-------
Subpari BB—Standards of Performance for
Kraft Pulp Mills
60.280 Applicability and designation of af-
fected facility.
(a) The provisions of this subpart
are applicable to the following affect-
ed facilities in kraft pulp mills: digest-
er system, brown stock washer system,
multiple-effect evaporator system,
black liquor oxidation system, recov-
ery furnace, smelt dissolving tank,
lime kiln, and condensate stripper
system. In pulp mills where kraft
pulping is combined with neutral sul-
fite semichemical pulping, the provi-
sions of this subpart are applicable
when any portion of the material
charged to an affected facility is pro-
duced by the kraft pulping operation.
(b) Any facility under paragraph (a)
of this section that commences con-
struction or modification after Sep-
tember 24, 1976, is subject to the re-
quirements of this subpart.
§ 60.281 Definitions.
As used in this subpart, all terms not
defined herein shall have the same
meaning given them in the Act and in
Subpart A.
(a) "Kraft pulp mill" means any sta-
tionary source which produces pulp
from wood by cooking (digesting)
wood chips in a water solution of
sodium hydroxide and sodium sulfide
(white liquor) at high temperature
and pressure. Regeneration of the
cooking chemicals through a recovery
process is also considered part of the
kraft pulp mill.
(b) "Neutral sulfite semichemical
pulping operation" means any oper-
ation in which pulp is produced from
wood by cooking (digesting) wood
chips in a solution of sodium sulfite
and sodium bicarbonate, followed by
mechanical defibrating (grinding).
(c) "Total reduced sulfur (TRS)"
means the sum of the sulfur com-
pounds hydrogen sulfide, methyl mer-
captan, dimethyl sulfide, and dimethyl
disulfide, that are released during the
kraft pulping operation and measured
by Reference Method 16.
(d) "Digester system" means each
continuous digester or each batch di-
gester used for the cooking of wood in
white liquor, and associated flash
tank(s), below tank(s), chip steamer(s),
and condenser(s).
(e) "Brown stock washer system"
means brown stock washers and associ-
ated knoi.ers, vacuum pumps, and fil-
trate tanks used to wash the pulp fol-
lowing the digester system.
(f) "Multiple-effect evaporator
system" means the multiple-effect
evaporators and associated
condenser(s) and hotwell(s) used to
concentrate the spent cooking liquid
that is separated from the pulp (black
liquor).
(g) "Black liquor oxidation system"
means the vessels used to oxidize, with
air or oxygen, the black liquor, and as-
sociated storage tank(s).
(h) "Recovery furnace" means either
a straight kraft recovery furnace or a
cross recovery furnace, and includes
the direct-contact evaporator for a
direct-contact furnace.
(i) "Straight kraft recovery furnace"
means a furnace used to recover
chemicals consisting primarily of
sodium and sulfur compounds by
burning black liquor which on a quar-
terly basis contains 7 weight percent
or less of the total pulp solids from
the neutral sulfite semichemical pro-
cess or has green liquor sulfidity of 28
percent or less.
(j) "Cross recovery furnace" means a
furnace used to recover chemicals con-
sisting primarily of sodium and sulfur
compounds by burning black liquor
which on a quarterly basis contains
more than 7 weight percent of the
total pulp solids from the neutral sul-
fite semichemical process and has a
green liquor sulfidity of more than 28
percent.
(k) "Black liquor solids" means the
dry weight of the solids which enter
the recovery furnace in the black
liquor.
(1) "Green liquor sulfidity" means
the sulfidity of the liquor which leaves
the smelt dissolving tank.
(m) "Smelt dissolving tank" means a
vessel used for dissolving the smelt
collected from the recovery furnace.
(n) "Lime kiln" means a unit used to
calcine lime mud, which consists pri-
marily of calcium carbonate, into
quicklime, which is calcium oxide.
(o) "Condensate stripper system"
means a column, and associated con-
densers, used to strip, with air or
steam, TRS compounds from conden-
sate streams from various processes
within a kraft pulp mill.
§ 60.282 Standard for\f articulate matter.
(a) On and after wie date on which
the performance test required to be
conducted by §80.8 is completed, no
owner or operator subject to the provj.-
sions of this subpart shall cause to be
discharged into the atmosphere: —
(1) From any recovery furnace any
gases which:
(i) Contain particulate matter in
excess of 0.10 g/dscm (0.044 gr/dscf)
corrected to 8 percent oxygen.
(ii) Exhibit 35 percent opacity or
greater.
(2) Prom any smelt dissolving tank
any gases which contain particulate
11-28
matter in excess of 0.1 g/kg black
liquor solids (dry wetght)[0.2 Ib/ton
black liquor solids (dry weight)].
(3) From any lime kiln any gases
which contain particulate matter in
excess of:
(i) 0.15 g/dscm (0.067 gr/dscf) cor-
rected to 10 percent oxygen, when gas-
eous fossil fuel is burned.
(ii) 0.30 g/dscm (0.13 gr/dscf) cor-
rected to 10 percent oxygen, when
liquid fossil fuel is burned.
§60.283 Standard for total reduced sulfur
(TRS).
(a) On and after the date on which
the performance test required to be
conducted by §60.8 is completed, no
owner or operator subject to the provi-
sions of this subpart shall cause to be
discharged into the atmosphere:
(1) From any digester system, brown
stock washer system, multiple-effect
evaporator system, black liquor oxida-
tion system, or condensate stripper
system any gases which contain TRS
in excess 6*f 5 ppm by volume on a dry
basis, corrected to 10 percent oxygen,
unless the following conditions are
met:
(i) The gases are combusted in a lime
kiln subject to the provisions of para-
graph (a)(5) of this section; or
(ii) The gases are combusted in a re-
covery furnace subject to the provi-
sions of paragraphs (a)(2) or (a)(3) of
this section; or
(iii) The gases are combusted with
other waste gases in an incinerator or
other device, or combusted in a lime
kiln or recovery furnace not subject to
the provisions of this subpart, and are
subjected to a minimum temperature
of 1200° F. for at least 0.5 second; or
(iv) It has been demonstrated to the
Administrator's satisfaction by the
owner or operator that incinerating
the exhaust gases from a new, modi-
fied, or reconstructed black liquor oxi-
dation system or brown stock washer
system in an existing facility is tech-
nologically or economically not feasi-
ble. Any exempt system will become
subject to the provisions of this sub-
part if the facility is changed so that
the gases can be incinerated.
(2) From any straight kraft recovery
furnace any gases which contain TRS
in excess of 5 ppm by volume on a dry
basis, corrected to 8 percent oxygen.
(3) From any cross recovery furnace
any gases which contain TRS in excess
of 25 ppm by volume on a dry basis,
corrected to 8 percent oxygen.
(4) From any smelt dissolving tank
any gases which contain TRS in excess
of 0.0084 g/kg black liquor solids (dry
weight) [0.0168 Ib/ton liquor solids
(dry weight)].
(5) From any lime kiln any gases
which contain TRS in excess of 8 ppm
by volume on a dry basis, corrected to
10 percent oxygen.
-------
§ 60,284 MoaJtarrag of emissions and op-
erations.
sa) Any owner or operator subject tc
J be provisions- of this subparf. shall in-
stall, calibrate, maintain, and operate
Use loilov.iufj c-oiiiiiiuous moiiltoruig
si-items:
>:ii A continuous inor.itoring system
tc, inoniior and record the opacity c*
the gases discharfctd unto the atn^os.
phere fiom any recoveiy furnace. Ths
span ol tnis system shall be set at 7C
percent opacity.
(2) Continuous mouitoring systems
tc monitor and record the concentra-
tion of TRS emissions on a dry basis
and the percent of oxygen by volume
on a dry basis in ths gases discharged
into the atmosphere from any iirae
xiln, recovery furnace, digester
system, biown stock washer system,
multiple-effect evaporator system,
black liquor oxidation system, or con-
densate stripper system, except where
the provisions of §60.283(a)(l) (iii) or
(iv) apply. These systems shall be lo-
cated downstream of the control
device(s) and the spams) of these con-
tinuous monitoring system(s> shall be
set:
(i) At a TRS concentration of 30
pprn for the TRS continuous monitor-
ing system, except that for any cross
recovery furnace the span shall be set
at 50 ppm.
(ii) At 20 percent oxygen for the
continuous oxygen monitoring system.
fb) Any owner or operator subject to
the provisions of this subpart shall in-
stall, calibrate, maintain, and operate
the following continuous monitoring
devices:
(DA monitoring device which mea-
sures the combustion temperature at
the point of incineration of effluent
gases which are emitted from any di-
gester system, brown stock washer
system, multiple-effect evaporator
system, black liquor oxidation system,
or condensate stripper system where
the provisions of § 60.283(aXl)(iii)
apply. The monitoring device is to be
certified by the manufacturer to be ac-
curate within ±1 percent of the tem-
perature being measured.
(2) For any lime kiln or smelt dis-
solving tank using a scrubber emission
control device:
(i) A monitoring device for the con-
tinuous measurement of the pressure
loss of the gas stream through the
control equipment. The monitoring
device is to be certified by the manu-
facturer to be accurate to within a
gage pressure of ±500 pascals (ca. ±2
inches water gage pressure).
(ii) A monitoring device for the con-
tinuous measurement of the scrubbing
liquid supply pressure to the control
equipment. The monitoring device is
to be certified by the manufacturer to
be accurate within a: 15 percent of
design scrubbing liquid supply pres-
sure. The pressure sensor or tap is to
be located close to the scrubber liquid
discharge point. The Administrator
may be consulted for approval of s.lt^i-
native ideations,
'r; j'.jiy our,i; 01 opei at">r nJ>] •.'. to
111;- L-'i '-• • i'.K'i's of ihu. s/ui3;'j.;ri .ha3i,
CXCl'i'V '. ilri'C Ult t ,'i)l IV'Jl'.J, of
> 6''.2Ji 1'a.it.IXiv; oi g (i'.|.783iai<4)
apply.
si) C3lcu!;5i.f- histi iciord z-i. ;: dnilv
ba*ij J 2-liCjii! averagf THS r.":ic.-'-':a-
l.'j,!>- i<;i the iv.(; cuiiit.fuU\M pf-'iiods
c.l each operating day. Kaci; 11 hour
avtsagft siial' be determined a* the
arithmetic mean of the appiopriate 12
contiguous 1-hour average total re-
duced sulfur concentrations provided
by each continuous monitoring system
installed under paragraph (aX2> of
this section.
<2) Calculate and record on a daily
basis 12-hour average oxygen concen-
trations for the two consecutive peri-
ods of each operating day for the re-
covery furnace and lime kiln. These
12-hour averages shall comsoond to
i he 12-hour average TRS concentra-
tions under paragraph (cXl) of this
fef-ction and shall be determined as an
ariiruj.etic mean of the appropriate 12
contiguous 1-hour average oxygen con-
centrations provided by each continu-
ous monitoring sjstem installed under
paragraph (a)(2) 03' this section.
(3) Correct all 12-hour average TRS
concentrations to 10 volume percent
oxygen, except that all 12-hour aver-
age TRS concentration from a recov-
ery furnace shall be corrected to 8
volume percent using the following
equation:
C,,,-C^x^l - X/21 - 10
where:
Com = the concentration corrected for
oxygen.
£.'„«„-the concentration uncorreeted for
oxygen.
A' = the volumetric oxygen concentration in
percentage to be corrected to (8 percent
for recovery furnaces and 10 percent for
lime kilns, incinerators, or Diner de-
vices).
y=the measured 12-hour average volumet-
ric oxygen concentration.
(d) For the purpose of reports re-
quired under §60.7(c), any owner or
operator subject to the provisions of
this subpart shall report periods of
excess emissions as follows:
(i) For emissions from any recovery
furnace periods of excess emissions
are:
(i) All 12-hour averages of TRS con-
centrations above 5 ppm by volume for
straight kraft recovery furnaces and
above 25 ppm by volume for cross re-
covery furnaces.
(ii) All 6-minute average opacities
that exceed 35 percent.
(2) For emissions from any lime kiln,
periods of excess emissions are all 12-
hour average TRS concentration
above 8 pprn by volume.
(3) For emissions from any digester
system, brown stock washer system,
11-
multiple-effect evaporator system,
black liquor oxici?tlon system, or con-
dentate stripper systom periods of
nK HL~i-vf 5 i;;>rn by -•<-.;,irpr iui!.%<;
Ch5 provi,-,..!,.; of § SG.283ia:(] > u/. ( ''-,
os tiv) pj/ply; or
(ii) All periods ii; excess of 5 rr.ini.'p.;
ana their duration J.uruie ^nic), i>~- -
combustion leiiipr.rature dt tlie pour
of incineraticn i.s less than !^3C' ^'.
where the provisio:.- c/'
§ 60.283(aXlXii) apply.
(e) The Administrator v-ill not rrn-
sider ceriods of excess emissions re-
ported und'-r paragraph id) of this sec-
tion to be indicative of a violation ci
§ 60.11Cd) provided that;
(1) The percent of the total number
of possible contiguous periods of
excess emissions in a quarter (exclud-
ing period? ol startup, shutdown, or
malfunction and perioas when r.he fr--
Ciliiy is rsot opernting) during vvhicb
excess crrsisMon.s occur doe? noi
exceed:
(i) One percent for TRS emissions
from recovery furnaces.
(ii"> Six percent for average opacities
from recovery furnaces.
<2) The Administrator cieterm^iii-S
that the affected facility, including air
pollution control equipment, i- main-
tained and operated in a manner
which is consistent with good air pol-
lution control practice for minimizing
emissions during periods of excess
emissions.
§ 60.285 Test methods and procedures.
(a) Reference methods in Appendix
A of this part, except as provided
under §60.8(b), shall be used to deter-
mine compliance with §60.282(a) as
follows:
(1) Method 5 for the concentration
of particulate matter and the associat-
ed moisture content,
(2) Method 1 for sample and velocity
traverses,
(3) When determining compliance
with § 60.282(a)(2), Method 2 for veloc-
ity and volumetric flow rate, s
(4) Method 3 for gas analysis, and
(5) Method 9 for visible emissions.
(b) For Method 5, the sampling time
for each run shall be at least 60 min-
utes and the sampling rate shall be at
least 0.85 dscm/hr (0.53 dscf/min)
except that shorter sampling times,
when necessitated by process variables
or other factors, may be approved by
the Administrator. Water shall be
used as the cleanup solvent instead of
acetone in the sample recovery proce-
dure outlined in Method 5.
(c) Method 17 (in-stack filtration)
may be used as an alternate method
for Method 5 for determining compli-
ance with §60.282(a)(l)(i): Provided,
That a constant value of 0.009 g/dscm
(0.004 gr/dscf) is added to the results
of Method 17 and the stack tempera-
-------
ture is no greater than 205° C (ca. 400°
F). Water shall be used as the cleanup
solvent instead of acetone in the
sample recovery procedure outlined in
Method 17.
(d) For the purpose of determining
compliance with §60.283(a) (1), (2),
(3), (4), and (5). the following refer-
ence methods shall be used:
(1) Method 16 for the concentration
of TRS,
(2) Method 3 for gas analysis, and
(3) When determining compliance
with §60.283(a)(4), use the results of
Method 2, Method 16. and the black
liquor solids feed rate in the following
equation to determine the TRS emis-
sion rate.
E — ( CmsFun + Cy,mFu,m + CjauFatis + C
9.2.2 Observation for Clogging of Probe.
If reductions in sample concentration* are
observed during a sample run that cannot
be explained by process conditions, the sam-
Where:
E = mass of TRS emitted per unity of black
liquor solids (g/kg) (Ib/ton)
Cms = average concentrator hydrogen
sulfide during the test period,
PPM.
CIMH = average concentration of methyl
mercaptan (MeSH) during the test
period, PPM.
Com = average concentration of dimethyl
sulfide (DMS) during the test period,
PPM.
CDMM = average concentration of dimethyl
disulfide (DMDS) during the test period,
PPM.
Fm = 0.001417 g/m' PPM for metric units
= 0.08844 lb/fts PPM for English units
fuaa = 0.00200 g/m1 PPM for metric units
= 0.1248 lb/ff PPM for English units
/no = 0.002583 g/m' PPM for metric units
= 0.1612 lb/ff PPM for English units
Fotaa = 0.003917 g/m1 PPM for metric units
= 0.2445 lb/ff PPM for English units
Q.I = dry volumetric stack gas flow rate cor-
rected to standard conditions, dscm/hr
(dscf/hr)
BLS = black liquor solids feed rate, kg/hr
(Ib/hr)
(4) When determining whether a
furnace is straight kraft recovery fur-
nace or a cross recovery furnace,
TAPPI Method T.624 shall be used to
determine sodium sulfide, sodium hy-
droxide and sodium carbonate. These
determinations shall be made three
times daily from the green liquor and
the daily average values shall be con-
verted to sodium oxide (Na2O) and
substituted into the following equa-
tion to determine the green liquor sul-
fidity: j
GLS = 100 CK.,]^.." + CK.OH + CN.xo,
Where: *
GLS = percent green liquor sulfidity
i = average concentration of No*
pressed as Na,O (mg/1)
CN.O// = average concentration of NaOH
expressed as Na,O (mg/1)
C«*CQ^= average concentration of Na,CO,
^expressed as Na,O (mg/1)
(e) All concentrations of particulate
matter and TRS required to be mea-
sured by this section from lime kilns
or incinerators shall be corrected 10
volume percent oxygen and those con-
centrations from recovery furnaces
e\-
11-30
-------
Subpart HH—Stcmdcrds of Perfor-
mance for Lime Manufacturing
Plants
Sec.
60.340 Applicability and designation of af-
fected facility.
60.341 Definitions. -
60.342 Standard for participate matter.
60.343 Monitoring of emissions and oper-
ations.
60.344 Test methods and procedures.
AUTHORITY: Sec. Ill and 301(a) of the
Clean Air Act. as amended (42 U.S.C. 7411.
7601), and additional authority as noted
below.
§ 60.340 Applicability anil designation of
affected facility.
(a) The provisions of this subpart
are applicable to the following affect-
ed facilities used in the manufacture
of lime: rotary lime kilns and lime hy-
drators.
(b) The provisions of this subpart
are not applicable to facilities used in
the manufacture of lime at kraft pulp
mills.
(c) Any facility under paragraph (a)
of this section that commences con-
struction or modification after May 3,
1977, is subject to the requirements of
this part.
§60.341 Definitions.
As used in this subpart, all terms not
defined herein shall have the same
meaning given them in the Act and in
subpart A of this part.
(a) "Lime manufacturing plant" in-
cludes any plant which produces a
lime product from limestone by calci-
nation. Hydration of the lime product
is also considered to be part of the
source.
(b) ''Lime product" means the prod-
uct of the calcination process includ-
ing, but not limited to. calcitic lime,
dolomitic lime, and dead-burned dolo-
mite.
(c) "Rotary lime kiln" means a unit
with an inclined rotating drum which
is used to produce a lime product from
limestone by calcination.
(d) "Lime hydrator" means a unit
used to produce hydrated lime prod-
uct.
§ 60.342 Standard for participate matter.
(a) On and after the date on which
the performance test required to be
conducted by §60.8 is completed, no
owner or operator subject to the provi-
sions of this subpart shall cause to be
discharged into the atmosphere:
(1) From any rotary lime kiln any
gases which:
(i) Contain participate matter in
excess of 0.15 kilogram per megagram
of limestone feed (0.30 Ib/ton).
(ii) Exhibit 10 percent opacity or
greater.
(2) From any lime hydrator any
gases which contain particulate matter
in excess of 0.075 kilogram per mega-
gram of lime feed (0.15 Ib/ton).
§60.343 Monitoring of emissions and op-
erations.
kiln and the mass rate of lime feed to
any affected lime hydrator. The mea-
suring device used must be accurate to
within ±5 percent of the mass rate
over its operating range.
(e) For the purpose of reports re-
quired under §60.7(c), periods of
excess emissions that shall be reported
are defined as all six-minute periods
during which the average opacity of
the plume from any lime kiln subject
to paragraph (a) of this subpart is 10
percent or greater.
(a) The owner or operator subject to
the provisions of this subpart shall in-
-------
MINIMUM NUMBER OF TRAVERSE POINTS
i
LJ
to
D
C
o
m
H
m
33
v>
C
•u
in
H
33
m
2
O
m
>
tO
C
CD
3
C
3
3
C
3
cr
0)
•n O
33 -*
I I
Tl CD
r- —i
o 8
5 TJ
D °.
v> ?
H £
C _K
33 O
CD ~<
J2 CD
n 5-
m* °'
2 I
W *~*
^ fO
O
TO
to
1 * P
^ !
fsififififisiiis^lf1
^«uwf Elii
jSjUl ^W«*» *^
^•' hi
.^-' Q-rtpBD^H^H
[EiiEUHIi
^B?i!:te
G'g«lfS-i5g-c.5'?"s1s ^fo^SS--??
§i!*iig!i5rHM I|^ol2i
-^ » ^SE 5 3 P =•£ * « -» oS»52.arS.=
-------
0.5
DUCT DIAMETERS UPSTREAM FROM FLOW DISTURBANCE (DISTANCE A)
1.0 1.5 2.0
2.5
50
t/J
O
ex.
LU
oo
40
> 30
O
cc
LU
20
z 10
T
^ /DISTURBANCE
MEASUREMENT
f--?-' SITE
DISTURBANCE
1
1
1
2 3 4 5 6789 10
DUCT DIAMETERS DOWNSTREAM FROM FLOW DISTURBANCE {DISTANCE R)
Figure 1-2. Minimum number of traverse points for velocity (nonparticulate) traverses.
222 Velocity (Non-ParticulaU) Traverses. When
velocity or volumetric flow rate is to be determined (but
not particular matter), the same procedure as that lor
partjculate traverses (Section 2.2.1) is followed, except
that Figure 1-2 may be used instead of Figure 1-1.
2.3 Cross-Sectional Layout and Location of.Travers*
2 3.1 Circular Blacks. Locate the traverse points on
two perpendicular diameters adcordlng U> Table 1-2 and
the example shown in Figure 1-3. Any equation (for
examples, see Citations2and Sin the Bibliography) that
Kivcs the same values as those in Table 1 2 ma> be used
in lieu of Table 1-2.
For porticulate traverse*, one of the diameters must l>e
in a plane containing the greatest eipected concentration
variation, e.g., after bends, one diameter shall be in the
plane of the bend. This requirement becomes less critical
as I IIP distance from the disturbance increases, therefore,
other diameter locationsmay be used, subject to approval
of the Administrator.
In addition, for stacks having diameters greater than
0.61 m (24 in.) no traverse poinu shall be located witlun
2.5 centimeters (1.00 in.) of the stack walls; and for stack
diameters equal to or less than 0.61 rn (24 in.), no traverse-
points shall be located wil hin 1.3 cm (0.50 in.) of the stack
walls. To meet these criteria', observe the procedures
given below.
2 3.1.1 (Stocks With Diameters Greater Than 0.01 m
(24 in.). When any of the traverse points as located In
Section 2.3.1 fall within 2.5 cm (1.00 in.) of the stack walls,
relocate them away from the stack walls to: (1) a distance
of 2.5 em (1.00 in.); or (2) a distance equal to the noztle
inside diameter, whichever is larger. These relocated
travers* points (on each end of a diameter) sliall be tbe
"adjusted" traverse points.
Whenever two successive traverse points are combined
to form a single adjusted traverse point, treat the ad-
justed point as two separate traverse points, both in the
sampling (or velocity nuafurement) procedure, and la
recording the data.
11-33
-------
TRAVERSE
POINT
1
2
3
4
6
6
DISTANCE.
S of diameter
4.4 .
14.7
29.5
70.5
85.3
95.6
(51 !n '''. V- !;.-.: K (:. ,>:,•,:'.' !i,l< I- "• Ml ' •' d'ict ti",J U) 1.,•!'"<• •..JIIIIR in th--.n
lii>',&!'<•<•.$. thf J^C^TK* or at--'M"-~ of -yilnnlr How at
tl*f sampler ir*-n'.!or) rn^'t be t1> u r i -a 'Hip (oli-jwlnij
tcchiLi(ju« i-e H. U'ptablo (or Ihii dft< rmiuatlon.
Figure 1-3. Example showing circular slack cross section divided into
12 equal areas, with location of traverse points indicated.
