  wood  residue,  as shown  in the
following examples:
                                   Example 1      Example 2      Example 3
Fossil fuel, Btu/h input              180            250            250
Wood residue, Btu/h input             100              0             60
Allowable emission rate lb/106 Btu      0.1            0.1            0.1
Allowable emissions for the stated
input, Ib/h                            28             25             31

3.3.2  Visible Emissions--
     Visible  emissions  from both  utility  and nonutility  boilers subject to
NSPS's are  limited to  20  percent opacity  except that  for  a period  not to
exceed six  minutes  per hour,  a  flue  gas  opacity  of not more than 27 percent
is permitted.  The  method  used to measure this parameter is EPA Method 9 (40
CFR 60 Appendix A).
      It  should  be  noted  (40  CFR 60.11) that  owners  or  operators of utility
and  nonutility boilers  may  request  the Administrator  of EPA to determine
opacity  of  the emissions  from these boilers  during  the initial  performance
tests.   If  the Administrator finds that the source was in compliance with all
applicable  standards  for which  performance tests were  conducted but during
the  time such performance  tests were conducted the source failed to meet any
applicable  opacity  standard,   the  Administrator  shall  notify  and advise the
source that the  source  may petition the  Administrator to  make  appropriate
adjustments to the opacity standard.
      The  Administrator  will  grant such a petition  upon  a  demonstration that
the  source  and  the associated air pollution  control  equipment were operated
and  maintained  in  a  manner  to minimize the  opacity  of  emissions during the
performance tests; that the performance tests  were performed under the proper
conditions;  and that the source and  the  control  equipment were  incapable of
being adjusted or operated to meet the applicable opacity standard.
                                       22

-------
     The Administrator will establish an opacity standard for the source at a
level at which  the source will be  able  to meet the opacity  standard  at all
times during which the source is meeting the mass emission standard.
                                       23

-------
                                  SECTION 4
                  BOILER EMISSIONS AND CONTROL TECHNIQUES

     Boilers are  usually  sized  according  to heat  input.   They  range  from
small  skid-mounted package units  to  large steam  electric generators that may
consume more than 100  tons  of coal  per hour.   Figure 4 shows  typical  size
ranges for various boiler applications.
     Particulate  emissions  are  a function of  fuel  type as  well  as  boiler
design.   Boilers  are  designed  in  many ways.  Some are  designed  to burn pul-
verized coal or oil   droplets  in a  suspended state; others  such  as  stoker-
fired units  are designed to burn  relatively  large pieces of coal, wood,  or
bark  on  a grate.   The  design  of  the boiler and  the fuel   requirements are
often based  on total system  size.    Figure  5 presents the ranges  of  uncon-
trolled particulate emissions for fuel/boiler combinations.

4.1  CONTROL OF PARTICULATE EMISSIONS
     Boiler flyash emissions are  typically controlled by systems that incor-
porate  high efficiency  mechanical  collectors,  electrostatic  precipitators,
(ESP's),  fabric filters,  or  wet scrubbers.   Particulate  matter  controls are
typically  applied  to coal-fired  but  not to oil-fired units  because  the un-
controlled emissions  from oil-fired units are generally less than 0.05 lb/106
Btu.   However,  techniques  are available  for minimizing particulate  matter
emissions  from  oil-fired units.   These  techniques  tend  to fall  into three
major categories:   operation and  maintenance procedures;  design  changes to
the burner and/or combustion chamber; and flue gas treatment.57
     The  most  promising control  techniques for  industrial  and  utility oil-
fired units are frequent cleaning of the fuel and the air-handling equipment;
use of ESP's designed for oil-fired boilers; continuous flue gas measurements
to  maintain optimum  combustion;   and use  of opacity  monitors  to warn the
operator of abnormal  combustion conditions.
                                       24

-------
re
in
                                              BOILER HEAT  INPUT  RATE,  106  Btu/h


                                              ID               50     100
50
500    1000
                     Apartment Bldgs.
                            Schools, Churches, Small Colleges,

                           	Office Bldg.. Hotels
                                                  Large Institutions and Hospitals
                                                    Industrial
                                                                              Utilities
                                     Figure 4.  Range of  boiler  sizes  by  use.

-------
   FUEL/BOILER TYPE
      UNCONTROLLED  EMISSIONS,  lb/106  Btu
     [    2"3     4~5     b     7    I
BITUMINOUS COALU
  Pulverized Wet Bottom
  Pulverized Dry Bottom
  Pulverized General
  Cyclone
  Spreader Stoker w/o F.R.
  Spreader Stoker w/F.R.a
ANTHRACITE COALb
  Pulverized Dry
  Overfeed Stoker
OIL
  Utilityc
  Industrial residual0
  Industrial distillate
NATURAL GAS6
  Utility
  Industrial
WOOD AND BARKf
  Wood
  Bark w/o F.R.a
  Bark w/ F.R.a
    NIL
    NIL

	Range	
 	Range.
 F.R. = Flyash reinjection.
 'Heating Value - 24,000,000 Btu/ton,
 10% ash content.
 :Heating Value - 150,000 Btu/gal.
           Seating Value -  140,000 Btu/gal.
           Seating Value -  1000 Btu/ft3.
           fHeating Value -  4000 - 6000 Btu/lb.
           Figure 5.  Relative uncontrolled particulate emissions
                   from various fuel/boiler combinations.
                                       26

-------
It  has been  suggested  that emission  reductions  up to  30 percent could  be
achieved  by  reducing the  interval  between cleaning  and inspections  from  1
year to 3 months.57   The ESP's are capable of reducing oil-fired particulate
emissions by 50 to 99 percent.   A reduction of over 90 percent can be obtain-
ed with  correctly sized  ESP's  designed specifically  for  oil-fired units.58
     The following discussions of control techniques are tailored to the con-
trol  of   particulate  matter from coal-fired  units because most  particulate
control efforts have centered on coal-fired units.
4.1.1  Mechanical Collectors
     Systems  based  on inertial  separation have been used for many years  to
control  boiler emissions.   Collection  efficiencies  vary  with boiler type,
method of combustion, properties of the fuel being burned,  and size distribu-
tion  of  the  flyash.   Typical  ranges  for  the collection  efficiencies asso-
ciated  with  mechanical  collectors  on various boiler  or  furnace  types  are
shown below:58
Furnace type
Cyclone furnace
Pulverized coal
Spreader stoker
Other stokers
Range of collection
efficiency, %
30 - 40
65 - 75
85 - 90
90 - 95




     The major  reason  for the variation in the  collection  efficiency is the
method  of  firing, which  influences the uncontrolled  emission rate  and the
size  of the particles  being emitted.  When  coal  is thrown or  blown into a
furnace, combustion  takes place  in a suspension; as the pieces of coal burn,
they  become  smaller so the  probability of being exhausted  in  the  stack gas
increases.    When  coal   is  introduced  tangentially  (e.g.,  in  a  cyclone
furnace),  the  burner acts  as  a mechanical separator and thus  reduces emis-
sions of larger particles.59
                                       27

-------
     Most mechanical  collectors are incapable of  controlling  emissions  from
coal-fired boilers sufficiently to meet any but the most lenient SIP require-
ments.  Generally, the control efficiency for mechanical collectors begins to
taper off at  about 5 to 10 urn,  and is almost zero for particles less than 1
to  2  pm, as  illustrated in  Figure 6.  Typically  mechanical  collectors  are
capable of meeting limits from 0.3 to 0.6 lb/106 Btu, although a recent trend
toward the  use  of a combination of mechanical  collectors  and fabric filters
arranged  in parallel  have controlled emissions  to  well  within  many  State
allowable emission limits.
4.1.2  Electrostatic Precipitators
     As  the control  requirements for particulate emissions from fuel combus-
tion  sources  became  more  stringent,  owners  of large  pulverized  coal-fired
boilers  began  to  use  ESP's.   ESP's are  reliable  control  devices  that  con-
sistently  remove more than  90 percent of  the flyash  in  the  exhaust gases.
Since 1970, the minimum  ESP collection efficiency has steadily increased due
to  the  more stringent emission limits resulting from  the  development of the
SIP's.   Presently,  the  electric utility industry routinely removes more than
99  percent of boiler flyash.
      In  addition  to more stringent  limits on particulate emissions, State and
local agencies  have  also imposed restrictions on  the  allowable sulfur oxide
(SO )  emissions  from fuel  combustion  sources.  In many cases  to  meet these
    /\
SO   limits, many fuel  combustion sources have chosen to burn fuel  with a low
sulfur content.   The lower sulfur content can  raise the flyash resistivity in
certain  cases  making it  more  difficult to  achieve adequate power  input, and
thus  effecting  the overall  ESP collection efficiency.  For spreader  stokers,
the carbon  content is usually very high which can lead to a very low flyash
resistivity.   Low resistivity flyash  is easily reentrained and  in many cases
can lower the overall ESP collection efficiency.
      Collection  efficiency  is ultimately a function of the ESP's plate area.
As  flyash resistivity increases,  more plate  area  is  needed.   Figure 7  pre-
sents  the relationship  between  collection  efficiency and surface collection
area  (SCA) for  various coal sulfur  contents.60
      ESP's  are  commonly used to control  particulate emissions from boilers
that  fire  coal, oil, and wood or bark.  Typically,  ESP's  can be used to  meet
                                       28

-------
ro
vo
           120
          100
                                10
           Double Vortex



           Multiclone



           Simple Cyclone
                                              i         r
                                                                     i	i
15
35
                          20       25       30

                              DIAMETER,  ym


Figure 6.   Control  efficiency vs.  particle size for mechanical  collectors.
50

-------
    99.9
                       COAL SUl.l UR I'F.UCI.IXir
    99.0
                                 2.5     2   1.5  1   0.5
o
2
LLJ

5
LL.
LL
LU

2
O


o
LU
    90.0
    80.0





    70.0


    GO.O
                5080          10160        15240

                (100)          (200)         (300)

                      SCA, m' /(m1 H) (ft2 /1000 elm)
                                                     20320
                                                      (400)
Figure 7.  Relationship between collection  efficiency and SCA  for
                  various coal sulfur contents.60
                                  30

-------
emission limits in the range of 0.03 to 0.1 lb/106 Btu.   However, the overall
limit that an ESP is capable of meeting depends on the type of fuel, the type
of boiler,  and the  general  operation and maintenance of  the  control  equip-
ment.
4.1.3  Fabric Filters
     The application  of fabric  filters  to fuel  combustion  sources is  rela-
tively  recent.   Although  the  basic  particle  collection mechanisms used  in
fabric  filters  are similar, the equipment geometry  and the  mode  of  fabric
cleaning are  quite  different.   There are two  basic factors  in fabric  filter
operation, particle  capture  and static pressure  loss.   The  design  of  fabric
filters  involves  a  number  of  factors  including process  variables such  as
temperature,  flyash particle size,  and composition of the gas stream,  along
with  their  relationships with  fabric  selection,  cake characteristics,  pres-
sure drop, cleaning cycle, and maintenance.
     Unlike ESP's,  fabric  filters  are sized solely on flue  gas volume.   The
variance in flyash  grain loading resulting from  different furnace  type  does
not  generally affect  fabric  filter size.  Fabric filters can achieve control
efficiencies  of 99  to  99.99  percent.   They  are generally  used to  control
pulverized  coal-fired  units; however,  they can  be used to control  oil-and
wood-fired  units  as  well as  stoker  coal-fired  units  when precautions  are
taken  to prevent  carryover of sparks  to  the  fabric.   Fabric  filters  can
attain  emission limits  of  0.01 to  0.2  lb/106 Btu.  The  ability to achieve
these  limits  depends  in large part  on  the source's ability  to operate and
maintain the  fabric filter.
4.1.4  Wet Scrubbers
     Although  a variety of  wet scrubbers exist, they all have similar par-
ticle  collection  mechanisms.  Inertial  impaction and Brownain diffusion are
dominant in most  conventional  scrubbers.  Therefore,  wet scrubbers generally
exhibit  strong  particle-size-dependent  performance, and  are  designed  to
collect  particles   smaller  than 5  pm  in  diameter.   Particle  size,  throat
velocity, and the liquid-to-gas ratio all have a  strong  impact  on the overall
collection  efficiency.   Wet  scrubbers   generally  achieve  collection  effi-
ciencies of 95  to  98 percent,  and can be used to meet emission  limits of 0.1
to 0.4 lb/106 Btu.
                                       31

-------
4.2  RELATIONSHIP BETWEEN ALLOWABLE EMISSIONS AND OTHER PARAMETERS
     As  noted  earlier,  several  factors  affect  the allowable  participate
emissions from  fuel  combustion  sources  including boiler  type,  ash  content,
and overall efficiency  of  the control device.   Figure 8  is  a nomograph that
can be  used to  quickly determine what  the allowable emissions  for  a coal-
fired boiler might be,  given the boiler type,  ash content,  and overall col-
lection  efficiency.   This  nomograph can  be  used to  roughly  estimate  the
overall control efficiency needed for a source, given the allowable emissions
in  either  lb/106 Btu, gr/scf, or  lb/1000  Ib dry  flue gas,  the boiler type,
and  the ash  content.   Additionally,  the  nomograph  can  be  used  to  roughly
estimate the  Ringelmann  number  that would be  associated  with  meeting a par-
ticular  emission  limit.   It  should  be pointed  out  that  there  is no simple
equation or method for  relating mass emissions  to  visible  emissions.   The
specific relationship between the  mass emission limit and the visible emis-
sion limit  can only be determined on a source-by-source basis by conducting a
series  of  stack tests  and visible emission observations under various source
conditions.
     Figure 8 is not an absolute estimator of allowable emissions and control
efficiency.   A  number   of   simplifying  assumptions  regarding  average  heat
content  of  the fuel,58  percentage  of excess  air, and  so forth, had  to be
made  to develop  such  a  nomograph.    Therefore,   it  should  not  be  used to
determine  the  control  efficiency needed  for  compliance with  a particular
regulation  or to evaluate the ability of a particular piece of control equip-
ment to meet a given mass or  visible emission limit.
     Figure 9  summarizes  the particulate emission rates  for  a typical 100 x
106 Btu/h  pulverized  coal-fired  boiler fueled with bituminous coal, assuming
the application of various control devices.
                                       32

-------
                 CYCLONE
                                  BOILER TYPL
/-"-
                                                     /PULVERIZED
                                        PIVOT LINE/
   0.3-



   0.2-





   0.1-
50.05-
g
           0.8-i
  0.02-
  0.01-1
                                                                        0.8-1
               0.5-
                                                                      —0.2-
                                                                        0.1-
                                                                       0.05-
                                                                               o
                                                                               z
                                                                               CE
                                                                               cc
                                                                                : o-
                                                                       0.02-1
                                                                            A
     Figure  8.   Nomograph  for relating allowable  emissions and  overall
                               control  efficiency.
                                         33

-------
              o
              _J
              o
              z
              a:
                    UNCONTROLLED  EMISSIONS
                    LOW  EFFICIENCY  CYCLONE
                    HIGH  EFFICIENCY  CYCLONE
CO
              O
              O
                    WET  SCRUBBER
13
              o:
              
-------
                                 SECTION 5
         COMPILATION OF PARTICULATE MASS AND VISIBLE EMISSION LIMITS

     This section compiles  the  mass and visible emission limits contained in
the SIP's  for the 50  States, the  District of Columbia, and  the  four terri-
tories  (American  Samoa,  Guam,  Puerto  Rico, and  the Virgin  Islands).   This
section  also  summarizes  the  requirements  for continuous  monitoring.   Users
are cautioned  to contact  the appropriate  State  and/or local  air  pollution
control agency and EPA Regional  Office to verify the specific emission limits
applicable to an individual source.

5.1    SUMMARY OF MASS AND VISIBLE EMISSION REGULATIONS BY STATE OR TERRITORY
     The  following  is a  summary by State  of the mass  and  visible emission
limitations  contained in  the  applicable  SIP.   Because  an  SIP  may  include
State  and  local  regulations,  local regulations along with the  State  regula-
tions  have been included in the summary where they are part of the applicable
SIP.   The  listing for each State  is  divided into  two parts.    Part  A  is  a
summary  of the  key  elements of the mass emission requirements,  and Part B is
a summary  of  the key elements  of  the  visible  emission requirements.   Part A
explains  how  the total  heat  input  is  determined;  how  the  regulation  is
applied  (i.e.,  entire plant,  individual  unit,  individual stack, etc.); the
units  of  the  regulation;  the number of the reference figure that provides a
graphical  representation  of the  applicable regulation; and  the measurement
method.  It also  contains,  in  some cases, a series of footnotes that explain
certain aspects of the regulations or any exceptions or exemptions.
     About half  of  the  States  or territories determine heat input based on
the aggregate heat  content for  all fuels  burned.   However,  about 30 percent
of  the States  or territories  use  the maximum design of the  equipment to
determine  heat  input.  About 15 percent  determine  heat  input  by using the
maximum  of  either the design or the  amount of  fuel  burned.   Less than half
(40%)  of the  States  or territories determine the heat content by considering

                                       35

-------
all  units;  about  20 percent  consider  the  individual  units;  and about  15
percent consider the individual stacks.
     Seven States or  territories  do not specify (NS)  whether  the  aggregate,
the maximum design,  or  the maximum of design  or  amount of fuel  burned is to
be  used  in determining the  total  heat input.   Ten States  or  territories do
not  specify  whether  the  determination  is  to consider  all units, just  the
individual units,  or the  individual  stacks.   However,  in practice  most of
these  States  make  the  determination  considering  all  units.   In terms  of
overall  applicability,  over half  of  the States apply  the  regulations on an
individual stack basis with the remainder of the States almost evenly divided
between  applying the  regulations  to the individual unit or the entire plant.
Almost all  States  or territories  expressed  the units  of  the  regulations as
either lb/106  Btu  or Ib/h.   There were,  however, a  few  jurisdictions that
expressed the units as lb/1000 Ib stack gas or gr/scf.
     Few  States specify  the  method  for determining  compliance.   In  a  few
cases  the  ASME  PTC-27 was the prescribed method.   In other cases,  the method
to  be  used is one that is to be specified by the Agency director; however, no
particular method was cited.   Because all  approved SIP's  are  enforceable by
EPA, Method 5 (40 CFR 60,  Appendix A) would be the method by which compliance
would  be  determined  in  the absence of a specified State method.  Therefore,
where  no  reference  method was specified, a blank was left in the appropriate
column in Part A.
     Part B summarizes the key elements of the visible emission requirements.
Some  States  or  territories  specify both a Ringelmann  number  and  an  opacity
limit.   Others  specify  a  Ringelmann and an equivalent opacity.  Still others
specify  a Ringelmann number.   The jurisdictions  are  almost  evenly  divided
between  those   requiring  20  percent  opacity  (Ringelmann  #1)  and  those  re-
quiring 40 percent opacity (Ringelmann #2) for existing sources.
     Most  States and local  agencies  allow visible  emissions to  exceed  the
prescribed standard  for  some finite period.   However,  six  States  have stan-
dards  without   an  exception  period.   For  the jurisdictions  with exception
periods,  most agencies  had an exemption for either 3 or 5 minutes in any one
hour.  There are, however, jurisdictions with exemption periods as short as  2
minutes or as long as 8 minutes in any one hour.  Although  some agencies have
excursions  associated with  the  prescribed  standards,  others  prescribe an

                                       36

-------
alternate  visible  emission  limit as well  as a  period when this  alternate
standard can be exceeded.   In addition,  one State (Mississippi)  specifies the
number of  minutes  that  the limit may be  exceeded  in any 24-h period and two
others (Washington and  New Hampshire)  specify the total number  of minutes in
any 8-h period.
     Although most States  only  specify  a visible emission limit for existing
sources, some  States also  specify  a limit  for  new sources.   In  all  cases,
these new  source limits were consistent with the NSPS requirements regarding
visible emissions.
     In all  jurisdictions  where  Ringelmann numbers were used, the Ringelmann
chart was the specified measurement method.  However, none of the States that
used  opacity alone  specified a  particular measurement  method.   Because the
Agencies did not specify  a method for opacity and because an approved SIP is
federally  enforceable,  the EPA  Reference Method 9 would be  used  to certify
compliance with  the visible  emission  standard.   No  specific notations were
made  in the  reference  method column in Part B unless a method other than the
Ringelmann chart or EPA Reference Method 9 was specified.

5.2  SUMMARY OF CONTINUOUS MONITORING REQUIREMENTS FOR OPACITY
     In addition,  to the  specification  of a measurement method, Part B iden-
tifies the requirements concerning  continuous  monitoring.    A  review  of the
State and  local  SIP  regulations  indicates that the State continuous monitor-
ing requirements fall  into four categories.   The first includes those States
that  have  incorporated the detailed continuous  monitoring  requirements into
their SIP's.   The  second  includes those states that have specific continuous
monitoring requirements in their  regulations,  but do  not  have the specific
performance specifications included as part of their SIP.  The third includes
those states  that  only specify  a general requirement  to conduct continuous
monitoring.  The  fourth includes  those states  that  do  not  specify any re-
quirements for continuous  monitoring.61   To date, 22 States or territories do
not have requirements  for  continuous monitoring; a few others specify that a
source may be  required to  conduct monitoring;  and  only about  25 percent
specifically require continuous  monitoring   of  opacity  for  fuel  combustion
sources.
                                       37

-------
5.3  STATE AND TERRITORY SPECIFIC SUMMARIES
     The  following  are state-by-state  summaries  of the mass  emission  rates
and  visible  emission  requirements  for  all   50  States,  the  District  of
Columbia, and  the  four territories.   A complete  copy of  the  regulations for
each State  is  in Appendix B.  Also, as  noted  earlier,  the reference figures
referred to in Part A are contained in Appendix A.
                                        38

-------
                                                                           ALABAMA
                                                  PART A.   ALLOWABLE MASS EHISSION RATE FOR INDIRECT HEAT EXCHANGERS







Political
Jurisdiction
State
Class I Co.
Class II Co.
Huntsville
Jefferson Co.
Mobile Co.

Total heat Input
based on:
TJ
0- U
** ut
• —
fc. V
K
X






J,
«

X






J,
w
w
T>
0 TJ
•1
E c
i^
it








3

C
3






3
C
3
ifl
•o
>
•5
c
t— 1






u
3
tn
g
•o
>
•o
c
1— «
X









1
o






Allowable
Missions
based on:

„
m
OL

£
C
UJ







c
1
TJ
>
|






Jtf
*J
tn
5
•O
>
I
X









|
O







Units of the
regulations


3
m

o
r-l

X1
X
X
X
X




1






u
3
VI
£

r-l
"X. VI








U
M
\
irt
C
'«
fc.
13










1
o









£
3
CT1
0)
U
C
£
01
*-
O»
oe

1-1
1-2
1-1
1-1
1-1



•a
5
I
c

3
VI
.
I
20
20
20
20
c
l»
*> 8
O— 3
°15
Z |rt




Exception

i
1
OL
3
3
3
3


\
60
60
60
60

fi
1 1.
3
3
3
3


t.




New sources
Requirement

i
1






i





C *-
£ tfl
11!




Exception

c
1
oe






i





C t-
iij






L
«






19
4-*
i
t-
VI
1






|f
sl
O 1-
3
C O>
X




Footnotes








-------
                          ALASKA
PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT  HEAT EXCHANGERS









Political
jurisdiction
State
Cook Inlet




Total heat Input
based on:

•o

4- i-
0 3
«t
L. ft)
fW
o»i—
S1-









M
01

E
X
10
I





C


•8
"*-
6?

X
10 U
ac o










4->
c
5






vt

c
.-
3
•O

I






w



^

•0
C











1-
o
NS"




Allowable
emissions
based on:



^
c
a.
"
c
IU








c
3

3
'>
C
X





W
U


3
•o

C











i.
o






Units of the
regulations




3
CD
<0
CD
£












X)






^/

2
jj
0
CD
O










*_
(A
C
t-
o
xl,2
X3









I-
4-*
O









0)

3
CD
<*-
U
C
fll
t-
41
QC
NA








.n

8
C
i
t.
3
^







Footnotes








1. 0.5 gr/scf, 0.10 gr/scf sources in operation prior
to July 1, 1972.
2. 0.15 gr/scf wood burning sources.
3. 0.3 gr/scf.
4. NS denotes not specified.
             PART B.  VISIBLE EMISSION REGULATIONS








Political
jurisdiction
State
Cook Inlet
Fairbanks
Existing sources
Requirement




c
£
s.
QC

2
1





>,
u
0.
o
20
40

>,
ra
c

*J w

660
0 1
Z If-)
3
3

Exception




c
c
I
01
o»
DC


3





>»
u
o.
0



x
Ifl
c
c •»-
m
f M
0> 3
1- C 1-
O •»- 3
z £


51






i_
o



New sources ^
Requirement




c
c
e
en
QC

1






>v
U
S

20

>,
n
c

J= «A
+J W
•I 3
O 'r~ D
E E 0
O 1
Z Ir-l

3

Exception




c
c
n
E
S.
oe








>,
u
o.
o



x
ft)
c

£ VI
4-1
lei










0)
4-»
o





E






£





*^
•i- E
C 01

w> cr
o u
3
••- C
C U
0 0




Footnotes








1. No greater than 40 minutes In any 24-h period.
2, Constructed after 8-17-71.


-------
                           ARIZONA
PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS





Political
jurisdiction
State
Nohave Co.
Pirns Co.
Plnal/Gila
Co.

YUM Co.



Total heat input
based on:
c
«- u
0 3
fk
Aggregrate
all fuels









c
f»

I
X









c
Ol
1

n-
o -a
i?
i\
X
X
X

X

X




3
"c
5
X
X
X

X

X


5
i

1
1









U
3
M

1
1












o









Allowable
emissions
based on:


"a.
£
C
UJ









'c

Individual









u
3
IA

Individual
X
X
X

X

X




1
o










Units of the
regulations


a
s
a

X2

9
x'

x




1
X1

X1






1

§
O
r-*











Grains/scf











I
o












Ol
<•_
€>
01
ac
1-3
1-3
1-3

1-3

1-3





method 1
jj
Measuremen'

PTC-
27
1ET.
5








Footnotes



1. < 4200 x 106 Btu/h
E=1.02Q°-769
> 4200 x 106 Btu/h
E - 17.0 Q°-«2
£
2. 10-4.000 x 10° Btu/h
Y - 1.02X-0"231
>_ 4000 x 106 Btu/h
Y ' Z7X-°'568
            PART B.  VISIBLE EMISSION REGULATIONS





Political
jurisdiction
State
Coconino Co.
Marlcopa Co.
Mohave Co.
PiM CO.
Pinal/Gila Cc
Yuma Co.
Existing sources
Requirement



Ringelmann
2
2
2
2
2
2




u
o
E1
E
E
E
40
E
20

c*
c
No more tha
	 mi nutes
1 hour

3
3
3



Exception



Ringelmann




3





u
a.
o




60



c"
c
c •*-
No more tha
	 minutes
1 hour




3





,







New sources
Requirement



Ringelmann










5-
U
fO
O.
o








c*
c
c •^>
4J
€1 3
U C U
Ti!