»•
Table 1-2. LOCATION OF TRAVERSE POINTS IN CIRCULAR STACKS
(Percent of stack diameter from inside wall to traverse point)
Traverse
point
number
on • •
diameter
1
2
3
4|
5'
6
7
8
Si
10
11
12J
1:1
i«
15
16
17
18
19
21);
21
22
23
24
• Number of traverse points on a diameter
2
14 fi
85.4
•
i
'
4
6 -7
25.0
75.0
33.3
6
4.4
14.6
29.6
70.4
85.4
95.6
•
8
3.2
10.5
19.4
32.3
67.7
80.6
89.5
96.8
*
.
y
10
2.6
8.2
14.6
22.6
34.2
65.8
77.4
85.4
91.8
97.4
12
2.1
6.7
11.8
17.7
25.0
35.6
64.4
75.0
82.3
88.2
93.3
97.9
14
1.8
5.7
9.9
14.6
20.1
26.9
36.6
63.4
73.1
79.9
85.4
90.1
94.3
98.2
16
1.6
4.9
8.5
12.5
16.9
22.0
28.3
37.5
62.5
71.7
78.0
83 .'1
87.5
91.5
95'. 1
98.4
18
1.4
4.4
7.5
10.9
14.6
18.8
23.6
29.6
38.2
61.8
70.4
76.4
81.2
85.4
89.1
92.5
95.6
98.6
20
1.3
3.9
•6.7
.9.7
12.9
16.5
20.4
25.0
30.6
38.8
61 .'2
69.4
75.0
79.6
83.5
87.1
90.3
93.3
96.1
98.7
22
1.1
3.5
6.0
8.7
11.6
14.6
18.0
21.8
26.2
31.5
39.3
60.7
68.5
73.8
78.2
82.0
85.4
88.4
91.3
94.0
96.5
98.9
24
1 1
3.2
5.5
7.9
10.5
13.2
16.1
19.4
23.0
27.2
32.3
39.8 '
60.2
67.7
72'. 8 '
77.0
80.6
83.9
86.8
89.5
92.1
94.5
96.8
98.9
2J.1 J Blacks With Diameters Equal to or Less Than
0.61 m CM in.). Follow the procedure In Section 2.3 1.1,
noting only that any "adjusted" points should b*
relocated away from the stack walls to: (1) a distance of
U cm (OJO ui.l; or (2) a distance equal to the DOti.!»
Inside diameter, whichever Is larger.
2JJ Rectangular Stocks Determine the number
of traverse point; as eiplained In Sections 2.1 and 2.2 of
tbis method. From Table 1-1, determine the grid con-
figuration. Divide the stark cross-section into as many
equal rectangular elemental areas as inverse points.
and then locate a traverse point at the centrold of each
equal area according to the example In Figure 1-4.
The situation of traverse points being too close to the
stack walls Is not expectea to arise with rectangular
•tacks. If this problem should ever arise, the Admuils-
trulor must be contacted for resolution of the matter.
2.4 Verification of Absence of Cyclonic Flow. In most
stationary sources, the direction of stack gas Bow Is
essentially parallel to the stack walls. However,
cyclonic now may exist (1) after such devices as cyclones
SJ3<3 inertia! demisters following venturi scrubbers. Of
•T"
I
I
I
Figure 1-4. Example showing rectangular slack cross
section divided into 1 2 equal areas, with a traverse
point at cenuoid of each area.
Level and trro the manometer. Connect » Type S
pilot tube to the manometer. Position the Type 8 pilot
tube at each traverse point, in succession, to that the
planes of the face openings of the pilot tube are perpendic-
ular to the slack cross-sectional plane, when the Type 8
pilot tube is in this position, it is at "0° reference." Now
the differential pressure (Ap) reading at each traverse
point. 11 a null (tero) pilot reading is obtained at 0*
reference at a pT«n traverse point, an acceptable now
condition eiists al that point. If the pilot reading li not
tero at 0' reference, rotate the pitol lube (up to ±90* yaw
angle), un til anullr«idingisobtnincd. Carefully determine
and record the value of the rotation angle (a) to the
nearest degree. After the null technique has been applied
at each travrse point, calculate Ihe average of the abso-
lute values of a. assign o values of 0° to those points for
which no rotation was required, and include ihese in the
overall average. If the average value of o is greater than
10°, the overall flow condition in the slack Is unacceptable
and allemative methodology, sulm*t to the approval of
the Administrator, must be used to perform accurate
cample and velocity traverses.
Z. BiblioffTapkj
1 Determining Dust Concentration In a Gas Stream.
ASME. Performance Test Code No. 27. New York.
1S57.
2. Devorkln, Howard, et al Air Pollution Source
Testing Manual. Air Pollution Control District. Los
Angeles, CA. November 1963
3. Methods lor Determination of Velocity, Volume,
Dust and Mist Coni«m of Oases. Western Precipitation
Division of Joy Manufacturing Co. Los Angeles, CA_
Bulletin WP-SO. 1968.
4 Standard Method for Sampling Stacks for Paniculate
Matter. In: 1971 Book of ASTM Standards Part 23.
ASTM Designation D-2828-71. Philadelphia, Pa. 1971.
S. Hanson, H. A., et al. Paniculate Sampling Strategies
for Large Power Plants Including Nonunlform Flow.
USEPA, ORD. ESRL, Research Triangle Park, N.C.
EPA-600/2-76-170. June 1976.
6. Entropy Environmentalists, Inc. Determination of
the Optimum Number of Sampling Points: An Analysis
of Method 1 Criteria. Environmental Protection Agency.
Research Triangle Park, N.C. EPA Contract No. 68-01-
8172, Task 7.
MXTHOD 2— DETERMINATION or STACT OAS VELOOTT
AND VOLUMETRIC FLOW RATE (TYPE S PITOT TUBE)
1. Prindplt and ApplicaWlttl
1.1 Principle- The average gas velocity In a stack Is
determined fjom the pas density and from measurement
of the average velocity head with a Type S (Stausscheibe
or reverse type) pitol tube.
1.2 Applicability. This method Is applicable for
measuremen! of the average velocity of a gas stream and
for quantifying gas Mow.
This procedure is nol applicable at measurement sites
which fail to meet the criteria of Method 1, Section 2.1.
Also, the method cannot be used for direct measurement
in cyclonic or swirling gas streams, Section 2.4 of Method
1 shows how to determine cyclonic or swirling flow con-
ditions. When unacceptable conditions enst, alternative
procedures, subject to the approval of the Administrator,
U.S. Environmental Protection Agency, must be em-
ployed to make accurate flow rate determinations;
examples of such alternative procedures are: (1) to install
straightening vanes: (2) to calculate the total volumetric
flow rate noichiornclrically, or (3) lo move to another
measurement site at which the flow is acceptable.
Specifications for the apparatus are given below. Any
other apparatus that has been demonstrated (subject !«
approval of the Administrator) to be capable of meeting
the specifications will be considered acceptable.
11-34-
-------
1.90-2.54 cm*
(0.75-1.0 in.)
~r
T
7.62cm(3in.)
TEMPERATURE SENSOR
LEAK-FREE
CONNECTIONS
•SUGGESTED (INTERFERENCE FREE)
PITOT TUBE • THERMOCOUPLE SPACING
Figure 2-1. Type S pilot tube manometer assembly.
2.1 Type 8 Pilot Tube. The Type S pilot tube
(Figure 2-1) shall be made ol metal tubing (e.g., sign-
less steel). It is recommended that the eitcrnal tubing
diameter (dimension Di, Figure 2-2b) be between 0.48
and.0.95 centimeter! (Mi »nd H Inch). There shall be
an equal distance from the base ol each leg of the pilot
tub« to its face opening plane (dimensions PA and />*.
Figure 2-2b); it Is recommended tbat this distance be
between 1.05 and 1.50 times the eiternal tubing diameter.
The {ace openings of the pitot tube shall, preferably, b«
aligned as shown in Figure 2-2; however, sliiht misalign-
ments of the openings are permissible (see Figure 2-3).
Tbe Type 3 pitot tube shall have a known coefficient,
determined as outlined In Section 4. An Identification
number shall be aligned to the pitot tube; this number
shall be permanently marked or engraved ou the body
of the tube.
11-35
-------
TRANSVERSE
TUBE AXIS
\
FACE
OPENING
PLANES
(a)
A SIDE PLANE
_L
LONGITUDINAL '
TUBE AXIS 1
7 °t A
\
B
NOTE:
PA
PB
,
B SIDE PLANE
(b)
AOR B
(c)
Figure 2-2. Properly constructed Type S pitot tube, shown
in: (a) end view; face opening planes perpendicular to trans-
verse axis; (b) top view; face opening planes parallel to lon-
gitudinal axis; (c) side view; both legs of equal length and
centerlines coincident, when viewed from both sides. Base-
line coefficient values of 0.84 may be assigned to pitot tubes
constructed this way.
II-36
-------
TRANSVERSE-
TUBE AXIS
LONGITUDINAL
TUBE AXIS""
w plW
.__^__. , I • • • I —
-<^-«>. 3 tefoH
_^.^rM_.
(f)
(g)
Figure 2-3. Types of face-opening misalignment that can result from field use or im-
proper construction of Type S pitot tubes. These will not affect the baseline value
of.ep{s) so Jong as ai and a2 < 10°, 01 and fa< 5°. z < 0.32 cm (T/8 In.) and w <
0.08 cm (1/32 in.) (citation 11 in Section 6).
11-37
-------
•• I.' 11 "J I'.'* -'! of&Tryx' P.
M-" n'i -.i>"M' or !-n u-''' 2"
i-i'd'V!" iv'.'te,"lio'wevrr. Hint the ".- iMr aud fmp'U-t
[irc^iirv li .les of «l imi.ird r'1"1 till"'' art Hr,-'I>:iblf lo
iiiiirtinr in pr.rlic ulaU'-bdon cr.5 sin .!•:•* 1 in n-r'.'c,
whuu-M-r ft slftnrUrd p'tot tube is li'ed to p-rfurm a
lra\er«e adio,tr.ie pii-of must l-e furnished Hint the
CIIK mnirM'f I he pilot tube-have not plu-,-|:id up during the
traverse j«-ri"O divisions on the
1- to 10-ln vertical scale. This type of manometer (or
other gauge of equivalent sensitivity) is satisfactory far
the m easurement of Ap values as low asl-3mm(0.051n.)
HiO. However, a differential pressure gauge of greater
sensltivily shall be used (subject to tbe approval of the
Administrator). If any of tbe following is found to be
true: 0) the arithmetic average of all Ap readings at the
traverse polnti In the stack is less than 1.3 mm (0.05 in.)
HrO- (2) far traverses of 12 or more points, more than 10
percent of the individual Ap readings are below 1.3 nun
(006 In.) HiO: (3) tor traverses of fewer than 12 points,
Sore than on. Ap reading is below 1.3mm (006 hO HrO.
Citation IK In Section 6 describes comroerciall v available
Instrumentation far tbe measuremen t of low-range gas
' As an alternative to criteria (1) through (3) above, th«
following calculation may be performed to determine u»
necessity ol using a more sensitive differential pressure
gauge: •
li ia
Ail '
i-l
r=
Ap,—Individual velocity head reading at a traverse
point, mm HrO (in. H.O).
n-Total number of traverse points.
A'-O.ia mm H»O when metric units are used and
0.005 In HrO when English units are used.
If T Is greater than 1.05, the veloelty head data an
unacceptable and a more sensitive differential pressure
gauge must be used. ,, .t
NOT*.—If differential pressure gauges other than
Inclined manometers are used (e.R., magnehclic gauges),
their calibration must be checked after each test series.
To check the calibration of a differential pressure gauge,
compare Ap readings of the gauge with those ol a gauge-
oil manometer at a minimum of three points, approxi-
mately representing the ranee of Ap values In the stack.
If. at each point, the values of Ap as read by the differen-
tial pressure gauge and gauge-oil manometer agree lo
within S percent, the differential pressure gauge shall b«
considered lo be in proj>er calibration. Otherwise, the
test series shall either be voided, or procedures lo adjust
the measured Ar values and Imal results shall be used,
subject to the approval of the Administrator.
2.3 Temperature Oaupe. A thermocouple, liquid-
filled bulb thermometer, bimetallic thermometer, mer-
cury-in-fflass thermometer, or other gaupc capable of
measuring temperature to uilhm 1.5 percent of the mini-
mum absolute stack tem|ioraiure slmll he used. The
temixrature paiipe shall be attached to the pilot tube
such that the sensor lip does not touch any metal; the
gauge shall be in an inlerfcrcm-c-fjve arrangement with
respect to the pilot tube Ucc openings (sec Figure 2-1
ana also Figure 2-7 in Section 4). Alternate positions may
be used If the pitot-tube-iemixrature cauge system is
calibrated according to the procedure of Section 4. Pro-
vided that a difference of not more than 1 percent in the
average velocity measurement is introduced, the Icm-
II e U[>}-ruwJ of
A p.. 7o;-T', r tu!"1
•, ur\ - or w ^'-r-.ill'-d i.-tui.> J11 IUUMU i.-r ui|i;i it- of
)n<- .-.Hinir slu^k pri':-ure to v n!,,n 2 i m.i. <(• ] in > llf
Ls uc''d 'J'he ^Lilic 1'ip of a 5' :'id:ird l> [.c pilot tube o-
on- Iff Of » T\pe X pilot tlllie with 'the f.ire op< ..... 1C
jilj-ifs ix>«;nonrd lur.illil u» the g.is flow may also be
us- d a= the pressure probe.
2.5 Barometer. A mercury, aneroid, or other barom-
eter capable of mea^unnp atuiosphcric pressure to
within 2.5 mm Ilg (0.1 in. Uf) may be used. In many
cases, the barometric reading may If obtained trom •
nearby national weather service station, in which case
the station value (which is the absolute barometric
pressure) shall be requested and an adjustment lor
elevation diflerences between the weather station and
the sampling point shall be applied at a rate of minus
2.5 mm (0.1 in.) Bg per 30-meter (100 foot) elevation
increase, or vice- versa for elevation decrease.
2.8 Gas Density Determination Equipment. Method
3 equipment, if needed (see Section 3.6), to determine
the stack gas dry molecular weicht, and Reference
Method 4 or Method 5 equipment lor moisture content
determination; other methods may be used subject to
approval of the Administrator.
2.7 Calibration Pitot Tube. When calibration of the
Type S pltot tube Is necessary (see Section 4), a standard
pilot tube Is used as a reference. The standard pltot
tube shall, preferably, have a known coefficient, obtained
either (1) directly from the National Bureau of Stand-
ards, Route 270, Quince Orchard Road, Qaitbersburg,
,v-.-\ . ,*
l"l"t tube »it'i i>i M.-t...i'.i' oxIV.i.i Al- i-
tli, cl.l, -. . . i- • !•. U , 1 fin. i.l. 2 T :• l.i ln« :i nl 'in. -
Irdt-l in I . me -' -i • nK. t ililions 7. b, n'nl 17 in
p.-ct ion C) I i ix l.< L, 1 J'lti.', llll^ •- ill 'ipnrd in i onlinp
to i
.s
M:il,
..
27.1 11. n.s-i l.criial (shown In Fi£ure2-4).clli|f>
or roulcal tip.
2.7.2 A minimum of six diameters . ctr.iipht rn-i (KiM'd
U|K)n D, the ntirnal diamrli-r ol the lulie) bel>iO
(0.05 and 1.0 In. HjO), and to the Dearest 1.3 mm IliO
(0.05 la. B>O) for Ap values above 25 mm HrO (1.0 In.
HiO). A special, more sensitive gaore will be required
to read Ap valnea below 1.3 mm lliO [0.05 In, 11 iO)
(see Citation 18 in Section 0).
CURVED OR
MITEREDJUNCTION
STATIC
HOLES
(-0.1D)
HEMISPHERICAL
TIP
Figure 2-4.~Standard prtot tube design specifications.
3. Procedure
3.1 Bet op the apparatus as shown in Figure 2-1.
Capillary tubioR or surge tanks Installed between the
manometer and pitot tube may be used to dampen Ap
fluctuations, li is rnconuuended, but not required, that
& pretest leak-check be conducted, as follows: (1) blow
through the pitol impact opening until at least 7.6 cm
(3 in.) II»O velocity pressure ri-pisters on the manometer;
then, close off tbe impact opening. The pfrssure shall
remain stable for at least 15 seconds; (2) do the same for
the static pressure side, except using suction to obtain
the minimum of 7.6 cm (3 in.) HiO. Other leak-check
procedures, subject to tbe approval of the Administrator,
may be used. -
3.2 Level and zero the manometer. Because the ma
no meter level and zero may drift due to vibrations and
temperature changes, m:ike periodic checks during the
traverse. Record all nottsstiry data as shown in the
example data sheet (ticure 2-5).
3.3 Measure the velocity hoad nnd (emperalure at the
traverse points spccilKxl by Method 1. Ensure that the
proper difTerential pressure pautre is being used for the
ranpe of Ap values encountered l«er Section 2.2). I/ It IB
necessary to chaige to a more sensitive pauge, do so, and
rcmensuro the A/> and l« rnpcraiure readings at each tra-
verse point. Conduct a post-test leak-chock (mandatory),
asde6LnbediDScctiou3.1 above, to validate the traverse
mo.
3.4 Measure the static pressure In tbe stack. On*
reading is usually adequate.
3.5 Determine the atmospheric pressure.
11-38
-------
PLANT.
DATE
, RUN NO.
STACK DIAMETER OR DIMENSIONS, m(in.)
BAROMETRIC PRESSURE, mm Hg (in. Hg)
CROSS SECTIONAL AREA,
OPERATORS
PIT.OTTUBEI.D.NO.
AVG. COEFFICIENT, Cp = .
LAST DATE CALIBRATED.
SCHEMATIC OF STACK
CROSS SECTION
Traverse
Pt No.
mm (inj H20
Stack Temperature
°K
mm Hg (in.Hg)
Average
Figure 2-5. Velocity traverse data.
11-39
-------
36 DtKTiTiirif t!ir «ti-V pa.' dry rnnK-ii'&r Te'rht
1 u' ro •]( .^'IOT^ I'UH*.-*^'1 or JTO Jivw lti*i. emit e.wn-
tln',1 CO'TOi. Cl\ "."'I Ni, U-'* Mr'utxi 3 to- prm-i^vj
cmiuluf; ',v nUutls ai:. an Br-'ii? ;)s Df^*d not bo con
d'"i'~U'd u.s^ & dry rr^'n^ij'r^ vrif-'ht or lwi.O. For ot'i^r
iirocc-vsc-i. o'.her rnclhtxls. rj1 )ocl to the Djiproval o! Ore
Adminlnrator. roui-t bo used.
37 Obtain the moMure oontent from Reference
Method 4 (or equivalent) or from Method 6.
3 8 Determine the cross-sectional area of the stack
or duct at the sampling location. Whenever possible.
physically measure Ihe sta• 1'ipire
If D, li l«-t»«>n
C 4S and 0 9*j CH5 (Mi &nd Es in,) and If /'* find ^'fl are
tin'ial a;idbc.t»tion 1 (& Bnd 1.50 Ii,, tlji-re ft'i- two pov.lile
options. (1) the. pilot tube nmy b« calibroti-j arilh olher source-sampling compon-
ara aSrned irithin the specifications illustrated In Flgur. —- <"• '- -•---" >~ """'-> « "»rl of
53 orM. The pilot tube shall not be used U It fads to
meet thes« alignment specification*.
After verifying the face opening alignment, measure
and record theloHowlng dimensions of the pilot tube:
used in combinaton wllh olbtr souree-sampung c
ents (Ihermocouple. sampling probe, noiile) as purl ol
an "assembly." The presence of olher sampling compo-
nents can somelimes aflecl Ihe baseline value of the Type
8 pllol tube coefficienl (Cilation » in Section 6); therefore
an assigned (or otherwise known) baseline coefficient
K
TYPE SPITOT TUBE
i ti.
\ . .11 • . .d !. .'it'
only »!i"h ' » !• .-' >r !- - - --
She vimlJr L* surii that Sta.O, n "TUC inn rl'
el'ects ar- ciin.r.a'ni ticiif^ '.'-0 D.nniiii --*>'.1:11 !:.>li;
inlcrfiTCi.cr-'.-.r cvinji'mnii arranpi :m nls t-,r ! > |>r b
pilot tnl'-s having cstcrna! tubing rti ui'i'iT^ in-iwi-fn
6 48 and 0",". cm ijit arid H in ) Tyin S pilot tnU a.!-, in-
bli« lhat fail to meet any or all of the Epe-dfic it ions, of
Figures 2-6 throuch 2-8 sliall be calibrotid Bc-cordinc lo
the proct-dur* outlined In Sections 4.1 2 through 4 1.6
below and prior lo calibration, the values of Ibe. intor-
componenl spacings (pltot-nonle, pitol-tlirrniocoujile,
pilot-probe sheath) shall be measured and recorded.
• Norz —Do not use any Type 8 pllol tube assembly
which Is constructed such that the impacl pressure open.
ing plane of Ihe pitol lube Is below Ihe entry plane of the
nozzle (set Figure 2-6b).
4.1.Z Calibralion Setup. If Ihe Typ* B pitol lube Is to
be calibraled, one leg of Ibe tube shall be pcrmanenlly
marked A, and the other, 3. Calibration shall be done In
a flow system having the following essential design
features:
«;> 1.8'0 cm (3/4 in.) FOR Dn- 1.3 em (1/2 in.)
SAMPLING. NOZZLE
A. BOTTOM VIEW; SHOWING MINIMUM PITOT-NOZZLE SEPARATION.
SAMPLING
PROBE
SAMPLING
NOZZLE
NOZZLE ENTRY
PLANE
STATIC PRESSURE
OPENING PLANE
IMPACT PRESSURE
OPENING PLANE
SIDE VIEW; TO PREVENT PITOT TUBE
FROM INTERFERING WITH GAS FLOW
STREAMLINES APPROACHING THE
NOZZLE. THE IMPACT PRESSURE
OPENING PLANE OF THE PITOT TUBE
SHALL BE EVEN WITH OR ABOVE THE
NOZZLE ENTRY PLANE.
Figure 2-6. Proper pitot tube - sampling nozzle configuration to prevent
aerodynamic interference; buttonhook-type nozzle; centers of nozzle
and pitot opening aligned; Dt between 0.48 and 0.95 cm (3/16 and
3/8 in.). n °
-------
THERMOCOUPLE
Z>i.9flcm{3/4inJ
TYPE SPITOT TUBE
ISAMPLE PROBE
I
THERMOCOUPLE
Z>S.Oicm
"cw
-O-
TYPE SPITOT TUBE
SAMPLE PROBE
Figure 2-7. Proper thermocouple placement to prevent interference;
Dt between 0.48 and 0.95 cm (3/16 and 3/8 in.).
** SNRfrT
, gfrdS
TYPE SPITOT TUBE
1
SAMPLE PROBE
Y>7.62cm(3inJ
Figure 2-8. Minimum pitot-sample probe separation needed to prevent interference;
D between 0.48 and 0.95 cm (3/16 and 3/8 in.).
4.1.2.1 The flowing gas stream must b« confined to •
duct of definite cross-sectional ar«>, either circular or
rectangular. For circular cross-flections, the minimum
diict diameter shall be 30.5 cm (12 In.); for rectangular
cross-sections, the width (shorter tide) shall be at least
25.4 cm (10 in.).
4.1.2 3 The crow-sectional area of the calibration duet
must b« constant over a distance of 10 or more duct
diameters. For a rectangular cross-section, ns« an equiva-
lent diameter, calculated from the following equation,
to determine the number of duct diameters:
D,--
2LIT
"(L+W)
Equation 2-1
diameter
• here:
/^, = Equival
£- Length
•*'= Width
To ensure the pre?ence of stable, fully developed flow
patterns at the calibration site, or "test section," the
si t* must be located at least eiplit diameters downstream
and two diameters up;>trfaru from the nearest disturb-
ances.
NOTE.— The eleht- and two-diameter criteria are not
absolute; other test «ection locations may be used (sub-
ject to approval of the Adrrumstrator),prov1ded that the
flow at the test site Is stable and demoostrably parallel
to the duct ails.
4.1.2.3' The flow »y?tera shall have the capacity to
trill-rule a tcst-f'ction velocity around 915 m/mln (3,000
n/mln). This velocity must be constant with time lo
guarantee steady flow during calibration. Not* that
Type B pitot tube coefficients obtained by single-velocity
calibration at 915 m/min (3,000 ft/min) will generally be
valid to within ±3 percent for the measurement of
velocities above 305 m/mln (1,000 ft/min) and to within
±5 to 4 percent for the measurement of velocities be-
tween 180 and 305 m/min (600 and 1,000 ft/min). If a
more precise correlation between C, and velocity Is
desired, the flow system shall have the capacity to
generate at least four distinct, time-invariant test-section
velocities covering the velocity range from 180 to 1,525
m/min (MO to 5,000 ft/min), and calibration data shall
be taken at regular velocity intervals over this range
(see Citations a and 14 In Section 6 for details).
4.1.2.4 Two entry ports, one each for the standard
and Type B pilot tubes, shall be cut In the t&>t section;
the standard pitot entry port shall be located slightly
downstream of the Type B port, so that the standard
and Type 8 impact openings will lie in the same cross-
sectioiial plane during calibration. To facilitate align-
ment of the pilot tubej dunug calibration, it is advisable
that the test section be constructed of pleiiglas or some
other transparent material.
4.1.3 Calibration Procedure. Note that this procedure
Is a general one and must not be used without first
referring to the special considerations presented in Sec-
tion 4.1.5. Note also that this procedure applies only to
single-velocity calibration. To obtain calibration data
for the A and B sides of the Type S pitot tube, proceed
as follows:
4.1.3.1 Make sure that the manometer is properly
filled and that the oil is free from contamination and Is ol
the proper density. Inspect and l»-at-check all pitot lines;
repair or replace if necessary.
4.1.3.2 Level and tero the nanometer. Turn on I lie
fan and allow the flow to stability Seal the Type S entry
port.
4.1.3.J Ensure that the manometer Is level and icroed.
Position the standard pitot tube at the calibration point
(determined as outlined In Sction 4.1 J.I), and align the
tube so that its tip is pointed directly Into the flow. Par-
ticular care should b* taken in aligning the tube to avoid
yaw and pitch angles. Make sure that the entry port
surrounding the tube is properly sealed.
4.1J.4 Read AP.U and record its value In a data table
similar to the on* shown in Figure 27*. Remove tb*
standard pitot tube from the dnct and disconnect It from
the manometer. Seal the standard entry port.
4.1.3.5" Connect the Type S pitot tub* to the. manom-
eter. Open the Type S entry port. Check the manom-
eter level and zero. Insert and align the Type S pitot tub*
so that its A side impact opening is at the same point as
was the standard pitot tube and Is pointed directly into
the Uow. Make sure that the entry port surrounding th*
tube is properly sealed.
4.1.3.8 Read Ap. and enter Its value In the data tab!*.
Remove the Type S pitot tub* from the duct and dia-
oonnect it from the manometer.
4.1.3.7 Repeat steps 4.1.3.3 through 4.1.3.C above until
three pair; of Ap readings have been obtained.
4.1.3.8 Repeat steps 4.1.3.3 through 4.1.3.7 above for
the B side of the Type S pitot tube.
4.1.3.9 Perform calculations, as described in Section
4.1.4 below.
4.1.4 Calculations.
4.1.4.1 For each of the sli pairs of Ap readings (!.»,
three from side A and three from side B) obtained in
Section 4.1.3 above, calculate th* value «f the Type 8
pilot tube coclliocnt as follows:
11-41
-------
PIT'OT TUBE IDENTIFICATION NUMBER:
CALIBRATED BYf. -
DATE:
RUN NO.
1
2
3
"A" SIDE CALIBRATION
' APstd
cm H20 '
(in. H205
APM
cmH20
(in. H20)
Cp (SIDE A)
Cp(s)
.
DEVIATION
Cp{i) • Cp(A)
BUNUO-.
1
2
3
"B" SIDE CALIBRATION
Apstd
crnHjO
(in. HzO)
•
APM
cmH20
(in.H20)
Cp (SIDE B)
CpW
' DEVIATION
Cp(t)-Cp(B)
•
AVERAGE DEVIATION = a (A OR B)
S |Cp{s)-Cp(AORB)|
1— r— -*— MUST BE <0.01
, (SIDE A)-Cp (SIDE B) |-*-MUST BE <0.01
Figure 2-9. Pitot tube calibration d?ta.
41 (3 Cr.' .1-1. I'.r i'_.
si(Jc vui i"-o;r, i.>fron> C, '
ra"ii Is ;idc vai'ir o! f,'.-f; •
low in£ equ"'. ion
Dcviation = CV . -r,,(A or B)
Equation 2-3
Y.1.4 4 Calculate », the m.iapi deviation from tlie
mean, for both the A and 1J sales of the pilot tube. Vse
the following equation:
' (side A or B)=-
»-»(.) =
t "
Equation 2-2
C, c. i—Type B pilot tube coefficient '
C,<.u> -Standard pitot tube coefficient; use 0.99 if the
coefficient is unknown and the tube is designed
according to the criteria of Sections 2.7.1 to
2.7 Ji of this method.
=Velocity head measured by the standard pilot
tube,emHiO(in.H,0)
Az>.=Velocity bead measured by the Type 8 pilot
tube, cm H,O (in. HiO)
4.1.4.2 Calculate C, (side A), the mean A-slde coef-
ficient, and S, (side B), the mean B-elde coefficient;
calculate the difference between these two average
values.
Equation 2-4
4.1.4.S Use the Type S pilot tul>e only if the values of
. (side A) and * (side B) are less than or equal to O.OT
and if tlip absolute value of Hie difference between C,
(A) and C, (B) is 0.01 or less.
4.1.5 Special considerations.
4.1.6.1 Selection of calibration point.
4.1.5.1.1 When an isolated Type S pilot tube is cali-
brated, select a calibration point at or near tlie center of
the duct, and follow tlie procedures oulljned in Sections
4.1.3 and 4.1.4 above. Tlie Type 6 pilot coefficients 10
obtained, i.e., ~, (side A) nnd C, (side B), will be valid,
so long as either: (1) Die l.solaled pilot lube is used; or
(2) Ihe pilot tube is used with oilier components (noiile,
thermocouple, sample probe) In an arrangement that is
free from aerodynamic interference effects (see Figures
2-0 through 2-8).
4.1.5.1.3 For Type B Pil«l tube-thermocouple com-
binations (without sample probe), select a calibration
point at or near the center of the duct, and follow the
procedures outlined in Sections 4.1.3 and 4.1.4 above.
The coefficients so obtained will be valid so long as the
pilot tube-thermocouple combination is used by itself
orwithothercomponentsin an interference-free arrange-
ment (Figures 2-6 and 2-8).
4.1.5.1.3 For assemblies with sample probes, the
calibration point should be located at or near the center
of the duct; however, insertion of a probe sheath into a
small duct may cause sipnilicanl cross-sectional area
blockape and yield incorrect coefficient values (Citation II
in Section 6). There-fore, to minimize the blockage eflccl,
Ihe calibration point may be a few inches off-center if
necessary. The actual blocl-npo effect will be negligible
when the theoretical bloHnqc, as determined by a
projected-area model of tlie probe sheath, is 2 percent or
less of the duct cro^s-sectionnl nrca for assemblies without
external sheaths (Figure 2-10-.il, and 3 percent or less for
assemblies with external shrotbs (Figure 2-10b).
4.1.5.2 For those prolw assemblies in which pitot
lube-nozzle interference is a factor (i.e., those in wbicb
the piiot-noizel separation distance fails lo meel the
specification illustrated in lriRure 2-6a), the value of
C,c> depends upon the amount of free-space between
the tube and nozzle, and therefore is a function of nozrle
sire. In they* instances, s^p-irat* calibrations shall b«
performed with each of the commonly nsed nozzle sites
in place- Note that the sincle-velocity calibration tech-
nique is acceptable for tins purpose, even though the
larger noizle'sizes O0.035 em or \i in.) are not ordinarily
used for isokinetic sampling at velocities around 815
m/min (3,000 ft/min), which is lire calibration velocity;
note also that it is not mx-rv-ary to draw an isokmetio
sample during calibration (see Citation IS in Section 6),
4.1.5.3 For a probe assembly constructed such that
Itj pitot tube is always used in Hie saraeptientation, only
one side of the pilot tube nnod be calibrated (the side
wluch will face the flow). Tlie pilot lube must still meet
the alignment specifications of r ipure 2-2or 2-3, ho» ever,
»nd must have an average de\ mtion («) value of 0.01 or
less (sec Scclion 4.1.4.4).
IJ.-42-.
-------
(a)
ESTIMATED
SHEATH
BLOCKAGE
r .ixw i
[pUCTAREAj
x 100
Figure 2-10. Projected-area m.odels for typical pilot tube assemblies.
4.1.6 Field Dae and R (-calibration.
4.1.6.1 Field Us*.
4.1.6.1.1 When > Type 8 pitot tube (Isolated tube or
assembly) Is used in the field, the appropriate coefficient
value (whether assigned or obtained by calibration) shall
be used to perform velocity calculations. For calibrated
Type 8 pitot tubes, the A side coefficient shall be used
when tbe A side of the tube faces tbe flow, and the B side
coefficient shall be used when the B side faces the flow;
alternatively, the arithmetic average of the A and B side
coefficient values may be used. Irrespective of which side
(aces the flow.
4.1.6.1.2 When a probe assembly is used to sample a
•mall duct (12 to 36 in. in diameter), the probe sheath
sometimes blocks a significant part of the duct cross-
aectlon, causing a reduction in the effective value of
~, (.). Consult Citation » In Section « for details. Con-
ventional pilot-sampling probe assemblies are not
recommended for use in ducts having inside diameters
•mailer than 12 Inches (Citation 16 m Section 6).
4.1.0.2 Beralibration.
4.1.6.2.1 Isolated Pitot Tubes. After each field use, the
pitot tube shall be carefully reexamined in top, side, and
end views. If the pitot face openings are still aligned
within the specifications illustrated in Figure 2-2 or 2-3,
It can be assumed that the baseline coefficient of the pitot
tube has not changed. If, however, the tube has bwn
damaged to the extent that it no longer meets the specifl-
mions o( Figure 2-2 or 2-3, the dainMe shall either b*
repaired to restore proper alignment of the face openings
or the tube sliall bo discarded.
4.1.6.2.2 Pitot Tuhe Assemblies. After each field use,
check the face opening alignment of the pitot tube, as
In Section 4.1.G.2.1; also, rcmeasure the intcrcomponeat
•pacings of the assembly. If the Intercompcnent spacings
have not changed and the face opening alignment u
acceptable, It can be assumed that the coefficient of the
assembly has not changed. If the face opening alignment
la no longer within the specifications of Figures 2-2 or
2-3, either repair the damage or replace the pitot tub*
(calibrating the new assembly, if necrsjary). If the inter-
component spacincs hare changed, restore the original
ipacnigs or recalibrate the assembly.
4.2 Standard pilot tube (If applicable). If a standard
pitot tube is used fur the velocity traverse, the tuta shall
be con:-truct
34 97 M L~lO).
3, 600— Conversion factor, sec/hr.
18.0- Molecular weight of water, g/g-mole (lb-lb-
mole).
5.2 Average slock gas velocity.
P.M.
Equation 2-0
3.3 Average alack gas dry volumetric flow rate.
Equation 2-10
1. Murk, L. S. Mrdnnical Enjinccrs' Handbook. Now
York^ AlcGraw-IIill Book Co., Ir.e. 1951.
2. Perry. J. II. Cliemic-il Entfneers' Handbook. K«w
York. McUraw-IIiU IJo.ik Co., Inc. 1900.
11-43
-------
3 Shi (h.i'l. It T . W E To.1.1 a-nl W. R Smith
Pirni/i" mro at Errors in Sl.icl" J- Mn|ilinq M< i^uri >"' "Is
I .S I nvm>ninciilnl I'rtiteMion Aprnc\, Rcsctirch
Tnun"l( J'.irk, N C. (TrcM-med :n thr Auriu il M' c;:nc of
tlu Air I'ollulion Control A^xxia'.ion, St Louis, Mo.,
June H-1M. l'J70)
4 Slund.ird Method for Sampling Slicks for Paniculate
Matter. In 1971 Bool of AST.M Statidjids, hart 23.
Philadelphia, Pa. 1971 ASTM Designation D-2928-71.
5. Vcmiard. J. K. Elementary Fluid Mwhanjcs. New
York. John \\ilcy and Sous, Inc. 1047.
6. Fluid Meters—Their Theory and Application.
American Society of Mechanical Engineers, New York,
N.Y 1159.
7 ASHRAE Handbook of Fundamcntils. 1972. p. 208.
8 Anuu:0 Book of ASTM Standards, Fart 26. 1974. p.
648.
». Vollaro, R. F. Guidelines for Type S Pilot Tube
Calibration. U.S. Environmental Protection Agency.
Research Tmngle Park, N C. (Presented at 1st Annual
Meeting, Source Evaluation Society, Dayton, Ohio,
September 18, 197S.)
10. Vollaro, R. F. A Type S Pilot Tube Calibration
Study. U.S. Environmental Protection Agency. Emis-
sion Measurement Branch, Research Triangle Park,
N.C. July 1974,
11 Vollaro, R. F. The Eflects of Impact Opening
Misalignment on the Value of the Type S Pilot Tube
Coefficient. TJ.8 Environmental Protection Agency,
Emission Measurement Branch, Research Triangle
Park, N.C. October 1976.
12. Vollaro, R. F. Establishment of a Baseline Coeffi-
cient Value lor Properly Constructed Type S Pilot
Tubes. U.S. Environmental Protection Agency, Emis-
sion Me.isurement Branch, Research Triangle Park,
N.C. November 1974.
13. Vollaro, R. F. An Evaluation of SingleA'elocity
Calibration Techniques as a Means of Delerminine Type
S Pilot Tube Coefficients. U.S. Environmental Protec-
tion Agency, Emission Measurement Branch, Research
Triangle Park, N C. Augusl 1975.
14. Vollaro, R. F. The Use of Type S Pilot Tubes lor
the Measurement of Low Velocities. U.S. Environmental
Protection Agency, Emission Measurement Branch,
Research Triangle Park, N.C. November 1876.
15. Smith, Marvin L. Velocity Calibration of EPA
Type Source Sampling Probe. United Technologies
Corporation, Pratt and Whitney Aircraft Division,
East Hartford, Conn. 197S.
16. Vollaro, R. F. Recommended Procedure for Sample
Traverses in Ducts Smaller than 12 Inches in Diameter.
U.S Environmental Protection Agency, Emission
Measurement Branch, Research Triangle Park, N.C.
November 1976.
17. Ower, E. and K C. Pankhurst. The Measurement
of Air Flow, 4th Ed., London, Pcrgamou Press. 1966.
18. Vollaro, R. F. A survey of Commercially Available
Instrumentation for the Measurement of Low-Range
Gas Velocities U.S. Environmental Protecliun Agency,
Emission Measurement Branch, Research Triangle
Park N.C. November 1976. (Unpublished Paper)
19. Gnyp, A. W., C. C. St. Pierre, D. 8. Smith. D.
Mouon, and J. Sterner. An Experimental Investigation
of the EBcct of Pilot Tube-Sampling Probe Configura-
tions on Ihe Magnitude of the S Type Pilot Tube Co-
efficient for Commercially Available Source Sampling
ri"bi
TVijM:.,! I , Ihi- Vi. *••- \ c.'V ,• .1 nr f.ir the
ol the J.i.\ jnuiuu i 1. 'K * '•", < j .a'J-i t ' 'J-
METHOD 3-G*? ANALYSIS FOR CtRRov r»n\ii>«,
OXVGI..S, EXCLSSAIK, AM>l>ci Motrc LLAFI \\ Liniir
1. Principle and Applicability
1.1 Principle. A pas sample Is c-itricted from a stack,
by one of tlic lollow-ing methods: (1) single-point, grab
sampling, (2) single-point, int»-£rfatcd sampling; or (3)
multi-point, integrated sampling. The gas sample is
analyzed for rx-reent carbon dioxide (COi), percent oxy-
gen (O:), and, If necessary, percent carbon monoxldt
(CO). If a dry molecular weight determination Is to be
made, either an Orsat or a Fynle > analyzer may be used
lor the analysis; for excess air or emission rale correction
factor determination, an Orsat analyzer must be u«cd.
1.2 Applicability. Tnis method Is applicable for de-
termining COi and Oi concentrations, excess air, and
dry molecular weight of a sample from a ga« slreom of a
fossil-fuel combustion process. The method u*a> also b*
applicable toother processes where It hasl>eendri«rinlnAd
that compounds other than COj, Oj. CO, and nitrogen
(Ni) are not present in concentrations sufficient to
aficcl the results.
Other methods, as well as modifications to the proce-
dure described herein, are also applicable for ?omc or &11
of the above determinations. Examples of sjK-cIfic meth-
ods and modifications include' (1) a multi-i>oint samp-
ling method using an Orsat anaJyier to analyze indi-
vidual grab samples obtained at eath point; (2) a method
using COi or Oi and stoichiometric calculations to deter-
mine dry molecular weight and excess air; (3) assigning •
value of 30.0 for dry molecular •» eight, in lieu of actual
measurements, for processes burning natural gas, coal, or
oil. These methods and modifications ma> be uvd, but
are subject to the approval of the Administrator.
2. Apparattu
As an alternative to the sampling apparatus and sy»-
tems described herein, other sampling sj stems (e.g.,
liquid displacement) may be use
-------
.PROBE
FLEXIBLE TUBING
FILTER (GLASS WOOL)
SQUEEZE BULB
•TO ANALYZER
Figure 3-1. Grab-sampling train.
RATE METER
AIR-COOLED
CONDENSER
PROBE
\
FILTER
(GLASS WOOL)
RIGID CONTAINER
Figure 3-2. Integrated gas-sampling train.
11-45
-------
« " ? Condenvr. An sir-cooled or water-cooled cop-
denw' or other condenser that will not remove O,.
CO,. CO, and Nj. may be us/- d to mnove excess roou ur»
which would interfere »itb the operation of the pump
^"rValvf'A needle valve Is used to adjust sample
EI2 ST Pu'mp. A IcaV-fre*. diaphragm-type Pump. «
equivalent is used to transport sample gas to the flexible
bag InsUU a mail surpe tank between the pump and
rail meter to euminal* the pulsation eflect of the dia-
pl??«n RMePMeter .Vhe rotamcter, or equivalent rate
meter, used should be capable of njc?suri"«Jlor I.-1
to within ±2 percent of the selected now ret*. A Bow
nit range of 500 to 1000 cm"min is »H!«J«*- --^
2.2.6 Flexible Baz. Any leak-free plastic (e.g., TeflUtf,
Mylar, Teflon) or plastic-coated »'un}ll"1i™ (e.E'- ^f±
nlMd Mylar) bag, or equivalent, harm? a capacity
wr^iteitlritbihe selected flow rate and time length
of tbe test run, may be used. A capacity in the range of
K to 80 liters is suggested.
To leak-check the bag, connect it to a water manometer
»nd ,^n» the baTto 6 to 10 cm H,O (2 to 4 In H,0>
Allow to «und for 10 minutes. Any displacement in the
water manometer indicates a leak An »lt*n»»t>»« >«*:
ebec): method Is to pressurize the bag to 5 to 10 cm i HrO
(2 to 4 In HrO) and allow to stand overnight. A deflated
from !(«• iKTicnt. CeJnilate the dry molecular wclplit as
liidirau-d in Section fl.3.
3.2^ Reix«t the analysis and calculation procedures
until the individual dry molecular weights lor any three
a-mlysej diner from their mean by no more than O.S
g/g-mole (OJ Ibflb-mole). Average these three molecular
weights, and report the results to the nearest 0.1 g/g-mole
(0.1 Ib/lb-mole).
8.3 Multi-Point, Integrated Sampling and Analytical
Procedure.
SJ.l Unless otherwise specified by tbe Adminis-
trator a minimum of eight traverse points shall b* used
for circular stackk .having diameters less then 0.81 m
(24 in.), a minimum of nine shall be uwd for rectangular
stacks having equivalent diameters less than 0.811 m
(24 in.), and a minimum of twelve traverse points shall
be used lor all other cases. Tbe traverse points shall be
located according to Method 1. The use of fewer points
is subject to approval of the Administrator.
332 Follow the procedures outlined In Sections 3.2.2
through 3.2.5, except for the following: traverse all sam-
pling points and sample at each point lor an equal length
of time. Record sampling data as shown in Figure 3-3.
EaommendVby the manufacturer, unless otherww
r^Molcnilar Weight Determination. An Orsat
•nalywr orVyrlte type combustion gas analywr may b.
Emission Rat« Correction Factor or -
4. Er,,if.or. J'.all Cu'trel:.>n facl^r a Jllf'.'» .1" 1'iln-
ii.ir.alton
NOTF —A F>r;tM>pe cnmlvuMion paf analyzer l« not
acceptable for ciu-is, air or en-nnou rait com-clion lurlor
drleriuJmuon. unless approvrd by the Administrator.
If both percent CO, and |»rccnl Oi are inrasured, the
anah-ticol rriuhs of any of the three procedures gi\en
below may also be used for calculating tlie dry molecular
Each of the three procedures below shall be uwd only
when specified in an applicable suhpan of the standards.
The use of these procedures for other purposes must have
specific prior approval of the Administrator.
4.1 Single-Point, Grab Sampling and Analytical
4°Tl ""he sampling point In the duct shall either be
at the centroid of the cross-section or at a point no closer
to the walls than 1.00 m (3.3 ft), unless otherwise specified
by the Administrator.
4.1.2 Bet up the equipment as shown in Kigure 3-1,
makinc sure all connections ahead ol the analyzer are
tight and leak-tree. Leak-check the Orsat analyzer ac-
cording to tbe procedure described in Section 6. Thu
leak-check Is mandatory.
». Z>rf MofceuJor B'tiffW Determmalin
AUT of the three sampling and analytical procedures
described below may boused for determining the dry
omt, Grab Sampling and Analytic*
M|UTrie sampling point In the duct shall either be
at {he centre Mrftne*cr£s section or at a point nodoser
Stoewalbthan 1.00m (3.3 ft), unless otherwise specified
TIME
TRAVERSE
PT.
-
x
f
AVERAGE
a
1pm
% DEV.8
i
%DEV=
t3 in Figure 8-1,
makmg «re all eections ahead of tbe »™%«t»"
Qavg
(MUST BE < 10%)
Figure 3-3. Sampling rate data.
SS™
rromTf£p1rcent Calculate the dry molecular weight a,
, analysis, and calculaUon
he sampling point In the duct shall be located
the flexible bag a, in
413 Place the probe In the stack, with the Up of tbe
Drobe positioned at the sampling point; purge the sam-
pling line. Draw a sample Into the analyier. For emission
rate correction factor determination, immediately ana-
lyie the sample, as outlined in Sections 4.1.4 and 4.1.5,
lor percent CO, or percent O,. 11 excess air Is desired,
proceed as follows: (1) Immediately analyze the sample.
as in Sections 4.1.4 and 4.1.5, lor percent CO,. O,, and
CO- (2) determine the percentage ol the gas that Is N,
by subtracting the sum of tbe percent CO,, percent O,,
and percent CO from 100 percent: and (3) calculate
percent excess air as outlined in Section 6.2.
414 To ensure complete absorption of the CO,, Oi.
or if applicable, CO, make repeated passes through each
absorbing solution until two consecutive readings are
the same Several passes (three or four) should be made
between readings. (If constant readings cannot be
obtained after three consecutive readings, replace the
Baeat.n. The sampling run
sbouW £ Staneous with, and for the same total
if^rth nttlme as the pollutant emission rate detcrmlna-
Uof ^UecUon of a, least 30 liters (1.00 ft«) of sample gas
to ?efornmended; however, smaller volumes may be
Integrated flue gas sample during
y uwTlt Is recommended that the Orsat leek-
£**escribed in Section 5 be ^1°™^^°'^.
determination; however, the check U optional. Deter-
mine tbe percentage of the gas that is N! and CO by sub-
Sictingthe sunToI the percent CO. and percent Oi
analysis to completed, leak^beck
(mandatory) the Orsat analyzer once again, as described
Insertion 5. For the results of the analysis to be valid
the Orsat analyier must pass this leak test before and
after the analysis. NOTE.—Since this single-point^ grab
sampling and analytical procedure Is normally conducted
Slonlunctlon with a single-point, grab sampling and
analyt cal procedure for a pollutant, only one analysis
is ordinarily conducted. Therefore, great care must be.
taken to obtain a valid sample and analysis Although
irTmost cases only CO, or 6, Is required. It Is recom-
mended that both CO, and O, be measured, and that
Citation 5 In the Bibliography be used to vabdaU the
"4.21 Single-Point. Integrated Sampling and Analytical
P4°2*dUThe Minpnng point m the duct shall be located
as specified in Section 4.1.L , .. « n-i *. I-
4 22 Leak-check (mandatory) the flexible bag as In
Section 2.2.6. Set up the equipment as shown in Figure
3-2 Just prior to sampling, leak-check (mandatory) the
train by placing a vacuum gauge at the condenser inlet,
pulUng a vacuum of at least 250 mm Hg (10 In. Hg).
pluggir-g tbe outlet at tbe quick disconnect, and then
11-46 •
turning ofi the pump. The vacuum shall remain stable
for at lca.n 0.5 rumule. Ev»ou»U the floiible bag. Con-
nect the probe and place it in the stack, with the Up of the
probe positioned at the sampling point; purge the sam-
pling line. Next, connect the bag and make sure tnat
all connections are tight and leak free.