Exception



Ringelmann










£?
u
o








e-
c
C i-
ss
til.
i-ij
o 1
Z IrH










1
o









•o
o
I
Heasurement









^j
, §
i!
Continuous
tor ing requ








Footnotes




1. E denotes eoulvalent opacity.







-------
                                                                           ARKANSAS
                                                   PART A.   ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS











Political
Jurl sdlcti on
State




Total teat Input
based on:


"g
c
0 3


W Wl
IB •—
u *»
O* 3
V *•
U
S"n







c
01

I/I
Ol

iximum
•o





c
Ol
in
o*



O T>
«
§£
E 3
••- .O
X
flj *-
I 0











2
§
<






«
c
3


S
•o
C






u
3



3
•o
,5












1
0
NS2



Allowable
emissions
based on:





c

a.
£
UJ
X





^
c
3


3
•o
TJ







o




3
•a
•o













1
0





Units of Uw
regulations







CD
O
(-H
^












c
r—
X1





o
3



»—
§
O
rH
•— Ol











U
 3

iii
o |£
Z IrH
53


Exception


c


Ol
c






>t
4J
U
*
O.
o



Ifl
c
c •*-
JC. trt
4-*
4) 3

•v
Z IfH








*_
«
JC
o



New sources^
Requirement


c
E

01
01
c
1





x

u
a.
o
E


c
a
c
c ••-
j5 «i
4J

O 1
Z 1 fH



Exception


c


1
ae
3







1



&
C
JC (A
"«!

i'ii
i 1^
53







£
0




I
i
C
-:






j
C 41
2.^
vt a-
IS

'r- C
C U
O O
0 *J



Footnotes






1. Constructed after June 1, 1975.
2. E denotes equivalent opacity.
3. No more than 3 times In a 24-h period.

-------
                      CALIFORNIA
PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS




Political
jurisdiction
South Coast
San Diego
Fresno
Sacramento
Bay Area

Total heat Input
based on:
0 3
Aggregrate
all fuels b





0
•1
•o
i
1





•o
*-
11






3
"c
5





§
"5
•o
1





U
3
t/l
1
1







5
o
NS«
NS
NS
NS
NS
Allowable
emissions
based on:

a
a.
e
*•
c
UJ





**
c
3
Individual





M
Individual
X
X
X
X
X

i






Units of the
regulations

3
*>
i






1
X1

X1


s
A
O
S
f-*
•"x. .
1







x
10
•-• «
Slu
iii
i 1^







Exception


£
S
1










>.
I







^
c
c •*-
M
•

J'lr!











S









s
£
X
C
*
S
3
M









r
i!
3?
C CJI
C 1.
0 0
X







Footnotes





1. LA, Orange, Nest-central area of Riverside County.
2. Rest of Riverside County.
3. E denotes equivalent opacity.





-------
                       COLORADO
PART A.  ALLOWABLE  MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS
Political
jurisdiction
State
Total heat Input
based on:
V
c
O 3
U O*
CT> 3
*l <•-
L.
X
c
Ol
1

c
Cn
IA
•1
Haximua c
or burnec


+J
C
3

C
3
Indlvidui
X
nt
TJ
-a
C


.c
•4J
o

Al lowable
emissions
based on:
c
'a.
•i
c
IXI

c
T3
C

u
1J
*J
*w
a
C
X

^
o

Units of the
regulations
0
X
n

ut
X5
O
o
CD
rH
~^s. Wl

U
VI
Wl
c

i.
4=
o


R«fer«nc« figurt
1-4

Measurement method

Footnotes


            PART B.   VISIBLE EMISSION REGULATIONS











Political
Jurisdiction
State
Existing sources
Reguirement





c
c

e
en
ee









2*
u
CL
O
20
x
TI

c
C —
JC Wt


• 3
U C 1.
ceo
o 1
z 1 --«

Exception





c
c

i
en
a









2-
u
a.
o
40
x
m

c
C i-
jC «n


V 3
U C t-

o 1
z !*-«
3









OP
*^

New sources
Rpqui rrmpnt





c
c

E

ae









$
U
CL
O
?0
^
«



C. VI
4-> «f

Siu
BE 0
Z 1 ^-*

Exception





c
c

J5

ae









51
U
a.
o
40
x
IV

c
c •*-
C. VI
4-* •

£2u

5 1^
3










O



•o
5



c


t-
VI




*Jt
c
-J- 2






c c"
*-* -r-
a o
o *-»


Footnotes













-------
                                                                        CONNECTICUT
                                                  PART A.   ALLOWABLE MASS EMISSION RATE  FOR INDIRECT HEAT EXCHANGERS






Political
jurisdiction
State



Total heat Input
based on:

1
•>- U
o 3
Aggregrate
all fuels t




c
•^
s
§
s



c
at
Ut

o -o
§£
X 0
X





M
*<
C
Z




3
"c

•o
'i




•
in
1
1







•I
£
o
NSl


Allowable
emissions
based on:


**
"o.
£
C
UJ
X



c
3
Individual




3
Ul
Individual






t.
o




Units of the
regulations



rH
Xz





s




3
M
*~ Ol






Grains/scf






1
o







£
a

Reference 1






T?
*

Measurement





Footnotes




1. NS denotes not specified.
2. 0.20 lb/106 Btu. existing
0.10 lb/106 Btu. new (constructed after 5-23-72)
*>.
Ul
                                                               PART B.  VISIBLE EMISSION REGULATIONS





Political
jurisdiction
State





Existing sources
Requirement

c
c

c
oe
1






>,

u
a.
o
20





1
c
C M-
*>
§-.- 3
E O






Exception

i

c
ee
2






>>

|
40





c
C f-
£s
£3

S 1"
5







t.
o






New sources
Requirement

c
c

c
ac









O






«
c
C *r-
5S
•V 3

E|°
5 L






Exception

c

"
QC









£






1
ss

E 0









i








1
|
3

X1






Footnotes




1. General opacity monitoring requirements for:
a. coal burning ,
b. liquid or solid > 5 x 10° Btu/h
c. Incinerator > 2,000 Ib/h
d. process sources > S Ib/h
e. No. 6 residual oil burners

-------
                                                                           DELAWARE
                                                   PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS















Political
jurisdiction
State



Total heat input
based on:


•o
c

0 3

Ol
4-* W
(V i—
U Ol
en 3
u
O1-—






c
o>

V)
O)


E

E
X
y
X1



c
01
in
01
•o


O T3
V
§c
u
•^ ^3
X
HI 1-











m


§

£





*

c



(0
3
•o


c
X




u
M

U)


IV
3
•a


T3
C
















4-*



" Allowable' "
emissions
based on:






c




o>

4-*
c





v

c




c t-
o o
0 4J
X
Footnotes







1. 15 minutes in any 24-h period.

-------
               DISTRICT OF COLUMBIA
PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS








Political
jurisdiction
District




Total heat Input
based on:

•a

^S
3 «
»3
< ••
X






»
•I
•o
S
•





Ot

S
O "O
II
Is








M
**
C
5





^
«J
C
3
*••
|
1





^
0
3
M
•J
5
1










5
1S^



Allowable
Missions
based on:



«,
•
a
I
C






+>
c
3
*IO
3
•o
•o
c





_^
u
3
m
•5
2

X















Unit* of the
regulations




3
O)

x*















^
U
3
M
A










S
in
s
c









i.
5










O>

g
£
1-5






TJ
O

g

3
|






Footnotes







1. NS denotes not specified.
2. Y • 0.17455X-0-23522
can not exceed 0.13 lb/106 Btu or be required to e*1t
<0.02 lb/106 Btu.
           PART B.  VISIBLE EMISSION REGULATIONS






Political
jurisdiction
District
Existing sources
Requlrenent



|
1
•r-
CC
2



x
1
40
£
C

-a
o |
z 1 1-1
121
Exception


c
i
o>
c
oe




>i
'5

•o
c
£ in

Ti!





I

New sources
Requirement


c
I
w
Ol
c




x
"s

£
c
rt
V3
J"i!

Exception



s
1




x
1

•0
c
s»

§ij





1



c
4->
g
4J
i
in
to



C
o t
*'5
Su
C Ol


Footnotes





1. 12 minutes In any 24-h period.

-------
                                                                              FLORIDA
                                                    PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS
Political
jurisdiction
State
Total heat Input
based on:
•o
*- L.
O 3
-Q
W
*-» u»
£1
s*-
OI-—
O>-—
< ID
X
c
0)
Ol
-o
X
10

1
V)
at
i!
X
(0 U
Z 0

in
c
3
X
M
4J
C
3
3
T3
C

U
3
ut
I
•a
c


01
-C
o

Allowable
emissions
based on:
c
>D
'o.
at
4->

c
3
fO
3
TJ
?
X
u
M>
a
•a
T3


Ol

Units of the
regulations
3
OQ
rH
X1
£

U
ra
tn
§
O
f-t

Srains/scf

t-


Jeference figure


•teasurenent method

Footnotes

1. 0.10 lb/106 Btu, all units > 250 x 106 Btu/h
(maximum 2-h average)
20% opacity, all units < 250 x 106 Btu/h.
00
                                                                 PART 8.  VISIBLE EMISSION  REGULATIONS










Political
jurisdiction
State



Existing sources
Requirement





c
c
1
"ii
c
a.
21










>,
u
M
0.
O
40



>,
IO
c
c ••-

£ VI
*-» W

§•>- 3
E 0
O I
•z. \ f-t




Exception





c
c
1
Of
O)
c











x
u
ID
a.
o




>,
,
u
a
20



>,
m
c
c •--


4-» Ol
4->
I'i §
o 1
Z IrH




Exception







m
01
O)
c
at
2










>,
•^
10
Q.
P
40



^
ID
C
C'r-


4-» 01

O •»- D
e e o
o I
Z IrH
2











u
01
4-*
o






?
^
i


c

i
3
V)
to






C
*^~ ^
o u

3
M O"
5 «
o u
3
•»- C
C U
o o

-------
                                                                            GEORGIA
                                                   PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS






Political
jurisdiction
State














Total haat Input
based on:
1
»- u
O 3

*.*•
O 3
f^
X















M
i
i














C
w
•o

)I
Ife

















s
5














M
c
3

TJ
1
X













1
M
r—
11
1
1-1

















u
o














Allowable
emissions
based on:


S
"o.
e
c
Ul














*;
3

I
1
x













S
in

•o
>
l

















&
I















Units of the
regulations



m
S

X

















£














1
M

§
58,
















«-
i!
•5
a

















ft.
|

















O)

"*-
u
c
•1
H-
W
CE
1-61
1-7'















£
+J
I

+*
C
|
M
i
















Footnotes





1. Existing sources
< 10 x 106 Btu/h
0.07 lb/106 Btu/h
10 - 2000 x 106 Btu/h
V > 0.7(lf)°'202
>2000 x 106 Btu/h
0.24 lb/106 Btu
2. New sources (constructed after 1-1-72)
< 10 x 106 Btu/h
0.5 lb/106 Btu/h
10 - 250 x 106 Btu/h
Y - 0.5(lf)°-5
>250 x 106 Btu/h
0.10 lb/106 Btu
VO
          (continued)

-------
         GEORGIA (continued)
                                                      PART B.  VISIBLE EMISSION REGULATIONS









Political
jurisdiction
State

Existing sources
Requirement






B

V
O»
oc
2







^

u
0.
o
40

>.
*0
c
C -f-





§•*- 3
E 0
0 (^
Z Jr-l


Exception






s

O)
QC
3







^

u
ex
o
60

x

C
«0
£. w

+J

§•»- 3
E 0
O 1
z !•-)
31









fc.
w
4-1
O


New sources?
Requirement




c



s,
c
QC
1









"o
a.
0
20


(O
c
c ••-






0 1^
Z If-H


Exception




c



s>
2
2











40


c
c





0 -i- 3
E E O
O 1
Z 1 >-*
2









L-
£
0



TJ
O
£
i



^

3
01



4-*
C
-?
C 0)



0 L


c t-
O 0
O 4J


Footnotes










1. In any half-hour period.
2. Constructed after 1-1-72.
Ul
o

-------
                         HAWAII
PART A.   ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS







Political
jurisdiction
State



Total heat Input
based on:
1
O 3
3«

s-



5.

«

U



&
IH
•o
H-
fc
J





M
**

§



w
*•
c
a
•5

1



3
M
3
•o








1
nS>


Allowable
(•Us tons
based on:

#*
a
7x

I
'i



'c
3
•a
3
•o
>
?
X


jt
tn
s
•a
'>
?







t.




Units of the
regulations


3
m

S
a







f.



u
3
M
5

O
rH
A IV





•*-
u
-^
Srains







1
X2





Ol

u

£
01
Ol






1

c

3
irt
•0





Footnotes





1. NS denotes not specified.
2. New and existing blgasse-burnlng boiler
0.4 lbs/100 Ib blgasse burned.
             PART B.  VISIBLE EMISSION REGULATIONS






Political
jurisdiction
State


Existing sources
Requirement


c
{
1
oc
2





^
1
40


&
c
Is

8-ii
S 1*



Exception


§
3
1
3





^
i
o
60


&
c
as


3Z






•i
o



New sources '
Requirement


c
c
?
1
ec
1





x
u
20


1
c
£ Id
*J
i'ij



Exception


c
•
oe.
3





^
u
z.
o
60


£
C
JC M

?'
32






u
o





*>
2
*J
c
i
III





if
o u
. §-
O k
5.™
c °C
33




Footnotes





1. Constructed after December 31. 1973.
2. During equipment breakdown or new fire building
only.

-------
                                                                                 IDAHO
                                                    PART A.  ALLOWABLE MASS  EMISSION RATE FOR INDIRECT  HEAT EXCHANGERS
Political
jurisdiction
State
Total heat input
based on:
Aggregrate of
all fuels burned
X
Maximum design

c
Dl
VI
41
•0
o -o
«
B 3
•*- .a
X
rt t~
ac o

M
C
3

tfl
4J
C
3
19
3
•a
•a
c

u
(0
3
•o
•r-
C
X

at
o

Allowable
emissions
based on:
c
,
'%
s
40
|
C
«o
C. Wt
4-1 0»
+*
V 3
§-r- 3
B,°
3. L
3
Exception
c
c
1
oe.

>»
u
n
8

g-
«
C
C -r-
fl
£. «A
4-> «
+J
W 3
§•«— 3
E 0
2 1:

L.
01
.C
+J
O

New sources 1
Requirement
Ringelnann
1
2-
u
flf
o.
o
20
|
C
!•
*J 01
+J
Si^
lij
s 1"
3
Exception
Ringelnann

|-
U
<0
a.
0

|
c
C -r-
10
£ in
-5
at 3
(- c (-
iii
0 \*
Z li-l

5
4J
0

Measurement nethod

4-*
il
8i
sl
§ u
C 01
4-> •»-
C U
0 0
O 4->

Footnotes

1. Did not specify a date for new sources.

-------
                                                                   ILLINOIS
                                              PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS





Political
jurisdiction
State
Chicago
Major-Metro.
Area

Outside
Major-Metro.
Chicago Area

Controlled
Sources
Cook Co.



















Total heat Input
based on:
J
o a
3«
?3
1^
x





























c
a
i
I
s






























C
Of
3
O 'O
II
S o































S
§
5






























M
C
3
3
•o
I-H






























1
VI
3
•o
1
*-«
X































•i
£
O






























Allowable
emissions
based on:

•a
S
c
UJ






























*>
i
•V
•o
Jo
c
t— *






























VI
1

'i
X































u
«











X5



















Units of the
regulations

i
|



y
xz


•s
X3

a
X






















i






























Jf
3
VI
£
o
"-. w































u
M
C
E
































i-
V
£
o

































Ol
•1
I
I*-
1-9
































i
c
VI
•9
X1































Footnotes




1. ASME power test codes.
2. Existing and new
Solid - 0.1 Ib/mnBtu
Liquid - 0.1 Ib/mnBtu
Combination - SSHS + 0.10 HL
where:
S, = solid fuel type partlculate emission standard.
Ib/lO* Btu
Hs = actual heat Input from solid fuel. 10* Btu/h
HL = actual heat Input from liquid fuel.
3. Existing
Solid
Q < 10 x 106 Btu/h 1.0 lb/10* __
10 < Q < 250 x 106 Btu/h E = 5.18Q-°-7E
Q ^ 250 x 106 Btu/h 0.1 lb/106 Btu
Liquid - see 2
Combination - see 2
4. The emission source must have an emission rate based on
original design or equipment performance test condi-
tions, whichever Is stricter, which Is < 0.2 lb/106 Btu
and the emission control must not be allowed to de-
grade > 0.05 lb/106 Btu.
5. PM emissions are limited to < 10X by weight of parti-
cles > 44 micron. Calculations are also made for the
various control zones to determine the net rate of
emission In Ib/acre/h from each emission source. The
limit for the zones Is as follows:
Zone 1-1.0 Ib/acre/h
Zone 2-3.0 Ib/acre/h
Zone 3-8.0 Ib/acre/h
OJ
         (continued)

-------
        ILLINOIS  (continued)
                                                     PART B.  VISIBLE EMISSION REGULATIONS







Political
jurisdiction
State


Cook County












Existing sources 3
Requirement




c
c
8,
C



2
















^
"u
IV
0.
o
30


40












>,
IV
c
c •*-
IV
JC W»
O> 3
iif
O 1
Z 1 r-*
















Exception




§
01
at
c
cc.





















u
(V
a.
0
30-
60














x
nj
c
C -r-
IV
J= V)
jj ai
!E|
O 1
Z |r-»
8




















L.
01
.c
o



x5












New sources
Requirement




c
c
8.
C





















u
,
5
c
C -r-

£5
* C L.
i'ii
° 1"
Z Ir-l
3

8


















t_
Ol
O


















?
^3
E
4_t
1
lA
i
x"

















c
•r- ^
I."
B 5
s?
Ira
•»- c
c u
o o
0 -U
X
















Footnotes







1. Source with actual heat Input > 250 x 106 Btu/h.

2. New sources < 250 x 106 Btu/h.
3. VE limitations shall not apply if emission source
was in compliance with the applicable mass emis-
sion limitation.
4. a) visual observation
b) use of calibrated smoke evaluation device
c) continuous monitors.
5. Cook County uses a measurement of smoke units; In
Zone 1, 20 smoke units are permitted and 35 units,
once during any 6-h period for each stack when
blowing soot or cleaning fines; In Zone 2, 50
units are permitted with an exemption as above of
62 units; and in Zone 3, up to 76 units/h per
stack is permitted with an exemption as above of
92 smoke units.
Ul

-------
                         INDIANA
PART A.   ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS




Political
jurisdiction
All areas ex-
cept Lake and
Porter Co. and
Metro. Indian-
apolis Intra-
state AQCR
Lake and Portei
Co. and Metro-
Indianapolis
Intrastate
AQCR

Total heat input
based on:
J
Aggregrate
all fuels 1





6
Max 1 nun de<
X




S
TJ
II






M
§
3
X




3
1
Individual





!
IA
Individual






t.
o





Allowable
emissions
based on:

*cL
•i
K-
C
UJ
X




§
Individual





s
VI
Individual






1
o






Units of the
regulations

3
m
s
a
X1


0


£
O





U
3
in
§
5
V. M
r- Ol






Grains/scf






|
o








8.
Reference f
3-1



1-K



*
Measurement







Footnotes


1. Emission limited by ASME Standard Ho. APS-1
with maximum allowable of 0.8 lb/10* Btu for
existing sources and 0.6 lb/10" Btu for new
sources < 250 x 106 Btu/h (constructed after
9-14-72).
2. Emission limit • 0.87 Q'°'16 lb/106 Btu
and 0.10 lb/10 Btu for new sources In
c
excess of 250 x 10° Btu/h.

             PART B.  VISIBLE EMISSION REGULATIONS








Political
jurisdiction
State




Existing sources
Requirement





fe
|
2









3>

40





f
••
c
c f
* 3
1- C f-
O I
Z |rH





Exception





c
•V
oc










x
1
60





Q
«
c
s~
-3
t i,.
5 1:











u
0
X1




New sources
Requl rement





i
I
oe
2









&
U
Q.
O
40





jj1
>
fi
«>
C
IA
n
£







V
i £
**~ P

*3

Is
o *<
X





Footnotes







1. Opacity up to 60S Is permitted while building a
fire for a period not to exceed 10 min in any
24-h or blowing tubes or cleaning for a period
not to exceed 5 min In any 60 min but not per-
mitted more than 6 times In any 24-h.

-------
                                                                                  IOWA
                                                     PART A.   ALLOWABLE MASS  EMISSION RATE FOR INDIRECT HEAT EXCHANGERS










Political
jurisdiction

State
Inside SMSA

Outside SMSA







Total heat input
based on:
•o
?
«t- U
0 3
n
* l/t
«fl •—
u o»
Ol 3
L.
CT^
•< «
X










c
O»
u»
01
T3

E
e
x
i










c
0>
(A


o -o
41
§ *~
B 3
« U
i o














M

-^-
§
^
^










M

C

*

•o
^
c
•— •










^
u
to
in

*^

T3
'*
c
»-«
X
















Ol

o










Allowable
emissions
based on:


^
c
,2
Q.

*
c
UJ











£
c
3

to
3
T3
;>
•o
c
•— «











£
M

IO
3
•o
;>
c
(—1
X
















t
5
o











Units of the
regulations




3
+J
m

ID
O
^
r—

X1
9
X2













.c
^
1 —











0
4-»

^

o
o
o
r-H
13 (O
r- 0>














(J

^
C
2
0

















u
41

O














1-
0)
•»-
01

c
£
«•-
w
oc
3-2


3-1









•o
o
w
e
4J
C

Q*

in
01
z












Footnotes










1. Existing and new
ASME Standard APS-1, Ftg. 3-1, with a maximum
allowable rate of 0.6 Ib/I06 Btu.

2. ASME Standard APS-2, F1g. 3-2, with a maximum
allowable rate of 0.8 for existing sources and
0.6 for new sources.
Note: Use Eq. 15 with C max = 50 ug/m3 for
stacks ^4,000 x IO6 Btu/h, a = 1.0; for stacks
< 4,000 x IO6 Btu/h, a < 1.0 as appropriate.
(Ti
                                                                  PART B.   VISIBLE EMISSION  REGULATIONS









Political
jurisdiction
State



Existing sources
Requirement






c
3
|
oc
?










^
u
a.
o
40



^



c

53
V 3
i*3
i £




Exception






£

1
cc











>t
u
10
0.
o




x

•0

c

-C tft
Ol 3
t C U
O -r- 3
\°
£ L
61











k
0




New sources
Requirement






c
c

1











^
u
1




x



c

£. (A
4-*
Ti!




Exception






c
c
s
oc











>»
u
*
o.
o






w

c

5«
V 3
sl!












L.





•§





c
1
Measur





c


c S


3
Ul O*
i *"
.t?
4-1 *r»
C t.
O O
O 4->
X2



Footnotes









1. Building or cleaning a fire or blowing tubes and
flues.
2. Opacity for coal and coal-gas fired steam
generating units.

-------
                                                                               KANSAS
                                                      PART A.   ALLOWABLE MASS EMISSION RATE FOR  INDIRECT HEAT EXCHANGERS






•••t i * t^.t
roi iiicai
jurisdiction
State

















Total heat Input
based on:
,
C
%- t-
O 3
JO
5-
ft- •
Ol 3
?*•
t-
Ol —
51*


















C
Ol
VI
9
I
I

















C
at
TJ

j!
••- ja
X o
X



















M
"c
^
X
















S
§

i
i

















u
•Jl

1
•a
c





















4-*

















Allowable
emissions
based on:

A*
c
(V
a.
r
c
X

















i

1
c

















u
Ul

3
TV
?




















L.
5


















Units of the
regulations



3
CD
O
i
X1




















A

















*
3

A
-a




















u
1
«a
i.




















ft.
4-*




















C
3
01

f
w
1-11



















5
2

C
3
£



















Footnotes





1. Total Input Allowable
106 Btu/h lb/h/106 Btw
<10 0.60
50 0.41
100 0.35
500 0.24
700 0.22
I. 000 0.21
2.000 0.17
5,000 0.14
7.500 0.13
> 10, 000 0.12
For Interpolation:
E - 1.026Q-0'"3
Note: ' Any existing coal burning unit operating < 100 h
in a yr may emit no more than 1.2 lb/10" Btu
pending dept. approval and if average annual emis-
sions do not exceed limit for the plant.
in
             (continued)

-------
        KANSAS (continued)
                                                      PART B.  VISIBLE EMISSION REGULATIONS
Political
jurisdiction
State
Existing sources
Requirement
Ringelmann


u
<0
o.
o
40
X
c
10
c
C -r-
«
.C tn
4-> 01
O) 3
l-ij
s C

Exception
c
i
8.