423 Esmplc at a constant rale, or as specified by the
Admimnrator. The sampling run must be simultaneous
with and lor the same loul length of lime as, the pollut-
ant inu^-ion rale determination. Collect' at least 30
liters (1 00 ft') of sample gas. Smaller volumes may be
collwied. subject to approval of the Admini-Orator.
424 Obtain one integrated flue gas sample during
each ittUutant emission rule determination. For emission
rale correction factor determination, analyze the sample
within 4 h"urs after it is tnken for percent CO.or percent
O, (as ouiuned in Sections 4.2.5 throupb 42.7) The
Orsafar-alyLor must be leak-checked .(see Section S)
before tbe analysis. If excess, air is desired proceed as
follows- (1) within 4 hours alter the sample is taken
anal"e « as in Sections 4.2.5 through 4.2.7, or percent
CO,. Oi. and CO; (2) determine tbe percentage of the
gas that is Nt bv subtracting the sum of the percent COi,
pfrcenl O,. and percent CO from 100 i*«*nt; (3) cal-
culate percent excess air, as outlined in Section 6.2
4 •> 5 To ensure complete absorption of the CO,, Oi.
or If api .Loable, CO, make relocated passes through each
absorbing solution until two consecutive readings are th»
same Several passes (three or four) shoilld be made be-
tween readings. (11 constant reading' cannot be obtained
8lt« thMTconsccutlve readings, replace the absorbing
"^e^Repeat tbe analysis until the following criteria
"J °6.V For percent CO,, repeat the analytical pro-
cedure unu! thJrtsults of any three Im»1>'50,^1'»
nnttl tbe results ol any three analyses difler by no mor»
-------
than (a) 0 3 r» roent by volume when Oj is liss than 15.0
percent or »b) 0.2 pt rcvnt by volume •» lw.n Oi is greater
than 15 0 percent. Average the thr-e acceptable values of
percent Oj and report the results to the nearest 0.1
For percent CO, rep. at the gna]>tlca! proce-
dure until the results of any three anal>.-<-s differ by no
more than 0.3 percent. Average the three acceptable
values of percent CO and report the results to the nearest
•^T^After the ftnaiysis is completed, leak-check
(mandatory) the Orsat analyzer once a^ain, as descnbed
in Sections. For the results of the analysis to be valid, the
Orsat analyzer must pass this leak test before and after
the analysis. Note: Although in most instances only COi
or Oj is required. It is recommended that both COi and
Oi be measured, and that Citation 5 in the Bibliography
be used to validate the analytical data.
4.3 Multi-Point, Integrated Sampling and Analytical
Procedure. *
4 3.1 DOth the minimum numb'-r of sampling points
and the sampling point location shall be as specified In
Section 3.3.1 of tins method. The use of fewer points than
ipecified is jobjcct to the approval of the Administrator.
432 Follow the procedures outlined in Sections 4.2.2
through 4.2.7, except for the following: Traverse all
sampling points and sample at each point for an equal
length of time. Record sampling data as show n in Figure
3-3.
S. Leak-Cluck Proeciluri for Ortal Analy:irt
Moving an Orsat analyzer frequently causes it to leak.
Therefore an Orsat analyzer should be thoroughly leak-
checked on site before the flue eas sample is introduced
Into it. The procedure for leak-checking an Orsat analyzer
8.1.1 Bring the liquid level In each pipette up to the
reference mark on the capillary tubing and then close the
pipette stopcock.
412 Raise the leveling bulb sufficiently to bring the-
confining liquid meniscus onto the graduated portion of
the burette and then close the manifold stopcock.
51.3 Becord the meniscus po.-ition.
514 Observe the meniscus in the burette and the
liquid level in the pipette for movement over the next 4
"Yui For the, Orsat analyzer to pass the leak-check,
two conditions must be met.
5151 The liquid level In each pipette must not fall
below.the bottom of the capillary tubing during this
4-mlnutelntcrva). •
i 1 5 2 The meniscus In the burette must not change
by more than 0.2 ml during this 4-minute interval.
5 1 « If the analy tcr fails the leak-check procedure, all
rubber connections and stopcocks should be checked
until the cause ofthe leak is Identified. Leaking stopcocks
must be disassembled, cleaned, and regreased. Leaking
rubber connections must be replaced. After the analyrer
Is reassembled, the leak-check procedure must be
repeated.
8. Calculntiont
8.1 Nomenclature.
Mj— Dry molecular »eight, g.g-mole (Ib/lb-mole).
%EA-Percent excess air.
%COi-Percent COiby volume (dry basis).
%Oj—Percent Oi by volume (dry basis).
%CO-Percent CO by volume (dry basis).
%Ni-Percent Niby volume (dry basis).
0.204= Ratio of Oi to Nj in air, v/v.
0 280-Molecular weight of Ni or CO, divided by 100.
0.320-;Molecular weight of Oi divided by 100.
0.440-Molccular weight of COi divided by 100.
6.2 Percent Excess Air. Calculate the percent excess
air (if applicable), by subslituling the appropriate
values of percent Oi, CO,and Ni (obtained from Section
4.1.3 or 4.2.4) into Equation 3-1.
%0,-0.5%CO
I \f]Q
).2G4%N,(%0,-0.5%CO)J ""
Equation 3-1
NOTE—The equation above assumes that ambient
air is used as the source of Oi and that the fuel does not
contain appreciable amounts of Nt (as do coke oven or
blast furnace gases). For those cases when appreciable
amounts of Ni are present (coal, oil, and natural gas
do not contain appreciable amounts of NI) or when
oxygen enrichment is used, alternate methods, subject
to approval of the Administrator, are required.
63 Dry Molecular Weight. Use Equation 3-2 to
calculate the dry :nolecular weight of the stack gas
Wi=0 440(CiCO.')+0 320(^O:)-r0.280(7cNi+';
-------
FILTER
(EITHER IN STACK
OR OUT OF STACK)
.*
STACK
WALL
CONDENSER-ICE BATH SYSTEM INCLUDING
SILICA GEL TUBE —7
AIR-TIGHT
PUMP
Figure 4-1. Moisture sampling train-reference method.
2.1.1 Probe. The prob« is constructed of stainless
iteel or glass tubnuj, sufficiently heated to prevent
water condensation, and is equipped with a filter, either
In-stack (e.g,, a plug of glass wool inserted Into the end
of the probe) or heated out-slack (e.g., as described in
Method 5), to remove particulale matter.
When stack conditions permit, other metals or plastic
tubing may be used for the probe, subject to the approval
of the Administrator.
2.1.2 Condenser. The condenser consists of four
Imjtinjrers connected in scries with ground glass, leak-
free liltlncs or any similarly leak-free non-contaminating
fittings. The first, third, and fourth impingers shall be
of the Greenburg-Simlh design, modified by replacing
the tin with a 1.3 centimeter (M inch) II) glass tube
extcnojrg to about 1.3 cm ($$ in.) from the l>ottom of
tli« flask. The second inipiiiper shall be of the Greenburg-
Brmlh design with the standard tip. Modifications (e.g.,
D5inc flexible ronnecnons bw ween the impinecrs, using
material* other than class, or usins flexible vacuum lines
to connect the filter holder to the condenser) may bo
used, subject to the approval of the Administrator.
Tbe first two Impmcers shall contain known volumes
of water, the third shall be empty, and the fottrth shall
contain a known weight of 6- to 10-mesh Indicating type
silica gel, or equivalent desiccant. If the silica gel has
been previously used, dry at 175° C (350° F) for 2 hours.
New silica gel may be used as received. A thermometer,
capable of measuring temperature lo within 1° C (2° F),
shall be placed st the outlet of the fourth linpinger, for
monitoring purposes.
Alternatively, any system may be used 'subject to
the appioval of the Administrator) that roots the sample
gas s'.rearo and allows ncasurcment of both the water
that ha:> been condensed and the moisture leaving the
condenser, each to within 1 ml or 1 g. Acceptable means
are to jneasure tbe condensed water, either gravi-
metrically or volumetrically, and to measure the mois-
ture leaving the condenser by: (1) monitoring tbe
temperature and pressure at the exit of the condenser
and using Dallon'5 law of partial pressures, or (2) passing
the sample gas stream through a tared silica gel (or
equivalent disiccant) trap, with exit gases kept below
20° C (68° F) and determining the weight gain.
It means other than silica get are used lo determine the
amount of moisture leaving the condenser, it is recom-
mended that silica gel (or equivalent) still be used be-
tween 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 roetered volume
2.1.3 Cooling System An ice bath container and
crushed ice (or equivalent) are used to aid in condensing
moisture.
2.1.4 Metering System This system Includes a vac-
uum gauge, leak-free pump, thermometers capable of
measuring temperature to within 3° C (5.4° F), dr> gas
meter capable of measuring volume to within 2 percent,
and related equipment as shown in Figure 4-1. Other
metering systems, capable of maintaining a constant
sampling rate and determining sample gas volume, may
be used, subject to the approval of the Administrator.
2.1.5 Barometer Mercury, aneroid, or other barom-
eter capable of measuring atmospheric pressure to within
2.4 mm Hg (0 1 in. OB) may be used. In many ca^cs. the
barometric reading may be obtained from a nearby
national weather service station, in which case the sta-
tion value (which is the absolute baromelric pressure)
shall be requested and an adjustment for elevation
differences between the weather station and the sam-
pling point shall be applied at a rate of minus 2.5 mm Hg
(0.1 in. Hg) per 30 ra (I(10 ft) elevation iucrca.se or rice
versa for elevation decrease.
2.1.8 Graduated Cylinder and/or Balance. These
Items are used to measure condensed water and mot-lure
caught in the silica gel to within I ml or 0.4 g. Graduated
cylinders shall have subdivisions no greater than 2 ml.
Most laboratory balances are capable of weighing to the
Dearest 0.4 g or less. These balances are suitable for
nse here.
2.2 Procedure. The following procedure Is written for
a condenser system (such as the impinger system de-
scribed in Sectinn 2.1 2) incorporating volumetric analy-
sis to measure the condensod moisture, and silica gel and
gravimetric analysis to measure tbe moisture leaving lh«
condenser
2.2.1 Unless otherwise specified by the Administrator,
a minimum of eight traverse points shall be used for
circular stacks having diameters less than O.G1 m (24 in.),
a minimum of uiue points shall be used for rectangular
stacks having equivalent diameters less than 0.61 m
(24 in ). an^ a mi.nmum of twelve trovers points shall
be used in all other cases. The traverse points shall tie
located according to Method 1. The use of fewer points
is subject to the approval of the Administrator. Select a
suitable pr«/['e and probe length such that all traverse
points can »•* sampled. Consider sampling from op|H>sit«
sid< s of the 5'.3>~k (four total sampling ports) for large
stacks, to permit u=e of shorter probe lengths. Mark the
prube with heat nsislant tain* or by some other method
to denote the pror>er distance into the stack or duct for
each sampling point. Place known volumes of water in
the first two nnpingcrs. Weigh and record the weight of
the silica gd to the nearest 0.5 g, and transfer the silica
•RC) to thr Jourth implnger; nltenmlively, the silica gel
may first i* transferred to the impinger, and the weight
of the sihra pel plus impinger reeordcd.
2.2.2 Erl»cl a total sampling time such that a mini-
mum total ras Tuluine ol UM sen (21 set) »jj) be col-
lected, at a rate no greater than 0.021 m'/mln 10.75 clni).
When both moistuie content and pollutant emission raU
are to be determined, the moisture determination shall
be simultaneous with, and lor the same total length of
time as. the pollutant emission rate run, unless othcrwiat
spccl.ied in an applicable subpart of the standards.
2.2.3 Stt up the sampling train as shown in Figurm
4-1. Turn on tbe probe healer and (if applicable) tn«
filter holing system to temperatures of about 12(f O
(248° F), to prevent water condensation ahead of tut
eondcnwr. allow time for the temperatures to stabilize.
Place crushed ice in the Ice bath container. It is recom-
mended, but not required, that a leak check be done. M
follows: Discoorject the probe from the first implncer or
-------
(If applicable) from the (liter hoMer. P!ug the Inlet to the
first impincer (or alter holder) and pull a KO mm (IS in.)
He vacuum »lower vacuum may be us^d. provided that
it is not exceeded during the test. A irakage rate in
excess ol 4 percent o( the avcraje sarai,l.n3 rate or O.OOOJ
m'/min (0.02 cfm). whichever is less, is unacce plable. •
Following the eak check, reconnect the probe to tne
sampling train.
224 During the sampling run. maintain a sampling
rate within 10 percent of constant rate, or as specified by
the Administrator. For each run. record the data re-
quired on the example data sheet shown in Figure 4-2.
Be sure to record the dry cas rr.et<>r reading at the begin-
ning and end of each sampling time increment and »'hen-
PLANT_
: DCATICm..
OPERATOR
RUN N0._ __
AMBIENT TEMPERATURE.
BAROMETRIC PRESSURE.
PROBE LENGTH mlh) _
ever sampling Is halted. Take other appropriate readings
at each sample point, at least once during each tun*
Increment. . .
2 2.5 To begin sampling, position the probe tip at the
first traverse pouit. immediately «tart the pump and
adjust the flow to the desired rate. Traverse the cross
section sampling at each traverse point for an equal
length of time Add more ice and, if necessary, salt to
maintain a temperature of less than 20° C (13° F) at the
silica gel outlet.
2.2.6 Aft«r collecting the sample, disconnect the probe
from the Glter holder (or from the first Impmgcr) and con-
duct » leak check (mandatory) as described in Section
Z2 .3. Record the leak rote. If the leatise rate etceeds thi
allowable rate, the tester shall either rejeit the test re
suits or shall correct the sample volume as in PecUon ft.l
of Method 5.Next, measure the volume of the moistur«
condensed to the nearest ml. Determine the increase in
weight of the silica gel (or silica gtl plus Impincor) to the
nearest 0 5 g Beiord this information (see example data
sheet. Figure 4-3) and calculate Use moiiture percentage,
as described in 2.3 below.
2 3 Calculations. Carry out the following calculations,
retaining at least one eitra decimal figure beyond that ol
the acquired data. Bound ofl figures after final calcula-
tion.
SCHEMATIC OF STACK CROSS SECTION
TRAVERSE POINT
NUMBER
======
•
TOTAL
AVERAGE
SAMPLING
TIME .
(0). mie,
=====
•
.
STACK
TEMPERATURE
•C ("F»
-•- 1
.
•
PRESSURE
DIFFERENTIAL
ACROSS
ORIFICE METER
(AH).
mmliiU H;0
METER
READING
GAS SAMPLE
VOLUME
m3 (ft3)
•
AVm
m3(ft3>
-
GAS SAMPLE TEMPERATURE
AT DRY GAS METER
INLET
(TmiB).QC(*F)
-
*»».
Avo..
OUTLET
fTm.rtl.'CPH
-
A»i.
TEMPERATURE
OF GAS
LEAVING
CONDENSER OR
LAST IMPINGER,
«C {°F>
"
Figure 4-2. Field moisture determination-reference method.
11-49
-------
riNM.
INITIAL
DIFFERENCE
IWINGfK
VOLUME,
nl
•
SMCA GEL
»tK5Ht.
•
Figure 4 3. Analytical d»U • reference method.
2.S.1 Nomenclature.
^..-Proportion of water vapor, by volume, In
the gas stream.
MW- Molecular weight ol water, 18.0 g/fe-mo)e
(Ig.Olb/lb-mole).
P_-=Absolute pressure (for this method, same
as barometric pressure) at the dry gas meter,
nun Hg (in. Eg).
J>,,w=Siandard absolute pressure, "CO mm Hg
(29.92 In. Hg).
" .R=ldeal gas constant, O.OC236 (mm Hg) )/
(K-mole) (°K) for metric units and 21.85 (in.
Hg) (ft«)/(lb-mole) <°R) for Enclish unlta.
T.= Absolute temperature at meter, *K (°R).
T.n=Standard absolute temperature, 293° K
.(S2S°R).
Vm™ Dry gas volume measured by dry gas meter,
dcm (del).
AV.-Incramcntal dry gas volume measured by
dry gas meter at each traverse point, dcm
(def).
V.<.i*>=Dry gas volume measured by the dry gas
meter, corrected to standard conditions,
dscm (dscf). . .
V..(.n>~Volume of water vapor condensed corrected
to standard conditions, tern (act).
Vm*t (• «) —Volume of water vapor collected fa silica •
gel corrected to standard conditions, son
(scO.
V/- Final volume of condenser water, ml.
Vi** Initial volume, if any, of condenser water,
ml.
»',= Final weight of silica gel or silica gel plus
IT,-* Initial weight of silica gel or silica gel plus
Impinger, g.
y— Dry gas meter calibration factor.
p.- Density of water, 0.9982 g/ml (0.002201
Ib/ml).
2.3.2 Volume of water vapor condensed.
Equation 4-1
where:
.Ki«0.001333 UI'/JD! for metric Units
=0.04707 Iti/ml lor English units
5.8.3 Volume of water vapor collected in silica gel.
„ (Wf-Wi)RT.«
Equation 4-2
• 7*.-,
(Tm)
KfjuulUm 4-3
whore:
A">=0.3oS8 "K/mni Dg for metric units
= 17.61 °Rlin. Ug tor English units
NOTE.—If the post-test leak rate (Section 226) ei-
ceeds the allowable rate, correct the value of V. in
Equation 4-3, as described In Section 6.3 of Method 6.
2.3.5 Moisture Content.
IT _L. If
r> v*t (tH) ~1" ' *•" <""O
where:
iT,-0.00)33i mVft tor metric units
-0.04716 ft'/g for English units
2.1.4 Sample gas volume.
're («td) T • vit («l
Equation 4-4
NOTE —In saturated or moisture dioplet-ladcn gas
streams, two calculations ol the moisture content of the
stack eas shall be made, one usinp a value based upon
the saturated conditions (see Section 1.2), and another
based upon the results of the impinper analysis. The
lower of these two values of B.. shall be considered cor-
rect.
2.3.0 Verification of constant sampling rate. For each
time Increment, determine the Al'«. Calculate the
average. If the value for any time increment differs from
the average by more than 1" percent, reject the results
and repeat the run.
3. Approximation Mtthod
The approximation method desinix'd below is pre-
sented only as a suggested method (set Section 1.2).
3.1 Apparatus.
. 3.1.1 Probe. Stainless steel or glass tubing, sufficiently
heated to prevent water condensation and equipped
with a filter (either in-slack or healed out-slack) to re-
move particuiale matter. A plug of glass wool, inserted
Into the end of the probe, is a satisfactory filter.
3.1.2 Impingers. Two midget Impingers, each with
30 ml capacity, or equivalent.
3.1.3 lc« Bath. Container and ice, to aid in condens-
ing moisture in impingers.
3.1.4 Drying Tube. Tube packed with new or re-
generated 6- to 16-mesh indii-atmc-tvpe silica gel (or
equivalent desiccant), to^dry the samjOe gas and to pro-
tect the meter and pump.
3.1.5 Valve. Needle valve, to regulate the sample gas
flow rale.
3.1.6 Pump. LeaV-free, diaphragm type, or equiva-
lent, to pull the gas sample through the train.
3 1.7 Volume meter. Dry gas meter, sufficiently ac-
curate to measure the,sample volume within 2%, and
calibrated over the range of flow rates and conditions
actually encountered during sampling.
3.1.8 Rate Meter. Rotameter, to measure the flow
range from 0 to 31pm (I) to 0.11 cfru).
3.1.9 Graduated Cylinder. 25ml.
3.1.10 Barometer. Mercury, aneroid, or other barom-
eter, as described in Section 2.1.5 above.
3.1.11 Vacuum Gauge. At least 760 mm He (30 in.
Bg) gauge, to be used (or the sampling leak check.
3.2 Procedure.
3.2.1 Place eiactly S ml distilled water In each im-
pinger. Assemble the apparatus without the probe as
shown in Figure 4-4. Leak check the train by placing a
vacuum gauge at the lulet to the first impingcr and
drawing a vacuum of at least 250 mm Bg (10 in. Hg),
plugging the outlet of the rotametcr, and then turning
off tie pump. The vacuum shall remain constant for at
east one minute. Carefully release tbe vacuum gauge
Ibefore unplugging the rotameter end.
11-50-
-------
HEATED PROBE
SILICA GEL TUBE
RATE METER,
VALVE
MIDGET 1MPINGERS PUMP
Figure 4-4. Moisture-sampling train - approximation method.
LOCATION.
TEST
COMMENTS
DATE
OPERATOR
BAROMETRIC PRESSURE.
CLOCK TIME
m
GAS VOLUME THROUGH
METER, (Vm)*.
m3 (ft3)
_
RATE METER SETTING
mVmin. (ft3/min.)
METER TEMPERATURE,
°C (°FJ
•
Figure 4-5. Field moisture determination - approximation method.
11-51
-------
T" Cmu "-••
rnV.Vii' ac/>-
-":,," u'lil ti
,,r4 (, l I,.., or r,
r Irn- tl,f I.r
""
t U IM'.O ll.e •' .A a:i.cui.l
' I"1'*
ir,"o!
do
334 A-I'l
; of t.e t c
the '--aiple. a.c.Wnf the con-
r, ,»d mclur, the voS^e to tb.
"U(?y" c. vniaiions Tlif c-'cul-tlon method prevnted is
detuned to en.fate the moisture in the nack fas;
ihe^,/ore other data, which are only necessary for iao-
ciirete moisture due'ninMions. are not-collected. The
In lowlnn eouauon. adequately eslimatf the moisture.
content for the pi_-Sx^ ol determining tokinetlc sam-
plinp role wturzs.
331 Nornrrr'a'ure.
B . —Appronr^ale proportion, by volume, ol
"" ualer vapor in the cas stream leaving the
secord in:p:nper, O.CCi.
B.. = V. ft!" vapor in tlie cas stream, proportion oy
A/.-Jlolecuiar wclcbt of water, 18.0 g,'g-mole
(18 0'bib mole)
P -Xb'o'ute pressure (for this method, same as
taro'rr.etric pn.iswre) at the dry fas mfleT^
P ,j=.Smrr:«rd sl.solute pressure, .00 mm tig
' (Vj tr- i*n 11 e)
P = Ideaf C'TS en-!sUmt, 0 OG3S (mm Hg) (m^/
(B-mole) (°K) for metnc units and 21 JO
(m Ug) (ff)/lb-mole) (°R) for Engtab
units. er /«n\
T. = Absc',ute temperature at meter, Ik. ( JU
T .jDElar.dard absolute temperature, ."JJ li.
* (528° R)
V',- Final volume of implnper contents, ml.
V.-Initial voUimeofimpinpej-conteJils.ini.
V. = Dry pas volume measured by dry gas meter,
1' i m=-Drv pas volume measured by dry gas meter,
• corrected to ttandard conditions, dscm
V i ,<>=Vo!uine of water Tapor condensed, corrected
" , .^^^t^S^W&BOlIb/tal).
Volume of water vapor collected.
332
<__ -f (0025)
Equation 1-7
procedure ol Method 5, Action S.7 to cV.ibrjie the
barometer.
5. Btt'ltofTap^l
1. Air roUution Eiicincrriii^Manual |5< coi.d Edition).
Dan
ASe
Re».
1923'Devorkin. Howard, et »1 Air Pollution Fource Test-
ing'Manual. Air I'olluuon Control District, Los Angeles,
Calif. N""ml^. «2«- .. -,,,lty. Volume.
amebon, I. A. (ed ). L'.S. tnvirom: en:al I roietiion
cency. OfTice of Air Duality IMauning »nd t-landards.
e'earcii Triangle Park, K.C. 1'ublication No. A}'-10.
'i'bevorkin. Howard, et »1 Air Pollution Fource Test-
m'Manual. Air I'olluuon Control District, Los Angeles,
""^''M^thods tor' Determination of Velocity, Volume.
Dust and Mist Content of C.v W^tem rrecipMatiou
Division of Joy Manufacturing Co , Los Angeles, Call!.
Bulletin W P-40. 1968.
•tr
'ire — "
Equ.-xtion 4-5
K, = 00013.13 n.'.inl 'or metric units
-0 04707 fl'.ml for Engluh units.
3.3 3 Gas volume.
Tm
Equation 4-6
T h', = 0 3RM "Konio TTf! for metric units
= 17.M °R/m HE for English units
11-52
-------
WETHOH «— DITEKMIXATION or St'iri it nioin-x
Emssioss Faou STATIO.SAM EUVKILS
1. Ptiucifb *»4 Awiutbilitf
1.1 Principle A mi sample is «lre<-l<>d from the
sampling point in the stack. Tbe sulfuric acid mm
Uncludjng sulfur tnoxide) and tbe «ulfur dioxide arr
separated Tbe sulfur dioxide Irecuon 15 measured by
toe barium-tborin tnretion method.
1.2 Applicability This met bod u applicable (or tbe
determination of sulfur dioude emissions from stationary
sources. Tbe minimum detectable limit of dropen peroiide. at a rale ol 1 0 1pm for
X minute;. Baaed on theoretical calculations. Uie upper
concentration limit in a 20-luer sample is about W.XX
me'm'.
Possible Interlerenu are free ammonia, water-toluble
cations, and fluoride;. The cations and fluorides are
removed by tlass * ool fillers and an isopropaiiol bubbler.
and benoe do not affect the SO; arialvju * hen sampler
are beinf takrn from a ras stream with lugh concentra-
tions of very line metallic fumes (nub as In Inlrlt to
control devices), a hich-emacncy glass nlxr filler mu.«i
be used in plan of the glass wool plug ti e., tb* one in
the probe1 to remore the ration inierftrem?
Fr«e anunouia interferes by reacting v.ith SOi to form
Paniculate lulfiie and by reacting with tbe indicator
If free ammonia » present (tbis ean be determined by
knowledge of the process and nolu-mf while paniculate
•latter in the probe and isopropenol bubble:), alterna-
tive metliods. subject to the approval ol tbe Adrniiustra
tar, U.S. Environmental 1'rciMion Agency, an
required.
11 Sampling. _ _.
*-!, and component parts are discussed below. ~Tbe
tester bai the option of substituting sampling equip-
ment described In Metbod 8 in place of tbe midget 1m-
plnger equipment of Metbod 6 However, tbe Method 8
train must be modified to Include a heated filter between
the probe and laopropanol impinger, and tbe operation
of the sampling train and sample analysis must be at
the flow rates and aolution volumes defined in Metbod 8
The tester also has the option of determining SGi
simultaneously with paniculate matter and moisture
determinations by (1) replacing the water In a Metbod i
impinger system with t percent perioxide solution, or
OK by replacing the Metbod i water impinger system
with a Metbod 8 Isopropanol-filter-peroxlde system. Tbe
analysis for SOi must be consistent with tbe procedure
IB Method 8.
11.1 Probe. BorosUicate glass, or stainless steel (other
materials of construction may be used, subject to tbe
approval of the Administrator), approximately 6-mm
inside diameter, with a beating system to prevent water
condensation and a filter (either In-slack or heated out-
ftack) to remove paniculate matter, Including luUuric
add mist. A plug of glass wool Is a satisfactory filter.
11.2 Bubbler and Impingen. One midget bubbler,
with medium-coarse glass (rlt and borodllou or quaru
(lass wool packed In top (see Figure 6-1) to prevent
•ulfuric acid mist carryover, and tone SO-ml midget
Impingen Tbe bubbler and midget Implngers must be
connected in series with leak-free glass connectors. 8111-
sooe rreue may be used. If necessary, to prevent leakare
At tbe option of tbe tester, a midget Impinger may be
•ad In place of tbe midget bubbler.
Other collection absorbers and flow rates may be used,
but are subject to tbe approval of tbe Administrator.
AJeo, collection efficiency must be shown to be at least
W percent for each t«ct run and must b« documented in
the report If tbe efficiency Is found to be acceptable after
a series of three tests, further documentation is not
required. To conduct the efficiency test, an extra ab-
sorber must be added and analyted separately. This
extn absorber must not contain more than t percent ot
the total BOi.
11J Glass Wool. BorosUIcate or quarts.
11.4 Stopcock Greene Acetone-Insoluble, beat-
stable slllcone grease may be used. If necessary.
11.5 Temperature Oauge Dial thermometer, at
equivalent, to measure temperature of gas leaving 1m-
ptnger train to within 1«C(2*P.)
11 e Drying Tube Tube packed with ft- to It-mash
tndiceHng; type silica (el, or equivalent, to dry tbe (a>
sample and to protect the meter and pump. If tbe slllac
eel has been used previously, dry at 116' C (ISO* F) lor
t hours. New sUica gel may be used as received. Alterna-
tively, other types of desiccajits (equivalent or better)
Bay be used, subject to approval of tbe Administrator.
11.7 Value. Needle value, to regulate sample (as flow
rate.
11J Pump. Leak-free disphragm pump, or equiv-
alent, to pull gas through tbe train. Install a small tank
between tbe pump and rate meter to eliminate the
pulsation eflect of the diaphragm pump on tbe rotaineter.
ll.f Rate Meter. Rotameier. or equivalent, capable
or measuring-flow rate to within ] percent of the selected
low rate of about 1000 certain
11.10 Volume Meter. Dry gat meter, sufficiently
•eeorete to measure the sample volume within 2 percent,
etJIbraUKl at tbe selected flow rate and conditions
actual!) encountered dunn* sampling, and equipped
with a temperature (auge (dial thermometer, or eqtiiv-
^*) capable of measuring temperature to within
11.11 Barometer. Mercury, ameroid, or other berom-
. "P*?1' °' measuring atmospheric pressure to within
14 mm Bg (0 1 in Hg) In many eases, the barometric
reading ma> be obtained from a nearby national weather
•rrloe station, In which ease the station value (which
Is the absolute barometric pressure) shall be requested
and an adjustment tor elevation differences between
the weather station and sampling point shall be applied
•t a rate of mm us 2.S mm Hg (0.1 In. Hg) per Mm (100 ft)
elevation Increase or rice versa for elevation decrease
11.12 Vacuum Gauge. At least 760 mm Hg (30 In
Hg) gauge, to be used tor leak check of the sampling
12 Sample Recovery.
12.1 Wash bottles. Polyethylene or (lass, MO ml,
two.
12.2 Storage Bottles Polyethylene, 100 ml, to store
Impinger samples (out par sample)
t.t Analysis
14.1 Pipettes. Volumetric type, 5-ml, 10-ml (one per
sample) , and 24-ml sixes.
11.2 Volumetric Flasks. 100-ml slse (one per sample)
•nd 100-ml slse.
ll.l Burettes. S- and SO-ml sites
11.4 Krlenmeyer Flasks. 260 mi-else (one lor each
•ample, blank, and standard).
11.6 Dropping Bottle 124-ml slse, to add indicator.
11.6 Graduated Cylinder. 100-ml slse
1>.7 Spectropbotometor. To measure absorbance a.
att nanometers
Unless otherwise Indicated, all reagents must conform
to the specifications established by tbe Committee on
Analytical Reagents of the American Chemical Societj
Where such specifications are not available, use tbe best
available grade.
1.1 Sampling.
1.1.1 WaterTbeionlsed, distilled to conform to ABTM
specification D1193-74, Type 3. At tbe option of the
analyst, tbe KMnO4 test lor oxidirsble organic matter
msy be omitted when high concentrations of organic
matter are not expected to be present.
1.1.2 laopropanol.tOpercent.MugOmloflsopropanol
with 20 ml of deioniied, distilled water. Check each lot of
laopropanol for peroxide Impurities as follows shake 10
ml of Isopropanol with 10 ml of freshly prepared 10
percent potassium Iodide solution Prepare a blank by
similarly treating 10ml of distilled water After 1 minute,
read tbe absorhence at K2 nanometers on a spectro-
photometer. If absorbance exceeds 0.1, reject alcohol tor
use
Peroxides may be removed from isopropanol by redis-
tilling or by passage through a column of activated
alumina; however, reagent grade laopropanol with
suitably low peroxide levels may be obtained from com-
mercial sources Rejection of contaminated lots may,
therefore, be a more efficient procedure
1.1.1 H)droren Peroxide, 1 Percent. Dilute 10 percent
hydrogen peroxide 1:* (v/v) with deiomied. distilled
water (10 ml Is needed per sample). Prepare fresh dally
1.1.4 Potassium Iodide Solution, 10 Percent Dissolve
10.0 grants KI in delonited, distilled water and dilute to
100 ml. Prepare wben needed.
1.2 Sample Recovery
1.2.1 Water. Deionited, distilled, as In 2 1.1.
1.2.2 Isopropanol. 80 Percent MiiSOmlofuopropano!
with 20 ml of cfeloniied, distilled water
».l Analysis
Ml Water Deionited, distilled, as In S.I. 1
1.1 2 laopropanol, 100 percent
11.1 Thorin Indicator l-(o-ersonopnenylazo)-2
napbtbol-3,6-disulfonic arid, disodium salt, or equiva-
lent Dissolve 0.20 g In 100 ml of deiomied, distilled
144 Barium Perchlorate Solution, 0.0100 N Dis-
solve 1 H . of barium perchloret* trihydrate (B»(C]O.)i
IHiOJ in 200 ml distilled water and dilute to 1 liter with
sopropanol Alternatively. 1 22 g of (B«Cli-2H.O| rn»>
be used Instead of tbe perchlorate Standardise as In
Section 4.5.
1.1.5 Sulfuric Acid Standard, 00100 N. Pun-has* or
standardise to *0 0002 N against 0 0100 N NaOH which
has previously been standardized against potassium
add phthalate (primary standard grade)
4. Pnature.
4.1 Sampling
4.1.1 Preparation of collection train Measure 15 ml of
SO percent isopropanol into the midget bubbler and 15
ml of 3 percent hydrogen peroiide into each of the first
two midget Impingen Leave the final midget Impinger
dry Assemble tbe train as shown In Figure 6-1 Adjust
probe heater to a temperature sufficient to prevent water
condensation. Place crushed ice and water around the
Impingen
4 I 1 Leak-check procedure A leak check prior to the
sampling run is optional however, a leak cherk after the
sampling run Is mandatory Tbe leak-check procedure is
as follows-
With the probe disconnected, place a vacuum Range at
tbe inlet to the bubbler and pull a vacuum of 250 mm
(10 In ) Bg. plug or pinch off the outlet cf tbe flow meter.
and then turn off the pump The vacuum shall remain
stable for at least 30 seconds Carefully release the
vacuum gan«e before releasing tbe Row meter end to
prevent back flow of the Impinger fluid
Other leak check procedures may be used subject to
the approval of the Administrator, U 8 Environmental
Protection Agencv The procedure used In Metbod 5 Is
not suitable for diaphragm pump*
4 I 3 Sample collection Record the Initial dry gas
meter reading and barometric pressure To begin sam-
pling, position the tip of the probe at the sampling point,
connect the probe to the bubbler, and start the pi imp
Adjust the sample flow to a constant rate of ap-
proximately 1 0 liter'mln »i Indicated by tbe rotsmeter
Maintain this constant rate (*10 percent) during the
entire sampling run Take readings (dry gas meter,
temperatures at dry gas meter and at Impinger outlet
and rate meter) at least every S minutes Add more Ice
during the run to keep the temperature of tbe gases
leaving the last Impinger at 20" C («• F> or less At the
conclusion of each run, turn off the pump, remove probe
from tbe 'tack, and record tbe final readings Conduct a
leak check as In Section 4.1 2 (This leak check is manda-
tory ) If a leak Is found, void tbe test run. Drain the tee
bath, and purge the remaining part of the train by draw-
ing clean ambient air through the system for 15 minutes
at the sampling rate
Clean ambient air can be provided by passing air
through a charcoal filter or through an extra midget
Impinger with 15 ml of S percent HiOt The tester may-
opt to simply use ambient air, without purification.
4.2 Sample Recovery. Disconnect the uapingers after
purging DiscardthecontentsoftbemJdgetbubbler Pour
tbe contents of the midget Impingers into a leak-free
polyethylene bottle for shipment. Rinse the three midget
Impingers and tbe connecting tubes with delonlxed,
distilled water, and add the washings to the same storage
container Mark the fluid level Seal and Identify the
sample container.
4.1 Sample Analysis. Note level of liquid In container,
and confirm whether any sample was tost during ship-
ment, note this on analytical data sheet If a noticeable
amount of leakage has occurred, either void tbe sample
or use methods, subject to tbe approval of the Adminis-
trator, to correct the final results
Transfer tbe contents of tbe storage container to a
100-ml volumetric flask and dilute to exactly 100 ml
with deionlted, distilled water. Pipette a 20-ml aliquot of
this solution into a 250-ml Erlenmeyer flask, add 10 ml
of 100 percent Isopropanol and two to four drops of thortn
Indicator, and titrate to a pink endpoint using 0 0100 N
barium perchlorate Repeat and average the titration
volumes Run a blank with each series of samples Repli-
cate tltrations must agree within 1 percent or 0.2 ml,
whichever Is larger.
(NOTI—Protect the 0.0100 N barium parchlorato
solution from evaporation at all times.)
S. OaHoratton
5.1 Metering System.
5.1.1 Initial Calibration. Before Its initial use in tbe
field, first leak check the metering system (drying tube.
needle valve, pump, rotameter, and dry (as meter) as
follows- place a vacuum gauge at the inlet to the drying
tube and pull a vacuum of ISO mm (10 In.) Hg- plug or
pinch off the outlet or the flow meter, and then turn off
the pump. The vacuum shall remain viable tor at least
10 seconds. Carefully release the vacuum (auge before
releasing the flow meter end.
Next, calibrate the metering system (at the —mpHnf
flow rate specified by the method) as follows: connect
an appropriately sited wet test meter (e.g., 1 liter per
revolution) to the Inlet of the drying tube. Make three
Independent calibration runs, using at least five revolu-
tions of the dry gas meter per run. Calculate the calibra-
tion factor, X(wet test meter calibration volume divided
by the dry gas meter volume, both volumes adjusted to
the same reference temperature and pressure), lor each
run, and average the results. U any rvalue deviates by
more than 2 percent from the average, tbe metering
system Is unacceptable for use. Otherwise, use tbe aver-
age as tbe calibration factor tor subsequent test run*.
6.1.2 Post-Ten Calibration Check. After each field
ten series, conduct a calibration check as In Section 1.1.1
above, except for tbe following variations: (a) tbe leak
check Is not to be conducted, (b) three, or more revolu-
tions of tbe dry gas meter may be used, and (c) only two
independent runs need be made. If tbe calibration factor
does not deviate by more than 5 percent from the Initial
calibration factor (determined In Section 5.1.1), then tbe
dry gas meter volumes obtained during the test series
are acceptable. If the calibration factor deviates by more
than 5 percent, recalibrate the metering system as In
Section 5.1.1, and for the calculations, use the calibration
factor (Initial or racalibration) that yields the lower gas
volume for each test ran.
11-53
-------
5.2 Thermometers. Calibrate against mercnry-irj-
(lass thermometers
4.S Rotazneter. The rotameter need not be calibrated
but should be cleaned and maintained according to the
manufacturer's Instruction.
t.4 Barometer. Calibrate against a mercury barem-
•Ur.
4.4 Barium Perchlorate Solution. Standardise tbe
barium percblorau solution against 25 ml of standard
suifuric acid to which 100 ml of 100 percent Isopropanol
has bean added.
«. OfcmtoHoax
Carry oat calculations, retaining at least one extra
decimal figure beyond that of the acquired data. Bound
off figures after final calculation.
»_1 Nomenclature.
C.-Concentration of sulfur dioxide, dry bads
' corrected to standard conditions, mg/dscm
(lb/dacf).
JV-Normality of barium parchknate titrant,
mill) equivalents/ml.
J".!,.,-Barometric pressure at tbe exit orifice of the
dry gas meter, mm Hg (In. Bg).
/>„<-Standard absolute pressure, 760 mm Hg
(29.92 in Hg).
Tm-
•Arente dry ft* meter tbtolute temperatnn,
•K CR)
JW K
1 'MI-Standard absolute temperature,
(528° R).
V.. Volume of sample aliquot titrated, ml.
V.-Dry gas volume as measured by tbe dry gas
-.dcm(dcf).
V.(_j)-Dry fM volume meemred by tbe dry |»
maur. enrecMd to atandard eondltloni,
daem (d*ef).
VMu-Tota! volume of tolotlon In which tbe lullor
dioxide auople Is contained. 100 ml.
Vi-Volume of bartoin percblorat* tltnnt oaed
tor tbe sample, ml (tTerafe of repllcaU
tloatlons).
Vn-Volume of barium percblorate Utrant used
for the blank, ml.
K-Dry cu meter calibration (actor.
12.03-Equivalent wriiht of sulfur dioxide.
a.2 Dry (ample fw Tolume, corrected to itandard
eondlUons. V. Pto,
-
JTi-0 mat •K/mm HI far metric unit*.
-17.M*R/ln. B( lor En»ll»h unit*.
M Sulfur dioxide concentration.
(V,-V«)
C
•O-
wtaen-
Jfi-X2.03 mi/meq. for metric onlti
•r.OMX10-*lb/iiwq. tor Bnfllab unit*.
Eqoatloo a-2
7.
I Atmonphtrlc Emiasloni from SuJfuric Add Manu-
ttcturlni Procrsara. D 8 UHEW. PRR. DIvLilon of Air
Pollution Public Health Service Publication No.
VM-AP-13 Cincinnati. Ohio 19A5.
2. Corbett, P. T. The D«t*rmlnatlon of SOi and BOi
in Flue Oaaea. Journal of the Institute of Fuel. fi. 237-
241, 1M1.
* Matty. R. E. and E. E. Dlehl. Meanirlnt; Flue-Ow
BOi and BOi. Power. 101: 9*-97 November 1M7.
4. Patton.W. F.andJ. A. Brink. Jr. New Equipment
and Techniques for Sampllnf Chemical Process Uasn.
J. Air Pollution Control Association IS 182 1963
S. Rom. J. J. Maintenance, Calibration, and Operation
of laokinetic Souree-Sampunc Equipment Office of
Air Protrrams, Environmental Protection Afency
Research Triangle Park, N.C. APTD-0676. March 1V77.
«. Hamll, H. F and D. E. Camann. Collaborative
Study of Method for the Df terminal ion of Sulfur Dioxide
Emlaiions from Stationary Sources (Fossil-Fuel Fired
Steam Generators) Environmental Protection Agency,
Research Triangle Park, N.C. KPA-«40/4-7*-034.
December 1971.
7. Annual Book of ABTM Standards Part 31. Water,
Atmospheric Analysis American Society tor Testing
aud Materials. Philadelphia, Pa. 1974. pp. 40-42
S Knoll. J.E. and M R. Midgett. Tbe Application of
EPA Method « to High Sulfur Dioxide Concentrations.
Environmental Protection Agency Research Tnangle
Park. N.C. «PA-«00/t-7«-OJ8, July 1V7V.
THERMOMETER
PROBE (END PACKED
WITH QUARTZ OR
FVREX WOOL)
SILICA GEL
DRYING TUBE
PUMP
Figure 6-1. S0£ sampling train.
SURGE TANK
11-54
-------
Mrraoe 7—DrnuoiunoK or Nmoonr Oza»
B»fJB»OHI FlOM BfiTlOHiSY SOUBCM
1. Prtndftt sue1 Ajn>Ue*t>Ui
1.1 Principle. A frab sample la collected In an evacu-
ated Bask containing a dilute sulfuric acid-nydrono
peroxide absorbing solution, and the nitrogen oxides.
axoept nitrous oxide, are measured oolonmeUrioaUy
oalng the pbenoldisulfonlc add (PDS) procedure.
1.2 Applicability. This method Is applicable to the
measurement of nitrogen oxidea emitted from stationary
sources. The range of the method has been determined
tobe2to400miulframaNO. (as NOs) per dry standard
cobte mater, without havlnf to dilute the sample..
S.1 Sampling (see Figure 7-1). Other frab ampllnf
•ysumj or equipment, capable of measurtnf sample
volume, to within ±1.0 percent and collecting a sufficient
wimple volume to allow analytical reproducibllitv to
within ±i percent, wlU be oonaldered acceptable alter-
natives, tubject to approval ol the Admirustrator, U.8
KnTlronmenlal Protection Ajrency. Th« following
equipment Is Died In lampllnf:
1.1.1 Probe. Boraallicate flaw) tubing, sufficiently
baited to prevent water condensation and equipped
with an lo-ctack or ooustack alter to remove particuiat*
matter (a plug of flu wool la satisfactory lor thi>
pnrpon). Stainless Heel or Teflon ' tubini may also be
mad for the probe Heatlnf Is not necessary U the prob»
remain! dry durinf the purfinf period.
' Mention of trade namef or specific prodocta does not
constitute endonement br the Environmental Pro-
Uctton Ajwacy.
S.1J Collection Flask Two-liue borxolliwte, round
bottom teal, with »hon neck and 24'40 standard taper
opening protected against Implosion or breakage
9.1 S Flask %&)vc T-bore stopcock connected to a
M/40 standard taper )olnt
3.1 4 Temperature Gauge Dial-type thermometer, or
other temperature gauiff. capable of roeaJurfng lc C
(¥• f) Intervals from -i to Mr C (2i to 125° F)
J.I i Vacuum Line Tublnjt capable of wllhgtandiof
a vacuum of 7i mm BJ: (3 In Hg) absolute prsasure, with
"T" connection and T-bort stopcock
2.1 6 Vacuum Oauff U-lube manometer, 1 meter
(K In.), with 1-mm (0 1-ln.) divisions, or other fauce
capable of measuring pressure lc within :t2.5 mm H|
(0.10 in Dgi
2 1 T Pump Capable of evacuating the collection
flaik to a pressure equal to or less than 76 mm Hj (I In.
Hi absolute
2.1 S 6que«e Bulb Ooe-wi).
J.I 9 Volumetric Pipette 26 ml
2.1.10 Btoprock and Ground Joint Oreace A hifh
Tacuum, high-temperatnre chlorofluorocarbon freaar It
required BaJocarbon 2S-56 has been found lo be efleotlve
ll.ll Barometer Mercurv, aneroid, or other barom
•tcr capable of measuring atmospheric pressure to within
2.J mm Hp (0 1 in He). ID man) cases, the barometric
raadiug ma) be obtained frorc a nearb) national weather
•ernce sialion. in which case the nation value (which ta
the absolute barometric pressure^ shall be requested and
an adjustment lor elevation dlfTrrfncet between the
weatlirr station and sampling point shall be applied at a
rate of minus 2 5 mm Hj (Olm Hg) per SO m (100 ft)
elevation increase, or vice versa for elevation decrease
2.2 garopl" Recovery. The following equipment ta
required for sample recovery
2-2.1 Graduated Cylinder. 50 ml with l-o>l divisions
2^2 Bloraf e Containers. Leak free polyethylene
•ottles.
2.2.S Wash Bottle Polyethylene or flao>
2.2 4 Glass SUrrinj Rod
2-2^ fTest Paper for Indicatinf pH To eovar the pH
2.3 Analysis Tor Use anaiyaia. the lollowlng eooip-
«J«Dl Is needed -nnd,to ** ajtlsfirtorj' Altematlvel) ,
polyTDethyl penlene beakers (Nalg» No 1203, liOmi) or
flan beaken (lie ml) ma) be used When gl«u beakers
•re used, etching of the beakers may cause solid matter
to be present In the analytical «UD the solids should be
removed by filtration (see Section 4 3)
2.3 1 Bteam Bath Low-temperature ovens or tberrao-
iUticall) controlled hot plates kept below 70* C (100° F)
air acceptable alternatives
2J 4 Dropping Pipette or Dropper Three required
2J 5 Polyethylene Polloemin One for each lample
and each standard '
2.86 Graduated Cybnder 100ml with 1-ml divisions
.«£3-; Voluin
2.1 11 AnalyUcal Balance To measure to within 0.1
PROBE
\
r
FILTER
GROUND-GLASS SOCKET,
§ NO. 12/6
110 nw
3-iVAt STOPCOCK:
T-6ORE, i PYREX.
BORE. 8-rnmOD
SQUEEZE BULB
IMP VALVE
PUMP
FLASK
FLASK SHIELD^. _\
THERMOMETER
GROUND-GLASS CONE.