U
>0
o.
0

m
c^
«
.C tn
4j Of
+J
01 3
o \
Z IrH

01
£1
4-1
0

New sources 1
Requirement
c
c
E
01
o>
c
Of

5-
U
a.
o
20
10
c •»-
ID
4-> a>
0) 3
t. c: u
O ••- 3
E e o
o |

Exception
Ringelmann

$
u
(O

(0
c
C f-
flf
x: in
0) 3
U C I.
o 1
Z li-H

U
01
o

Measurement method

Continuous moni-
toring requirement

Footnotes

1. Date not specified.
U1
oo

-------
                                                                            KENTUCKY
                                                   PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS








Political
jurisdiction
State1








Total heat Input
based on:
•Q
w?
O 3
3«

If









S

«

1
x







g,
S
•o
«-
Sc
L











S

§
X








c

3
•a
1









8
M
3
V
>
1













1








Allowable
emissions
based on:


**
n
a.

£
C









C
3
3
TJ
•5
c
X







^
4->

"5
3
•o
>
•5
c













1









Units of the
regulations



3
CO

O
l-t
X2












f









1
M
£

is











s

1













1











t>

.?
s
c
£
•
1-15
1-K
1-14








I
+j

c

3
VI
M










Footnotes






1. Sources > 1 x 106 Btu/h or > 50 x 106 Btu/h If natural
gas, distillate fuel oil, or a combination Is burned.

2. New sources (constructed after 4-9-72) -
E - 0.9634Q-0'2356
Existing sources -
Priority I E • 0.9634Q-°-2^
Priority II E » 1.2825Q'"-;?;£
Priority III E - 1.3152Q""''158
where: 10 < Q < 10.000 x 106 Btu/h
U1
vo
                                                               PART B.  VISIBLE EMISSION REGULATIONS





Political
Jurisdiction
State1

Priority I
Priority II
or III

Existing sources
Requirement

c
c
8.







2
U
£
o


20
40

c
•:
£gu
iij





Exception

c
c
1







>,
u
tv
a.
o


40
60

c
*
c
i:
1L
s i:


2
6




L.
i





New sources
Requirement

c
I
1
Of.







>,
u
20




|
£ VI

11:





Exception

c
c
1
DC







5-
i
o
40




1

£Iu

2







£







JC,
«.
f
to







$
8 '5
f £
•^ C
C t.
0 0
o *•»
X2





Footnotes




1. Sources > 1 x 106 Btu/h or > 50 x 106 Btu/h If
natural gas, distillate fuel oil, or a combi-
nation Is burned.
2. No requirements for fluidized bed catalyst
regenerator. In general not as specific as
Appendix P of part 51.

-------
                                                                          LOUISIANA
                                                  PART A.  ALLOWABLE  MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS














Political
Jurisdiction
State


Total heat Input
based on:


O)
c
%- u
O 3



10 •—

C» 3
1-




c













t.
01
o



Units of the
regulations









O3

|
^
X1












£
.0




U


U)

.n


o
o
s
£ g,









"»-
u
(A

c
t-
o













t
4-1






0>
t-



H-

41
u
C
£
0)
tx





Q
£




*>
c



M
f




Footnotes













1. 0.6 lbs/106 Btu.
2. NS denotes not specified.
(Ti
O
                                                              PART B.   VISIBLE EMISSION REGULATIONS









Political
Jurisdiction
State
Existing sources
Requirement





c
10
B

I"
OL
\







"5
o.
o
20
?
W
C
C -r~



O •*- 3
o1J
i U
4
Exception





c

f
oe






X
*->
8
O.
O

?
10
C
c ••-
10
4-» 01
4-*

0 ••- 3
"if








t-
o

New sources
Requirement





c
i

1








•*-
IO
a
o

c
<0

C T-

f tn
1- C 1-

5 i:

Exception





c
c

01
c
ae.








T-
10
a.
o

c
10



£ M

Q ••- 3
o |*








U
4J
0



O
c.




I
1_
3
«A
10
31



C


^»
3
3?
0 C-
3
C O)
••- c
o o
C_l •*->
X

Footnotes










-------
                           MAINE
PART A.   ALLOWABLE MASS ENISSION RATE FOR  INDIRECT HEAT EXCHANGERS





Political
jurisdiction
State1



Total heat Input
based on:
?
%- «-
O 3
Aggregntt
•11 fuels




fe
*
I
3



c
a
3
*„
l!
It
x




3
1
<



w
**
§
1
1



M
U
3
i
i
*-4
X





S



Allowable
emissions
based on:

„
"a.
•
*>
c
UJ



tl
i
IS
3
•o
E
•-4



^t
U
•a
*j
w
lo
3
•o
•a
»-•
X





£
o




Units of the
regulations


1
°
r-
X




f
^
r-



^
u
«
+>
ul
Jl
r-l
•— o»





Grains/scf





t.
«j
o






r
3.
Reference f
1-1!





1

Heasurcnent
X2




Footnotes



1. All equipment > 3 x 106 Btu/h regardless of fuel type
and all fuel burning sources > 10 x 10* Btu/h.
2. EPA test method 1 and 5.
            PART B.   VISIBLE  ENISSION REGULATIONS





Political
jurisdiction
State
Existing sources
Requirement

,

cc
2

>,

u
s
40

1
e
.C Wl
-3

Z liH

Exception

c
c

1




I
o


c

ill




u
V
o

New sources
Requirement

,

1
ae




u
I


c
"3

ili
5 1:

Exception

c
c

1
ae.




a.
o


1
Is
£3






£
O



^
§

3
in



«*
uous monl-
requi renen

T- C
O O
U 4-"


Footnotes




1. 15 mln In any 3-h period.

-------
                                                                           MARYLAND
                                                     PART ft.  ALLOWABLE MASS  EMISSION RATE FOR INDIRECT HEAT EXCHANGERS












Political
Jurisdiction
Garrett, Alle-
gheny, Wash-
ington,
Frederick,
Calvert,
Charles, St.
Mary's, Caro-
line, Cecil,
Dorchester,
Kent, Somer-
set, Talbot,
Wicomlco,
Worchester
Counties
Baltimore City.
Anne Arundel ,
Baltimore,
Carroll,
Hartford,
Howard, Mont-
gomery,
Prince Georgt

Total heat Input
based on:


•o
Jj

.0

in
91

—




















's



&

IA
01
TJ
g
—
•7











i










c

2
•o


o -o
.£
t- JO
3 t.




























VI
"c

^-























VI
"c




3
•-
c











X











U
m




TJ
^~
=






























V
4-t





















Al lowab IP
emissions
based on;





c
•n

Q.
*

C























^
C




TJ
•^
C























u




TJ

-*
C











X


















0
*»






















Units of the
regulations






3

oa
o
J3












xz

















J=
^























•g
2
VI



g
CD
J3 •«





























VI
VI
C.
u.
0










1
X1







V3
X









i_
JC
o


























e
3

V-


u
C
•»
t.
•
€1
oc











1-3?
I-4C











•o
Q

|


c
9
!
^
VI
s























Footnotes











1. New sources - use Figure 1-39 (constructed after 1-17-7Z)

2. Existing
(L
< 10 x 10° Btu/h
E • 0.60 1b/106 Btu ,
10 < 0 < 10,000 x 10° Figure 1-40
> 10,000 x 10* Btu/h
r - 0.12 lb/106 Btu

3. Adjust to 50% excess air.











CT)
ro
            (continued)

-------
           MARYLAND (continued)
                                                       PART B.  VISIBLE EMISSION REGULATIONS




Political
jurisdiction
State
Garrett. Alle-
gheny, Wash-
ington,
Frederick Co
Baltimore City
Anne Arundel
Baltimore,
Carroll.
Hartford.
Howard. Mont
gomery.
Prince
George's Co.
CaWert.
Charles. St.
Mary's. Caro
line. Cecil.
Dorchester,
Kent, Queen
Anne's.
Somerset,
Talbot.
Ulconico.
(torches ter
Existing sources
Requirement

c
c
8.
ee



\


















1

a-
s
a.
o



20








0









20
|
c =
.C W
*> tt
Clu
iif
•






















Exception

i
1



2








2









2

•
o



40








40









40
1
f;
i*1
Z l<-l



e








6









6


t.
o























New sources
Requi rement

|
•
o>
c
QC
























3-




0








0









0
5
C
C •--
«J
£ HI
«-* V
*>
•1 3
t- C U
slf























Exception

|
Ol
c
oe



2








2









2


u



40








40









40
1
e
I-
"5
Til



6








6









6


1

























1
s
«J
c
3
Ml
X2
























C
1 •
ft
C O*
•^ C
** —
c <-
o o
*J +*
























Footnotes



1. Constructed after 1-17-73.
2. Method 9.





















CT>
to

-------
                                                      MASSACHUSETTS
                                    PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS











Political
jurisdiction
State













Total heat Input
based on:

•o
•>
c
<*- fc.
O 3
.0
0»
4-> t/t
« i—
(- V
O> 1-
5—
X















c
o»


V
"°
I
1














o»

vt
•i
"O


o -o
€1
9E
e =i
a: o




















M
C
5
X













VI

"c



3
•o
>
1














_^
U
3



3
•a
>
•5
c





















t.
0













Allowable
emissions
based on:





c
ID
"o.
1
•*-»
UJ















•*-*
c
3


|

•5
—.














j^
u
>a
M


3
T3
•D
t— i
X




















0)

0














Units of the
regulations






3
*J
CD
tt
O
rH

£
X1





















\
£














^
u
m



r-
O
0
o
rH

£ a




















u
in
M
C
«
O





















u
0)
5
o

















Ol
C-
D)



Ol
U
c
01
Ol
 250 0.05
(0.10 If S0? control
device)
EXISTING
3-250 0.15
> 250 0.15
Existing In critical area of concern
3-250 0.12
3 250 0.12
2. EPA Method 5.
(continued)

-------
MASSACHUSETTS  (continued)
                                            PART B.  VISIBLE EMISSION REGULATIONS




Political
jurisdiction
State


Existing sources
Requirement


RIngelNnn
1




\

20

>, 1
*
No no re thi
	 n1 nutcs
1 hour



Exception


R1ngc1*ann
2




if
I

40

^
•
No wore th«
	 n1 nutcs
1 hour
6
2



t
i



New sources
Requl renent


Ringelnann





i



x
ec
HI*



Exception


Ringelnann





I
o



^
c
£ w
«* •
ill





1





^
c
8
fleasurcncnt





^
i!
Continuous
toring rcqu
X1



Footnotes



1. General opacity requirement for selected fossil
fuel sources - oil or solid fuel and
> 10 x 106 Btu/h.

-------
                        MICHIGAN
PART A.  ALLOWABLE MASS  EMISSION RATE  FOR INDIRECT HEAT  EXCHANGERS










Political
jurisdiction
State


Wayne County

Total heat Input
based on:

•o
•i
c
H- U
O 3
.O
s*
01 3
te







c
o>

I/I
•o
1
X
X




c
o>

M
O)
•a

i!
X
•a i-
Z 0










«n
c
^





M

C


Ml
TJ
1
X




^
u
3


Ml
•o
I











4-1
O




Allowable
emissions
based on:





c
Ml
O.
•1
—
C
UJ







c
3

|
—
C
X




_^
u
Ml


•o
.*
C











V
o





Units of the
regulations






OD
r-t
5











£
5





j.
u
«
44
I/I

O
g
o
£ 3.
X


x






u
V)
c
u











1
o










o>


w
u
c
o>
t-
o>
H-
0)
QC
4-11
1-2"





•a
s
+J
g


4»
U
3
M
Ml






Footnotes








1. Pulverized coal (Includes cyclone furnace).

2. Other modes of firing.

            PART B.  VISIBLE EMISSION REGULATIONS













Political
jurisdiction
State
Wayne County
Existing sources
Requirement







c
c
s

a:
2
1.5









^
*»
u
1

30



Ml
C

10
JZ M

« ^
U C U
i ei
5 1"
31
31
Exception







c
c
B

S,
DC
3










x
*/
s
o






c




«tJ
«. c >-
i "e o
32












O


New sources
Requirement







c
c
Ml
*—
tt











>
*•
U
I





Ml
C



4-» 4»
+J
C C U
:6|°
i L


Exception







c
c
s

c
Of.











^
4->
U
Ml
a.
0






c

Ml
C. Wl
*J «
*>
b- C t-
J













o




•o
o


^


c
0)
i
a>
u
wt




^J
c


C 01

3
tfl IT
3 a>

C O)
c u
o o
0 +>



Footnotes












1. 3 minutes In any 30 minute period.
2. Shall not be exceeded on more than 3 occasions
during any 24-h period.

-------
                                                                          MINNESOTA
                                                  PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HCAT EXCHANGERS




Political
jurisdiction
State





Total heat Input
based on:
,!
Aggregrata
all fuels 1





S
I
i
X




&
3
O TJ
•— A
x o






3
^





*j
§
1
I
X




.K
3
M
S
|







5
o





Allowable
Missions
based on:

"a.
S
*J
C
Ul





i
Individual





1
HI
Individual
X





1
0






Units of the
regulations

I
•L
ft
X1'2





S





Jt
S
^ «
•— Ol






Grains/scf






1
o








t
Ot
Reference t








I
+J
i
3
1
APS
1





Footnotes


1. New sources and sources located within Mlnneapolis-
St. Paul AQCR and the city of Duluth.
0.4 lb/106 Btu
2. Existing sources and sources outside above areas.
0.6 lb/106 Btu
cn
                                                              PART B.  VISIBLE EMISSION REGULATIONS




Political
jurisdiction
State




Existing sources
Requirement


ee
3
2-3

1-2



u
o
60
40-
fin
20-
40
x
c
•
No no re th
	 minutes
1 hour

4

41

Exception


i
f
QC







1





x
c
ill







1
o





New sources
Requirement


Ringelmann
1






It
I
o
20




^
^
C Ml
*> •





Exception


Ringelaann







a.
o





^
c
Cf-
ill
5"!







•u







1
£
X
Measurenen







^
i!
Continuous
toring req
X2





Footnotes



1. In any 30 minute period.

2. No requirements for existing fossil fuel fired
steam generators.


-------
                                                                        MISSISSIPPI
                                                 PART A.   ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS











Political
jurisdiction
State

Total heat input
based on:
^
C



3*
u'S

fc-
X

c
o»


V
•o
e

1

C
Ol

01


O •Q
«l

it
ac o







4->


X
«A
^
C



3
•O

T)
C

^





3
•o

?









5
o

Allowable
emissions
based on:





ID
a.

c
UJ
X

4-»
C
3

—
3
"O

>
•o
c


U
^J


r-
3
•o

>
•o
c









Ol
o


Units of the
regulations





3
CO
(O
o
fH
X








"s.

J*
U



£k
O
O
O
l-t
\ M»






•».


c
1_









4->













loi




4-»
B


C
!

3
Wl
1



Footnotes









1. Combination boilers - up to 0.30 gralns/scf.
CTi
00
                                                             PART B.  VISIBLE EMISSION REGULATIONS







Political
jurisdiction
State




Existing sources
Requirement



i

01
I
O£
2








2-
u
a
a.
o
40




c


4J 01
ti,.
"li
151




Exception


c

^
I
3








2*
u
a.
o





aj
c
c •»-

4J at
4-*
£3
C t-
g ••- 3
I E 0
102









i.
01
-C
4-*
O





New sources
Requirement


c
c
fll
E
01
I









21
I





c
S"~

-5
Ol 3
c c t-
i^3
0 (^
Z Ir-*





Exception


c
c
j5
01
c
QC









2*
U

-------
                                                                           MISSOURI
                                                     PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT  EXCHANGERS






Political
Jurisdiction
State

Independence
Kansas City

Springfield-
Greene Co.

St. Louis












Total heat Input
based on:
•o
c
O 3
— a
S.3
c*-
Z^





















**
M
•o
I
1




















J,
«
«

jl
X 0
X

X
X


X

X














•1
1
;
X

X
X


X













M
1

1

j=




















M
s

_
|

=

























0




















Allowable
emissions
based on:

—
g
a.

*>
c
UJ




















—
c
3

TX

I




















s
Wl

|

c
X

X
X


X

X
















o





















Units of the
regulations


3
03
S
£
X1
1
X3
X3


X2

X3,4















|




















U
£
t\
o
§
is.






















^_
u
M
M
C
k
O























k
v
5
0























i
Ol
•C
U
C
u
*-
ae
1-16

1-17





1-16














m§
i
*j
i
i
PTC
27
PTC
27
PTC
27

PTC
27
PTC
27












Footnotes





1. Existing -
Log y • -0.23299 Log X * 1.4091
10 < x < 10,000
< 10 x 10° Btu/h • 0.60 lb/106 Btu
i 10.000 x 106 - 0.18 lb/106 Btu
New (constructed after 4-3-71) -
< 10 x 106 - 0.60 lb/106 Btu
> 2.000 x 106 - 0.10 lb/10» Btu
Tog y • -0.3882 log X » 2.1454
10 < x < 2,000 x 106
2. 10 < x < 10.000 x 106
Log y • 0,2330 Log X -2,0111
< 10 x 10° • 0.60 lb/106 Btu
>. 10.000 x 106 • 0.12 lb/10* Btu
3. Existing
E * 1.09Q-0-25'
< 10 x 10" • 0.6 lb/106 Btu
> 5.000 x 106 • 0.12 lb/106 Btu
New (constructed after 2-1S-79)
E - O.B Q-°-301
< 10 x 106 - 0.4 lb/106 Btu
> 1,000 x 106 • 0.1 lb/106 Btu
4. Also regulations based on stack height.
vo
             (continued)

-------
MISSOURI (continued)
                                          PART 8. VISIBLE EMISSION REGULATIONS











Politic*)
Jurisdiction
State
Independence
Kansas City
Springfield-
Greene County
St. Louis
Existing sources
Requirement






c
c
in
E
41
c
oc
2
I
1

2
2







x
«->
Q.
O








C
•9
C
e —
HJ
«J •»
*>
t. C b
o ••- 3
I 8 0
0 |
Z 1 i-l






Exception






c
c
*
e

Ol
c
QC
3
3
3

3
2







x
4-1
s
o.
o









|Q
C
c —
n
*-» ta
« 3
U C t-
8-*- 3
CO
O 1
z 1 •-«
6
6
6

6
6









o






New sources!
Requi rement






c
c
t)
e

c
1
1
1

1
I







^
*j
a.
o







X
c

c
C -r-
19
£ Wl
*-• «
L C U
ceo
^ i:






Exception






c
|

CT
C
ae
3
3
3

3
2








4-»
U










c
c -*-
2-
4-* *
• J
k C b
"V
F
6
6

6
6









*
o








•o
o
^

i

c
I
t_
•o
*
I








4-1
c
1 «l

Q C

«» O"
^ ai
o u
C O)
4-1 -^
c u
o o
U 4-1
X






Footnotes










1. Constructed after 4-3-71 except St. Louis where
new Is constructed after 2-15-79.





-------
                        MONTANA
PART A.   ALLOWABLE MASS EMISSION RATE FOR  INDIRECT HEAT EXCHANGERS









Political
jurisdiction
State


Total heat Input
based on:




O 3
JO
Aggregrate
all fuels
X





-?
Wl
1
5






-*

O T)
Ql
II
•— £1
5 o








VI
C
3
?



VI


S

•o
—
c






*J

1
—
c
X








•
0


Allowable
emissions
based on:




—
c
•o
a.
ai
—
c
UJ






c

1
-»-
c




u



rtl
—
c
X








5



Units of the
regulations






3
*J
CD
IB
O
r-l
X







JC



^c
u

*»

o
o
SM








u
in
VI
C
L.








U
0






V
u

o»

Reference
!oi




^



•

c
L.
3
VI
•a




Footnotes







1. Existing.
2. Hew (constructed after 11-73-68).
            PART B.  VISIBLE EMISSION REGULATIONS
Political
jurisdiction
State
Existing sources
Requirement
Ringelmann
2
U
ns
a.
o

c
c
C f
•a
C. M
*-» V
li|
o 1
Z It-*

Exception
c
c
Ol
c
ae
3
2-
U
a.
o

c
"l!
4

5
0

New sources *
Requirpmpnt
c
a*
c
DC


U
•V
a.
o
20
c
•fl
c
C Wl
»J «l
Ol 3
CEO

Exception
c
c
at
c
ae

X
a
o
60
1
C
is§
5 1:
4

S
o

\
VI
I

Continuous imni- i
toring requirement i

Footnotes

1. Constructed after 11-23-68.

-------
                                                                             NEBRASKA
                                                        PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS











Political
jurisdiction
State
Omaha

Lincoln



Total heat Input
based on:

a*
c
«- u
O 3
a
41

•a —
4" *-
U
-St1^
X







c



"O

1







c
—

O

NS

NS


Allowable
eml scions
based on:




c
it

GL
V
—
UJ
X






^j
c
3




-^
-
5







(J




Tl

.^
•o
C

X













*
o



NS



Units of the
regulations





3

CO
O
£1
X1
X

X










t-
a







u
3





O
O
o
r-*
£* 19
i~ a»












u

Ml
C
o














L.
0










*
CT>




U
C
•1
u
t)
ac
1-15
I-H

1-ZC





a
5
e


c


V
u
w»
£

PTC
Z7





Footnotes










1. <10 x 106 Btu/h 0.60 lb/106 Btu
>3BOO x 106 Btu/h 0.15 lb/106 Btu

Y . '-°^6
V » allowable emissions
X • total heat Input
ro
                                                                  PART B.  VISIBLE EMISSION REGULATIONS










Political
Jurisdiction
State
Omaha
Lincoln4


Existing sources
Requirement





c
c
g

W
Oi
c
 •*-
C L.
O O
(J 4^
X2




Footnotes











1. Constructed after 8-17-71.
Z. Fossil Fuel-Fired Steam Generators only.
3. No more than 3 occasions 1n any 24-h period.
4. No limit on opacity for units < 0.10 lb/1000 Ibs
flue gas.

-------
                                                                             NEVADA
                                                   PART A.  ALLOWABLE MASS  EMISSION RATE FOR INDIRECT HEAT EXCHANGERS







Political
jurisdiction
State (except
Reno, Sparks,
Washoe Co.)

Reno, Sparks,
Washoe
Counties



Total heat input
based on:
?
C
•»- t-
o 3
X3
10 •—
t-
< *









.?
til
s
Max i nun








c
Ol
in

O TJ
1 1
S,.
3E 0

X









M
'i

X






Ul
1

§
Individ








U
3
IA

IV
D
Individ












1
0








Allowable
emissions
based on:


c
IO
"a.
ff
1
UJ

X







c

3
Individ








U
IV
 4.000 x 10° Btu/h
E ' 17.0 Q-°-568
Z. 0.15 gr/scf
U)
                                                               PART B.  VISIBLE  EMISSION REGULATIONS







Political
jurisdiction
State except
Clark, Reno,
Sparks,
Washoe Co.
Clark, Reno,
Sparks,
Washoe Co.
Existing sources
Requirement


c
c
?
1






1




>,
U
o.
o



20



|
C

•*-» Ol
Cit
Se3
1 i:



3


3
Exception


c
c
2
S,
oe











>.
i







i
c

4J «

5 1*












£
o







New sources
Requirement


c
c
3
1
oe











>,
I







|
C
K

ff i i.
o 1
Z IrH







Exception


c
c
3
1
QC.











Z
'5
a.
o







1
c


•1 3
iij












o









TJ
01
E
*J
C
01
§
(A
i









i!

Ha

1-
C O)
••* c
C U
0 0
o w



X




Footnotes














-------
                                                      NEW  HAMPSHIRE
                                   PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS
1













Political
jurisdiction
State













Total heat input
based on:

•o
w
c
H- t-
O 3


4-> (A
U (V
O) 3
Ol <*-
u
X
















c
O)

(A
01
-o


E
X
I













c
01


(V
•o

H-
O T3
E?
3 L.
E 3
X
z o





















V)
4-*
C
3















tA


C
3



3
•o

'5
















O
Ifl

(A



^

T3
X
























5














Allowable
emissions
based on:






c


O-
a*
5


















c




^

•5
















(J
flj

(A


(0


•5
X
























x:















Units of the
regulations







3

m
u>
o
xi.z
























^




















Ol
u
c
_ 10.000 x 106 Btu/h
E = 0.19 lb/106 Btu
2. New (constructed after 2-18-72)
Q <_ 10 x 106 Btu/h
E = 0.60 lb/106 Btu
10 < Q < 250 x 106 Btu/h
E = 1.0286Q-0'23"
Q > 250 x 106 Btu/h
E = 0.10 lb/106 Btu
(continued)

-------
       NEW  HAMPSHIRE  (continued)
                                                    PART B.  VISIBLE EMISSION REGULATIONS







Political
jurisdiction
State -
sources ,
< 250 x 10°
Btu/h
sources ,
> 250 x 10°
Btu/h
Existing sources
Requirement



c
i

01
O)
c
DC

2






x

Q.
O

40


20
x
*
c
c ••-
5 «
W 3 .

O -r- 3
E E O
O 1
3E I r-l





Exception



c
c

1
QC








x

U
O

40


40
^
19
C
C VI
Ol 3

ii|

62


2





u
•i
£
4J
O





New sources'
Requirement



c
c

f

1








I

20


20
^
•0
c
:«

iii
5 1:





Exception



i

O)
oc










o




40
x
A
C
VI
*J 01

!!,l
Z li-l

62


2





t.
o







•o
5
I
c

IA
1









ii
I?

•f- C
c t-
0 0
CJ •»>






Footnotes






1. Constructed after 2-18-72.
2. Installations equipped with automatic soot
blowers will be permitted to exceed No. 2
for a period not to exceed 60 min In any
8-h period.


U1

-------
                     NEW  JERSEY
PART  A.  ALLOWABLE MASS  EMISSION RATE FOR INDIRECT HEAT EXCHANGERS











Political
jurisdiction
State






Total heat input
based on:
•o
«
c
O 3
a


*o —
t- W
CTI a
u
en —
u>. —
X







c
Ol




9
X






C
d

M
TJ


0 "O
IE
--- ^3
X













*J
C







w»
*>
C
D


«
3
T3
-5






.X
U
i«
*-»
in



D
TJ
5
C
X













5
4-*
O






Allowable
emissions
based on:



4J
C


ex
*>
4J
c
UJ







.*-»
c
3


•fl
3
O
-5
c






.X
U
•n
*j
(A


«
3
TJ
T3
C
X













c
*>
o







Units of the
regulations







CD
«
\
£3














^*,
A
X1





^

3




O
0
\ «
JO a
a.
0






c
c

l«
JC VI
*-* *
*J

?S3
5 1:












JC
o







tJ

w

JV
•

(A
IV








1 *
s?

•1 0-
0 t

>- c:
*• ^~
C 1.
o a






Footnotes








1. Sources > 200 x 106 Btu/h and stacks with cross
sectional dimension > 60 In.
2. Sources < 200 x 106 Btu/h. No visible
emissions.
3. 3 min In any one-half hour period.

-------
                       NEW  MEXICO
PART A.  ALLOWABLE MASS  EMISSION RATE FOR  INDIRECT HEAT EXCHANGERS






Political
jurisdiction
State







Total heat Input
based on:
J
o a
a
il
u
< "a
X






s
IA
•o
i
^-
1







&
M
«

ll
•*- A
Ife









V)
i

;







M
§

3

1
*-*
X






s
tfl

•o

•o
c
*-*










V
£
o







Allowable
emissions
based on:

c
Ol

c
UJ







c

1

•a
c
X






u
3
V)

'i
TJ

I










•1
5
o








Units of the
regulations


3
OQ
10
^
^
X1









^
£







I

S
S
^a









u
•^
IV
u
o










Jj
o










£
O)

8
•1
41
H-
,.
1-
233







method |

I
2
1

PTC-
27






Footnotes





1. Coal burning -
0.05 lb/106 Btu
Oil burning -
> 1012 Btu/yr/un1t
E < 0.005 lb/106 Btu
2. Existing.
3. New (12-31-71)
            PART B.   VISIBLE EMISSION REGULATIONS





Political
jurisdiction
State (except
Albuquerque-
Bernallllo
Co)
AI buquerque-
Bernallllo
Co.
Existing sources
Requirement


|
.1
OL



1


1


5-
U
§






20
&
C
c •*-
££
+J
2iu
's>°
S U


l
X1



Exception


c
c
1
DC









if
V
S







&
c
2o
"S
Siu
S5.l
£ L










5
o







New sources
Requirement


c
c
1
ec









5-
»
O.
O







&
c
c-«-
•3
£ in
^3
tlu
i5.I
s L







Exception


c
c
01
cr









i-
i







&
c
e-^
5«
"3
2?u
il|
o |£
Z llH










*J
o









1
+J
?
jrenent
tn
1









4J
il
I-?
«&
3 *>
§(.
O»
«t
O O
(_> *J








Footnotes




1. No more than 1 mln 1n any 30 min.







-------
                                                                      NEW YORK
                                                     PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS













Political
Jurisdiction
State














Total heat input
based on:
-o

c
<•- L.
O 3
XS

•a •—
(- *
CT J
t.
f ^
X















c



01




X
•o
X














c
O!


Ol
T3

*-
01

3 *-

X





















*>

"c

;=














w


c


' —
3
TJ


?














^





• —
5
TJ


T3
C
X























«
j=
*j














Allowable
eml ss ions
based on:





c
•fl
Q.

*|
H^
C

















c
3

•—
3
T3

•^
C














M
U


in

1 —
5
•o

.*
c
























v
4-*















Units of the
regulations






3
CD

«
2
a
X























_c
^














.M
U


wt

XI
"~"
o
o
^4
^ s




















*•
y

VI
-^
»_
























v
O


















u

Ol



w

V
jj
*
CK
1-35
l-3(















0

01
E


C
«
£
u
5
i
















Footnotes













1. Solid fuel -burning units
spreader stoclter, 0 < 300
0.60 lb/106 Btu
other units. Q < 300
Q, 106 Btu/h E. lb/106 Btu
1-100 0.6
200 0.45
300 0.30
Units > 300 Btu/h
Q <_ 10 0.6 lb/106 Btu
10 < o < 10.000 E • 1.02 q'°-m
011 fired or coal > 250 x 106 Btu/h
E - 0.10 lb/106 Btu
oo
            (continued)

-------
        NEW  YORK  (continued)
                                                     PART B.  VISIBLE EMISSION REGULATIONS




Political
jurisdiction
State

Existing sources
Requirement


RingelMnn
1



S
20

*
e =
No more tha
	 minutes
1 hour
3

Exception


RingelMnn
2



O
1
40

«
c
c ••-
£ VI
s*
ill
0



i.
1


New sources
Requirement


Ringelmann




£
I


«
C
O ••- 3
• CO
O 1
Z |rH


Exception


Ringelnann




o.
o


 250 x 106 Btu/h fuel combustion sources
(except gas-fired) and Portland cement kilns and
Chinker coolers only.
vo

-------
                                                             NORTH CAROLINA
                                            PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS









Political
jurisdiction
State











Total heat input
based on:
^

c
»- u
0 3
.O


IB • —
i- W
01 3
W V-
u
«t 'w
X












c
01



1
19
X











C
01

t/>
9

"*-
O XI
i!
2 u
I O

















c
3
5
X










I/I

c


«o
-o
1












u
*->



3
T>
"D
C

















41
0











Allowable
emissions
based on:


^
c


a.
*
c
UJ













c
3



3
1












U
3


(D
3
T3
2
X
















1-
•4J
o












Units of the
regulations






CO
o
^
XU

















43












U
in



O
O
0
r- 01
















o
in
c


















t-
o














W
u
3
Ol
H~

Ol
erenc.
(X
1-
24 1
?~2











TJ
O
_c

I

c

u
3














Footnotes








1 . Q <_ 10 x 106 Btu/h
E = 0.6 lb/106 Btu
10 < Q < 10,000
E=1.090Q-°-2594
q > 10,000
E = 0.10 lb/106 Btu
2. Hood-burning units
q <^ 10 x 106 Btu/h
E = 0.70 lbs/106 Btu
Q > 10 x 106 Btu/h
E^i.iegsq-0-2230
oo
o
        (continued)

-------
        NORTH  CAROLINA  (continued)
                                                   PART 8.  VISIBLE EMISSION REGULATIONS




Political
jurisdiction
State

Existing sources 1
Requirement


Ringelmann
2



U
1
40

a
c
No more tha
	 minutes
1 hour
52

Exception


Ringelmann




Q.
0


Q
C
5*
*J tl
.3
U C L
113
5 1:





5
o


New sources
Requirement


i
£
oe
i



>.
o
20

IV
c

-------
                                                                      NORTH DAKOTA
                                                 PART A.  ALLOWABLE HASS EMISSION HATE FOR  INDIRECT HEAT  EXCHANGERS













Political
jurisdiction
State








Total heat input
based on:

•a
41
C
«- u
0 3
a
V
m •—
L. V
If
.f^
X










c
O)

M
w

E
i
1








c
Di

VI
4*
T3

*-
41
E C
3 u
•r- £3
X O
















4J

C
3
5
X








VI
4-1

C
3

• —
3

••-
••-
C
i— «










U
flj
4->


< —
3

•»-
••-
C
i— •



















41
+J
O








Allowable
emissions
based on:






c

a.

4*
"-
C
UJ










4->


3

r-
3
•0

—
C










U
(0
4->


r—
3

•r-
•--
C
X


















41
O









Units of the
regulations







3
CD

a
^
K1.2

















^
^3










U
10

V)

-O
'
o
o
s
^ St















H-
u
ut

vt
c
i-


















1-
41
O












41
U



H-

41
U
C
2
O>
41
QC
1-
262









|





*-»
C
E
41
f-
3
IA
i










Footnotes












1. Existing

E = 0.8 lb/106 Btu
2. New (constructed after 12-15-73)
Q <_ 10 x 106 Btu/h
E = 0.6 lb/106 Btu
Q > 10 x 106 Btu/h
E = o.enq-0-131
CD
M
                                                             PART 6.  VISIBLE  EMISSION REGULATIONS












Political
jurisdiction
State
Existing sources
Requirement





c




Ol
tx.
2









4-»
U
n
40
x
•0
c
c ••-
•a
JZ in


4> 3
1- C 1-
E E 0


Exception





c


E

0)
C
QC
3









4->
U

60
^
n
c
c •*—
•o


4-*
41 3
U C t-
e E o
0 I*
Z 1 rH
4










4)
x:
4-*
O

New sources1
Requirement





c

n
e

O)
tx.
1








x

u
*o
0.
o
20
x
<0
c

a
£ V)


4) 3
(- C t~
E E 0


Exception





c

10
E

0>
c
QC
3









•*-•
U
s
60

10
c
c ••-
n
£ tfl

*• 3
4* 3
1- C t-
ii 0
O 1
4










4»
o



O
4J



C


41
U
in



Footnotes












1. Constructed after 12-15-73.

-------
                                                                                OHIO
                                                    PART A.   ALLOWABLE MASS EMISSION RATE FOR INDIRECT  HEAT EXCHANGERS






Political
jurisdiction
State




Total heat input
based on:
•o
*- t
O 3
n
3-
|s
1_






Ol

Ul
i
X




c


t-
O TJ
ii
••- X3
X
IV 1-
Z 0
X






(A
C
5
X



in
*J

3
ividual
•o
c
l-t




^


ividual
•o
c







t_
J=
*J
o




Allowable
emissions
based on:



c
Q.
£
*J
C
UJ







ividual
•a
c




^
•3

ividual
•o
c
X






U
o





Units of the
regulations



3
to
£
X1







£




U
•0


~V Wl
XI «
•— Ol







H-
u
tn
VI
C
•0
i.







L.
*J
O







f
3

H-
i

i-
37
1-
38



C.
w

surement
«
PTC-
27




Footnotes





1. Priority I regions - curve 1-37.
Priority II and III regions - 1-38.


00
OJ
                                                                 PART  B.  VISIBLE EMISSION REGULATIONS



Political
jurisdiction
State
Existing sources
Requirement

Ringelmann
1

!>
u
a
20
c
§••- 3
E 0

Exception
-
Ringelmann
3

f
60
c
O •»- 3
3

1

New sources
Requirement

RingelHann


£

c
No more thar
	 minutes i
1 hour

Exception

i


if
\

c
to more thar
— minutes
L hour


|



]
Measurement



ii
Continuous i
lor ing requ


Footnotes




-------
                                                                         OKLAHOMA
                                                 PART A.   ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS










Political
jurisdiction
State
Tulsa











Total heat input
based on:

•o
?
t- L.
O 3
a

u 'i
O> 3
t_
«* ID

X












S

i/t
0)
"D
X
£
X











c
en
0)


H-
O "O
IE
E 3
X
£^


















I/I
C
_
5














c
3


3
^
C
X













u



3
•^
^



















•I
C.
0












Allowable
emissions
based on:




c
m
o.
Ol
•*->
c
UJ














c
3


>0
'-5

X













u
w
ut


•a
S




















•
o













Units of the
regulations






4-*
OQ
p-l

X1
X2

















"v.















U
(0
u>


o
o
rH


















<*-
U
VI
•-
t-



















w
o
















O)
u
3
O)

f-

41
U
C
10,000 0.10
2 Q, E, ,
106 Btu/h lb PW/100 h
<10 0.60
TOO 0.35
1,000 0.20
>10,000 0.12
00
                                                              PART B.  VISIBLE EMISSION REGULATIONS
Political
jurisdiction
State
Tulsa
Existing sources
Requirement
Ringelmann
1
2
>»
•r-
u
10
a
o
20
>>
c
01
c
c ••-
m
£ u>
-»-» at
4->
01 3
O ••- 3
EE,°
I L

Exception
c
i
OJ
O)
c
QC
3
>»
u
(0
o.
0

^
>o
c
c ••-
m
£ V)
^s
« 3
is
o
z
3
O
£
r-l
51
6
U
tl
£.
*>
O

New sources
Requirement
Ringelmann
1
>,
u
ia
a
o

?
(O
c
c •«-
fl
£ «/>
*-5
ai 3
O •»- 3
EBO
5 L

Exception
c
c
»
u

-------
                                                                             OREGON
                                                   PART A.   ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS






Political
jurisdiction
State



Total heat Input
based on:

J
O 3
A
Aggregrate
all fuels




c
IA
Max 1 BUB de




c
Ol
*

Max i mi* of
or burned






M
i




'i

Individual




u
IB

Individual






t_
o
NS1


Allowable
Missions
based on:


c
"a.
t
C
UJ




*>
c

Individual




!

Individual
X





1
o




Units of the
regulations



3
03
*
O
r-f
.O






|




U
3
in

.0






•t.
U
IA
M
C
C9
X2





1
o







C
Ol
H-
Referencc






T>
5
2
*>
Heasurenen





Footnotes




1. NS denotes not specified.
2. Existing - 0.2 gr/scf.
New - 0.1 gr/scf (constructed after 6-1-70)
00
                                                                PART B.   VISIBLE EMISSION REGULATIONS





Political
jurisdiction
State




Existing sources'
Requirement


c
2
8,
OL
?







^
u
§
40





«
f (ft
ttj
11!
3




Exception


c

1
CK








X
U
1






C
£«
«j •
8Ei
0 I*
Z IrH









1
O





New sources
Requi resent


c
c
1
ac
1







^
I
20





c
C '^
£ M

Q -r- 3
!v
i L
3




Exception


c
c
8.
QC








^
U
s.
o






1
c
g.-
£ IA
-s
€1 3










|






XI
o
*J
s
4-»
w
Heasur






^
il
3

- ?
C ft-
33





Footnotes





1. Existing sources outside special control area and
all existing wood waste boilers.
2. New sources in all areas and existing sources
Inside the special control area (constructed
after 6-1-70).

-------
                                                                       PENNSYLVANIA
                                                  PART A.  ALLOWABLE MASS EMISSION HATE FOR INDIRECT HEAT EXCHANGERS














Political
Jurisdiction
State
Al 1 eQheny Co
Philadelphia
Co.








Total heat Input
based on:


T)

*- L
0 3

W
*J Wl
•W —
t- 41
v •*-
X
x
x











O»

wt
W
T3

•
Maxiau











c

•—
01



o -o

fc
-J
"x
TJ U.
=F o



















4-1

c
3













«-*
~c
3



3
•o

c
X
x
x










u
4J





•o

•5
c






















5
0










Allowable
emissions
based on:






c
ij

ex

«i
c
UJ













*•*
c
3




•o

•o
c
X
x
x










u
*->







1






















£
0











Units of the
regulations







3

en

0

X1
X2
x3-'



















£


.5










u
2





o
§
^ M
A f*
-— Ol





















c






















l_
£
















U
o>





c
W
u
41
ac.
l-2<
1-3C











•o
Q
f.
«J
W






3
ifl












Footnotes
»











i. 6Q. E<6
106 Btu/h Ib/io" Btu
2.5 < Q < 50 0.4 „ „
50 < Q 7 600 E • 3.6
Q > 600 0.1
2. ,Q, E.fi
10b Btu/h lb/106 Btu
0.2 < 0 < 50 0.40 n ,,
50 < Q < 850 E ' 3.5Q~U'be>
0 i 850 0.08
3. Units built prior to 4-10-79 must meet 0.2 lb/106 Btu.
4. Units built after 4-10-79 must meet 0.1 lb/106 Btu.
5. Coal conversions must meet 0.12 lb/10 Btu after
7-1-80 and 0.06 lb/106 Btu after 7-1-84.
CO
cr>
                                                              PART 8   VISIBLE EMISSION REGULATIONS
Political
jurisdiction
State
Philadelphia
S Allegheny
Counties
Existing sources
Requi rcment
c
c
c
1

u
S
20
C
•9
C
s
*J
U
ex
o
20
20
No wore than
	 minutes in any
1 hour
3
3
Exception
Ringelnann
3
4-*
U
ex
o
60
60
c
c
« *~
C. VI
*-» W
W 3
U C U
0 •- 3
!"is
^ i-.
0
0
1
o

Measurenent nethod |
X1
Continuous aoni- |
toring requirement 1

Footnotes

1. Devices approved by the Department and maintained
to provide opacity measurements, or by trained
observers.
2. Allegheny County new are those constructed after
8-17-71.

-------
                                                                      RHODE  ISLAND
                                                 PART A.  ALLOWABLE  MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS






Political
jurisdiction
State



Total heat Input
based on:
•o
«- i.
O 3
QI
S,s
It H-
t-




S
•
Maximu* d
X


c
ot
M
*-
Haxinum o
or burned






c
3
X



i
, 	
Individua



.at:
3
in
r^
Individua






i-
0



Allowable
emissions
based on:

^

*o.
c
LLJ




C

Individua




u
+J

Individua
X





u
o




Units of the
regulations


.
a
S
X1





|




U
•a
in

\ in





^_
u

i

Heasureme





Footnotes




1. Q. 106 Btu/h E, lb/106 Btu
1 < Q < 250 0.2
Q >_ 250 0.1
00
                                                             PART B.   VISIBLE EMISSION REGULATIONS







Political
jurisdiction
State


Existing sources
Requirement



c
c
2
f
ae
1






X
u
20



c
C -r-

4-1 4»
r?,
slf
3


Exception



f
2
1
ae







>,
S




C
•0
f M
f 3
•v
Z IrH








2
0



New sources
Requirement



c
c
2
1
CR*







>.
U




C
C t-

4-* «J
• 3 u
SE|
o 1
Z IrH



Exception



c
c
2
f
ae







2-
U
10
Q.




C
C •*-
10
£ in
*J 01
*J
Siu
0 •*- 3
1°
s L








5
9





•a
2
*j
c
u
3
in
«





 5 x 10° Btu/h.

-------
                                                                     SOUTH  CAROLINA
                                                 PART A.  ALLOWABLE MASS EMISSION RATE  FOR INDIRECT HEAT EXCHANGERS













Political
jurisdiction
State







Total heat Input
based on:

•o

c
O 3
.O


10 •—

Ol 3
Ot^
•eX. (O










C
Ol

IA




i
3
x






c
o*

01



O "O
0)
§c
t-
e 3
•r- .O
x o














IA


c
3
5
X







IA
4->
C




3
•o

-5
c









u
3
VI



3
•o

1

















0)
£
o







Allowable
emissions
based on:





c
19

Q,

-?
UJ









4-»
C
3




•o

•5
c









u
*J
Ul


«o
3
•o

1
X
















01
JC
+*
0








Units of the
regulations






3

CO

&
i-H

X1
















.C










u
3





O
o
3
^s. in
A «
•— Ol













V-
u
IA

IA
C
m
o

















L.
at
o













3
O)



ai

c
t
*»-
Ol
QC
1-31









o
jr

0)


c



3
I









Footnotes












1. Q < 1300 x 106 Btu/h
E = 0.6 lb/106 Btu
Q > 1300 x 106 Btu/h
E - 57.84Q-0'637
Except existing sources prior to February 11, 1971.
Q < 10 x 106 Btu/h
E = 0.8 lb/106 Btu
oo
oo
                                                             PART B.  VISIBLE EMISSION REGULATIONS










Political
jurisdiction
State






Existing source*
Requl recent






c

f
Of
2













x
u
10
o.
o









id
C -t-



01 3
O ••- 3
"if







Exception






c
§
Ol
c
DC
3













x
u
1









«
C f-


*-t «
• ^
i-ij
o 1
Z IrH
52














k-
o







u 1
New sources'
Requirement





c
c

1
DC
1













x
U
10
a.
0








3

C ••-
a

*j a

§i
o
Z

•l






o
f-«

Exception





c
c
3
V
O)
c
ae
3













x
u
a
a
o









*
C -f-


*•» V

O ••- 3
E E 0
5 1:
52














k_
o









•a

1
^



E
Measur









^
c
"c w
E -r-



o u
3
.£?
4J ••-
C L.
O O
O 4->
X3







Footnotes









1. Constructed after 2-11-71.
2. 20 mln 1n 24-h period.
3. Required for steam generators > 250 x 106 Btu/h
except where only gaseous fuel Is burned, oil or
a mixture of gas and oil Is burned and PM and
visible emission requirements are met, or the
annual average opacity factor Is 30X or less.

-------
                                                                        SOUTH DAKOTA
                                                  PART A.  ALLOWABLE MASS EMISSION RATE FOR  INDIRECT HEAT EXCHANGERS





Political
jurisdiction
State


Total heat Input
based on:

•o
•»
»* M



S
Haxlnun dei
X


1
ll




U)
C
3
X


VI
«J
C
3
Individual



3
v»
Individual




1
o


Allowable
emissions
based on:


*CL
£
c
UJ
X


c
Individual



|
Individual




1



Units of the
regulations


5
CD
s
"N.
X1



f
"X
J3



M
O
§
t-l
\ *o




Grains/scf




1
o






1
Reference f





TJ
i
i
M




Footnotes



1. Solid fuel or fuel oil
E = 0.30 lb/106 Btu
00
vo
                                                               PART B.  VISIBLE  EMISSION REGULATIONS







Political
jurisdiction
State
Existing sources
Requirement




c
c
8.
OC
1





**
U
o
20
>,
(0

c
•9
C Wl
t- c u
Z | tH

Exception




i

QC
3





**
S
o.
0
60
>,
a

c
K
-a

ol5
Z 1 r~*
3





i-
o

New sources
Requirement




i
I
oc





X
«J

>.
*

c
2.
*> w
J,^
81J
£ IrH

Exception




c
c
1
OC






|

>.
n


4-* «
«J
813
si:






L.
O



1



1
Measur



c

c w

'5
o 2
=f
c t-
0 O
o »>


Footnotes








-------
                                                                         TENNESSEE
                                                  PART A.  ALLOWABLE MASS EMISSION RATE  FOR INDIRECT HEAT EXCHANGERS












Political
jurisdiction
State














Total heat Input
based on:

«
c
•*- u.
O 3
.0

4-> tn
19 r-
Q) a
u
cn»—
QI*—
X















C

in
01
•o

§
















C
o>
VI



o -o
Of
§ £

l_
x: o




















in

C

5
X














4-»
C
3


ID

•o
••-
C















U

tn


•D

-a
•n
c























f-
O














Allowable
emissions
based on:



4-»
c
IQ

*0.
*

C
LU















^
C



IV
=1
Tl
•n
C















U
3
u*




^
•2
C
X






















w
0















Units of the
regulations







CD
«
r-t
^
X1






















J=
^















u
fO





§
o
rH
^ 5>



















<*-
(J
Vt

•^
U
tD























W
0


















e
O)

£

Ol
u
c
OJ
OP
4)
QC
1-32
[-33















•o
^
I

4-1
c
01

1
VI
T1
















Footnotes











1. Diffusion equation If Q < 400 x 106 Btu/h

E = 20650 ah
Q '
a = 0.67 If stack height (h) < 200 ft
0.80 If h > 200 ft
Note: when more than one stack exists, E Is
divided by (N)0-Z5 where N = number of
stacks or use Fig. 1-32 and 1-33.
Existing
Q. 10° Btu/h E, lb/106 Btu
Q 1 10 0.6
10 < Q < 10,000 1.0903Q"0-259''
Q >. 10,000 0.10
VO
o
         (continued)

-------
        TENNESSEE (continued)
                                             PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS







Political
jurisdiction














Total heat Input
based on:
TJ
O a
A
•I
ti^
t- •>
S-S
fe














&
M

i
i













&
M

•»-
Max i Hum o
or burned

















3
"c













M
i


Individua













u
3
V)


ID
3
•o
TX
C

















+J













Allowablt
emissions
based on:


c

*Q.
£
C














C


Individua













u
3
in


Individua

















u














Unlts of the
regulations




eo
i-i

















S













It
M

A
"*-v M
JO  250 0.10
2. Wood-fired units existing (corrected to 12X C02)
Q £ 50 x 106 Btu/h
E = 0.33 gr/sdcf
Q ^ 100 x 106 Btu/h
E * 0.10 lb/106 Btu
Interpolate 50-100 Btu/h
New (constructed after 4-3-72)
Q <_ 25 X 106 Btu/h
E = 0.33 gr/sdcf
vo
        (continued)

-------
        TENNESSEE  (continued)
                                           PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS










Political
Jurisdiction



Hamilton Co.








Total heat input
based on:

•o
t>
<*- L.
0 3

W
t- 'at
Ot 3
«c «














O)

wt
4)
|
X



X







c
01

41


•*-
ll
st
»: 0


















-
5



X








U)

c


1 —
•o
c













u
4-*
W»

i —
I
C



















4-*
O











Allowable
emissions
based on:





c

Ol
c
UJ













4-»
c
3

i —
•o
c













u
4J


1 —
•o
i



X















5
o












Units of the
regulations






D
CO
O
o
i



x3















-v.
a













u
-»S
(A

.Q
§
-O ra
•- 01

















t-
u
\
Ul
c
1-
o


















u
o

















3
O)



£
£
o>
oc



1-32
1-33









TJ

4->
V
E


C
1
£













Footnotes









Q £ 100 x 106 Btu/h
E = 0.20 gr/sdcf
Interpolate 25-100 Btu/h
3. Existing - Schedule I
New - Schedule 2 or schedule 3 If built after
January 1, 1975
Q, 106 Btu/h E. lb/106 Btu
I 11 III
0-10 0.60 0.60 0.60
100 0.40 0.33 0.17
1,000 0.27 0.18 0.10
to
        (continued)

-------
        TENNESSEE  (continued)
                                                    PART B.  VISIBLE EMISSION REGULATIONS








Political
jurisdiction

State
All areas ex-
cept Davidson,
Hamilton. Knox
and Shelby Co.3






Existing sources
Requirement



c
1

Si
DC

1



2










^

u
§

20



40








n
c
c •*-
C Wl
^a
•1 3
1- C 1.
I'i 3
i i:

52










Exception



c
c
m
E

Si
£
















>.
*l
u
1













>
c

t

f in
tt



i'i o
i












rH


















ft.
O












New sources
Requirement



c
i

«
O!
C
ac.

i



2












u
£
o

20



40







>


c'
m
c
£ in


i'i
s.


o
r-4

52




















Exception



c
c

s.
c

















•JJ
1













a
c
2 wi
^l

i'i o
5 1:

















t
«i
i














.p

4-*
i
C
i
u
Wl
m














4-»
c
i]
in cr
1s
C Dl
••- C
C U
0 0

X











Footnotes








1. Constructed after 4-3-72.
2. 20 min in any 24-h.
3. Hood-fired units > 100 x 106 Btu/h.
If other emission sources exhaust through
the same stack:

y = 40.0 Vw + 20.0 VR
where: V - opacity standard, I
Vw = exhaust flow rate, dscf, from
wood-fired unit
VR = exhaust flow rate, dscf, other
emission sources.
vo
U)

-------
                           TEXAS
PART A.   ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS













Political
jurisdiction
State










Total heat Input
based on:

•o
41
c
H- t-
O 3

41

U 41
O> 3
t.
<"S
X












c
Ol


-s



E
1










C
O)

I/I
Ol


<*-
o -o
41
§c
L.
E 3
••- .a
m t-
a: o
















VI
4-*

C
3
5











in

c
3

^
3
"O

•r-
C
X











u

in

'•O

•o

..-
c




















41
4-1
O










Allowable
emissions
based on:




4->
c
no
o.