STANDARD TAPER. GROUND-GLASS
Z SLEEVE NO. 24/40 SOCKET. § NO. U/5
rmx
210 mm
•FOAM ENCASEMENT
- - VBOILING FLASK -
NW **!'' 2-LITER. ROUND-BOTTOM, SHORT NECK.
r WITH J SLEEVE NO. 24/40
Figure 7-1. Sampling train, flask valve, and flask.
11-55
-------
Unless otbsrwl*? indioat«d. It i» Sutended that nil
rtacenli eon tons U> the specinec.uoiu established by siie
Commute* or* Analytical R«wn;< ot tbe American
Chemical kocietj veer? yuch sp«:i8oauoni arp £vaal
•bit, other* i« t»? the best svaiiabie grwlc
*.! Sampling To prtpa-"? the abaor'mnj solution,
•ntiously add 2 8 ml concentrated HiSO( tc 1 liter of
•Monited. distilled water Mil well and add 6 ml of t
psrcer.t byorofcn peroiide, freshl> prepared from K
psrrent hydrogen peroildf solution The absorbing
sniution should be utcd witbtr, 1 week of lt> preparation
Do not expose to srtreme heat or direct sunlight
aJ Sample Recovery Two reagents are required for
(simple recover)
u.) Sodium Hydroxide (IN) Di«»!v» 4C g NaOH
Sr d*ionised, distilled water and dilute to 1 liter
U.2 Water DwonlwdL distilled to conform to ASTM
•iwciaoaUoD DllW-74, Type t. At the option at the
saalyit, the KMNOi tart for oxidiuble orfanlc matter
nay be omitted wb«n high ooDoentralions of organic
«3Att«r are not expected to oe present
S.S Analysis Fo- the analysis, tbe following reagent*
ire required
l-l 1 Fuming Bulfunc Acid 55 to 18 percent by weight
true sulfur tnoiide HANDLE WITH CAUTION
1.S.2 Phenol White solid
t.J.1 Bullunc Acid Concentrated. M percent mini-
xmmasst) HANDLE WITH CAUTION
1.8 4 Potassiurn Nitrate Dned at 10S to 110° C (WO
to 230C F) for s minimum of 2 hours Just pnor to prepare
tton of standard solution
MS Standard KNOi Solution Dissolve aiactlj
S.18S g of dried potassium nitrate (KNOi) in deionited.
distillc** water and dilute to 1 liter with deionited.
flisnlli _, water in a 1,000-ml volumetnc flask
1.36 Working Btand&rd KNOi Solution Dilute 10
tol o! t e standard solution to 100 ml with deionited
distilled* water One mlUiliter of the working standard
solution Is equivalent to 100 «g nitrogen dioxide (NOi)
1.3.7 Water Deionited, distilled as in Section 322
136 Pbenoldisulfomc Acid Solution Dissolve 25 g
$if pure wbJte phenol in 150 ml concentrated sulfunr
lido on a steam bath Cool, add 75 ml fuming sulfuric
ftcid. and beat at 100° C (212° F) tor 2 hours Store in
i> dark, stoppered bottle
4k. Praojura
4.1 Sampling
4.11 Pipette 25 ml of absorbing solution into a sample
flask, retaining a sufficient quantity for tise in prcparing
tbe calibration standards Insert the flask valve stopper
into the flask with the valve in the "purge" position
Assemble tbe sampling train as shown in Figure 7-1
>,nd place the probe at the sampling point Make Jure
that all fittings are tight end leak-free, and that all
ground {lass Joints have been properly greased with a
liigh-vacuum, high-temperature chlorofluorocarbon-
tased stopcock grease Tun; -the flask valve and thr
pump vuLlve to tbeir "evacuate" positions Evacuate
the fl&sk to 75 mm Hg (S In Hg) absolute pressure or
)«•> Evacuation to s prwsdre approaching the vapor
jressure of water at the ensting temperature, is desirable
Turn the pump valve to its "vent" position and turn
eC the pomp Check for leakage by observing tbe m»
IOmeter tor any pressure fluctuation (Any variation
create- than 1C mm Eg (C 4 to Eg) over a period o!
I minute ie not acceptable, and tbe flask is oct tc be
' used until the leakage problem is corrected Pressure
to the flask is not to eicsed 75 mm Hg (3 in Hg) absolute
8t the time sampling Is comiaencod ) Record the volume
af tbf flask and valve (V,). the fl»5!r temperature (T,).
end the barometric prasjuit Turn the flask valve
axinterclockwue tc Its "pur*?" position wid do Use
same with tbe puiap V&'ITP Purge tbe probe find tb«
vacuu-ri tube using the equeete bulb It oonde.pj»tion
occurs in the probe and the ati v»i" arei. 'o«s*. the
probe and purge rjitC the condensation ,)
fe equal to tbe barometric prejsi>-ure leass the manometer
reading Immediately turn the fl»;k valve to tbe "tain-
pie" position and permit the g-^s to enter tbe flask until
pressures in tbe fiat'k and sarcole hne. (' e , duct, stack)
are equrJ This will usually require tbout 15 seconds
ft longer period indicates fc "plasr" in the probe, which
must be corrected before se >fplmc i* continued After
soileiCtLnc the sample, turr t -.; fla.'k »alve to !t5 "purfe"
pasitloi and disconnect th» fla."k from U»e sftrnpllnj
irain Shake tbe fl&fk for s' IESSI 5 minutes
45! V the ss&s being •fr.p'ti conisJas insutEcieat
atygen for tbe convers^r. <-•! NO '• NOi (e I , sm ap-
pUcAble suhpan o* '.be n.»i'dard r^c.- require taking s
irsple of s caiibraiji". «,,-,- u istur- of NO m N>), then
fttfygen ghall ue iritf^u'^d i:>'.c IV 3p:-!v to p«rrrait tbi^
ftaii^&rsiorj Ozygtti ^rny b™ IntrixSuc*--! into the Jlaak
by orjr of tnii* E ' %^ds, (1) ^e'or? *?*cusun^ tbf
sampUns rl^Ak, fit ^llh pir,1 ryhnd?r oi^gen, thfin
*rvjat»S»sk i', 'cnHfe-Cn Hj! »r-5olut» prassurt
ssr tf^, rjr {21 iij-: yssTi r ;:. the Has1'- rsi\*~ aimpUiif,
saospbere \i.
fttsnospbefic
4-2 Ss,7.-.ul< K«vvwy T r tV ft^sV «-.
•rf !•; '--A- -; j.-i.l then s^.»*£ " - ocr.vf. 's *ir S r
sward the fl*si tempersrurt (T,), Uie barometric
pr«snirt, aci) tbe diStrejio between the mercury itveis
B tbe ni*i)OO2ater TDf absolule internal pressure in
the lilt's D •} Is the baromctnc p-»ssur» kas tbe mar'-
taaet^r rwilin^ Transler the conteni! of tor flask to *
h(kk-!res polyethyle-.' bottle Rmsp the flask twlcs
with 5-ml portions oi de'iituied. distilled watej and add
tine ruise water tc tbe bottle Adjust the pH to between
9 and 12 by adding *odju.m hydroxide (1 N). dropwise
(about 25 to K drops' Check the pH by dipping a
•urring rod into the aolutlon and then touching the rod
to the pH test paper Remove as little material as Dotsib!?
during this sup Mark the height o! the liquid level §o
that the container can be checked for leakage after
transport Label the container to clearly Identify 1U
eoottnu Baa! the container for shipping
4-3 Analysis Note the level of the liquid in container
•od confirm whethej or not any sample was lost duri.ig
shipment, cote this on the analytical data sheet II a
noticeable amount ol le&kagr has occurred, either void
the sample or u» methods, subject to tbe approval of
the Admimstrator, to correct the final results Immedi-
ately pnor to analysis, transfer the contents of tbe
•hipping container to a 50-ml volumetric flask, and
rtnae tbe container twice with 5-m) portions of deiomwd,
distilled water Add tbe rin.v water to tbe flask and
dilute to the mark with deiomt^d. distilled water, mil
thoroughly Pipette a 25-ml aliquot into the prooeiain
•vmporating dish Return any unused portion of tbe
sample to the polyethylene storage bottle Evaporate
the 2A-ml aliquot to drynexs on « steam b»th and allow
to cool Add 2 ml phenoldistilfcnic acid solution to the
dned residue and tnturate thoroughly with a povleth>l-
aoe policemAT. Make sure the solution contacts all the
rttiduf Add. 1 ml deionited, distilled w»t«r and four
drops of concentrat«d sulfunc acid Heat tbe solution
on a steam bath for 3 minutes with occasional stirring
Allow the solution to oool, add 20 ml deionued. distilled
water, mil weU by itimng, and *dd concentrated am-
monium hydroxide, drop wise, with constant stirring.
until tbe pH is 10 (as determined by pH paper), jj ^,e
sairple contains sobds, these must be removed b>
filtration (centnfugation is an acceptable alternative,
•object to tbe approval of the Administrator), as follows
filler through Whatman No. 41 filter paper Into a lOb-mi
volumetric flask, nnse the evaporating dish with three
t-ml portions of deionited. distilled «ater, Alter these
three nnses Wash tbe filter with at least three 16-ml
portions of deionited, distilled water Add tbe niter
washings to the contents of the volumetric flask and
diluu to tbe mark with deionited, distilled water U
•olids are absent, the solution c&n be transferred directly
to tbe 100-rol volumetric flask and diluted to tbe mark
with deionii*d distilled water, Mu the contents of the
flask thoroughly, and measure the ebsorbanoe at the
optimum wavelength used for tbe standards (Section
i.2 1), using the blank solution as K wro reference Dilute
the sample and the blank with equal volumes of deion-
taed, distilled water if the absorbance eiceeds A,, the
kbsorbance of tbe 400 *g N O: standard ifcx Section 5.2.2)
ft 1 yiasfc Volume Tbe ^olum* of thi> eollection frasl
flftak valve oombmaticn must be known pnor in sup-
pling Ajaemble the flask and &aik valve and fll! wK'
w*t«r, to the stopcock Measure tht volume of w»tar to
±10 ml Record this volum? on tbe &ask
fi 2 Bpectrophotometer Cabbration
1.21 Optimum ^»velengt'i Determination For erst h
Used and: vansble wavelength specirophotsmetars
calibrate against standard certified wavelength of S!0
zun, every 6 months Alternatively, for van&bif wa?^
Jenglh spectropbotomelers. acSJi the spectrum bstww
400 snd 416 nm using e 200 ^ N Oj stanclurd solution isx
Section e.2 2) If a peat doe« not occur, the jpecfropho-
lometer is probabl> mai/ur,ctiomti^, and should be re-
paired When B peak is obtained wlthia the 400 to «S run
range, the waveieneth at wh'Cb this p^k occurs sh»\l bt
th* optimum •wavelength for iht rDeasLirsinent si sb-
sorbance for bo*h the st&ndards and s&mptes
122 Dfterminition of Sp^'-rripnotosni-ter Cslibr*
Uon Fector K. Add 0 0, J 0, S S. S 0 and 4 0 ml of tbf
ENOj working standard solution (S ml'"!*' at KQs'< to
a series of five porcelain evaporating dishes To asch, s>dd
16 ml at absorbing noiution !0 mi deiorui«i, dlstii'.ed
water, and sodium bydroiide E1N), dropwise, arstil Xlse
pH is between 8 and 12 (sbou! 25 to 86 drops e*f.h!
Bepinning with the evaporation step, foMow tne. analy-
sis procedure of Section 4 8, until the solution has be*n
transferred to the 100 ml volumetric flask end dilutad to
the mark Measure the ebsoi ba;-.c* of each solution, wt ihe
optlirum wavelength, as df~?raiin«! in Section ^ 2 1
This calibration procedure muit bf rcp«*t«J on each Ssv
that samples ar*- »nalyt<-'1 Calculate the spectrophotosn-
pt«r calibration factor as follows
K «100 ^*iil?-!*l-"tMi±l^
Equation 7-1
wlwrs
Jf.-CaSbrsUin fsctar
^i-Absorbsnc* o! tbe lOfftS WOi standard
*4i"» Alteorbano? of tbe 301^-^ NOi BtAsdard
A\~ Abv3rb»ne? of the 30T>*£ NOi stand»rtf
ti»Jf<»>hi«, a. 596,0. ASTM Designation »-16f»-60.
p. 7&--T29.
t Jacob, M B. The Chemical Analysis of Air Pollut-
ants New Yor» Intencience Publishers, Inc. I860
ts! JO, p. 1M-*K
4 Beatty, R L , L. B. Berger, and H. H. Schrenk
>«1«-Kiinatiori o! Otid«s of Nitrogen by the Pbenoldisul-
oni" Acid lUstbod Bureau of Mints, U.6. Dept. of
Jat»nor R. I- 8687 February 1M3
S Hamll, H. F. »afi D. K, C»m»nn. Co!l»borative
Btudy of Method tor the 3>lanntn»tion of Nitrogen
O&i|!, H y. aad H E Tboasfcs. Col)*borative
e«>4y of Mitbod tor as^ Drtermlnation of Nitrogen
Oiidf amisrion* Irom Stptsonary Sources 'Nitnc Acid
HUISK' Bot-V'wjt Ha*»-O. Icsiictitt r '••: Er
.
?*rk. N.C. Mas? 9, 1874.
-------
METHOD »—DITIKXINATION or Scircuc Aon Mist
AND Sutrui DIOXIDE EUIBSIONI FBOM STATIONA**
Souicca
1. Principle end AppltcAbilitv
I.I Principle A gas sample a eitractnd Isoklnetlcally
from the stack. The sulfunc acid mill (Including sulfur
uiciidi) and the sulfur diondo are, separated, and both
fractions are measured scporafel) by (be baritnu-lhoriD
Utration method.
1.2 Applicability This method is applicable (or tbe
detomiinatlon of sulfunc acid nust (including sulfur
trionde, and in the absence of other paniculate matter)
and sullui dioiide emissions from stationary sources
Collaborative tests have shown that the minimum
delectable limns of the method are 0 OS milligrams/cubic
meter (003) 10-' pounds/cubic foot) for sulfur trtonde
and 1.2 mi/in' (074 10-' In It') for sulfur dioiide No
upper limits have been e'slabli-hcd Based on theoretical
calculations lor 200 niilliliters of 3 percent hydrogen
peroiide solution, the upper concentration limit tor
sulfur dioiide in a 1 U m> (36 .1 ft1) |as sample is about
12.500 m|!'ni> (7 7X10-' Ib'fl'l The upper limit can be
extended l>y increasing the quantity of prroiide solution
In the impmgers
Possible interfering agent! of this method are fluorides,
free ammonia, and dimeth>l aniline If any of those
interfering agents are present (this can be determined by
knowledge of the process), alternative methods, subject
to the appruTal of the Administrator, are required
Filterable paniculate matter may h« determined along
with SOi and S0> (subject to the approval ol the Ad
mlnlstraior) however, the procedure u»ed for paniculate
matter must be consistent wlih the specifications and
procedures given In Muhod 5
2 1 Sampling A achemallc of the sampling train
uaed ID this method Is shown In Figure S-l, ft Is almilar
to the Method S train i-icrpl that the filter portion b
dUii-rent and the lilier hold< r dors not have to be huled
C'ommerrlal mudfls of this train are available For those
who desire to build their own, however inmi>lrlt con-
•trui lion dfialls arc d<-srril)rd In AI'TD-a*! Change*
from the AI'TlMUil dmunii'iit and allownt.lc modi-
fications to Fluure 8-1 are dlicusjx-d In the lollowlnf
•UbMiUou
T!M> operating and maintenance procedures for the
aanipHnu train are di*nlU>d In AI'TI)-O>re Since correct
luutfc l> lni|urtaiit In obliunlni \alid results all usen
•huuld rrjd ihu AI'TI)-uj78 ita-urr..-nt and adopt tbe
operating and nialnirnunce pnx'durcs outlined In It.
unless otherwise si»rifird hori'in Further details and
cuhlrllnf. on o|M>ruiiiin and niointi'imnce arc given In
M>'ihod 5 and should I* read and followed whenever
they are applicable
2 1 1 ProW Noulc. Same as Method 5. Section 2.1.1.
2 I .' I'rolfo lJm>r Uoro&lllcaiii or ijuaru glas&, with a
hi-atlng system to prevent vl*llile condeiL>«uon during
aampuni Do not tue metal probe liners.
'11 3 I'uol Tubr Same ai Method 5. Section 2 1 3
2.1 4 DlfforenliaJ fneenn Oaufr Same an Method 5
••cllonZ.l 4.
2 l.S Filter Bolder Boralllcale gla», with a glas;
frit fllttr support and a illlcone rubber gasket Other
Baket materials, e g . Teflon or VIurn, may be us»d §ub-
J«ct to the approval of the Administrator The holder
dwtgB thall provide a peel tire aeal against leakage from
tbe oulilde or around tbe filter The fllur holder ihall
be placed between th» firtt and aecond lmpin«er» Now
Do not heat the film holder.
S.l.t lmplnger»—FOUJ. aa thown in Figure »-i The
•nt and third thai) be of tbe Oreenhurg-Bmllh ,-lnign
with lundard tip* Tbe atcond and fourth I ha!] b« of
tbe Orernburg-Bmlth design, mndlfied by nplarlng the
ln»ert with an approilmalfly 13 mllllmeur (OS in.) ID
flam tube, having an unconntrlrted tin located 13 min
(01 In ) from the bottom of the flask Blmllar collection
tyiusna, which nave been approved by the Admlnlj-
trator. marbeotcd
21.7 Met»rlnj 6v«t«m. Same as Method 6. Section
».1J Baromeusr. Same u Method 4. Section 21 9
2.1.9 Oas Density Determination Equipment Bane
M Methods, Section 2.1.10-
1.1.10 Temperature Gauge. Thermometer, or equiva-
lent to mrMure tbe temperature of the gas eavini tbe
tmpioger train to within Fc CT r>
2.2 Sample Reeoverr.
TEMPERATURE SENSOR
PROBE
PtTOT TUBE
TEMPERATURE SENSOR
THERMOMETER
FILTER HOLDER
.CHECK
/VALVE
7
REVERSE TYPE
PITOT TUBE
IMPINGERS
BY-PASS VALVE
•VACUUM
LINE
VACUUM
GAUGE
MAIN VALVE
DRY TEST METER
Figure 8-1. Sulfuric acid mist sampling train.
11-57
-------
NOT*.—If moisture ooeteat b «o b» determined by
imptnger analysis, weigh each of tbe first thra* tmpingtrs
(jplus absorbing-solution)to th* !»••*•* 0.5 g end record
tiiese weights. The wei(ht of the silica If i (or slllc* gel
Dim container) must also b* determined U> th« saareet
0 J g and recorded
4.1.4 Pretest Leek-Check Procedure. FoUcw UM
basic procedure outlined in Method 6, Section 4.1.4.1,
noting that the probe heater shall be adjusted to tba
minimum temperature required to prevent condense-
tk». and also that T&rbaie such as, plugging the
inlet to the Oiler holder • * V shall be replaced by,
••• • • plugging the inlet to the first impinge: • • '."
The pntctt leak-check 1* optional.
4.1-S Train Operation. Follow th« bask procedurM
outlined in Method 5. Section 4.1.5, in conjunction with
the tallowing speclsJ instructions Data shall be recorded
«o a sheet similar to the one In Figure 8-J. Tbe sampling
nt» (hall not exceed 0.030 m'/mln (1.0 eta) during UM
run. Periodically during the test, observe tbe connecting
Una between the probe and fint Impinger for signs o?
(sondeniatlon. It It does occur, adjust th* probe beater
wttiag upward to the minimum temperature required
Co prevent condensation. If component changes become
accessary during a run, a leek-check shall be done Im-
mediately before each change, according to the procedure
outlined in Section 4.1.4.2 of Method 5 (with appropriate
modifications, as mentioned in Section 4.1.4 o( this
method); record all leak rate*. If tbe leakage raWs)
loosed the specified rate, tbe tetter shall either rold tbe
ran or shall plan to correct the sample volume as out-
lined in Section 8.3 of Method S. Immediately after com-
Ijonent changes, leak-checks are optional. If then
leak-checks an done, tbe procedure outlined In Section
4.1.4.1 of Method 5 (with appropriate modifications)
ifcallbeuted
After taming oil tbe pomp and regarding tbe final
nadings at the conclusion of eacb run, remove the probe
from the stack. Conduct a poet-teat (mandatory) leak-
aheck as in Section 4.1.4.3 of Method 5 (with appropriate
modification) and record the leak rate. If the post-test
leakage rate eiceeds the specified acceptable rate, the
tester shall either correct the sample volume, as outlined
in Section 6.3 of Method 5. or shall void the run.
Drain the ice bath and, with the probe disconnected,
purge the remaining part of the train, by drawing clean
ambient air through the system for 15 minutes at tbe
average flow rate used tor sampling.
NOTE.—Clean ambient air can be provided by passing
air through a charcoal filter. At tbe option of tbe tester,
ambient air (without cleaning) may be used.
4.1.S Calculation of Percent Isokinetic. Follow tbe
procedure outlined in Method 5, Section 4.1.0.
4-2 Sample Recovery.
4-2.1 Container No. 1. If a moisture content analysis
to to be done, weigh tbe first impinger plot eontoota to
tbe nearest 0.5 g and record this weight.
Transfer the contents of the first Impinger to a J!0-ml
graduated cylinder. Rinse the probe, first Impinger, all
connecting glassware before the filter, and the front half
of the filter holder with 80 percent isopropanol. Add the
rinse solution to tbe cylinder. Dilute to 250 ml with 80
paroent isopropanol Add the filter to the solution, mil,
and transfer to the storage container. Protect the solution
against evaporation. Mark the level of liquid on bet
aontainerand identify the sample container.
4.2.2 Container No. 2. II a moisture content analysis
is to be done, weigh tbe second and third impingers
(plus contents) to the nearest O.A g and record these
weights. Also, weigh tbe spent silica gel (or silica gel
plus impinger) to the nearest 0.5 g.
Transfer tbe solutions from tbe second and tblrd
Impingers to a 1000-ml graduated cylinder. Rinse all
connecting glassware (including back half of filter holder)
between the filter and silica geilmpinger with daioniied,
distilled water, and add this rinse water to tbe cylinder.
Dilute to a volume of 1000 ml with deionlsed, distilled
water. Transfer the solution to a storage container. Mark
tb« level of liquid on tbe container. Seal and identify UM
sample container.
4J Analysis.
Note the level of liquid In containers 1 and I, and eon-
firm whether or not any sample was lost during ship-
ment, note this on the analytical data sheet. If a notice-
able amount of leakage has occurred, either void UM
sample or use methods, subject to the approval of UM
Administrator, to correct the final results.
4J.1 Container No. 1. Shake the container holding
the tsopropanol solution and tbe filter. If the filter
breaks up, allow tbe fragments to settle lor a few minute*
before removing a sample. Pipette a 100-ml aliquot of
tbis solution into a 250-mi Erlenmeyer ftaek. add it < > 4
drops of thorin Indicator, and titrate to a plni ent »int
using 0 0100 N barium per chlorite Repeat tbe tltri.ion
with a second aliquot of sample and average UM iteration
value*. Replicate utrations most agree within I pcnant
cr 0.2 ml, whichever Is greater.
4JJ Contain* No. 2. Thoroughly mil tbe sctattoo
la tbe container holding the contents of tbe wooed and
third impingers- Pipette a 10-ml aliquot of sample into a
SSO-ml Krlenmeyer flask. Add ml of isopropmnol. % to
4 drops of thorin indicator. and titrate to a pint endpelct
oing 0.0100 N barium pertblorotc Repeat th* titretios
with a Mcond aliquot of sample and tvtragf tbe titration
value* Replicate tttrelloa* man agree witfein 1 perosat
V OJ ml. whichever it greater.
4JJ Blanks Prepare blanks by adding ! to 4 drop*
ef tbortn indicator to 100 ml ef SO percent isopropenol-
Ttevte the blanks in the same manner as ice samples.
a.1 Calibrate equipment using the proaedorei ipeei-
ted in tbe following sections of Ucthod & Section &JS
(iMtering system), Section 5.5 (tsmperatare gauges).
Section 5.7 (barometer). Note tbat the recommended
Ittk-eher k ol tbe metering system, deecrlbed in SecUcc
(.4 of Method J. also applies to this method
oJ Standardise tbe bariom perchlorate solotlon with
tt ml of standard rjlfuric fccid. to which 100 ml of 100
ptrant Isopropanol bas beec added.
eeiaU tbe moJsturs content of tbe s8ark g*s, u*«f Eou*
tS0Q S-S of Method 4 Tbe "Note" In fteruon 6 5of M?i.fi'X!