4>
•r-
UJ












4-*
C


n
3

•*-
..-
c
X











u
3


^


•r-
-,-
C




















a>
o











Units of the
regulations






4-»
CD

«O
S
5
X1



















-C
.a

X2









JHC
u
3
in

rt

o
g
o
1-1
J3 id
•— at
















u
i/i

i/i
•^
u
o




















ai
o


X3











Of
t-
3
Ol

t-
Ol
^

U
0.
o
30
15








c*
Kt
C
« '*"
£ IA
4-* «
-*-•
41 3
U C (-
I e o
° 1*
Z | rH
5
52







Exception




c
c
s

4*
Oi
c
°£














^
4J
U
O.
o










c*
c
c •--
5 »
4> ^
ecu
O -r- 3
E E 0
O 1
Z 1 rH
















t
5
o









New sources'
Requirement




c
c
3

S
C
*














^

u
J
o
20
15








I

•»
c
c -»-

£ in
+-• 0>
4) =
1- C

u
§•*- 3
e o
o
z
x:
iH
5
Exception




c
c


s.
c
QC














^

u
Q.
O










£»
•0
c
c -^
£ in
4J 41
*3
41 3
U C U
§•»- 3
E 0
, x:
o
Z 1 r-4.
















u
5
o











•o
o
I

c

u
3
i/l
10
X











^J
c
"c S
E ••-
sl
O t-
3
c o>
•r- C
4J -r~
C U
O O
CJ 4->
X3









Footnotes










1. Constructed after 1-31-72.
2. Sources with flow rate > 100,000 acfm unless
opacity monitor is Installed in flue.
3. General opacity requirement for any stationary
flue with more than 100,000 acfm and greater
than 151 opacity averaged over a 5 minute period.
General S0? requirements for primary nonferrous
smelters and any sulfurlc acid plant using SO,
control on such smelters.

-------
                                                                                   UTAH
                                                         PART  A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS







Political
jurisdiction
State

Total heat input
based on:
1
t- t-
O 3
a
Aggregrate
all fuels

c
01


Max i At* de
X
c
Ol



O V
|!





in
i
X
m
C
3

T3
1

3

M

I*J
3
•o
1






*-»

Allowable
emissions
based on:



c
•0
ex
c

^
c


T5
?
X
-

(A

*
3
^
1






£


Units of the
regulations




ID
*
A
X1





i

U
«-»
Ml

O
o






u
ut
1.






*J
o




C



V
u
c
ac




1




«



Footnotes





1. 10 lbs/106 Btu (0.18 gr/itm calories).
•OD
tn
                                                                     PART B.  VISIBLE  EMISSION REGULATIONS





Political
jurisdiction
State
Uasatch
Front area
Existing sources
Requirement


c
c
c*
c





„
1
40

20
|

£S
• 3
U C U
J"l-



Exception


i
ee.





x
1



£
c
i;
*-» «•
el.
f "5 o
s i:
a

3



o



New sources '
Requiremenl


i
1
QC





X
4-*
O
70


|
c
c •*-
IV
C VI
«-> w
5 1:



Exception


c
c
Ol
c
ac





x
u
1*
o.
o



5
e
c —
^1
s i:
3





£
O





|
S
remnt
w
*





«J
C
Q £
I*
Is




Footnotes




1. Constructed after 4-?5-71.



-------
                          VERMONT
PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS












Political
jurisdiction

State









Total heat input
based on:

•o
«
c
>*- u
O 3
£J
4>
+J in
« r—
t- 4>
O) 3
ft* H—
t-
01 —
Olf—
a
+J



5
•a
•o
•-.
X

















*
0









Allowable
emissions
based on:




4-»
c
fl)
a.
a»
£
UJ











4-*
C
3


3
^
•o
^










^e
u
»0
+J
VI


10
3
TJ
•5
^
X

















Of
£
O










Units of the
regulations






a
4-*
CD

rH
*v
^
X1

















£
\
^










^
u
3
i/i

-Q

O
O
rH
^. in
f— en















H-
u
VI
\
IA
ra
o


















ai
-C
0















3
O)

t4-

01
(J
c
ai
OP
•*-
a:
1-31











TO
o
£
*j
i

+j
c
i
01
u
tn
m
z











Footnotes











1. Existing
Q <_ 10 x 106 Btu/h
E = 0.5 lb/106 Btu
(0.90 g/106 cal)
10 < Q < 300
E - 1.4865Q-0'"32
Q >_ 300
E = 1.0 lb/106 Btu
(0.18 q/106 cal)
            PART B.   VISIBLE EMISSION REGULATIONS










Political
jurisdiction
State

Existing sources
Requirement






c
!
1
3
2







>,
I
60
40

c

c.
n

+j «i

olJ
Z IrH
0
6
Exception





c
c
(O
B
C
oe.









>.
u
a.
0


>
c
"
c
»
u
>a
s
60
20

c

c
jg *~
£ in
«J 01
S3
C U
§•»- 3
E 0
0
6
Exception






c
3
01









s
o
o.
o


X
c

c
•0

4-» 01
01 3
U C i-











t-
s
o




o

O)
E
4-*


01
u
I/I
i




C
1 2:
C W
Q (-
3
Wl O"
3 a>
3
c at
c t~
0 0



Footnotes









1. Constructed after 7-1-71.


-------
                                                                           VIRGINIA
                                                    PART A.  ALLOWABLE MASS EMISSION  RATE FOR INDIRECT HEAT EXCHANGERS








Jurisdiction
State
AQCR 7










Total heat Input
based on:
c
•*- L.
O 3


** *ft
U











&

M

i
1











&
VI


*.
;i
* a
Su
X














M
C
^
X










M
«J
C
3


1
17
C











3
«*


1
c
















5











Allowable
emissions
based on:


c
*v
"a.
«*
*>
c
UJ











c



I
1











u
5
M


1
1
X














ft.
5
a












Units of the
regulations




m
jQ
X1
X2














f











u
3
in

A
§
5S















u
Ml
M
t.
u
















1
a














r
Ol



£
2














I

*J
c
I
3
M













Footnotes






1. Q < 10 x 106 Btu/h
E • 0.6 lb/106 Btu
c
10 £ Q < 10,000 x 10° Btu/h
Q > 10.000 x 106 Btu/h
E • 0.10 lb/106 Btu
2. 0 < 100 x 106 Btu/h
E • 0.3 lb/106 Btu
100 < Q < 10,000 x 106 Btu/h
E • 0.900H-0-"86
Q > 10.000 x 10S Btu/h
E - 0.10 Ib/Btu
vo
                                                                PART B.   VISIBLE EMISSION REGULATIONS
Political
jurisdiction
State
Existing sources
Requirement
c
ee

5-
U
O.
o
20
1
Is
• 3
J":
*
Exception
c
c
1
oc


u
•ff
ex
o

•fj
i;
«-l •
* i u
IV
£ L

k
JC
*>
o

New sources
Requirement
R1ngel«ann

Z
a.
o

If
** 41
!',*
Z lr-<

Exception
i
C
QC

I

r
C
*-» •
**
MI
s L

s

•o
I
c
Wl

-------
                                                                 WASHINGTON
                                            PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS













Political
jurisdiction
State

NH Air Pollu-
tion Control
Auth.
Puget Sound

SW Air Pollu
tion Control
Auth.

Olympic Air
Pollution
Control Auth



I Allowable
Total heat Input
based on:



c
H- U
O 3

01
«-> I/I

l~ 01
Ol 3
at **-
£-
CJI-—
Oi-—



















c
at

W»
at
-o


E
X
X
















c


(A
01
T3


O -D

§C
L
e 3
••- &
X
ID U
X 0























U)


C
3
^

















in

c



ig

•o
>
C


















u

QC



















o
£
«J



c
01


3
1


















Footnotes












1. Existing - 0.20 qr/dscf
New - 0.10 gr/dscf (constructed after 10-5-73)

2. Existing - 0.20 gr/scf
New - 0.05 gr/scf
3. Existing - 0.10 g/scf
New - 0.05 g/scf

4. Wood residue
Existing - 0.20 qr/scf
New - 0.10 gr/scf

5. 0.10 gr/scf
Hog-fuel - 0.2 gr/scf
Natural gas - 0.3 gr/scf
6. NS denotes not specified.
<£>
CO
         (continued)

-------
          WASHINGTON  (continued)
                                                   PART B.  VISIBLE EMISSION REGULATIONS









Political
jurisdiction
State
NW Air Pollu
tlon Auth.
Puget Sound
SW Air Pollu
tlon Control
Auth.
Olympic Air
Pollution
Control
Yakima Co.
Clean Air
Auth.
Spokane Co.
Air Pollutior
Control Auth,
Existing sources
Requirement







01
01
c
oc

2
2
2


2


1


1






x
U
I
40
40
40



40


20


20
>.
Id

C
S""
VI

il 1
i i:
31.2
31'2
34
3


3


3


3
Exception





c
c
s,
c



2-3


2-3












^
£
10













>.
Id

C
s-

"S
Of 3
K- C L.
Sei
si:



65


65













Jj
o













New sources
Requirement





c
c
in
E
01
Ol
c
oc


\
1


1





1







S"~
o.
o
20

20



20





20
>.
W

C

£ in
"3
01 3
U C 1-
I'i o
s i:
31,3


3


3





3
Exception





c
c
8.
c
K


2
















^
U
a.
o


40










>.
id

c

£ M
^S
Ol 3
t. C t-
I5|?


15

















i-
Ot
0















|

01
E

C
i
u
3
in
*















c
1 4V



3
in o*
§2
.I.™
C 1-
0 0
u *>
X













Footnotes









1. Not exceed IS mln In any consecutive 8-h.
2. Does not apply If source meeting < 0.20 gr/dscf.
3. Does not apply If source meeting < 0.10 gr/dscf.
4. Does not apply to equipment utilizing wood residue
when source is meeting < 0.05 gr/scf.
5. Hog fuel boiler.

6. Constructed after 10-5-73.






vo

-------
                                                                     WEST  VIRGINIA
                                                  PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS













Political
Jurisdiction
State





























Total heat Input
based on:


w
c
«- t_
O 3
n
ty
•a —
L. *
* *~
en.—
^ "«
































C
en

v>

TJ
5
-5
X
*
X
X





























c
.,_
tn
V
•o


o -o
•1

1 o





































M
C

~
X






























£

c
3


3
TI

'































O





3
TJ

=








































5





























Al lowabie
emissions
based on:






c

Q.


C
X






























^,

c



3
TJ

?































O

4-1



3
T3

^








































5






























Units of the
regulations








ID

t-H
-*x
X1'2






































,e
^































(J


Ul


*~
|
I-*
•^ s





































o
vt
^
^_
IV
t_







































V
J=
o




































en







s-e































o
o
«J

B

*>
C
i
1
in
i































Footnotes












1. If plant Is expanded by addition of new unit, allowable
emission rate for new unit shall be determined as
follows:
where.
R * total allowable emission rate 1n pounds per hour
for the new fuel burning unit(s);
H . » total design heat Input In 10* Btu's/h of the
existing and new similar units;
R . • total allowable emission rate In Ibs/h
corresponding to H.t; and
H • total design heat Input In 10* Btu's/h for the
new fuel burning un1t(s).
2. Type "a" units
Product of 0.05 and total design heat Inputs,
no more than 1200 Ibs/h.
Type "b" units
Product of 0.09 and total design heat Inputs,
no more than 600 Ibs/h.
Type "c" units
10* Btu/h Ib/h
10 3.4
100 16.6
3.333 300.0
No more than 300 Ib/h
where:
(1) Type "a" Is any unit which has primary purpose
of generating steam to produce electric power
for sale.
(2) Type "b" Is any unit not classified as "a" or "c".
(3) Type "c" Is any hand-fired or stoker-fired unit.
O
o
           (continued)

-------
WEST VIRGINIA (continued)
                                           PART 0.  VISIBLE EMISSION REGULATIONS






Political
Jurisdiction
State










Existing sources
Requl resent



c
c
1
.5













5-
I











|
C
5 "*~
*>
Cgi.
8-1
£ ^
•










Exception



i
1
oe
1


2










x
a
a.
o











1
c
C f
C M
3C r-l
81
2
1
1203
I203
IcU









k
0











New sources
Requirement



c
c
1
DC














5-
i











1
c
c ••-
f 1
III
£ ,-,











Exception



i
I
oe














x
I











>.
e
c -*-
?!
o
Z rH















L.
O













|
S

C
3
w
1













C
1 5
• *»-
ii
C 9
c'u
o o
«J.»












Footnotes





I. Exemption applies to soot blowing and firebox
cleaning and Is applicable during any 8 h
period.

2. Exemption applies to start-up of units except
hand-fired or stoker-fired.
3. Exemption applies to start-up of hand-fired
or stoker-fired units. Rlngelnan 13 for first
45 minutes. Rlngelman 12 for remaining 75
minutes.
4. Director may require - general requirement.

-------
                                                                       WISCONSIN
                                                PART A.   AUOWABIF MASS EMISSION RATE FOR  INDIRECT HEAT EXCHANGERS














Political
jurisdict ion

Statp












,
Total heat input
based on.


a*
c
•*- t_
.O


ITJ —
C- Ol
O> Z3
u
01 —
/I




—
-^>
c
•— •
X























Oi

o














Units of thp
regulations






3

01

'O
o
1-1
.0
•—
X1























£

•—















o

*J
tn
XI



O
i-H

— 01



















•*-
o


I/I
.^

o
























«
*J
o

















Oi


o>
^

41
(j
c

l-
tu

c*:
3-2
3-3
3-4
3-5













•D

4J

E
^j




t_
^
Ol
s:















Footnotes














1. Category I - New or modified sources (except in
Southeast Wisconsin Intrastate AQCR)
Q _'_ 250 x 106 Btu/h E - 0.15 lb/106 Btu
Q > 250 x 106 Btu/h E = 0.10 lh/106 Btu
Existing Lake Michigan Intrastate AQCR Fig. 3-5
(ASME No. APS-1) with maximum E, irrespective of
", 0.6 Ib/in6 ntu.
All sources in Southeast Wisconsin Intrastate AQCR.
(Q < 250 x 106 Btii/h - Not permitted to burn coal).
All sources - 0.15 lb/106 Btu.
Existing sources (except Michigan and S.E. Wisconsin
Intrastate AOCR'sj Fiq. 3-6 (ASME NO APS-1) with
max E = 0.3 lb/10& Btu.
O
M
        (continued)

-------
       WISCONSIN  (continued)
                                                    PART B.  VISIBLE EMISSION REGULATIONS







Political
Jurisdiction
Category I
Category II -
control plan
submitted by
July 1. 1971
compliance
by July 1,
1973
Category III
or IV - Lake
Interstate
AQCR, South-
east Wiscon-
sin Intra-
state
Existing sources
Requirement



c
c
1



2






1




>.
\



40






20
C
c
s-
£ Ul
tl
ill
^ IH











Exception



c

•1
o>
c



4






4




$
I



80






80
c
m
c
C -r-
.
I
20










|
C


tl
iii
? IH











Exception



c
c
I
4














^

80










!
c


*J 41
4-*
iii
? IH
52















I













•o
O
c.
E
«J
C
1
3
«A
m













•I
|C
"5
ui cr
1s
C D>













Footnotes






1. Constructed after 4-1-72.
2. Cleaning and starting fire but not more than
3 times/day. If stack test Is run concurrently
with Ringelmann test, opacity should be set 101
above average read by stack test.









o
U)

-------
                          WYOMING
PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS
Political
jurisdiction
State
Total heat input
based on:
Aggregrate of
all fuels burned

MaxiHui design
X
Haximun of design
or burned

U)
C
3
X
I/I
C
(O
3
-o
>
1

3
*
3
C

t_
0)
JC
O

Allowable
emissions
based on:
c
(0
Q.
£
'i
LU

4-1
C
3
•o
>
1

U
•9
3
T3
•>
•5
C
X
o

Units of the
regulations
3
CO
O
rH
JO
X1
JC
JQ

U
3
JO
O
O
o
l-t
JO fO
>— O)

lins/scf
u

Ol
o


erence figure
£
1-41

•o
o
JC
4-*
I
I

Footnotes

1. Existing
Q,106 Btu/h E, lb/106 Btu
Q <^ 10 0.6
10 < Q < 10,000 0.8963I"0'1743
Q >_ 10,000 0.18
             PART B.  VISIBLE EMISSION REGULATIONS











Political
jurisdiction
State2



Existing sources
Requirement





c
n
E

0>
c
oc.











>>

u
s
40






•>
(0


JC vi



*J
01 I

E


O
JC
6






Exception





c
10
E

O)
c
oc











>^

u
,
4?
u
40





F
c
c •*-




O -f- 3
E E 0
0 I*
Z IrH
6












U
U
JC
4-*
o






•o

JC
4-*


4-*



3
I/I
<0
Ol
z:






^j

7=1

E 'f"
3



C (-
O O
o *-»





Footnotes










1. Constructed after 4-9-73.
2. Source specific opacity limits will be established
for large fuel burning units which can not meet
20% opacity limit.

-------
                                                                   AMERICAN SAMOA
                                               PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS




Political
jurisdiction
Territory

Total heat Input
based on:
0 3
Aggregrate
all fuels 1

&
I
i

&
Wl
41
•o
O T»
IE
X
X

Wl
c
£

Wl
c
3
1
TJ
C

I
Wl
1
•o
c
X


5
o

Allowable
Missions
based on:

Q.
t
tl
UJ
X
«i
§
Individual

u
3
in
Individual


u
u
o


Units of the
regulations

I
s
a
X1

c.
2.

I
Wl
A
S
o
r-4
A IV
•— Ot


lins/scf
u


u
o




£
Ol
>renc* 1
«




£
I
isurement
JE



Footnotes


1. 0.10 lb/106 Btu.
o
01
                                                           PART B.   VISIBLE EMISSION REGULATIONS






Political
jurisdiction
Territory
Existing sources
Requirement



i
1
oe
1



^
u
o
ZO
c
C i-


*-3
HI
"if

Exception



c
f
DC
3



^
u
o
60
c
c ••-



O — 3
oG|°
i U
3




u
o

New sources
Requirement



i
1
ac




^
Q.
O

 41
.3
t. C k.
iii
S 1*





U
*>
o



method



u
3
Wl
I



moni-
i rement


3 V
0 <-
3
££
C U
o o
CJ **


Footnotes







-------
                            GUAM
PART A.   AUOWABLF MASS EMISSION RATE  FOR  INDIRECT HEAT EXCHANGERS














Pol i tical
jurisdiction
Territory
Total heat input
based on:


TJ
ID
c
"+- t-
O D
r>
o>

IT) r—
L 01
cn =3
u
cn —
cn —
0
H


C
CT

kp
or
TJ


o TJ
0)
e c
a t.
•- £3
X
(0 L
i: o











-«->

c


O
NS>
AlTowaBle
emissions
based on:






4-*
C
ftJ

Q.





n>
3
•o


T)
C














(V
-C
4-»
CD
NS1
Units of the
regulations








3
*J
CD

«
O
i-H
\
£l














x:
JD



^
o
•B
+J


r>


(^
O
O
r-l
~N^ in
£3 n
— CT









•4-

o




Hi
i_
3
CT>



O)
U
C
OJ
ID
(U
o:


TJ
Q
c.
+J
Of
E

4->
c
(V
E
or
u
13
i/t
m
01
•3L

Tootnotes















1. NS denotes not specified.
             PART 8   VISIBLE  EMISSION REGULATIONS







Political
jurisdiction
Territory
Existing sources
Requirement



c
c
n
E
41
f
oc.
1




X
u
o.
o
20
>.
«
c
c •*-
5 tA
Of 3
O 1

Exception



c
c
O>
c
3




^
u
«
ex
0
60
>,
,
u
1

>,
«
c
C -r-
_£; y,
* i u
la|
O I
Z 1 rH

Exception



c
c
1
oc





x
u
•a
o

>,
19
C
-C «
•1 3
§•»- 3
E 0
Z If-l






U
O



?
**
*
c
1
W)

c
i g

s-
i/i O*
ia
•*— C
c t~
0 -M


Footnotes








-------
                       PUERTO  RICO
PART A.  ALLOWABLE MASS EMISSION RATE FOR INDIRECT  HEAT EXCHANGERS






Political
jurisdiction
Territory

Total heat Input
based on:

•a
°l
Aggregrata
all futls 1
X


«
Maximum dt


o»
«
O tJ
•"•• J3
X
n L.
X 0




M
C
£


W
C
3
•o
TJ
C


•j;
VI
1
1
X




5
o

Allowable
emissions
based on:


^
"a.
t
ti
iU


^
c
3
Idividual
K-.


J<
U
3
M
Idividual
>-i
X



t.
o


Units of the
regulations



3
ID
s
—
X1



•N.
r-


J<
U
Ml
rH





Grains/scf




1
o





£

Reference f




•o
5
0)
E
Measurement



Footnotes




1. 0.30 1b/106 Btu.
            PART B.  VISIBLE EMISSION REGULATIONS



Political
Jurisdiction
Terrl tory
Existing sources
Requirement
i
1
oe
1
If
S
s
20
c
l«
-5
l"i!

Exception
c
c
1
3
5-
U
I
60
c
s i:
41

U
o

New sources
Requirement
c
8,
(K


1
o

1
c
c •.-
^1
i. c u
£i|

Exception
,
I
OC

iS-
1

C
c ••-
l"i!


*J
o



i
*j
i
3
VI
i



nuous moni-
j requirement
^- c
+> '*-
C U
o o
o «->


Footnotes


1. Any 30 minutes.

-------
                                                                       VIRGIN  ISLANDS
                                                   PART A.   ALLOWABIF MASS EMISSION RATE FOR INDIRECT HEAT EXCHANGERS
O
oo
- - -













Political
jurisdiction
Territory




_ .__ _ .......
Total heat input
based on:

"O
Of

«•- t-
0 3
n

(0 —

Ol 3

5*«
x







c
01

IB
V


3

x:





c



01
rj

"*-
91
§C
L.

*TJ t-
z: o















c

^






vt


c


•—
3

••-
—
C
X






u




1 —


•r-
—
c
















a*
o





AI lowabte
eml ss ions
based on:






c

Q.

O)
-,-
C
UJ









c


—
3

•r-
-,-
C
X








•M


1 —
3

••-
•^
C
















«
O






Units of the
rngulations







3
CD

'JO
2
£
X1















.c
£







u
(0



XI

o
o
r-*
£ g,












•*-
VI

VI
•-
O
















0)
0





















1-4;







O


or
E


c
F

u
VI
£





- - -

Tootnotes













1. lOj'h 1b/106 Btu
< 10 0.60
100 0.352
1,000 0.207
>. 10,000 0.09
                                                              PART B  VISIBLE EMISSION REGULATIONS














Political
Jurisdiction
Territory
Existing sources
Requirement







c

(0
E

V
o>
c
on
2











u
iV
ex
0
40
;


c
T)

C
C —
to
.C u


01 :
u c
O -r-
E E
o








t-
O
i-H

Exception







c
c



Ol
c
a;











*_>
u
fQ
a.
o


?
c

c
c —
lfl



a; -
1- C
tf
o











u
3
O
JC
i-H













L.
41
^
+J
0

New sources
Requi rement







c


e

w
C7I
C
1











u
•0
a
o
20

c

c
c -
IV
c wt
4-1 «
*J

U C L.
§— 3
E 0
1 1:

Exception







c
c



ft
c
2












u
•fl
Q.
O
40


S

c
c —

-C VI


Ol 3
E- C (-
E E O
O 1
Z IrH
6












U
«P



•o
o


E


C
Of
E
W

3
tf)
Ol
*



^
C
i J(
C IV
0 (-
e ^
3

3 V
0 «-
3

** -^
C t-
o o


Footnotes
















-------
                                 REFERENCES
 1.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Alabama.  EPA 450/2-80-007.  July 1980.

 2.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Alaska.  EPA 450/2-80-008.  July 1980.

 3.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Arizona.  EPA 450/2-80-009.  July 1980.

 4.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Arkansas.  EPA 450/2-80-010.  July 1980.

 5.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     California.  EPA 450/2-80-011.  July 1980.

 6.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Colorado.  EPA 450/2-80-012.  July 1980.

 7.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Connecticut.  EPA 450/2-80-013.  July 1980.

 8.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Delaware.  EPA 450/2-80-014.  July 1980.

 9.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     District of Columbia.  EPA 450/2-80-015.  July 1980.

10.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Florida.  EPA 450/2-80-016.  July 1980.

11.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Georgia.  EPA 450/2-80-017.  July 1980.

12.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Hawaii.  EPA 450/2-80-018.  July 1980.

13.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Idaho.  EPA 450/2-80-019.  July 1980.

14.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Illinois.  EPA 450/2-80-020.  July 1980.

15.   Regulations  and  Non-Regulatory Revisions  to  State Implementation Plan:
     Indiana.  EPA 450/2-80-021.  July 1980.


                                      109

-------
16.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Iowa.  EPA 450/2-80-022.  July 1980.

17.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Kansas.  EPA 450/2-80-023.  July 1980.

18.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Kentucky.  EPA 450/2-80-024.  July 1980.

19.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Louisiana.  EPA 450/2-80-025.  July 1980.

20.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Maine.   EPA 450/2-80-026.  July 1980.

21.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Maryland.  EPA 450/2-80-027.  July 1980.

22.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Massachusetts.  EPA 450/2-80-028.  July 1980.

23.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Michigan.  EPA 450/2-80-029.  July 1980.

24.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Minnesota.  EPA 450/2-80-030.  July 1980.

25.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Mississippi.  EPA 450/2-80-031.  July 1980.

26.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Missouri.  EPA 450/2-80-032.  July 1980.

27.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Montana.  EPA 450/2-80-033.  July 1980.

28.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Nebraska.  EPA 450/2-80-034.  July 1980.

29.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Nevada.  EPA 450/2-80-035.  July 1980.

30.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     New  Hampshire.  EPA 450/2-80-036.  July 1980.

31.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     New  Jersey.  EPA 450/2-80-037.  July  1980.

32.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     New  Mexico.  EPA 450/2-80-038.  July  1980.
                                       110

-------
33.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     New York.  EPA 450/2-80-039.  July 1980.

34.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     North Carolina.  EPA 450/2-80-040.  July 1980.

35.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     North Dakota.  EPA 450/2-80-041.  July 1980.

36.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     Ohio.  EPA 450/2-80-042.  July 1980.

37.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     Oklahoma.  EPA 450/2-80-043.  July 1980.

38.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     Oregon.  EPA 450/2-80-044.  July 1980.

39.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     Pennsylvania.  EPA 450/2-80-045.  July 1980.

40.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     Rhode Island.  EPA 450/2-80-046.  July 1980.

41.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     South Carolina.  EPA 450/2-80-047.  July 1980.

42.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     South Dakota.  EPA 450/2-80-048.  July 1980.

43.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     Tennessee.  EPA 450/2-80-049.  July 1980.

44.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     Texas.  EPA 450/2-80-050.  July 1980.

45.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     Utah.  EPA 450/2-80-051.  July 1980.

46.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     Vermont.  EPA 450/2-80-052.  July 1980.

47.  Regulations  and Non-Regulatory  Revisions  to State Implementation  Plan:
     Virginia.  EPA 450/2-80-053.  July 1980.

48.  Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Washington.   EPA 450/2-80-054.  July 1980.

49.  Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     West Virginia.  EPA 450/2-80-055.  July 1980.
                                       Ill

-------
50.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Wisconsin.  EPA 450/2-80-056.  July 1980.

51.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Wyoming.  EPA 450/2-80-057.  July 1980.

52.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     American Samoa.  EPA 450/2-80-058.  July 1980.

53.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Gaum.  EPA 450/2-80-059.  July 1980.

54.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Puerto Rico.  EPA 450/2-80-060.  July 1980.

55.   Regulations  and  Non-Regulatory  Revisions  to State Implementation  Plan:
     Virgin Islands.  EPA 450/2-80-061.  July 1980.

56.   State   Implementation   Plans  Emission.    Regulations  for   Particulate
     Matter:  Fuel Combustion.  EPA 450/2-76-010.  August 1976.

57-   Control  of  Particulate  Matter  from Oil Burners  and  Boilers.  EPA  450/
     3-76-005.  April 1976.

58.   Compilation  of  Air  Pollutant Emission Factors.  Second edition.  AP-42.
     February 1980.

59.   Smith,  W.  S.  and C. W.  Gruber.  Atmospheric  Emissions from  Coal  Combus-
     tion.   An  Inventory  Guide.    U.S.  Department  of  Health Education  and
     Welfare.  AP-24.  April  1966.

60.   Roek, D. R.,  and R. Dennis.  Technology Assessment  Report for Industrial
     Boiler   Applications:    Particulate   Collection.    EPA   600/7-79-178h.
     December 1979.

61.   Compilation  and Analysis  of State  Regulations for  S02, NO  , Opacity,
     Continuous  Monitoring,   and  Applicable Test  Methods.   Prepared for  U.S.
     Environmental  Protection Agency  by Engineering Science  under EPA  Con-
     tract No. 68-01-4146, Task No. 40.  June 1978.
                                      112

-------
          APPENDIX A

REFERENCE FIGURES FOR ALLOWABLE
        EMISSION RATES
             113

-------
  1.000,
CD


O
i—I

_O



OO

O
I—I
oo
I/O
I—I

UJ

UJ
_J
oa


o
_j
_i
•=C
   .001
                              10
100                    1,000

HEAT INPUT,  106  Btu/h

Reference  Figure 1-1.
10,000
50,000

-------
  l.OOOr-
CO
u>
O
co

O
I—«
CO
CO
HH

LU

LU
—I
CO


O
_J
_l
eC
    .001
                               10
100                    1,000
HEAT INPUT,  106  Btu/h
10,000
50,000
                                                     Reference Figure  1-2.

-------
(Ti
     CO
     u>
     o
     o
     I — I
     oo
     CQ
     
-------
  .1
•M
CO
ID
o
in
•z.
o
CO
CO
LU
_J
co

^
O
_J
_J
<£.
       0
10
100                    1,000

HEAT INPUT,  106 Btu/h
10,000
50,000
                                                     Reference  Figure 1-4.

-------
CD
       l.OOOr-
        .500
     CO

     in
     o
     .—I


     JD




     OO
     z:
     o
     »—t
     oo
     oo
     CO

     <£
                                   10
100                    1,000


HEAT INPUT,  106  Btu/h
10,000
50,000
                                                         Reference Figure  1-5.

-------
     00


     to

     O
     to
     z
     O

M    K
H    CO
vo    i— <
     CQ
     <:

     o
                                                         100                    1,000


                                                         HEAT INPUT, 106 Btu/h
10,000
50,000
                                                         Reference Figure 1-6.

-------
to
o
                                  10
100                   1,000

HEAT INPUT, 106 Btu/h
10,000
50,000
                                                       Reference  Figure  1-7.

-------
        .000,
fo
                                                       100                   1,000
                                                       HEAT INPUT, 106 Btu/h
                                                       Reference Figure 1-8.
10,000
50,000

-------
K)
NJ
        l.OOOr
         .500
     CO

     u>
     CD
     i-H


     -d


      Vl

     I/O
     z
     o
.100
.050
               it!
CO


o
	I
_l

-------
       .1,
NJ
(jj
-l->
CQ


-------
4->
CQ

u>
o
,—I

-Q


 fN
I/O

O
CQ


O
_J
_l

-------
        .OOOr-r
Un    £
        .001
            0
10
100                    1,000
HEAT INPUT, 106 Btu/h
10,000
50,000
                                                        Reference  Figure 1-12.

-------
    .OOOrT-rr
        I '-r
    ,500-i
 =3


CQ

ID
o
I—t

jQ


  *>

t/>
CQ


O
_l
_l
et
                               10
100                     1,000

HEAT  INPUT,  106 Btu/h

Reference  Figure 1-13.
10,000
50,000

-------
       1
to
     CO


     
-------
       1.000,
00
         .500
     CO


     ID

     CD
     00
     •z.
     o
     »— i
     01
     CO
     co

     3
     O
     _l
     _J
     «=c
                                   10
100                    1,000

HEAT INPUT,  106 Btu/h


Reference  Figure 1-15.
10,000
50,000

-------
       .1.000™
NJ
VO
CD

ti>
o
I—I

-Q


 n
co
z
o
i—i
co
co
     CQ
     «t

     O
        .001
                                   10
                                                    100                    1,000

                                                    HEAT  INPUT,  106 Btu/h
10,000
50,000
                                                         Reference Figure  1-16.

-------
       1.000
        ,500 :
    CQ

    
-------
.001
                         10
100                   1,000
HEAT INPUT, 106 Btu/h
10,000
50,000
                                              Reference Figure 1-18.

-------
       l.OOOr-
        .500
    CO

    u>
    o
    1 — I

    jQ


     r>
    C/1
    z:
    o
u>
    co

    3
    O
    _l
    _J
    •a:
                                   10
100                    1,000

HEAT INPUT,  106  Btu/h

Reference  Figure 1-19.
10,000
50,000

-------
u>
U)
 3
CO
u>
O
t—I
_o

to
O
>—I
to
to
»—I
s:
LU
UU
CO
3
O
_1
_J
«c
                                    10
                                                      100                     1,000
                                                      HEAT INPUT, 106  Btu/h
10,000
50,000
                                                          Reference Figure  1-20.

-------
10
100                   1,000
HEAT INPUT, 106 Btu/h
10,000
50,000
                     Reference Figure 1-21.

-------
to
       1.000
        .500
     4->
     00
    u>
     O
     to
     z
     O
     to
     to
     UJ
     _J
     co
        ,100
        .050
                                   10
100                    1,000

HEAT INPUT,  106  Btu/h


Reference Figure 1-22.
10,000
50,000

-------
   l.OOOr-rrTTT
    .500
CQ

l£>
o
I—I

JD


  *\


§
•—<
<^
t/o
CO

-------
     OQ
     u>
     O
co
-j
o
»—4
to
     UJ
     _l
     CO
     •=£.
                                   10
                                                    100                    1,000

                                                    HEAT INPUT,  106  Btu/h
10,000
50,000
                                                         Reference  Figure 1-24.

-------
       1.000:
00
     CO

     to

     o
     1—I


     JQ




     OO


     O
     I—I

     OO
     oo
     CO


     o
     _1
     _l
     
-------
       l.OOOr-rrT
u»
VD
 3
co
u>
o
.—I
-Q
 r
CO
o
I—I
CO
co
     co
     O
     _J
     _I
     •=c
                                    10
                                                      100                     1,000
                                                      HEAT  INPUT, 106 Btu/h
10,000
50,000
                                                          Reference Figure 1-26.

-------
   l.OOOr-T
    .500
CO

ID
o
i—i

-O


  ft
GO

O
f—«
CO
GO
CD

3
O
_l
_J
•=£
                              10
100                    1,000

HEAT INPUT,  106  Btu/h

Reference  Figure 1-27.
10,000
50,000

-------
4J

OQ
co
z
o
to
to
CO
•a:
       0
10
100                    1,000

HEAT INPUT,  10s  Btu/h
10,000
50,000
                                                    Reference Figure  1-28.

-------
K)
       l.OOOr-r-,
         .500!-^
     CO

     to
     o
     ,—I

     _o


      r
     oo
     ^
     o
     I—I
     oo
     oo
     <:
     o
,100
.050
        .010
        .005
        .001
               It
                  II
         i
                            i i

                             11
                                     _L.J

                                      ill
                                      M


                                      I
II
                                          it
                                           .Hi
                                                      ill
                                             il
                                             I

                                                     HI
                                                      ffl
t
                                                                     r
                                                              lU
                                                                 i
                           ftt
                                                                              Ill
                                                                               \A
                                                                                «
                                                                                JlJJ:
                                                                          l!
                                                                                   ill;
                 •Jffl
                                                                                               lii-
                                                                                    it
                                                •Jl
                                                   ffi
                                                                                                              TTTT
                                                                                                             Tit
                                                                                                                rfi
                                                              l ! I i
                                                                 t!H
                                                                 i  u
                                                                            111
                                                                            H-i
                                                                                                                            411
                                    10
                                                  100                     1,000

                                                  HEAT  INPUT,  106 Btu/h
                                                          10,000
                                                       50,000
                                                           Reference Figure 1-29.

-------
  l.OOOr-r
    .500
CO
to
O
    ,100
-  .050
I/O
•z.
O
to
to
CO

-------
10
100                   1,000
HEAT INPUT, 106 Btu/h
10,000
50,000
                     Reference Figure 1-31.

-------
       1.000
Ul
CO

U3
O
i—I

-Q



 r

oo


O



to
    CQ



    O
    	I
    _J
    «a:
                                   10
                                                    100                    1,000

                                                    HEAT  INPUT,  106 Btu/h
10,000
50,000
                                                         Reference Figure  1-32.

-------
10
100                   1,000
HEAT INPUT, 106 Btu/h
Reference Figure 1-33.
10,000
50,000

-------
-M
OQ
u>
O
CO
Z
O
co
to
CD

-------
CD
       1.000,
        .500-
     CQ

     u>
     O
     i—i


     JO


      r
     co
     •z.
     O
     >—<
     oo
     CO
     CO

     3
     O
     _J
     _l
     
-------
    •000|Tin
co

u>
O
i— I

_O
t/J
CO
UJ

UJ
_1
CQ


O
_1
_J

-------
Ul
o
            0
10
100                   1,000

HEAT INPUT, 106 Btu/h
10,000
50,000
                                                       Reference  Figure  1-37.

-------
CD

to
O
i—I


JQ




to


O
i—i



i—i
SI
UJ


UJ
_J
CO



O

_J
«=C
       0
10
100                    1,000

HEAT INPUT,  106 Btu/h
10,000
50,000
                                                     Reference  Figure 1-38.

-------
       1.000,
Ul
         .500-44-
CO

us
o
r—I

JO


  f\
CO
2:
o
t—I
to
1/1
     CQ


     O
     _J
     _J
     eC
                                   10
                                                     100                     1,000

                                                     HEAT  INPUT, 106 Btu/h
10,000
50,000
                                                          Reference Figure 1-39.

-------
       l.OOOr
en
10
CO


u>

O
I—I


_a



 •t

co


O
I—I

co
co
ca


o
_i
_i
•=c
        .010
        .005
        .001
                                   10
                                                     100                    1,000


                                                     HEAT INPUT, 106  Btu/h
10,000
50,000
                                                         Reference Figure 1-40.

-------
10
100                   1,000
HEAT INPUT, 106 Btu/h
10,000
50,000
                     Reference Figure 1-41.

-------
       1.000
01
     +J
     00
    o
    1— I


    _Q



      A

    oo
    co


    o
    _i
    _i
    «c
                                                        100                    1,000


                                                        HEAT INPUT,  106  Btu/h
10,000
50,000
                                                        Reference Figure  1-42.

-------
    1.000


    0.500
M-
O
in
°>  0.100
 ft


g  0.050
i—i

oo
t—I
2:
LU

LU

g  0.010

o

-J  0.005
    0.001
         10'
  10"            105


   FLOW RATE, cfm



Reference Figure 2-1,
106
107
                                           156

-------
 a
 2
 3
 a
«o
 o
 z
 o
    1.5
1.0
0.9
0.8

0.7
0.6

0.5

0.4
         1' '|''"I''  '|'"
                           \\\\
    UM GIOUMD UVU DUS1 CO*«CINTI*riOM

    £ 1OO wf —J »OI 3-11 mio
    * ia »•• mi »oi ae •*••« • i *M

    £ IT.* mJ !•* S« hr»
 -  0.3
    0.2
 D
 u
 H
 a
 <
 a.
                 • All*
1 »U»1T*MVIALIT »L*f TIIIAIM
1. ix O' MIAT IM^UI v» SIACK &s tiMSiA^i i
3 STACK MtlGMT tS »Mf itCAl i**C« MUCMT
«. C«*»M tl »OI • JIMCkl STACK
    0.1
                                            i i 11	t   i I  I i i i i
                510        50  100       500 1,000    5,000 10,000

        TOTAL EQUIPMENT CAPACITY RATING, TO6 Btu/hr INPUT
                   ASME STANDARD, APS-1
                     Reference  Figure 3-1.
                              157

-------
        5   10        50  100        500 1,000     5,000 10,000
TOTAL EQUIPMENT CAPACITY RATING, TO6 Btu/hr INPUT
           ASME STANDARD, APS-1
            Reference  Figure  3-2.
                    158

-------
       S tOO «•• "^ POt
       « »ft *>«• -O IOI 1C «M I hr
        5   10        50  100       500 1,000     5,000 10,000
TOTAL EQUIPMENT CAPACITY RATING, 106 Btu/hr INPUT
           ASME STANDARD, APS-1
           Reference Figure 3-3.
                    159

-------
 Q.
 2
o
 o
z
g

—
s
 <  0.2-
 u

 H
 ce
 <
 a.
                  ^ 100 ttt ™J 'Of 3-11 •*•«

                    SO »f MA POt 30 •••«  I


                    IT i«« *i (». 34 >w.
       1           5    10         50  100        500  1,000     5,000 10,000


          TOTAL EQUIPMENT CAPACITY RATING, 106 Btu/hr INPUT

                      ASME STANDARD, APS-1
                        Reference  Figure  3-4.
                                  160

-------
        5   10        SO  100       500 1,000     5,000 10,000
TOTAL EQUIPMENT CAPACITY RATING, 106 Btu/hr INPUT
           ASME STANDARD, APS-1
            Reference Figure 3-5.
                    161

-------
   1.000
g. 0.500
O

O

O
^  0.100
-Q  0.050
r—

 «\

oo


O
I—I

I/O
oo


£  0.010
CO



O
	1

_l

=£
   0.005
   0.001
                        10             100             1000          10,000



                          STEAM CAPACITY RATING, 1000  1 bs of  steam/h




                                     Reference Figure  4-1.
                                                                                  100,000
                                           162

-------
IO
en
o


X)
o
o
o
10
co
z
o
oo
CO
OQ




I



<
1.000



0.500
0.100
     0.050
s    0.010
     0.005
     0.001
                         10             100            1000          10,000


                           STEAM CAPACITY RATING, 1000 Ibs of steam/h




                                      Reference Figure 4-2.
                                                                              100,000
                                            163

-------
l/l
.Q
    1.000
S  0.500
§
0   0.100
£   0.050


oo
z:
o
oo
I/O
UJ

LU
_1
CO
<:

o
    0.010
    0.005
    0.001
                         10              100            1000         10,000

                          STEAM  CAPACITY  RATING, 1000 Ibs of steam/h



                                      Reference Figure 4-3.
                                                                                   100,000
                                              164

-------
       1000.0

        500.0
Ul
CO
o
I—I
CO
co
h—I
Ul
Ul
_l
CO

-------
       1000.0
        500.0
                -rtii
(Ti
        100.0
    2   50.0
    oo
    oo
CO


o
_l

<   10.0






      5.0
          1.0
                rin
                . .11
                 4-
                j r I
                -I i '-
                -1-14
                fll
                !  !l
               W4H
                III
                 Ml

                        I
                          iWli
                          1
  ill
.UiiL
                               ill
  i
    mlf
          i <  i


         ttit
                                            .L
         4XTL-U::
                                         ISK
                                           Ji
                                            L,
                                           >r
i
 i!1
                           liii
                          -U!
                                                                  i

                                  ill]
                                                                 L-Ul
                                                                       -•f
j.i
                                                                      IL
                  or
                                                                         u
ijj^
                      §• i

                       L
                                              11.

                                              I
                                            uiuiii
                                            II:
                                                                                 LiU
                                                           -tt
                                     llU
                                      II
                                     ]-
                                   iii:
                        pri-frr
                        ill! '•
                                                                                            .11
                                                                                               i i i


                                                                                               it
                                                                                              nt
                                                                                                      -M
                                                                                                      il
                                (Mlii
                               iiljlii
                                ill,
                               Jur;
                                                   il
                                        t
                                                                              "t
                                                                                                                    !. .U.
                                                                                    in1!
                                                 mj
                                                 ilk
                                                                 1M
                                                                 rh
                                                                 in
                                                                                                                           Jill
                                                                                         n
                                       10
                               100                      1000


                               HEAT  INPUT, 10"  Btu/h


                               Reference Figure 5-2.
                                              10,000
                                                      100,000

-------
   500
   100
co
z
o
CO

CO
    50  —
                            10"                   105


                        STACK EFFLUENT  FLOW  RATE,  acfm.




                             Reference  Figure  6-1.
106
                                   167

-------
  1000
o
«t
I—
00
   100
Q
DC


Q


c£

I—
1/1
    10
                            1014                   105

                        STACK EFFLUENT FLOW  RATE,  acfm
10E
                             Reference Figure  6-2.
                                 168

-------
  1000


   500
to
to
LlJ

UJ
_l
CO

-------
    APPENDIX B



CONVERSION FACTORS
      170

-------
Multiply
Btu/hr input

send cu ft/sec
stnd cu ft/min
grams/sq m
grams/sq m/day
grains/stnd cu ft
grains/stnd cu ft
grains/stnd cu ft
grains/send cu ft
  (adjusted to 50%
  excess air)
grams/stnd cu m
grams of gas/stnd
  cu m
megawatts of steam*
  generated
  electricity
micrograms of gas/send
  cu m
milligrams of gas/stnd
  cu m
milligrams/send cu m
ppm by vol

ppro by vol

.ppm by vol

ppm by vol
percent by vol
pounds of gas/hr
pounds of gas/hr
pounds/1000 Ib  gas*
    APPENDIX  B
CONVERSION  FACTORS

   JBy
    10"

    mol wt x 9.3
    tool wt x 0.155
    2.85
    86.5
    1.89
    2300
    2.30
    2.20

    0.435
    24.2 x lOVmol wt

    10T

    0.0242/raol  wt

    24.2/mol  wt

    4.35 x 10"4
    mol wt x 41.3 x 10"

    mol wt x 0.0413

    mol wt x 41.3
    104
    6.48/mol wt
    0.108/mol wt
    0.53
 To Get
 Megawatts of steaiz."
  generated elec-
/ teicity (approx.)
 pounds of gas/hr
 pounds of gas/hr
 short tons/sq mi
 short tons/sq mi/mo
 pounds/1000 Ib gas*
 milligrams/stnd  cu m
 grams/stnd cu m
 pounds/10* Btu input

. grains/stnd cu ft
 ppm by vol

 Btu/hr input (appro*.)
 ppm by vol

 ppm by vol

 grains/stnd cu ft
 grams of gas/stnd
  cu m
 milligrams of gas/stnd
  cu m
 micrograms of gas/stnd
  cu m
 percent by vol
 ppm by vol
 stnd cu ft/min
 stnd cu ft/sec
 grains/stnd cu ft
                                171

-------
Multiply

pounds/1000 Ib gas*       1.18
  (adjusted to 50%
  excess mlr)

pounds/10* Bru input      0.45
pounds/10* Btu input      0.85



short tons/sq mi           0.35

short tons/sq mi/mo       0.0116
 To Get

pounds/10* Ecu input
grains/stnd cu ft
  (adjusted to 50%
  excess ait)
pounds/1000 Ib gas*
  (adjusted to 50%
  excess air)

grams/sq m
grams/sq m/day
 • DO! wt «= 29

     • - Bctcr
  •el wt= o>oltcul«r w*ijhl
   •tod* (Undatd it 70 T mnd «tmo»pheiie prcmiur*
                               172

-------
              APPENDIX C

METHOD 5--DETERMINATION OF PARTICULATE
   EMISSIONS FROM STATIONARY SOURCES
                 173

-------
                              APPENDIX C
             METHOD 5—DETERMINATION OF PARTICULATE
               EMISSIONS FROM STATIONARY SOURCES
1.   Principle and Appl icabi 1 ity
   '  1.1  Principle.  Participate matter is withdrawn isokinetically
from the source and collected on a glass fiber filter maintained at
a temperature in the range of 120 +_ 14°C (248 +_25°F) or such other
temperature as specified by an applicable subpart of the standards
or approved by the Administrator, U.  S. Environmental Protection
Agency, for a particular application.  The particulate mass,  which
includes any material that condenses  at or above the filtration
temperature, is determined gravimetrically after removal of uncombined
water.
     1.2  Applicability.  This method is applicable for the determina-
tion of particulate emissions from stationary sources.
2.  Apparatus
     2.1  Sampling Train.  A schematic of the sampling train used in
this method is shown in Figure 5-1.  Complete construction details
are given in APTD-0581  (Citation 2 in Section 7); commercial  models
of this train are also  available.  For changes from APTD-0581 and
for allowable modifications of the-train shown in Figure 5-1, see
the following subsections.
     The operating  and  maintenance procedures for the sampling train
are described in APTD-0576 (Citation 3 in Section 7).  Since correct
usage  is important  in  obtaining valid results, all users should read
APTD-0576 and adopt  the operating and maintenance procedures 'outlined
in it,  unless otherwise specified herein.  The sampling train consists
of the  following components:
                                   174

-------
     2.1.1  Probe Nozzle.  Stainless steel (316) or glass with sharp,
tapered leading edge.  The angle of taper shall be <30° and the
taper shall be on the outside to preserve a constant internal  diameter.
The probe nozzle shall be;of the button-hook or elbow design,  unless
otherwise specified by the Administrator.  If made of stainless steel,
the nozzle shall be constructed from seamless tubing; other materials
of construction may be used, subject to the approval of the
Administrator.
     A range of nozzle sizes suitable for isokinetic sampling  should
be available, e.g., 0.32  to 1.27 cm (1/8 to 1/2 in.)--or larger if
higher volume sampling trains are used—inside diameter (ID) nozzles
in increments of 0.16 cm  (1/16 in.).  Each nozzle shall be calibrated
according  to the procedures outlined in Section 5.
     2.1.2  Probe Liner.  Borosilicate or quartz glass tubing with a
heating  system  capable of maintaining a gas temperature at the exit
end  during  sampling  of 120 +_ 14°C  (248 +_ 25°F), or such other tempera-
ture as  specified by  an  applicable  subpart of the standards or
approved  by the Administrator for  a particular application.   (The
tester may opt  to operate the equipment  at a temperature lower than
that specified.)  Since  the actual  temperature at the  outlet  of the
probe  is  not  usually  monitored during sampling, probes constructed
according to  APTD-0581 and  utilizing the  calibration curves of
APTD-0576 (or calibrated according to the  procedure  outlined  in
APTD-0576)  will  be  considered acceptable.
                             175

-------
(Ti
              cc
                             TEMPERATURE SENSOR
.. PROBE

 TEMPERATURE
   SENSOR
                                                                IMPINGER TRAIN OPTIONAL,MAY BE REPLACED
                                                                     BY AN EQUIVALENT CONDENSER
                                                  HEATED AREA   THERMOMETER
                                                                                 THERMOMETER
                         PITOTTUBE

                              PROBE
                        REVERSE-TYPE
                          PITOTTUBE
                                                           IMPINGERS              ICE BATH
                                                                   BY-PASS VALVE
                                                                                   VACUUM
                                                                                    GAUGE
                                  THERMOMETERS
                                                                            MAIN VALVE
                                              DRY GAS METER
                            AIRTIGHT
                              PUMP
CHECK
VALVE
                                                                                                •VACUUM
                                                                                                  LINE
                                              Fjyure 51. Parliculalc-sampling tr;iin.