I also appb« u> this mstbcd Note thai U Ibt- «Suant fs;
ttraaru can b* considered nt»nt nw«J not bt e*lcuja>i«i
*J aulfuric add mist (including BOO eoooratntioD
Note.— Carry ont calcnlationt ratelning at wait ooe
•rtra decimal figure bevond that of tbe acquired data,
Bound off figures after final calculation.
4.1 Nomenclature.
A." Cross-sectional ana ofnoule, m' (ft>).
«•- Water vapor in the gas straam, proportion
by volume.
CHsSOi-Sulfurtc acid (inclnding BO() concentration.
g/dscm Ob/dscf).
CBOi**Sulfur dioxide oonoantratioe, s/dsem Ob/
dscf).
/-Percent of Isokinetic sampling.
N-Nonnabty of barium parchlorate titrant, I
•xjuivalenti/liter.
n»r- Barometric proxure at the sampling sit*.
mm Eg (In. Hg).
P.-Absolute stack ft* pnHon, mm Hg On.
fttd- Standard absolute prawm. 780 mm Hg
CB.K in. Hg).
r.- Avenge absolute dry gas meter temperatur*
(*eeFlgure8-2),°E(*R).
r.- Average absolute stock gas temparature (SM
KjnreS-2),*Kr B).
Tvtd- Standard absolute temperature, SO* K
(828° B)
V.'Volnme of sample aliquot titrated, 100 ml
lor HiBOi and 10 ml for BO,.
Vi,»Total volume ofliqu.it! collected in implnjen
and silica gel, ml.
V.- Volume of gas s&mple M mMrarad by dry
ns meter, dcm (den .
V.dtd)- Volume of gas sample measured by tbe dry
ns meter oorrecteo to standard conditions.
oscm (dscf).
•,-Average stack gas velocity, calculated by
Method 2, Equation 2-0. using dataobUiiMd
torn Method 8, as/see (ft/sec).
Vsoln- Total volume of solution In which tbe
sulfuric acid or sulfur dlonde sample is
gontained, 2SO ml or 1,000 ml, respectively.
Vi-Volume of barium perchlorate tltrant used
tor tbe tample.ml.
Vit- Volume o! barium perchlorate tltrant used
tor tbe blank, ml.
y-Dry gas meter calibration factor.
AH- Average pressure drop across orifice meter,
mm (in.) HrO.
8-Toul sampling time, min.
U.S-Speclfic gravity of mercury.
60- tec/mi n
100 -Con version to percent
8.2 Average dry gas metxr tempenture and average
ertficc prewure drop See dst» sb«t (Figure 8-2).
43 Dry Qas Volume Correct the sample volume
measured by tbe dry gas meter to standard conditions
Off C and 760 mm Hg or 68" F and 2B.92 in. Hg) by using
Equation 8-i.
otd) =
Equition 8-2
JCt- 0.04904 s/mUl>%quiv»)eT>t for metric ctr.lt-,
-1.0§lXl£Hlb/a58Q lor Kaglish oniu.
t.e BuUur dioxide oeuoentration.
Equation 8-3
i-0.0203 r/meafor m«trlc units
-7.081X10->lb7meq for Xoglish tmiU.
S.7 Ijokinetlc Variation.
C.7.1 Calculation from raw data.
100 r.[
MtV.P.A,
Equation 8-4
C,-0.003464 mm Hf-m»/mJ-*K for metric onlts
«0.003K7e in. Hg-nVml-'B for £n;ush onlu.
ft.7.2 Calculation bnm intermediate values.
-K,
Equation S-5
where
Xi-4420 tor metric nniu.
-C.OM50 for English units
M Acceptable Results If 10 percent eric Analyse pp 40-42 Amwicmn Society
tor Testing and Material Pbiladelphia, f&. 1974
11-58
-------
U.l Wasb Bottles. Pslfstiiytoa* «r tl**e, HC si!
(two).
12.: Orsduafcx) CyKndw* S6C ml, i Uter. fVeJo'
Bet/lc fiaikj may ai*c be uasd.'
J-J I Storage Bottles. Leal-free polyethylene boUta,
lOW ml SUM (two (or eaeb sampling run).
124 Trip Balance SHVfnun capacity, to roearare to
sfcO.5 i (necessary only If a moisture content aaalyali t>
to b» done).
2.9 Analysis
2.1 1 Pipettes. Volumetric 25 ml, 100 ml.
2.3.2 Bun-el W «t> ml
2.3.3 Erlenmeyer Flask 2SO ml. (one for each aunpk
blank and standard).
2.S 4 Graduated Cylinder. 100 ml.
J.I 5 Trip Balance. 400 | capacity, to meanir* to
*O.S|
2.1 e Dropping Bottle. To add indicator •oration,
125-ml atse.
Unless otherwise Indicated, all reagents ere to conform
to tbe specifications Mtabllshed by the Committee mi
Analytical Reagents of tbe American Chemical Society.
wbere such specifications are available. Otherwise, ue
tbe best available trade.
1.1 Sampling.
1.1.1 Fillers Same as Method 5, Section 3.1.1.
1.1.2 BlUca Oel. Same as Method ft. Section 1.1. 2.
1.1.1 Water. Delonlted. distilled to conform to ABTM
HMdflcatlon D11V3-74. Type 1. At tbe option of tbe
analyst, tbe XMnOi test for oxjdltable orfanlc matter
•ay be omlttad when high concentrations o( organic
Better art not expected to be present.
t! 4 Isoprspanoi SO Permit. Mix §W m! of tepro-
paao) wltb JOO ml of delonUed, distilled water.
MOTS — Ziperienoe Kasabown that only A.C.B.ftwde
hopropanol is Mtltfortory. TeiU hevp shown that
isopropaDo! obtained from cemmerclal sources oece-
easlonaUy bas peroilde imparities tbat will cauae w-
roo«ou0ly bi|(h sulftirlc acid mist measurement. Use
U)e (ollowlnf Ust for detecting peroilde* In each lot of
Inpropanol Sbakr 10 ml of tbe isopropanol with 10 ml
•f freshly pnpurd lOporcrnt poUwiura Iodide aolotlon.
Prepare a blank by similarly treating 10 ml of distilled
vat«r After 1 minute, read the ahsorbanc* OD a spectro-
pboiompter at S&2 naoometen. If the abaorbaoce exceeds
0.1, tbe Isopropanol shall not be used. ParosJdes may be
ramoTed from laopropano! by redistilling. or by r"~r»-
Uucou|(h a column of actirsted alumina However, re-
•cenV«rade Isopropanol with suitably low peraxldeleTels
to readily available from commercial sources; therefore,
rejection of contaminated lots may be more •fflelanl
than following the peroilde removal procedure.
1.1 & Bydre«en Peroilde. 1 Percent DUoU 100 ml
al W nerrent hydroten peroxide to 1 liter with deJoolsed,
distilled water. Prepare fresh daily.
1.1.« Crushed Ice.
1.2 Sample Recovery.
1.1.1 Water. Same as S.I.!.
1-2.2 Isopropanol, W Percent. Berne as 1.1.4.
1.1 Analysis.
U.I Water Same as 3.1.3
1.1.2 Isopropenol, 100 Percent.
1.1.3 Thorln Indicator. I-(o-enonophenyla*o)-2-HBpb-
tbol-3, t-dlsulfordc acid, dlsodium salt, or oqnlvmleot.
Dtosolve 0.101 In 100 ml of delonlted distilled water
$14 Barium PercMorate (00100 Normai) Dtasoit-
l.Kt of barium perehloreu trfhydrete (BKC10 Determinations Follow the pro-
cedure outlined in Method 5, Section 4 1 2
4.1.3 Preparation of Collection Train Follow the pro-
cedure outlined in Method 5. Section 4 1 3 (eicept for
tbe second paragraph and other obviously inapplicable
pens) and use Figure 8-1 instead of Figure 5-1 Replace
the second paragraph with Place 100 ml of 80 percent
taopropano! in the Ant Impinger, 100 ml of 3 percent
hydrogtn peroxide in both the second and third Im-
pinge.™, retain a portion of each reefeot tor us* as a
blank solution. Place about J00| of sUlceiel In tbt fourth
implncer.
WANT.
LOCATION
OPERATOR
BATE
RUN NO
SAMPLE BOX NO.
METER BOX NO..
METERAH*
C FACTOR
PITOT TUBE COEFFICIENT. C».
STATIC PRESSURE. •• H| lie, HI)
AMBIENT TEMPERATURE
BAROMETRIC PRESSURE
ASSUMED MOISTURE. X
PROBE LENGTH, m (It)
SCHEMATIC Of STACK CROSS SECTION
NOZZLE IDENTIFICATION NO
AVERAGE CALIBRATED NOZZLE DIAMETER, onlinj.
PROBE HEATER SETTING
LEAK RATE. m3/mi«,(cfm)
PROBE LINER MATERIAL
FILTER HO.
TRAVERSE POINT
NUMBER
TOTAL
SAMPLING
TIME
(«).»ia.
AVERAGE
VACUUM
••HI
-------
MXTKOS » — VKTTAI. DCTBMUfArlOW Of TBX
OPACITY or UOaaiOMS VmOK STAnOKACY
sou&cxe
Many •tationary sources discharge visible
emissions into the atmosphere; the*e emls-
nioaa are usually la the abape of a plume.
This method involves the determination of
plume opacity by qualified observer*. The
method includes procedures for the training
and certification of observers, and procedures
to be used in the field for determination of
plume opacity. The appearance of a plume as
viewed by an observer depends upon a num-
ber of varUMea, some of which may be con-
llroUable and some of which may not be
oontroUable In the field. Variables which oan
In controlled to an extent to which they no
longer exert a significant Influence upon
plume appearance include: Angle of the ob-
server with respect to the plume; angle of the
'Observer wltb respect to the sun; point of
'Observation of attached and detached steam
plume; and angle of the observer with re-
spect to a plumct emitted from a rectangular
stack with a large length to width ratio. The
method includes specific criteria applicable
to these variables.
Other varlablr which may not be control-
lable in the fleiu are luminescence and color
contrast betwei ' the plume and the back-
ground against viicb the plume is viewed.
These variables exert an influence upon the
appearance of a plume as viewed by an ob-
server, and can affect the ability of the ob-
server to accurately assign opacity values
to the observed plume. Studies of the theory
of plume opacity and field studies have dem-
onstrated that a plume is most visible and
presents the greatest apparent opacity when
viewed against a contrasting background. It
follows from this, and is confirmed by field
trials, that the opacity of a plume, viewed
under conditions where a contrasting back-
ground is present caa be assigned with the
greatest degree of accuracy. However, the po~
"tential for a positive error is also the greatest
•when a plume is viewed under such contrast-
ing conditions. Under conditions presenting
a leas contrasting background, th» apparent
opacity of t> plume Is leas and approaches
eero as the color and luminescence contrast
decrease toward zero. &» a result, significant
negative bias and negative errors can be
m&da when a plume is viewed under lesa
contrasting conditions. A negative bias de-
creases rather than Increases the possibility
that a plant operator will be cited for a vio-
lation of opacity standards due to observer
error.
Studies have been undertaken to determine
the magnitude of positive errors which can
be made by qualified observers -wblie read-
Ing plumes under contrasting conditions and
•using the procedures set forth in this
method. The results of tbesa studies (field
trials) which involve a total of 76S sets of
25 readings each are as follows:
(I) For black plumes '133 sets at a smoke
generator) , 100 percent of the sets were
read with a positive error1 of leas than 7.6
perceot^opacHy; 99 ras'-ceijt were read with
a positive error of lea* thstn 5 percent opacity.
(2) For white plumes (17{Ts*t* at a smoke
generator, 183 i«U a*. & coed-fired power plant,
288 sets fti a sulfur) - acid plant), S9 percent
of tb* M>t* were *t6t with ts, positive emjf of
less thaa "?3 parr-sat op&clty, 81 fiercest were
T«fed witR & puiTivs error ofl^a than 6 per-
esnt epsclty.
The posit!?*
•With asi »v» •
therti'Gifs SB: ,
method aiu,-:'
determining
cable opaci
V.e«mkt!csi«J «r»or
"- of tn?«nty-fiTO «>&d!x.g* 5s
»: ta.-ttQ into account- wiMn
poaetb-* ifir,':'»tSax-a «tf Appli-
s. wt, portfire* •»*gvar:-.3t;.'»«rag»
1. Principle and oppHecMHty.
l.t Principle. The opacity of •missions
from stationary sources Is determined vis-
ually by a qualified observer. -
1.3 Applicability. This method to appli-
cable for the determination of the opacity
of emissions from stationary sources pur-
suant to I 80.11 (b) and for qualifying ob-
servers for visually determining opacity of
•missions.
3. Procedures. The observer qualified Sn
accordance with paragraph 8 of this method
•hall use the following procedures for TU-
ttally determining the opacity of embsrions:
t.l Position,, The qualified observer shall
stand at a distance sufficient to provide a
clear view of the emissions with tb» cun
oriented in the 140* sector to his back. Con-
sistent with maintaining ths above require-
ment, the observer shall, as much as possible,
make his observations from a position such
that his line ot vision li approximately
perpendicular to the plume direction, and
when observing opacity of emissions from
rectangular outlets (e.g. roof monitors, open
baghouses, noncircular stacks), approxi-
mately perpendicular to th» longer axis of
the outlet. The observer's line of sight should
not include more t.hsr. one plume at a time
when multiple stacks are involved, and in
any case the observer should make his ob-
servations with bis line of sight perpendicu-
lar to the longer axis of such a set of multi-
ple stacks (e.g. stub stacks on baghouses).
2.2 Field records. The observer shall re-
cord the name of the plant, emission loca-
tion, type facility, observer's name and
affiliation, and the date on a field data cheet
(Figure 0-1). The time, estimated distance
to the emission location, approximate wind
direction, estimated wind speed, description
of the sky condition (presence and color of
clouds), and plume background are recorded
on a field data sheet at the time opacity read-
ings are initiated and completed.
2.3 Observations. Opacity observations
Shall bo made at the point of greatest opacity
in that portion of the plume where con-
densed water vapor !• cot present. The ob-
server shall not look continuously at to®
plume, but instead shall observa tb« plume
momentarily at iS-second intervals.
83.1 Attached Bteain plumes. When con-
densed water vapor Is present within tbs
plume as it emerges from the emfeeilon •-
second period.
S.S Data Reduction. Opacity shall be eli-
te-mined as an average of 24 consecution
observations recorded at IB-second IntervsV,,
Divide the observations recorded on the rec-
ord sheet into sate of 24 consecutive obser-
vations. A set ia composed of any 24 con-
secutive observations. Sets need not be con-
secutive in time and. in no case shsli two
sate overlap, for each set af 24 observ? v•»-%
calculate ihe average by stunmtng the opacity
of the 3*. observations aod dividing this
by 24. If an applicable standard specifies an
averaging time requiring more than 21 ob-
servations, ealeul&te the average for all ob-
servations made during the specified time
period. Record the average opacity on a record
sheet. (See Figure 9-1 for an example.)
8. QuaU/lcationt and testing. -
8.1 Certification requirements. To receive
certification as a qualified observer, a can-
didate must be tested and demonstrate the
ability to assign opacity readings in B percent
increments to 25 different black Blums* "«»
U different w<c plumes, with an error
not to «*o*»d 15 psrosnt opacity on any one
reading and an average error not to exceed
7.8 percent opacity in aach category. Candi-
dates shall be tested according to the pro-
cedures described In paragraph 8.2. Smoke
generators used pursuant to paragraph 3.2
•hall be equipped with a smoke meter which
meets the requirements of paragraph 3.3
The certification shall be valid for a period
of 6 months, at which time the qualification
procedure must be repeated by any observer
in order to retain certification.
• 8.3 Certification procedure. The certifica-
tion test consists of showing the candidate a
complete run of 60 plumes — 25 Mack plumes
and 25 white plumes— generated by a smoke
generator. Plumes within each set of 26 black
and 25 white runs shall be presented in ran-
dom order. The candidate assigns an opacity
value to each plume and records his obser-
vation on a suitable form. At the completion
of each run of 60 readings, the More of the
candidate is determined. If A candidate fails
to qualify, the complete run of 50 readings
must be repeated in any retest. The smoke
test may be administered as part of a smoke
•chcoi or training program, and may be pre-
ceded by training or familiarization runs of
the smoke generator during which candidates
are showa black and white plumes of known
opacity.
• 8.3 Ssiok* generator epeclfioatioxus. Any
•moke generator used for the purposes of
paragraph S3 tsh&ll be equipped with » smoke
m»ter installed to measure opacity across
the diameter of the smoke generator stack.
The emok» ine-tar output shall display la-
stack opacity based upon a pathlength equal
to KSK aUct: exit diameter, on a full 0 to 100
percent chart recorder aoale. The smoke
meter optical design and performance sh&U
raeet the specifications shown in Table 9-1.
The cmolte meter thiai be calibrated as pre-
scribed in paragraph 83.1 prior to the con-
duct of each smoke reading test. At the>
oooxpletion of each test, the zero and span
dnn thai! be checked and If the drift ex-
•oeeds ±1 percent opacity, the condition shall
bo corrected prior to conducting any subse-
quent test runs. The smoke meter shall be
demonstrated, at the time of Installation, to
zne«t the specinca.Uaas listed in Table fr-i.
This demonstration shall be repeated fol-
lowing any subsequent repair or replacement
of toe photocell or associated electronic cir-
cuitry including the chart recorder or output
m»ter. or v"mr, $ cxsnhj, whichever occurs
Ot jferattsa. Tb* smoke meter if
omlltwated zflte allowing a minimum of 80
-enicutee VSJT-SUJ- by alternately producing
simulated cfwcitf of 0 percent end 100 per-
~'sr.t. When Bt&ble response Bt 0 percent or
100 percent is noted, the smoke meter is ad-
j-itt&d to prortuc* an output of 0 percent or
100 |>erc«nt, as appropriate. Tills calttirwfeloa
•hall be **pt*t*d uata stable 0 percent and
100 percent readings *r* produced without
ftdjustment. Simulated 0 percent and 100
percent ops-sit^ «^Juss z»«f be prcdwsad by
alternately switch tog th» rw*? t* *&e light
eaure* oa ^ad =2 i.Ml« the staoks
is not producing
IT-60
-------
tarn
i
Speoi/UxrttDn
Xneaadeeoent lamp
operated at nominal
rated, voltage.
Photoplo (daylight
• spectral response of
ttae human eye-
reference 4.3).
angle.
16* maximum total
angle.
•±a% opacity, maxi-
mum.
±1% opacity, 80
minutes.
Parameter:
*, Light KMtrce ,.
b. fJpeetral response
of photocell.
c. Angle of view
4. Angle of projec-
tion.
e. Calibration error.
f. Zero and apart
drift.
f. Response time—
8.3J Smoke meter evaluation. The smoke
meter design and performance are to be
evaluated at follows:
3.3.2.1 Light aource. Verify from manu-
facturer's data and froxr voltage measure-
ments made at the lamp, as Installed, that
the tf™r la operated witbux *S percent of
the nominal rated voltage.
8.3.2.2 Spectral response of photocell.
Verify from manufacturer's data that the
photocell has a photoplc response; 1*, the
•pectnl sensitivity of the cell shall closely
approximate the standard spectral-luminos-
ity curve for photoplc vision which b refer-
enced in (b) of Table 9-1.
3323 Angle of view. Check construction
geometry to ensure that the total angle of
•view of the smoke plume, as seen by the
photocell, does not exceed 16*. The toUl
angle of view may b* calculated from: •=»
tan-* d/2L, where t—total angle of view;
d=the sum of the photocell dlameter+th«
diameter of the limiting aperture: and
I,=tbe distance from toe photocell to th»
limiting aperture. The limiting aperture tt
the point In the path between the photocell
and the smoke plum* where the angle of
Ttow to mo* restricted, In smok» generator
•moke meters tnto to normally -aa orifice
plate.
8.3.3.4 Angle of projection. Check con-
struction geometry to ensure that the total
•ogle of projection of the lamp OB tb*
smoke plume does not axoeed It'. Ttee total
angle of projection may be calculated from:
*=2 tan-1 d/2L. where »= total angle ol pro-
jection; d= the sum of the length ef the
lamp filament 4- the diameter of the I'^'t^g
aperture; and Ic= the distance from the lamp
to the limiting aperture.
8.8.2.6 Calibration error. Using neutral-
density filters of known opacity, check the
error between the actual response and the
theoretical linear response of the smoke
meter. This check is accomplished by first
calibrating the smoke meter according to
8.3.1 and then Inserting a serlee of three
neutral-density filters of nominal opacity of
30, 60, and 76 peroent In the smoke meter
pathlength. Filters cailbartod within ±2 per-
cent shall be used. Oar* should be taken
•when inserting the filters to prevent stray
light from affecting the meter. Make a total
of five nonconsecutlve readings for each
filter. The ftT1""""' error on any one read-
ing shall be 3 peroent opacity.
3.8.2.6 Zero and span drift. Determine
the rero and span drift by calibrating and
operating the smoke generator in a normal
manner over • 1-hour period. The drift is
measured by checking the nro and span at
the end of this period.
932.1 Response time. Determine the re-
sponse time by producng the series of five
simulated 0 peroent and 100 peroent opacity
values and observing the time required to
reach stable response. Opacity Talus* of 0
percent and 100 peroent may be simulated
by alternately switching the power to the
light source off and on while the smoke
generator Is not operating.
4. RrJcrcnces.
4.1 Air Pollution Control District Rules
and Regulations, Los Angeles County Air
Pollution Control District, Regulation XV.
Prohibitions, Rule 60.
43 Weicburd, lielvin X, Field Operations
and Enforcement Mtnital for Air, TJJ3. Envi-
ronmental Protection Agency, Research Tri-
angle Park. N.O, APTD-1100. August 1972.
pp. 4.1-4.36.
C3 Condon, E. IT., and Odishaw.H, Hand-
book of Physios, McOrsw-HUl Oo, XT, N.T.
19H, Table 8.1. p. 6-S2.
11-61
-------
RECORD OF VISUAL DETERMINATION OF OPACITY
PAGE of
COMPANY
LOCATION_
TEST NUMBER.
DATE
TYPE FACILITY^
CONTROL DEVICE
HOURS OF OBSERVATION.
OBSERVER
OBSERVER CERTIFICATION DATE_
OBSERVER AFFILIATION
POINT OF EMISSIONS
HEIGHT OP DISCHARGE POINT
CLOCK TIME
OBSERVER LOCATION
Distance to Discharge
•Direction from Dtscharga
Height of Observation Point
BACKGROUND DESCRIPTION
HEATHER CONDITIONS
Wind Direction
Wind Speed
Ambient Temperature
SKY CONDITIONS (clear.
overcast* % clouds, etc.} .
PLUME DESCRIPTION
Color
Distance Visible
OTHER I»FORI1AT!0?I
Initial
Final
SUMMARY OF AVERAGE OPACITY
Set
Number
-
JimA
Start—End
Opaciti • .
Sum
Average
Readings ranged from
to
,3t opacity
The source was/was not in compliance with
the time evaluation vias made.
at
-------
FIGURE 9-2 OBSERVATION RECORD
PAGE OF
COMPANY '
LOCATION
TEST NUMBER"
WTE
OBSERVER
TYPE FAClltTV
POINT OF EMISSTORT
Mr.
Hin.
u
1
2
3
4
5
6
/
B
9
1o
ll
12
13
14
Ib
16
7
8
9
20
21
22
23
24
25
*b
27
28
29
0
Seconds
15
30
«b
STtAM PLUhE
(chtek 1f applicable)
Attached
Detached
COMMENTS
FIGURES-? OBSERVATION RECORD
(Continued)
PAGE OF .„
COHPANY
LOCATION
TEST NUMBET
DATE '
OBSERVER
TYPE FACIllTV ""
POINT OF EMISSlCRT
Hr.
M1n.
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
Seconds
0
Ib
JO
4b
STEAM PLUME
(check If applicable)
Attached
Detached
'
COMMENTS
^
|FB Doc.74-2«160 Filed 11-11-74:8:46 Ma]
-------
Method 19. Determination of Sulfur
Dioxide Removal Efficiency and
Particulate. Sulfur Dioxide and Nitrogen
Oxides Emission -Rates From Electric
Utility Steam Generators
I. Principle and Applicability
1.1 Principle.
1.1.1 Fuel samples from before and
after fuel pretreatment systems are
collected and analyzed for sulfur and
heat content, and the percent sulfur
dioxide (ng/Joule, Ib/million Btu)
reduction is calculated on a dry basis.