-------
     Either borosilicate or quartz glass probe liners  may be  used
for stack temperatures up to about 480°C (900°F); quartz  liners
shall be used for temperatures between 480 and 900°C (900 and 1650°F).
Both types of liners may be. used at higher temperatures than  specified
for short periods of time, subject to the approval  of  the Administrator.
The softening temperature for borosilicate is 820°C (1508°F), and  for
quartz it is 1500°C (2732°F).
     Whenever practical, every effort should be made to use borosilicate
or quartz glass probe liners.  Alternatively, metal liners (e.g.,  316
stainless steel, Incoloy 825,  or other corrosion resistant metals)
made of seamless tubing may be used, subject to the approval  of the
Administrator.
     2.1.3  Pitot Tube.  Type S, as described in Section  2.1  of
Method 2, or other device approved by the Administrator.   The pi tot
tube shall  be attached to the probe (as shown in Figure  5-1)  to allow
constant monitoring of the stack gas velocity.  The impact (high
pressure) opening plane of the pitot tube shall be even with or
above the nozzle entry plane  (see Method 2,  Figure 2-6b)  during
sampling.   The Type S pitot tube assembly shall have a known coefficient,
determined  as outlined in Section 4 of Method 2.
     2.1.4  Differential  Pressure Gauge.  Inclined manometer or
equivalent  device  (two),  as described  in Section 2.2 of Method 2.
One  manometer shall be used for  velocity head  Up)  readings, and
the  other,  for orifice differential pressure readings.
  Mention  of trade  names  or  specific  products  does  not  constitute
  endorsement by the  Environmental  Protection  Agency.
                                177

-------
     2.1.5  Filter Holder.  Borosllicate glass, with a glass frit
filter support and a silicone rubber gasket.  Other materials of
construction (e.g., stainless steel, Teflon, Viton) may be used,
subject to the approval of the Administrator.  The holder design shall
provide a positive seal against leakage from the outside or around the
filter.  The holder shall be attached immediately at the outlet of
the probe (or cyclone, if used).
     2.1.6  Filter Heating System.  Any heating system capable of
maintaining a temperature around the filter holder during sampling
of 120 +; 14°C (248 + 25°F), or such other temperature as specified by
an applicable subpart  of  the standards or approved by the
Administrator for a particular application.  Alternatively, the tester
                                             /
may opt  to operate the equipment at a temperature lower than that
specified.  A temperature gauge capable of measuring temperature to
within 3°C  (5.4°F) shall  be installed so that the temperature around
the filter  holder can  be  regulated and monitored during sampling.
Heating  systems  other  than the one shown in APTD-0581 may be used.
      2.1.7  Condenser.  The following system shall be used to determine
 the  stack  gas moisture content:   Four impingers connected in series
with  leak-free  ground  glass fittings or any  similar  leak-free non-
 contaminating fittings.   The  first,  third,  and  fourth impingers  shall
 be of the  Greenburg-Smith design, modified  by  replacing the  tip  with
 a 1.3 cm (1/2  in.)  ID  glass  tube  extending  to  about  1.3 cm  (1/2  in.)
 from the bottom of the flask.   The  second  impinger  shall  be  of  the
 Greenburg-Smith design with  the standard tip.   Modifications (e.g.,
                                 178

-------
using flexible connections between the Impingers, using materials
other than glass, or using flexible vacuum lines to connect the
filter holder to the condenser) may be used, subject to the
approval of the Administrator.  The first and second impingers shall
contain known quantities of water (Section 4.1.3), the third shall
be empty, and the fourth shall contain a known weight of silica gel,
or equivalent desiccant.  A thermometer, capable of measuring tempera-
ture to within 1°C  (2°F) shall be placed at the outlet of the fourth
impinger for monitoring purposes.
     Alternatively, any system that cools the sample gas stream and
allows measurement  of the water condensed and moisture leaving the
condenser, each  to  within 1 ml or 1 g may be used, subject to the
approval of the  Administrator.  Acceptable means are to measure the
condensed water  either gravimetrically or volumetrically and to measure
the  moisture  leaving the condenser by:   (1) monitoring the temperature
and  pressure  at  the exit of the condenser and using Dal ton's law of
partial  pressures;  or  (2) passing the sample gas stream through a
tared  silica  gel  (or equivalent desiccant) trap with exit gases kept
below  20°C  (68°F)  and  determining the weight gain.
     .If means  other than  silica gel are  used to determine the amount  of
moisture leaving the condenser,  it is recommended  that silica gel  (or
equivalent)  still  be used  between the condenser  system and  pump  to
prevent moisture condensation in  the  pump and metering devices and
to  avoid the  need to make  corrections for moisture in  the metered
volume.
                               179

-------
     Note:   If a determination of the participate matter collected
in the impingers is desired in addition to moisture content, the
impinger system described above shall be used, without.modification.
Individual  States or control agencies requiring this information
shall be contacted as to the sample recovery and analysis of the
impinger contents.
     2.1.8  Metering System.  Vacuum gauge, leak-free pump, thermometers
capable of measuring temperature to within 3°C (5.4°F), dry gas meter
capable of measuring volume to within 2 percent, and related equipment,
as shown in Figure 5-1.  Other metering systems capable of maintaining
sampling rates within 10 percent of isokinetic and of determining
sample volumes to within 2 percent may be used, subject to the approval
of the Administrator.  When the metering system is used in conjunction
with  a pitot  tube, the system shall enable checks of isokinetic rates.
      Sampling trains utilizing metering systems designed for higher
flow  rates than  that described in APTD-058T or APTD-0576 may be used
provided that the  specifications of this method are met.
      2.1.9  Barometer.  Mercury, aneroid, or other barometer capable
of measuring  atmospheric pressure to within 2.5 mm Hg (0.1 in. Hg).
 In many  cases,  the barometric reading may be obtained from a nearby
national weather service station, in which case the station value
 (which  is  the absolute barometric pressure) shall be requested and
an adjustment for elevation differences between the weather station
and  sampling  point shall be applied  at  a  rate  of  minus  2.5 mm  Hg
 (0.1  in. Hg)  per 30  m  (100 ft) elevation  increase or vice  versa
 for  elevation decrease.
                                  180

-------
     2.1.10  Gas Density Determination Equipment.   Temperature
sensor and pressure gauge, as described in Sections 2.3 and 2.4  of
Method 2, and gas analyzer, if necessary, as described-in Method 3.
The temperature sensor shall, preferably, be permanently attached
to the pi tot tube or sampling probe in a fixed configuration,  such
that the tip of the sensor extends beyond the leading edge of  the
probe sheath and does not touch any metal.  Alternatively, the sensor
may be attched just prior to use in the field.  Note, however, that
if the temperature sensor is attached in the field, the sensor must
be placed in an interference-free arrangement with respect to  the
Type S pitot tube openings (see Method 2, Figure 2-7).  As a second
alternative, if a difference of not more than 1 percent in the average
velocity measurement is to be introduced, the temperature gauge need
not be attached to the probe or pitot tube.   (This alternative is
subject  to  the approval of the Administrator.)
     2.2  Sample Recovery.  The following items are needed:
     2.2.1   Probe-Liner and Probe-Nozzle  Brushes.  Nylon bristle
brushes  with stainless steel wire handles.  The probe brush shall
have extensions  (at  least  as long as  the  probe) of stainless  steel,
Nylon, Teflon, or  similarly  inert material.   The brushes  shall  be
properly sized and  shaped  to brush  out  the  probe liner  and  nozzle.
      2.2.2   Wash Bottles—Two.  Glass wash  bottles are  recommended;
polyethylene wash  bottles  may  be  used at  the  option  of  the  tester.
 It is  recommended  that acetone  not  be stored  in polyethylene  bottles
 for longer  than  a  month.
                                181

-------
     2.2.3  Glass Sample Storage Containers.  Chemically resistant,
borosilicate glass bottles, for acetone washes, 500 ml or 1000 ml.
Screw cap liners shall either be rubber-backed Teflon or shall be
constructed so as to be leak-free and resistant to chemical attack
by acetone.  (Narrow mouth glass bottles have been found to be less
prone to leakage.)  Alternatively, polyethylene bottles may be used.
     2.2.4  Petri Dishes.  For filter samples, glass or polyethylene,
unless otherwise specified by the Administrator.
     2.2.5  Graduated Cylinder and/or Balance.  To measure condensed
water to within  1 ml or 1 g.  Graduated cylinders shall have sub-
divisions  no greater than 2 ml.  Most laboratory balances are capable
of weighing to the nearest 0.5 g or less.  Any of these balances is
suitable  for use here and in Section 2.3.4.
     2.2.6  Plastic Storage Containers.  Air-tight containers to
store silica gel.
     2.2.7  Funnel and  Rubber Policeman.  To  aid in transfer of silica
gel  to  container; not necessary  if silica gel is weighed in the field.
     2.2.8 Funnel.   Glass or polyethylene, to aid in sample recovery.
     2.3   Analysis.   For  analysis, the  following equipment is needed:
     2.3.. 1  Glass Weighing Dishes.'
     2.3.2 Desiccator.
     2.3.3 Analytical  Balance.  To measure to within 0.1  mg.
     2.3.4 Balance.  To  measure to within  0.5  g.
     2.3.5 Beakers.   250 ml.
     2.3.6 Hygrometer.   To  measure  the relative  humidity  of  the
 laboratory environment.

                                  182

-------
     2.3.7  Temperature Gauge.  To measure the temperature of the
laboratory environment.
3.  Reagents
     3.1  Sampling.  The reagents used in sampling are as follows:
     3.1.1  Filters.  Glass fiber filters, without organic binder,
exhibiting at least 99.95 percent efficiency (<0.05 percent penetration)
on 0.3-micron dioctyl phthalate smoke particles.   The filter efficiency
test shall be conducted in accordance with ASTM standard method
D 2986-71.  Test data from the supplier's quality control program  are
sufficient for this purpose.
     3.1.2  Silica Gel.  Indicating! type, 6 to 16 mesh.  If previously
used, dry at 175°C  (350°F) for 2 hours.  New, silica gel may be used
as received.  Alternatively, other types of desiccants (equivalent or
better) may be used, subject to the approval of the Administrator.
     3.1.3  Water.  When analysis of the material caught in the
impinger? is required, distilled water shall be used.  Run blanks
prior to  field use  to  eliminate a high blank on test samples.
     3.1.4  Crushed  Ice.
     3.1.5  Stopcock Grease.  Acetone-insoluble, heat-stable silicone
grease.   This is not necessary  if screw-on connectors with Teflon
sleeves,  or similar, are used.  Alternatively, other types of  stopcock
grease  may  be used,  subject  to  the approval of the Administrator.
     3.2  Sample Recovery.   Acetone—reagent grade,  <0.001 percent
residue,  in glass  bottles—is required.   Acetone  from  metal  containers
generally has a  high residue blank and should  not  be used.   Sometimes,
                              183

-------
suppliers transfer acetone to glass bottles from metal containers;
thus, acetone blanks shall be run prior to field use and only
acetone with low blank values- (<0.001 percent) shall be used.  In
no case shall a blank value of greater than 0.001 percent of the
weight of acetone used be subtracted from the sample weight.
     3.3  Analysis.  Two reagents are required for the analysis:
     3.3.1  Acetone.  Same as 3.2.
     3.3.2  Desiccant.  Anhydrous calcium sulfate, indicating type.
Alternatively, other types of desiccants may be used, subject to the
approval of the Administrator.
4.   Procedure
     4.1  Sampling.  The  complexity  of this method is such that, in
order  to obtain reliable  results, testers should be trained and
experienced with  the test  procedures.
     4.1.1   Pretest Preparation.  All the components  shall be maintained
and  calibrated according  to  the  procedure described in APTD-0576,  unless
otherwise specified herein.
     Weigh  several  200  to 300 g  portions of  silica gel in air-tight
containers  to  the nearest 0.5 g.   Record the  total weight of  the
silica gel  plus  container, on each  container.   As an  alternative,  the
silica gel  need  not be  preweighed,  but may  be  weighed directly  in  its
 impinger or sampling  holder just prior to  train assembly.
      Check  filters visually against light  for irregularities  and
 flaws  or pinhole  leaks.   Label  filters of  the proper  diameter on  the
 back side near the edge using  numbering  machine ink.   As an alternative,
                                    184

-------
label the shipping containers (glass or plastic petri dishes) and
keep the filters in these containers at all times except during
sampling and weighing....
     Desiccate the filters at 20 +_ 5.6eC (68 + 10°F) and ambient
pressure for at least 24 hours and weigh at intervals of at least
6 hours to a constant weight, i.e., <0.5 mg change from previous
weighing; record results to the nearest 0.1 mg.  During each
weighing the filter must not be exposed to the laboratory atmosphere
for a period greater than 2 minutes and a relative humidity above
50 percent.  Alternatively (unless otherwise specified by the
Administrator), the filters may be oven dried at 105°C (220°F) for
2 to 3 hours, desiccated for 2 hours, and weighed.  Procedures other
than those described, which account for relative humidity effects,
may be used, subject to the approval of the Administrator.
     4.1.2  Preliminary Determinations.  Select the sampling site and
the minimum number of sampling points, according to Method 1 or as
specified by the Administrator.   Determine the stack pressure,
temperature, and the range of velocity heads using Method 2; it  is
recommended that a leak-check of  the pitot lines  (see Method 2,
Section  3.1) be performed.  Determine the moisture content  using
Approximation Method 4  or  its alternatives for the purpose  of making
isokinetic  sampling rate  settings.   Determine  the stack  gas dry
molecular weight,  as described  in Method  2,  Section  3.6;  if integrated
Method  3 sampling  is used  for molecular weight determination,  the
 integrated  bag  sample  shall  be  taken simultaneously  with, and  for
 the same total  length  of time  as, the particulate sample run.
                             185

-------
     Select a nozzle size based on the range of velocity heads,  such
that it is not necessary to change the nozzle size in order to maintain
isokinetic sampling rates.  During the run,  do not change the nozzle
size.  Ensure that the proper differential  pressure gauge is chosen for
the range of velocity heads encountered (see Section 2.2 of Method 2).
     Select a suitable probe liner and probe length such that all
traverse points can be sampled.  For large  stacks, consider sampling
from opposite sides of the stack to reduce  the length of probes.
     Select a total sampling time greater than or equal  to the minimum
total sampling time specified in the test procedures for the specific
industry such that (1) the sampling time per point is not less than 2
min, (or some greater time interval as specified by the Administrator),
and  (2) the sample volume taken (corrected  to standard conditions) will
exceed the required minimum total gas sample volume.  The latter is
based on an approximate average sampling rate.
     The sampling time at each point shall  be the same.   It is recom-
mended that the number of minutes sampled at each point  be an integer or
an integer plus onehalf minute, in order to avoid timekeeping errors.
     In some circumstances, e.g., batch cycles, it may be necessary to
sample for shorter times at the traverse points and to obtain smaller
gas  sample volumes.  In these cases, the Administrator's approval  must
first be obtained.
     4.1.3  Preparation of Collection Train.  During preparation and
assembly of the sampling train, keep all openings where  contamination
                                 186

-------
can occur covered until just prior to assembly or until  sampling
is about to begin.
     Place 100 ml of water in each of the first two impingers, leave
the third impinger empty, and transfer approximately 200 to 300 g of
preweighed silica gel from its container to the fourth impinger.
More silica gel may be used, but care should be taken to ensure that.
it is not entrained and carried out from the impinger during sampling.
Place the container in a clean place for later use in the sample
recovery.  Alternatively, the weight of the silica gel plus impinger
may be determined to the nearest 0.5 g and recorded.
     Using a tweezer or clean disposable surgical gloves, place a
labeled  (identified) and weighed filter in the filter holder.  Be sure
that the  filter  is properly  centered and the gasket properly placed
so as to  prevent the sample  gas stream from circumventing the filter.
Check the filter for tears after assembly  is completed.
     When glass  liners are used, install the selected nozzle  us'ing
a  Viton  A 0-ring when  stack  temperatures are less  than 260°C  (500°F)
and  an  asbestos  string gasket when  temperatures  are  higher.   See
APTD-0576 for  details.   Other connecting systems using either 316
stainless steel  or Teflon  ferrules  may  be  used.   When metal  liners
are  used, install the  nozzle as  above  or by a  leak-free  direct
mechanical  connection.  Mark the  probe  with heat resistant tape or
by some other  method to  denote  the  proper  distance into  the stack or
duct for each  sampling point.
                              187

-------
     Set up the train as in Figure 5-1, using (if necessary) a very
light coat of silicone grease on all ground glass joints, greasing
only the outer portion (see APTD-0576) to avoid possibility of
contamination by the silicone grease.  Subject to the approval of
the Administrator, a glass cyclone may be used between the probe and
filter holder when the total particulate catch is expected to exceed
100 mg or when water droplets are present in the stack gas.
     Place crushed ice around the impingers.
     4.1.4  Leak-Check Procedures.
     4.1.4.1  Pretest Leak-Check.  A pretest leak-check is recommended,
but not required.  If the tester opts to conduct the pretest leak-check,
the following procedure shall be used.
     After the sampling train has been assembled, turn on and set the
filter  and probe heating systems at the desired operating temperatures.
Allow time for the temperatures to stabilize.  If a Viton A 0-ring or
other leak-free connection  is used in assembling the probe nozzle to
the probe  liner, leak-check the train at the sampling site by plugging
the nozzle and pulling a 380 mm Hg  (15 in. Hg) vacuum.
     Note:  A  lower  vacuum may be 'used, provided that it is not exceeded
during  the test.
      If an asbestos  string  is used,  do not connect the probe  to the
train during  the leak-check.  Instead, leak-check the train by first
plugging  the  inlet to the  filter  holder  (cyclone, if applicable)  and
pulling a  380  mm Hg  (15  in. Hg)  vacuum  (see  Note immediately  above).
Then  connect  the probe  to  the train  and  leak-check at about 25 mm Hg
 (1  in.  Hg) vacuum; alternatively, the  probe  may  be leak-checked with
                                 188

-------
the rest of the sampling train, in one step, at 380 mm Hg (15 in.  Hg)
vacuum.  Leakage rates in excess of 4 percent of the average sampling
rate or 0.00057 m3/min (0.02 cfm), whichever is less, are unacceptable.
     The following leak-check instructions for the sampling train
described in APTD-0576 and APTD-0581 may be helpful.  Start the pump
with bypass valve fully open and coarse adjust valve completely closed.
Partially open the coarse adjust valve and slowly close  the bypass
valve  until the desired vacuum is reached.  Do not reverse direction
of bypass valve; this will cause water to back up into the filter
holder.  If the desired vacuum is exceeded, either leak-check at
this higher vacuum or end the leak check as shown below and start  over.
     When the  leak-check is completed, first slowly remove the plug
from the inlet to the probe, filter holder, or cyclone (if applicable)
and immediately turn off the vacuum pump.  This prevents the water in
the impingers  from being forced backward into the filter holder and
silica gel  from being entrained backward, into the third impinger.
     4.1.4.2   Leak-Checks During  Sample  Run.  If, during the sampling
run, a component  (e.g.,  filter assembly  or  impinger) change  becomes
necessary,  a  leak-check  shall  be  conducted  immediately before  the
change is  made.   The  leak-check'shall  be done according to  the procedure
outlined  in Section  4.1.4.1  above,  except  that  it shall be  done at a
vacuum equal  to  or  greater  than  the maximum value recorded  up  to  that
point  in  the  test.   If  the  leakage  rate  is  found  to be no  greater than
0.00057 m /min (0.02 cfm)  or 4 percent of the  average  sampling rate
                               189

-------
(whichever is less), the results are acceptable, and no correction
will need to be applied to the total volume of dry gas metered;
if, however, a higher leakage rate is obtained, the tester shall
either record the leakage rate and plan to correct the sample volume
as shown in Section 6.3 of this method, or shall void the sampling run.
     Immediately after component changes, leak-checks are optional;
if such leak-checks are done, the procedure outlined in Section 4.1.4.1
above shall be used.
     4.1.4.3  Post-test Leak-Check.  A leak-check is mandatory at the
conclusion of each  sampling run.  The leak-check shall be done in
accordance with the procedures outlined in Section 4.1.4.1, except
that it shall be conducted at a vacuum equal to or greater than the
maximum value reached during the sampling run.  If the leakage rate
is  found  to  be no greater than 0.00057 m /min  (0.02 cfm) or 4 percent
of  the average sampling rate  (whichever is less), the results are
acceptable,  and no  correction need  be applied  to the total volume of
dry gas metered.  If, however, a higher leakage rate is obtained, the
tester shall  either record the leakage rate and correct the sample
volume as shown in  Section 6.3 of  this method,  or shall void  the
sampling  run.
      4.1.5  Particulate Train Operation.   During the  sampling run,
maintain  an  isokinetic  sampling  rate  (within  10 percent of true
 isokinetic unless otherwise  specified  by  the  Administrator)  and  a
 temperature  around  the  filter of 120  +  14°C  (248 +  25°F),  or  such other
                                  190

-------
temperature as specified by an applicable subpart of the standards
or approved by the Administrator.
     For each run, record the data required on a data sheet such as
the one shown in Figure 5-2.  Be sure to record the initial dry gas
meter reading.  Record the dry gas meter readings at the beginning
and end of each sampling time increment, when changes In flow rates
are made, before and after each leak check, and when sampling is halted.
Take other readings required by Figure 5-2 at least once at each sample
point during each time increment and additional readings when significant
changes  (20 percent variation in velocity head readings) necessitate
additional adjustments in flow rate.  Level and zero the manometer.
Because  the manometer level and zero may drift due to vibrations and
temperature changes, make periodic checks during the traverse.
     Clean the portholes prior to the test run to minimize the chance
of sampling deposited material.  To begin sampling, remove the nozzle
cap, verify that  the filter and probe heating systems are up to
temperature,  and  that the pitot tube and -probe are properly positioned.
Position the  nozzle at the  first traverse point with the tip pointing
directly into the gas stream.   Immediately start the pump and  adjust
the  flow to isokinetic conditions.  Nomographs are available,  which
aid  in  the rapid  adjustment of  the  isokinetic  sampling  rate without
excessive computations.  These  nomographs are  designed  for use when the
Type S  pitot  tube coefficient  is  0.85 j^0.02,  and  the stack  gas
equivalent density  (dry  molecular weight)  is  equal to 29 +_4.   APTD-0576
details the procedure  for  using the nomographs.   If  C   and M.  are
outside the above stated ranges,  do not use  the  nomographs unless
appropriate  steps (see  Citation 7  in  Section 7)  are  taken  to compensate
for  the deviations.
                                191

-------
        PLANT
        LOCATION.
        OPERATOR.
        DATE	
        RUN NO
       SAMPLE BOX NO..
       METER BOX N0._
       METERAH@	
       C FACTOR	
AMBIENT TEMPERATURE
BAROMETRIC PRESSURE .
ASSUMED MOISTURE. % _
PROBE LENGTH,m III)	
NOZZLE IDENTIFICATION NO..
AVERAGE CALIBRATED NOZZLE DIAMETER, ctndn.]
PRODE HEATER SETTING	
LEAK RATE. m3/mm.(clm)	
PROBE LINERMATERIAL	
       PITOT TUBE COEFFICIENT.Cp.
                                                 SCHEMATIC OF STACK CROSS SECTION
STATIC PRESSURE, mm Hg (in.Mg)
FILTER NO.'	
TRAVERSE POINT
NUMBER












TOTAL
SAMPLING
TIME
(01. mm.













AVERAGE
VACUUM
mrn Hg
(in Hg|














STACK
TEMPERATURE

• °C (°F|














VEIOCITY
HEAD
|APSI.
"»n|in |H^O














PRESSURE
DIFfERENTIAL
ACROSS
ORIFICE
METER
nvn H^O
(in H20)














GAS SAMPLE
VOLUME
m3 (Il3l














GAS SAMPLE TEMPERATURE
AT DRY GAS METER
INLET
°C ("F|












Avfj.
OUTLET
"C (°F|












Avi|.
Avq.
FILTER HOLDER
TEMPERATURE
°C |'F|














TEMPERATURE
; UF GAS
LEAVING
CONDENSER OR
LAST IMPINGER.
'C ("F)














ro
                                                          Figure  5-2.  Pariiculale field data.

-------
     When the stack is under significant negative pressure (height
of impinger stem), take care to close the coarse adjust valve before
inserting the probe into the stack to prevent water from backing into
the filter holder.  If necessary, the pump may be turned on with the
coarse adjust valve closed.
     When the probe is in position, block off the openings around
the probe and porthole to prevent unrepresentative dilution of the
gas stream.
     Traverse the stack cross-section, as required by Method 1 or as
specified by the Administrator, being careful not to bump the probe
nozzle into the stack walls when sampling near the walls or when
removing or inserting the probe through the portholes; this minimizes
the chance of extracting deposited material.
      During the test run, make periodic adjustments to keep the
temperature around the filter holder at the proper level; add more
ice and,  if necessary, salt to maintain a temperature of  less than
20°C  (68°F) at the condenser/silica gel outlet.  Also, periodically
check the  level and  zero of the manometer.
      If  the pressure drop  across the filter becomes too high, making
isokinetic  sampling  difficult  to maintain, the  filter may be  replaced
in the midst  of a  sample run.   It  is recommended that another complete
filter assembly be used  rather  than attempting  to  change  the  filter
itself.   Before a new  filter  assembly  is  installed, conduct a leak-check
(see  Section  4.1.4.2).   The  total  particulate weight  shall  include the
summation of  all  filter  assembly catches.
                                193

-------
     A single train shall be used for the entire sample run, except
in cases where simultaneous sampling is required in two or more
separate ducts or at two or more different locations within the same
duct, or, in cases where equipment failure necessitates a change of
trains.  In all other situations, the use of two or more trains will
be subject to the approval of the Administrator.
     Note that when two or more trains are used, separate analyses of
the front-half and  (if applicable) impinger catches from each train
shall  be performed, unless identical nozzle sizes were used on all
trains,  in which  case, the front-half catches from the individual trains
may  be  combined  (as may the impinger catches) and one analysis of front-
half catch and one  analysis of  impinger catch may be performed.  Consult
with the Administrator for details concerning the calculation of
results when  two  or more  trains are used.
     At the  end  of  the sample run, turn off the coarse adjust valve,
remove the  probe  and  nozzle from  the stack, turn off the pump, record
the  final  dry gas meter  reading,  and conduct a  post-test leak-check, as
outlined in  Section 4.1.4.3.  Also,  leak-check  the pitot lines as
described  in Method 2,  Section  3.1;  the  lines must pass this  leak-check,
 in order to  validate  the  velocity head data.
      4.1.6  Calculation  of Percent  Isokinetic.   Calculate  percent
 isokinetic (see  Calculations,  Section  6)  to  determine  whether the  run
was  valid  or another  test run  should  be  made.   If  there was difficulty
 in maintaining isokinetic rates due  to source  conditions,  consult  with
 the  Administrator for possible  variance  on the  isokinetic  rates.
                                   194

-------
     4.2  Sample Recovery.  Proper cleanup procedure begins as soon
as the probe is removed from the stack at the end of the sampling
period.  Allow the probe to cool.
     When the probe can be safely handled, wipe off all external
particulate matter near the tip of the probe nozzle and place a cap
over it to prevent losing or gaining particulate matter.  Do not cap
off the probe tip tightly while the sampling train is cooling down
as this would create a vacuum in the filter holder, thus drawing water
from the impingers into the filter holder.
     Before moving the sample train to the cleanup site, remove the
probe  from the sample train, wipe off the silicone grease, and cap
the open outlet of the probe.  Be careful not to lose any condensate
that might be present.  Wipe off the silicone grease from the filter
inlet  where the probe was fastened and cap it.  Remove the umbilical
cord from the last impinger and cap the  impinger.  If a flexible line
is used  between the first impinger or condenser and the filter holder,
disconnect the line at the filter holder and let any condensed water
or liquid drain into the  impingers or condenser.  After wiping off the
silicone grease,  cap off  the filter holder outlet and  impinger inlet.
Either ground-glass stoppers,  plastic caps,  or  serum caps may  be used
to close these openings.
     Transfer the probe  and  filter-impinger  assembly to the  cleanup
area.   This  area  should  be clean  and  protected  from  the wind so  that
the  chances  of contaminating or  losing  the  sample will  be minimized.
                               195

-------
     Save a portion of the acetone used for cleanup as a blank.  Take
200 ml of this acetone directly from the wash bottle being used and
place it in a glass sample container labeled "acetone blank."
     Inspect the train prior to and during disassembly and note any
abnormal conditions.  Treat the samples as follows:
     Container No. 1.  Carefully remove the filter from the filter holder
and place it in its identified petri dish container.  Use a pair of
tweezers and/or clean disposable surgical gloves to handle the filter.
If it is necessary to fold the filter, do so such that the particulate
cake is  inside the fold.  Carefully transfer to the petri dish any
particulate matter and/or filter fibers which adhere to the filter
holder  gasket, by using a dry Nylon bristle brush and/or a sharp-edged
blade.   Seal the container.
      Container No. 2.  Taking care  to  see that dust on the outside
of the  probe or other exterior surfaces does not get into the  sample,
quantitatively recover particulate  matter ,or any condensate from the
probe  nozzle, probe  fitting, probe  liner, and front half of the
filter holder by washing  these components with acetone and placing
the  wash in  a glass  container.  Distilled water may be used instead
of acetone when approved  by  the Administrator and  shall  be used when
specified by the  Administrator; in  these  cases, save  a water  blank
and  follow the  Administrator's directions on analysis.   Perform  the
acetone rinses  as  follows:
                                  196

-------
     Carefully remove the probe nozzle and clean the inside surface
by rinsing with acetone from a wash bottle and brushing with a Nylon
bristle brush.  Brush until the acetone rinse shows no visible particles,
after which make a final rinse of the inside surface with acetone. .
     Brush and rinse the inside parts of the Swagelok fitting with
acetone in a similar way until no visible particles remain.
     Rinse the probe liner with acetone by tilting and rotating the
probe while squirting acetone into its upper end so that all inside
surfaces will be wetted with acetone.  Let the acetone drain from the
lower end into the sample  container.  A funnel (glass or polyethylene)
may be used to aid in transferring liquid washes to the container.   Follow
the acetone rinse with  a probe brush.  Hold the probe in an inclined
position, squirt acetone into the upper end as the probe brush is being
pushed with a twisting  action through the probe; hold a sample container
underneath the lower end of  the probe, and catch any acetone  and particu-
late matter which  is brushed from the probe.  Run  the brush through the
probe  three times  or more  until no visible particulate matter is carried
out  with  the  acetone or until  none remains  in the  probe  liner on visual
inspection.   With  stainless  steel  or other metal  probes,  run  the brush
through  in  the  above prescribed manner  at least  six times since metal
probes have  small  crevices in which  particulate  matter can be entrapped.
Rinse  the brush  with acetone, and  quantitatively collect these washings
in the sample container.   After the  brushing, make a final acetone rinse
of the probe  as  described  above.
                                  197

-------
     It is recommended that two people be used to clean the probe
to minimize sample losses.  Between sampling runs, keep brushes clean
and protected from contamination.
     After ensuring that all joints have been wiped clean of silicone
grease, clean the inside of the front half of the filter holder by
rubbing the surfaces with a Nylon bristle brush and rinsing with
acetone.  Rinse each surface three times or more if needed to remove
visible particulate.  Make a final rinse of the brush and filter
holder.   Carefully rinse out the glass cyclone, also (if applicable).
After  all acetone washings and particulate matter have been collected
in  the sample container, tighten the  lid on the sample container so
that acetone will not leak out when it is shipped to the laboratory.
Mark the  height of the  fluid level to determine whether or not
leakage occurred  during transport.  Label the container to clearly
 identify  its  contents.
     Container  No.  3.   Note  the  color of the  indicating silica gel
 to determine  if it  has  been  completely spent  and make a notation of
 its condition.  Transfer the silica gel from  the fourth impinger to
 its original  container  and  seal.   A funnel  may make  it easier  to pour
 the silica  gel  without  spilling.   A rubber  policeman may be  used as
 an aid in removing  the  silica  gel  from  the  impinger.   It is  not
 necessary to remove the small  amount  of dust  particles that  may  adhere
 to the impinger wall  and are difficult  to remove.   Since the gain  in
 weight is to be used for moisture calculations,  do not use any water
                                  198

-------
or other liquids to transfer the silica gel.  If a balance is
available in the field, follow the procedure for container No.  3
in Section 4.3.
     Impinger Water.  Treat the impingers as follows:  Make a
notation of any color or film in the liquid catch.  Measure the
liquid which is in the first three impingers to within +1  ml by
using a graduated cylinder or by weighing it to within +0.5 g by
using a balance (if one is available).  Record the volume  or weight
of liquid present.  This information is required to calculate the
moisture content of the effluent gas.
     Discard the liquid after measuring and recording the  volume or
weight, unless  analysis of the tmpinger catch is required (see Note,
Section 2.1.7).
     If a different type of condenser  is used, measure the amount of
moisture condensed either volumetrically or gravimetrically.
     Whenever  possible, containers should be shipped in such a way that
they remain  upright at all times.
     4.3  Analysis.   Record the data  required on  a sheet  such as the
one  shown in Figure 5-3.  Handle  each  sample container as follows:
     .Container No.  1.  Leave  the  contents  in the  shipping container
or  transfer  the filter and  any  loose  particulate  from  the sample
container to a tared  glass weighing  dish.   Desiccate for  24 hours
in  a desiccator containing  anhydrous  calcium  sulfate.  Weigh to a
constant  weight and  report  the  results to  the  nearest 0.1  mg.   For
purposes  of this  Section,  4.3,  'the term "constant weight" means
                               199

-------
Plant__	
Date	
Run No	
Filter No.	
Amount liquid lost during transport
Acetone blank volume, ml.	
Acetone wash volume, ml	
Acetone blank concentration, mg/mg (equation 5-4).
Acetone wash blank, mg (equation 5-5)	
CONTAINER
NUMBER
1
2
TOTAL
WEIGHT OF PARTICULATE COLLECTED.
mg
FINAL WEIGHT


^xC^
TARE WEIGHT


^x^7
Less acetone blank
Weight of paniculate matter
WEIGHT GAIN






FINAL
INITIAL
LIQUID COLLECTED
TOTAL VOLUME COLLECTED
VOLUME OF LIQUID
WATER COLLECTED
IMPINGER
VOLUME,
ml




SILICA GEL
WEIGHT.
9



9* ml
      •CONVERT WEIGHT OF WATER TO VOLUME BY DIVIDING TOTAL WEIGHT
       INCREASE BY DENSITY OF WATER (Ig/ml).
                                   INCREASE, g
                                      1 g/ml
= VOLUME WATER, ml
                         Figure 5-3.  Analytical data.
                                   200

-------
a difference of no more than 0.5 mg or 1 percent of total weight
less tare weight, whichever is greater, between two consecutive
weighings, with no less than 6 hours of desiccation time between
weighings.
     Alternatively, the sample may be oven dried at 105°C (220°F) for
2 to 3 hours, cooled in the desiccator, and weighed to a constant
weight, unless otherwise specified by the Administrator.  The tester
may also opt to oven dry the sample at 105°C (220°F) for 2 to 3 hours,
weigh the sample, and use this weight as a final weight.
     Container No. 2.  Note the level of liquid in the container and
confirm on the analysis sheet whether or not leakage occurred during
transport.   If a noticeable amount of leakage has occurred, either void
the sample or use methods, subject to the approval of the Administrator,
to correct the final results.  Measure the liquid in this container
either volumetrically to +1 ml or gravimetrically to +0.5 g.  Transfer
the contents to a tared 250-ml beaker and evaporate to dryness at ambient
temperature  and pressure.  Desiccate for 24'hours and weigh to a
constant weight.  Report the results to the nearest 0.1 mg.
     Container No. 3.  Weigh the spent silica gel (or silica gel plus
impinger) to the nearest 0.5 g using a balance.  This step may be con-
ducted in the field.
     "Acetone Blank" Container.  Measure acetone  in this  container
either volumetrically or gravimetrically.  Transfer the  acetone  to
a  tared  250-ml beaker and  evaporate  to dryness  at ambient temperature
and pressure.  Desiccate for  24  hours  and  weigh to  a  constant  weight.
Report the  results to the  nearest  0.1  mg.
                                   201

-------
     Note:  At the option of the tester, the contents of Container



No. 2 as well as the acetone blank container may be evaporated at



temperatures higher than ambient.  If evaporation is done at an



elevated temperature, the temperature must be below the boiling point



of the solvent; also, to prevent "bumping," the evaporation process



must be closely supervised, and the contents of the beaker must be



swirled occasionally to maintain an even temperature.  Use extreme



care, as acetone is highly flammable and has a low flash point.



5.  Calibration



     Maintain a laboratory log of all calibrations.



     5.1  Probe Nozzle.  Probe nozzles shall be calibrated before



their initial use in the field.  Using a micrometer, measure the



inside diameter of the nozzle to the nearest 0.025 mm (0.001 in.).



Make three  separate measurements using different diameters each time,



and obtain  the average of the measurements.  The difference between



the high  and low numbers shall not exceed 0.1 mm (0.004 in.).  When



nozzles become nicked, dented, or corroded,'they shall be reshaped,



sharpened,  and recalibrated before use.  Each nozzle shall be per-



manently  and uniquely identified.



     5.2  Pitot Tube.  The Type S pitot tube assembly shall be calibrated



according to the procedure outlined  in Section 4 of Method 2.



     5.3  Metering System.  Before its initial use in the field, the



metering  system shall be calibrated  according to the procedure outlined



in APTD-0576.   Instead of physically adjusting the dry gas meter dial



readings  to correspond to the wet test meter readings, calibration



factors r.ay be  used  to mathematically correct the gas meter dial readings



to the  proper  values. Before calibrating the-metering system,  it is sug-



gested  that a  leak-check HP conducted.  For  metering  systems having  diaphragm




                                  202

-------
 pumps,  the normal  leak-check  procedure  will  not  detect  leakages within
 the pump.   For these cases the following  leak-check  procedure is
 suggested: -make a  10-minute calibration run  at 0.00057  m3/min (0.02 cfm);
•at the  end of the  run,  take the difference of the measured wet test meter
 and dry gas  meter  volumes; divide  the difference by  10, to get the leak
 rate.   The leak rate should not exceed  0.00057 m3/min (0.02 cfm).
      After each field use, the calibration of the metering system
 shall  be checked by performing three calibration runs at a single,
 intermediate orifice setting  (based on  the previous  field test), with
 the vacuum set at  the maximum value reached  during the  test series.
 To adjust the vacuum, insert  a valve between the wet test meter and
 the inlet of the metering system.   Calculate the average value of the
 calibration factor.  If the calibration has  changed  by  more than 5 per-
 cent, recalibrate  the meter over the full  range  of orifice settings, as
 outlined in APTD-0576.
      Alternative procedures,  e.g., using  the orifice meter coeffi-
 cients, Tiay be used, subject to the approval of  the  Administrator.
      Note:  If the dry gas meter coefficient values  obtained  before
 and after a test series differ by more  than  5 percent,  the test
 series shall either be voided, or calculations  for  the  test series
 shall be performed using whichever meter  coefficient value  (i.e.,
 before or after) gives the lower value  of total  sample  volume.
      5.4  Probe Heater Calibration.  The  probe  heating  system shall  be
 calibrated before its initial use in the  field  according to  the  pro-
 cedure outlined in APTD-0576.  Probes constructed according  to APTD-0581
 need not be calibrated if the calibration curves in APTD-0576 are  used.
      5.5  Temperature Gauges.  Use the procedure in Section 4.3  of
 Method 2  to calibrate in-stack temperature  gauges.   Dial thermometers,
                              203

-------
such as are used for the dry gas meter and condenser outlet, shall be



calibrated against mercury-in-glass thermometers.



     5.6  Leak Check of Metering System Shown in Figure 5-1.  That



portion of the sampling train from the pump to the orifice meter



should be leak checked prior to initial use and after each shipment.



Leakage after the pump will result in less volume  being recorded than



is actually sampled.  The following procedure is suggested (see



Figure 5-4):  Close the main valve on the meter box.  Insert a one-



hole rubber stopper with rubber tubing attached into the orifice



exhaust pipe.  Disconnect and vent the low side of the orifice manometer.



Close  off the low side orifice tap.  Pressurize the system to 13 to



18 cm  (5 to 7 in.) water column by blowing into the rubber tubing.



Pinch  off the tubing and observe the manometer for one minute.  A loss



of pressure on the manometer indicates a leak in the meter box; leaks,



if present, must be corrected.



     5.7  Barometer.  Calibrate against a mercury barometer.



6.  Calculations



     Carry  out calculations, retaining at least one extra decimal



figure beyond that  of the  acquired data.  Round off figures after



the final  calculation.   Other  forms of the equations may be used as



long  as  they  give equivalent results.



      6.1   Nomenclature.


                                                2    2
      A      = Cross-sectional  area of  nozzle, m  (ft  ).



      B      = Water vapor  in  the  gas  stream,  proportion by  volume.
       ws


      C      = Acetone  blank residue  concentration,  mg/g.
       a


      c      = Concentration of particulate matter  in  stack  gas,  dry



              basis,  corrected to standard conditions,  g/dscm (g/dscf).



      I      = Percent  of isokinetic  sampling.



                                  204

-------
ro
o
                    RUBBER
                    TUBING
                               RUBBER
                               STOPPER
ORIFICE
                                                                             VACUUM
                                                                              GAUGE
        BLOW INTO TUBING
        UNTIL MANOMETER
       READS 5 TO 7 INCHES
         WATER COLUMN
                            ORIFICE
                          MANOMETER
                                        MAIN VALVE
                                          CLOSED

                                     AIR-TIGHT
                                       PUMP
                                         Figure 5-4.  Leak check of meter box.

-------
L      = Maximum acceptable leakage rate for either a pretest
 a
         leak check or for a leak check following a component
         change; equal to 0.00057 m /min (0.02 cfm) or 4 percent
         of the average sampling rate, whichever is less.
L.     = Individual leakage rate observed during the leak check
         conducted prior to the "i  " component change (i  = 1,
         2, 3. . . .n), m /min .Jcfm).
                  y
L      = Leakage rate observed during the post-test leak check,
         m' /min (cfm).
m      = Total  amount of particulate matter collected, mg.
M      = Molecular weight of water, 18.0 g/g-mole (18.0 Ib/lb-mole).
 w
m      = Mass of residue of acetone after evaporation, mg.
 a
P,     = Barometric pressure at the sampling site, mm Hg (in. Hg).
 oar
P      = Absolute  stack gas pressure, mm Hg (in. Hg).
P  d   = Standard  absolute  pressure, 760 mm Hg  (29.92 in. Hg).
R      = Ideal  gas constant, 0.06236 mm Hg-m3/°K-g-mole (21.85 in.
         Hg-ft3/°R-lb-mole).
T       = Absolute  average  dry  gas  meter temperature  (see  Figure 5-2),
          °
           K
 T       =  Absolute  average  stack  gas  temperature  (see Figure 5-2),
          °
           K
 T      =  Standard  absolute  temperature,  293°K  (528°R).
 V      =  Volume of acetone  blank,  ml.
  a
 V      =  Volume of acetone  used  in wash, ml.
                              206

-------
V-j     = Total volume of liquid collected in impingers and
         silica gel (see Figure 5-3), ml.
Vm     = Vo^ume °f 9as sample as measured by dry gas meter,
         dcm (dcf).
Vm(std)= Vo''ume °^ 9as sample measured by the dry gas meter,
         corrected to standard conditions, dscm (dscf).
V /   ,v= Volume of water vapor in the gas sample, corrected to
         standard conditions, scm (scf).
v      = Stack gas velocity, calculated by Method 2, Equation 2-9,
         using data obtained from Method 5, m/sec (ft/sec).
W      = Weight of residue in acetone wash, mg.
 a
Y      = Dry gas meter calibration factor.
AH     = Average pressure differential across the orifice meter
         (see Figure 5-2), mm HgO (in. H20).
p      = Density of acetone, mg/ml (see label on bottle).
 3
p      = Density of water, 0.9982 g/ml  (0.002201 lb/ml.).
 W
e      = Total sampling time, min.
e,     = Sampling  time interval, from the beginning of a run until
         the first component change, min.
6.     = Sampling  time interval, between  two successive  component
         changes,  beginning with the  interval  between  the  first
         and second  changes, min.
e      = Sampling  time interval, from the final  (n   )  component
         change  until the end  of the  sampling  run,  min.
                             207

-------
     13.6  = Specific gravity of mercury.
     60    = Sec/min.
     100   = Conversion to percent.
     6.2-  Average dry gas meter temperature and average orifice
pressure drop.  See data sheet (Figure 5-2).
     6.3  Dry Gas Volume.  Correct the sample volume measured by the
dry gas meter to standard conditions (20°C, 760 mm Hg or 68°F,
29.92 in. Hg) by using Equation 5-1.
    v       _ u Y I  std
    Vm(std) - VmYlT

                               std
*  K,V Y
                (AH/13.6)
                                                      Equation 5-1
where:
     KI = 0.3858 °K/mm Hg for metric units
        = 17.64 °R/in. Hg for English units
     Note:  Equation 5-1 can be used as written unless the leakage
rate observed during any of the mandatory leak checks O.e., the
post-test leak check or leak checks conducted prior to component
changes) exceeds L  .  If L_ or L. exceeds L , Equation 5-1 must be
                  a       p     i          a
modified as follows:
     (a)  Case I.   No component changes made during sampling run.  In
this case, replace  V  in Equation 5-1 with the expression:
                    m
          [V  - (L  - L ) 6]
            m     p    a
                                   208

-------
     (b)  Case II.  One or more component changes made during the


sampling run.  In this case, replace Vm in Equation 5-1 by the


expression:
     V* -  «1 -   2 (1-1 - L.) 6, - Up - L.) 6p]




and substitute only for those leakage rates (L^ or L ) which exceed
     6.4  Volume of water vapor.
                                                     Equation 5-2
      n ^ .I w w y    * ** V ' 'ui  / \ r ^ ^ /4 /     fc  ' **
                   \   / \ Stu /



where:



     K2 = 0.001333 m /ml for metric units



        = 0.04707 ft3/ml for English units.



     6.5  Moisture Content.
     Bwc  =  rj	'	          .             Equation 5-3

      ws     V       + Vw(std)
     Mote:  In saturated or water droplet-laden gas streams, two



calculations of the moisture content of the stack gas shall be made,



one from the impinger analysis '(Equation 5-3), and a second from the



assumption of saturated conditions.  The lower of the two values of



B   shall be considered correct.  The procedure for determining the
 W 5


moisture content based upon assumption of saturated conditions is



given in the Note of Section 1.2 of Method 4.  For the purposes of this



method,  the average stack gas temperature from Figure 5-2 may be used  to



make this determination, provided that the accuracy of the  in-stack


temperature sensor is +_ l°c (2°F).





                               209

-------
     6.6  Acetone Blank Concentration.
                 ma
     Ca     '  Va"a
     6.7  Acetone Wash Blank.
Wa  =  Ca Vaw pa
                                                    Equation 5-4
                                                         Equation  5-5
     6.8  Total Particulate Weight.   Determine the total  particulate
catch from the sum of the weights obtained from containers  1  and  2
less the acetone blank (see Figure 5-3).   Note:   Rfrfer to Section
4.1.5 to assist in calculation of results involving two or  more
filter assemblies or two or more sampling trains.
     6.9  Particulate Concentration.
c£  =  (0.001 g/mg)
6.10 Conversion Factors:
From
scf
g/ft3
g/ft3
J_£
m3
gr/ft
lb/ft
   3
     g/ft                    g/m
     6.11  Isokinetic Variation.
     6.11.1  Calculation From Raw Data.
                   lc
                            (V
                              m
                           60 9 v  P  A
                                 s  s  n
                                                         Equation 5-6
                                                Multiply by
                                                 0.02832
                                                15.43
                                                 2.205 x 10
                                                35.31
                                                                ~3
                                                         Equation 5-7
                                    210

-------
where:
     K. = 0.003454 mm Hg-m3/m1-°K for metric units
        = 0.002669 in. Hg-ft3/ml-°R for English units.
     6.11.2  Calculation From Intermediate Values.
                 Ts Vstd) Pstd 10°
                       'S
           Tstd
           <   Ps v           ws
where:
      K4  =  4.320  for  metric  units
         =  0.09450  for English  units.
      6.12  Acceptable Results.   If 90  percent  <_ I  <_ 110 percent, the
 results  are  acceptable.   If the  results  are  low in comparison to the
 standard  and I  is beyond the  acceptable range, or, if  I  is  less than
 90 percent,  the  Administrator  may opt  to accept the results.  Use
 Citation 4 to make judgments.   Otherwise, reject the results and repeat
 the test.
 7.  Bibliography
      1.   Addendum to Specifications for Incinerator Testing at  Federal
 Facilities.    PHS, NCAPC.  Dec. 6, 1967.
      2.   Martin, Robert M.  Construction Details of Isokinetic  Source-
 Sampling Equipment.  Environmental Protection Agency.  Research
 Triangle Park, N. C.  APTD-0581.  April, 1971.
      3.  Rom, Jerome J.  Maintenance, Calibration,  and Operation
 of  Isokinetic Source Sampling Equipment.  Environmental  Protection
 Agency.   Research Triangle  Park,  N. C.   APTD-0576.   March,  1972.
                                211

-------
     4.   Smith, W. S., R. T. Shigehara, and W. F. Todd.  A Method
of Interpreting Stack Sampling Data.  Paper Presented at the
63d Annual Meeting of the Air Pollution Control Association,
St. -Louis, Mo.  June 14-19, 1970.
     5.   Smith, W. S., et al.  Stack Gas Sampling Improved and
Simplified With New Equipment.  APCA Paper No. 67-1-19.  1967.
     6.   Specifications for Incinerator Testing at Federal Facilities.
PHS, NCAPC.   1967.
     7.   Shigehara, R.T.  Adjustments in the EPA Nomograph for
Different  Pitot Tube Coefficients and Dry Molecular Weights.  Stack
Sampling News  2_:4-ll.  October, 1974.
     8.  Vollaro, R. F.  A  Survey of Commercially Available  Instrumentation
For  the Measurement of Low-Range Gas Velocities.  U. S. Environmental
Protection Agency, Emission Measurement Branch.  Research Triangle
Park, N.  C.   November, 1976  (unpublished paper).
     9.   Annual Book of ASTM  Standards.  Part  26.  Gaseous Fuels;
Coal and  Coke; Atmospheric  Analysis.  American Society  for Testing
and  Materials.  Philadelphia,  Pa.   1974.  pp.  617-622.
                                  212

-------
                                   TECHNICAL REPORT DATA
                            (Please read Instructions on the reverse before completing)
1. REPORT NO.
                              2.
                                                            3. RECIPIENT'S ACCESSION-NO.
4. TITLE AND SUBTITLE
                                                            5. REPORT DATE
 Analysis of State and  Federal  Participate and  Visible
 Emission Regulations for Combustion Sources
                  January 1982
             6. PERFORMING ORGANIZATION CODE
7. AUTHOR(S)
 David Dunbar, B.E. Blagun,  and Donald J. Henz
             8. PERFORMING ORGANIZATION REPORT NO.

                  PN  3525-12
9. PERFORMING ORG \NIZATION NAME AND ADDRESS
  PEDCo Environmental,  Inc.
  11499 Chester Road
  Cincinnati, Ohio  45246
                                                            10. PROGRAM ELEMENT NO.
             11. CONTRACT/GRANT NO.
                  68-02-3512
                  Work Assignment No.  12
 12. SPONSORING AGENCY NAME AND ADDRESS
  U.S.  Environmental  Protection Agency
  Office of Air Quality  Planning & Standards
  Research Triangle Park,  North Carolina  27711
             13. TYPE OF REPORT AND PERIOD COVERED
                  Final
             14. SPONSORING AGENCY CODE
 15. SUPPLEMENTARY NOTES
  U.S.  EPA Project Office  -  Kenneth R. Woodard
 16. ABSTRACT
  This  document provides  a  compilation of the  particulate and visible  emission
  limits from the State  Implementation Plans  (SIP's)  and Federal Standards  of
  Performance for New Stationary Sources that  are applicable to fuel combustion
  sources.   A comparison  of mass emission rates  along with a summary of  the
  mass  and visible emission regulations by state or territory is presented.
  This  document also provides our overview of  the emissions from boilers and
  the control techniques  typically being used  to meet the current SIP  require-
  ments.
17.
                                KEY WORDS AND DOCUMENT ANALYSIS
                  DESCRIPTORS
                                              b. IDENTIFIERS/OPEN ENDED TERMS
                             COSATI Field/Group
  Air Pollution
  Combustion
  Opacity
  Particles
State  Implementation Plan
New Source  Performance
Standards
Emission Regulations
Visible Emissions
Particulate Emissions
13B
21B
14G
18. DISTRIBUTION STATEMENT

  Unlimited
19. SECURITY CLASS (This Report)
Unclassified
                           21. NO. OF PAGES
212
                                              20. SECURITY CLASS (Thispage)
                                              Unclassified
                                                                          22. PRICE
EPA Form 2220-1 (9-73)

-------