(Optional Procedure.)
1.1.2 Sulfur dioxide and oxygen or
carbon dioxide concentration data
obtained from sampling emissions
upstream and downstream of sulfur
dioxide control devices are used to'
calculate sulfur dioxide removal
efficiencies. (Minimum Requirement.) As
an alternative to sulfur dioxide
monitoring upstream of sulfur dioxide N
control devices, fuel samples may be
collected in an as-fired condition and
analyzed for sulfur and heat content.
(Optional Procedure.)
1.1.3 An overall sulfur dioxide
emission reduction efficiency is
calculated from the efficiency of fuel
pretreatment systems and the efficiency
of sulfur dioxide control devices.
1.1.4 Particulate, sulfur dioxide,
nitrogen oxides, and oxygen or carbon
dioxide concentration data obtained
from sampling emissions downstream
from sulfur dioxide control devices are
used along with F factors to calculate
paniculate, sulfur dioxide, and nitrogen
oxides emission rates. F factors are
values relating combustion gas volume
to the heat content of fuels.
1.2 Applicability. This method is
applicable for determining sulfur
removal efficiencies of fuel pretreatment
and sulfur dioxide control devices and
the overall reduction of potential sulfur.
dioxide emissions from electric utility
steam generators. This method is also
applicable for the determination of
particulate, sulfur dioxide, and nitrogen
oxides emission rates.
2. Determination of Sulfur Dioxide
Remo val Efficiency of Fuel
Pretreatment Systems
2.1 Solid Fossil Fuel.
2.1.1 Sample Increment Collection.
Use ASTM D 2234', Type I, conditions
A. B. or C, and systematic spacing.
Determine the number and v\ eight of
increments required per gross sample
representing each coal lot according to
Table 2 or Paragraph 7.1.5.2 of ASTM D
2234 '. Collect one gross sample for-each
raw coal lot and one gross sample for
each product coal lot.
2.1.2 ASTM Lot Size. For the purpose
of Section 2.1.1, the product coal lot size
is defined as the weight of product coal
produced from one type of raw coal. The
raw coal lot size is the weight of raw
coal used to produce one product coal
lot. Typically, the lot size is the weight
of coal processsed in a l-day'(24 hours)
period. If more than one type of coal is
treated and produced in 1 day, then
gross samples must be collected and
analyzed for each type of coal. A coal
lot size equaling the 90-day quarterly
fuel quantity for a specific power plant
may be used if representative sampling
can be conducted for the raw coal and
product coal.,
Note.—Alternate definitions of fuel lot
sizes may be specified subject to prior
approval of the Administrator.
2.1.3 Gross Sample Analysis.
Determine the percent sulfur content
(%S) and gross calorific value (GCV) of
the solid fuel on a dry basis for each
gross sample. Use ASTM 2013 ' for
sample preparation, ASTM D 3177 * for
sulfur analysis, and ASTM D 3173 ' for
moisture analysis. Use ASTM D 3176 '
for gross calorific value determination.
2.2 Liquid Fossil Fuel.
2.2.1 Sample Collection. Use .ASTM
D 270 * following the practices outlined
for continuous sampling for each gross
sample representing each fuel lot
2.2.2 Lot Size. For the purposes of
Section 2.2.1, the weight of product fuel
from one pretreatment facility and
intended as one shipment (ship load,
barge load, etc.) is defined as one
product fuel lot. The weight of each
crude liquid fuel type used to produce
one product fuel lot is defined as one
inlet fuel lot.
Note.— Alternate definitions of fuel lot
sizes may be specified subject to prior
approval of the Administrator.
Note.— For the purposes of th- , method,
raw or inlet fuel (coal or oil) is > efined as the
fuel delivered to the desulnirizstion
pretreatment facility or to the steam
generating plant. For pretreated oil the input
oil to the oil desulfr 'ization process (e.g.
hydrotreatment em tied) is sampled.
2.2.3 Sample Analysis. Determine
the percent sulfur content (%S) and
gross calorific value (GCV). Use ASTMD
240 ' for the sample analysis. This value
can be assumed to be on a dry basis.
1 Use the most recent revision or designation of
the ASTM procedure specified. .
'Use the most recent revision or designation of
the ASTM procedure specified.
11-64
-------
il.3 Calculation of Sulfur Dioxide Remov-
il Efficiency Due to Fuel PretreatmenL Cal-
ulate the percent sulfur dioxide reduction
ue to fuel pretreatment using the follow-
ng equation:
100
'•V6CVo
SS^GCV,
'here:
Rr = Sulfur dioxide removal efficiency due
pretreatment; percent.
S0 = Sulfur content of the product fuel lot
on a dry basis: weight percent.
5, = Sulfur content of the inlet fuel lot on
a dry basis: weight percent.
-V.=Gross calorific value for the outlet
fuel lot on a dry basis: kJ/kg (Btu/lb).'
-V, = Gross calorific value for the inlet
fuel lot on a dry basis; kJ/kg (Btu/lb).
"JoTE.—If more than one fuel type is used
produce the product fuel, use the follow-
: equation to calculate the sulfur contents
r unit of heat content of the total fuel lot,
5/GCV:
Where:
%R. =Sulfur dioxide removal efficiency of
the sulfur dioxide control system using
inlet and outlet monitoring data; per-
cent.
EM , = Sulfur dioxide emission rate from the
outlet of the sulfur dioxide control
system; ng/J Ob/million Btu).
EM i = Sulfur d.oxide emission rate to the
outlet of the sulfur dioxide control
system; ng/J (Ib/million Btu).
3.3 As-fired Fuel Analysis (Optional Pro-
cedure). If the owner or operator of an elec-
tric utility steam generator chooses to deter-
mine the sulfur dioxide imput rate at the
inlet to the sulfur dioxide control device
through an as-fired fuel analysis in lieu of .
data from a sulfur dioxide control system
inlet gas monitor, fuel samples must be col-
lected in accordance with applicable para-
graph in Section 2. The sampling can be
conducted upstream of any fuel processing.
:.g.. plant coal pulverization. For the pur-
poses of this section, a fuel lot size is de-
fined as the weight of fuel consumed in 1
day (24 hours) and is directly related to the
exhaust gas monitoring data at the outlet of
th*- sulfur dioxide control system. .
3.3.1 Fuel Analysis. Fuel samples must bo
analyzed for sulfur content and gross calo-
rific value. The ASTM procedures for deter-
mining sulfur content are defined in the ap-
plicable paragraphs of Section 2.
3.3.2 Calculation of Sulfur Dioxide Input
Rate. The sulfur dioxide imput rate deter-
mined from fuel analysis is calculated bv:
2.0(«f)
~GCV
2-0(SSf)
x 10 for S. I. units.
x 10 for English units.
Where:
"S/GCV
k-1
Y . (-.S./GCV. )
" * *
here:
, = The fraction of total mass input derived
from each type, k, of fuel.
5»-Sulfur content of each fuel type, k, on
a dry basis; weight percent.
CVk = Gross calorific value for each fuel
type, k. on a dry basis; kJ/kg (Btu/lb).
= The number of different types of fuels.
determination of Sulfur Removnl Efficien-
cy of the Sulfur Dioxide Control Device
;.l Sampling. Determine SO, emission
,es at the inlet and outlet of the sulfur
>xide control system according to meth-
s specified in the applicable subpart of
e regulations and the procedures specified
Section 5. The inlet sulfur dioxide emis-
>n rate may be determined through fuel
alysis (Optional, see Section 3.3.)
.2. Calculation. Calculate the percent
nova] efficiency using the following equa-
n:
9(m)
I » Sulfur dioxide input rate from as-fired fuel analysis,
ng/J (Ib/million Btu).
IS, = Sulfur content of as-fired fuel, on a dry basis; weight
percent.
GCV - Gross calorific value for as-fired fuel, on a dry basis;
kJ/kg (8tu/lb).
3.3.3 Calculation of Sulfur Dioxide Emis- dioxide emission rate. £»„, determined In
«on Reduction Using As-fired Fuel Analysis. the applicable paragraph of Section 5.3. The
The sulfur dioxide emission reduction effi- equation for sulfur dioxide emission reduc-
ciency is calculated using the sulfur imput tion efficiency is:
rate from paragraph 3.3.2 and the sulfur
Where:
SR /f, « Sulfur dioxide removal efficiency of the sulfur
dioxide control system using as-fired fuel analysis
j
data; percent.
ESO * Su1fur dioxide emission rate from sulfur dioxide control
system; ng/J (Ib/million Btu}.
I$ - Sulfur dioxide input rate from as-fired fuel analysis;
ng/J (Ib/million Btu).
11-65
-------
\. Calculation of Overall Reduction in
°otential Sulfur-Dioxide Emission
4.1 The overall percent sulfur
dioxide reduction calculation uses the
sulfur dioxide concentration at the inlet
to the sulfur dioxide control device as
the base value. Any sulfur reduction
realized through fuel cleaning is
introduced into the equation as an
average percent reduction, %Rf.
4.2 Calculate the overall percent
sulfur reduction as:
looci.o- O.o-^J) d.o-
rfhere:
M
SR
For SI Units:
Overall sulfur dioxide reduction; percent.
o
I. « Sulfur dioxide removal efficiency of fuel pretreatment
from Section 2; percent. Refer to applicable subpart
for definition of applicable averaging period.
Sulfur dioxide removal efficiency of sulfur dioxide control
9
device either 0. or C02 - based calculation or calculated
from fuel analysis and emission data, from Section 3;
percent. Refer to applicable subpart for definition of
applicable averaging period.
S. Calculation of Particulate, Sulfur
Dioxide, jind Nitrogen Oxides Emission
Hates
5.1 Sampling. Use the outlet SOi or
Oi or COt concentrations data obtained
in Section 3.1. Determine the particulate,
NO., and O» or CO. concentrations
according to methods specified in an
applicable subpart of the regulations.
5.2 Determination of an F Factor.
Select an average F factor (Section 5.2.1)
or calculate an applicable F factor
(Section 5.2.2.). If combined fuels are
Bred, the selected or calculated F factors
are prorated using the procedures in
Section 5.2.3. F factors are ratios of the
gas volume released during combustion
of a fuel divided by the heat content of
the fuel. A dry F factor (FJ is the ratio of
the volume of dry flue gases generated
to the calorific value of the fuel
combusted; a wet F factor (Fw) is the
ratio of the volume of wet Cue gases
generated to the calorific value of the
fuel combusted; and the carbon F factor
(F<:) is the ratio of the volume of carbon
dioxide generated to tfie calorific value
of the fuel combusted When pollutant
and oxygen concentrations have been
determined in Section 5.1, wet or dry F
factors are used. (Fw) factors and
associated emission calculation
procedures are not applicable and may
not be used after wet scrubbers; (Fe) or
(F
-------
Where:
Fa, F.. and F, have the units of scm/J, or scf/
million Btu; %H. %C. %S, %N, %O, and
%HjO are the concentrations by weight
(expressed in percent) of hydrogen,
carbon, sulfur, nitrogen, oxygen, and
water from an ultimate analysis of the
fuel; and GCV is the gross calorific value
of the fuel in kj/kg or Btu/lb and
consistent with the ultimate analysis.
Follow ASTM D 2015* for solid fuels, D
240* for liquid fuels, and D1826* for
gaseous fuels as applicable in
determining GCV.
5.2.3 Combined Fuel Firing F Factor.
for affected facilities firing
combinations of fossil fuels or fossil
fuels and wood residue, the Fd, Fw, or Fe
factors determined by Sections 5.2.1 or
5.2.2 of this section shall be prorated in
accordance with applicable formula as
follows:
20.9
n
£ X
k-1
n
I x
k-1
k Fdk
k Fwk
or
or
c
c
'Where:
x»=The fraction of total heat input derived
from each type of fuel, K. ,
n=The number of fuels being burned in
combination.
5.3 Calculation of Emission Rate.
Select from the following paragraphs the
applicable calculation procedure and
calculate the particulate, SOa, and NO,
emission rate. The values in the
equations are defined as:
E=Pollutant emission rate, ng/J (Ib/million
Btu).
C=Pollutant concentration, ng/scm (Ib/scf).
Note.—It is necessary in some cases to
convert measured concentration units to *•
other units for these calculations.
Use the following table for such
conversions:
Conversion Factor* lor Concentration
From— To— Multiply by—
B/scm ng/scm 10*
mg/scm . ng/scm .- ,, ^n*
1.602X101*
2.660x10*
1.912x10*
1.860X10-'
ppm/(NOJ.__ fc/scf 1.194x10-'
5.3.1 Oxygen-Based F Factor
Procedure.
5.3.1.1 Dry Basis. When both percent
oxygen (%OaJ and the pollutant
concentration (C.J are measured in the
flue gas on a dry basis, the following
equation is applicable:
' Mrd L20.9 - %02(jJ
5.3.1.2 ' Wet Basis. When both the
percent oxygen (%O2w) and the pollutant
concentration (Cw) are measured in the
flue gas on a wet basis, the following
equations are applicable: (Note: Fw
factors are not applicable after wet
scrubbers.)
CdFd
20.9
(a)
20.9
••20.9(1 -
Where:
Bw.=Proportion by volume of water vapor in
the ambient air.
In lieu of actual measurement, Bwm
may be estimated as follows:
Note.—The following estimating factors are
selected to assure that any negative error
introduced in the term:
, 20.9 i
X20.9(l - 8) - $0.'
will not be larger than —1.5 percent
However, positive errors, or over-
- estimation of emissions, of as much as 5
percent may be introduced depending
upon the geographic location of the
facility and the associated range of
ambient mositure.
(i) Bw.=0.027. This factor may be used
as a constant value at any location.
(ii) 8,.=Highest monthly average of
BW, which occurred within a calendar
year at the nearest Weather Service
Station.
(iii) 8,,=Highest daily average of B,,
which occurred within a calendar month
at the nearest Weather Service Station,
calculated from the data for the past 3
years. This factor shall be calculated for
each month and may be used as an
estimating factor for the respective
calendar month.
(b) i - c. F, d
-wfd
20.9
Z0.9
Where:
Bw,=Proportion by volume of water vapor in
the stack gas.
5.3.1.3 Dry/Wet Basis. When the
pollutant concentration (C,) is measured
on a wet basis and the oxygen
concentration (%Ojd) or measured on a
dry basis, the following equation is
applicable:
c _ r w d i r 20.9 -i
L20.9 - JO,
2d
When the pollutant concentration (CJ
is measured on a dry basis and the
oxygen concentration (%OM) is
measured on a wet basis, the following
equation is applicable:
11-67
20.9
5.3.2 Carbon Dioxide-Based F Factor
Procedure.
5.3.2.1 Dry Basis. When both the
percent carbon dioxide (%CO2,J and the
pollutant concentration (Cd) are
measured in the flue gas on a dry basis,
the following equation is applicable:
"d rc
5.3.2.2 Wet Basis. When both the
percent carbon dioxide (%COiw) and the
pollutant concentration (C,) are
measured on a wet basis, the following
equation is applicable:
TOO
5.3.2.3 Dry/Wet Basis. When the
pollutant concentration (C,) is measured
on a wet basis and the percent carbon
dioxide (%CO>d] is measured on a dry
basis, the following equation is
applicable:
When the pollutant concentration (CJ
is measured on a dry basis and the
precent carbon dioxide (%COtw) is
measured on a wet basis, the following
equation is applicable:
5.4 Calculation of Emission Rate
from Combined Cycle-Gas Turbine
Systems. For gas turbine-steam
generator combined cycle systems, the
emissions from supplemental fuel fired
to the steam generator or the percentage
reduction in potential (SO>) emissions
cannot be determined directly. Using
measurements from the gas turbine
exhaust (performance test, subpart GG)
and the combined exhaust gases from
the steam generator, calculate the
emission rates for these two points ,
following the appropriate paragraphs in
Section 5.3.
Note. — Fw factors shall not be used to
determine emission rates from gas turbines
because of the injection of steam nor to
calculate emission rates after wet scrubbers;
F4 or Fc factor and associated calculation
procedures are -used to combine effluent
emissions according to the procedure in
Paragraph 5-2.3.
The emission rate from the steam generator
is calculated as:
-------
sg
Where:
£„ = Pollutant emission rate from steam
generator effluent, ng/J (lb/mil!ion Btu).
E, = Pollutant emission rate in combined
cycle effluent; ng/J (Ib/million Btu).
£,, = Pollutant emission rate from gas turbine
effluent; ng/J (Ib/million Btu).
XM=Fraction of total heat input from
supplemental fuel fired to the steam
generator.
X,,,=Fracu'on of total heat input from gas
turbine exhaust gases.
Note.—The total heat input to the steam
generator is the sum of the heat input from
supplemental fuel fired to the steam
generator and the heat input to the steam
generator from the exhaust gases from the
go s turbine.
6.5 Effect of Wet Scrubber Exhaust,
Direct-Fired Reheat Fuel Burning. Some
wet scrubber systems require that the
temperature of the exhaust gas be raised
above the moisture dew-point prior to
the gas entering the stack. One method
used to accomplish this is directfiring of
an auxiliary burner into the exhaust gas.
The heat required for such burners is
from 1 to 2 percent of total heat input of
the steam generating plant. The effect of '
this fuel burning on the exhaust gas
components will be less than ±1.0
percent and will have a similar effect on
emission rate calculations. Because of
this small effect, a determination of
effluent gas constituents from direct-
fired reheat burners for correction of
stack gas concentrations is not
necessary.
Where:
s0=Sldndard devidtiun of the average outlet
hourly average emission rates for the
reporting period; ng/J [Ib/million Btu).
s(= Standard deviation of the average inlet
hourly average emission rates for the
reporting period; ng/J (Ib/million Btu).
6.3 Confidence Limits. Calculate the
lower confidence limit for the mean
outlet emission rates for SOa and NO,
and, if applicable, the upper confidence
limit for the mean inlet emission rate for
SO« using the following equations:
E.'=E.-t..-s.
Table 19-1.—FFactors for Various fuels'
Where:
Ef' =The lower confidence limit for the mean
outlet emission rates; ng/J (Ib/million
Btu).
E|*=The upper confidence limit for the mean
inlet emission rate; ng/J (Ib/million Btu).
t,.M = Values shown below for the indicated
number of available data points (n):
Fueltyp*
Cc«t
Anthracite'.. - —
LrgnrtB
Of t>
Gitr
Natural
(Man* ---,-
dscni
j
2.71x10-*
2.63x10-'
2.65X10-'
2.47x10"'
243x10-*
2.34x10-'
2.34x10-'
248x10"'
2.58x10-'
dsa
10' Btu
(10100)
(9780)
(9660)
(•100)
(8710)
(8710)
(8710)
(9240) -
(9600) _
WSCffl
J
£83x10-'
2.86x10-'
3.21X10-'
2.77x10-'
2.85x10-'
2.74X10-'
£78X10-'
w»cf
10* Btu
(10540)
(10640)
(11950)
(10320)
(10610)
(10200)
(10390)
•cm
J
0530x10-'
0484x10-'
0.513x10-'
0.383x10-'
0.287x10-'
0.321x10-'
0.337x10-'
0492x10-'
0497x10-'
•Ct
10* Btu
(1970)
(1800)
(1910)
(1420)
(1040)
(1190)
(1250)
(1830)
(1850)
• At ctamtaKl accorckng to ASTM D 388-66
' Crude, rwidual, or distillate.
•Det>rmned«! standard condfeon*. 20* C (68* F) and 760 mm Hg (29 92 in. Hg).
n
2
3
4
5
6
7
S
•
10
11
12-18
17-21
22-26
27-31
32-51
52-81
92-151
152 rx more
Values tor U*
**»
6.31
2.42
2.35
2.13
2.02
1.94
1.89
1.86
1.83
1.81
1.77
1.73
1.71
1.70
168
1.67
1.66
1.65
6. Calculation of Confidence Limits for
Inlet and Outlet Monitoring Data
6.1 Mean Emission Rates. Calculate
the mean emission rates using hourly
averages in ng/J (Ib/million Btu) for SO»
a.nd NO, outlet data and, if applicable,
SOj inlet data using the following
equations:
I x,
f m
1 "1
Where:
E,,=Mean outlet emission rate; ng/J (lb/
million Btu).
E,=Mean inlet emission rate; ng/J (Ib/million
Btu).
x.*= Hourly average outlet emission rate; ng/J
(Ib/million 3tu).
x,=Hourly ave, ige in let emission rate; ng/j
(Ib/million Btu).
l30=Number of outlet hourly averages
available for the reporting period.
ia,=Numberof inlet hourly averages >
available for reporting period.
8.2 Standard Deviation of Hourly
Emission Rates. Calculate the standard
deviation of the available outlet hourly
average emission rates for SOi and NO,
and, if applicable, the available inlet
hourly average emission rates for SOi
using the following equations:
PCC
PCC -
Where:
The values of this table are corrected for
n-1 degrees of freedom. Use n equal to
the number of hourly average data
points.
7, Calculation to Demonstrate
Compliance When Available
Monitoring Data Are Less Than the
Required Minimum
7.1 Determine Potential Combustion
Concentration (PCC) for SO*
7.1.1 When the removal efficiency
due to fuel pretreatrnent (% R() is
included in the overall reduction in
potential sulfur dioxfde emissions (% RJ
ar.d the "as-fired" fuel analysis is not
used, the potential combustion
concentration (PCC) is determined as
follows:
ng/J
Ib/milHon Btu.
Potential emissions removed by the pretreatment
I process, using the fuel parameters defined 1r>
section 2.3; ng/J (Ib/mllllon Btu).
11-68
-------
7.1.2 When the "as-fired" fuel
analysis is used and the removal
efficiency due to fuel pretreatment (% Rf)
is not included in the overall reduction
in potential sulfur dioxide emissions (%
RJ, the potential combustion
concentration (PCC) is determined as
follows:
PCC = I.
Where:
!, = The sulfur dioxide input rate as defined
in section 3.3
7.1.3 When the "as-fired" fuel
analysis is used and the removal
efficiency due to fuel pretreatment (% RJ
is included in the overall reduction (%
RO), the potential combustion
concentration (PCC) is determined as
follows:
PCC
PCC
7.1.4 When inlet monitoring data are
used and the removal efficiency due to
fuel pretreatment (% R,) is not included
in the overall reduction in potential
sulfur dioxide emissions (% RO), the
potential combustion concentration'
(PCC) is determined as follows:
PCC = EC
Where:
E,* = The upper confidence limit of the mean
inlet emission rate, as determined in
section 6.3.
7.2 Determine Allowable Emission
Rates (Bud).
7.2.1 NOV Use the allowable x
emission rates for NO, as directly
defined by the applicable standard in '
terms of ng/J (Ib/million Btu).
7.2.2 SO.. Use the potential
combustion concentration (PCC) for SOt
as determined in section 7.1, to
determine the applicable emission
standard. If the applicable standard is
an allowable emission rate in ng/J (lb/
million Btu), the allowable emission rate
10'; ng/J
1b/m1U1on Btu.
is used as E.^. If the applicable standard
is an allowable percent emission,
calculate the allowable emission rate
(E,ut) using the following equation:
Where:
% PCC = Allowable percent emissipn as
defined by the applicable standard;
percent. —
7.3 Calculate E, * /Eua. To determine
compliance for the reporting period
calculate the ratio:
Where:
£„*-= The lower confidence limit for the
mean outlet emission rates, as defined in
section 6.3; ng/J (Ib/million Btu).
EM = Allowable emission rate as defined in
section 7.2, ng/J (Ib/million Btu),
. If E,,* /E.U, is equal to or less than 1 .0, the
facility is in compliance; if E,*/!^ is greater
than 1.0, the facility is not in compliance for
the reporting period.
|FR Doc 79-17*07 Filed S-S-TB: 8:45 an]
BILLING CODE ««H>V4I
11-69
-------
Method 20—Determination ot Nitrogen
Oxides, Sulfur Dioxide, and Oxygen
Emissions from Stationary Gas Turbines
1. Applicability and Principle
1.1 Applicability. This method is
applicable for the determination of nitrogen
oxides (NO,), sulfur dioxide (SO3), and
oxygen (Oj) emissions from stationary gas
turbines. For the NO, and O-, determinations.
this method includes: (1) measurement
system design criteria, (2} analyzer
performance specifications and performance
test procedures; and (3] procedures for
emission testing,
J.2 Principle. A gas sample is
continuously extracted from the exhaust
stream of a stationary gas turbine; a portion
of the sample stream is conveyed to
instrumental analyzers for determination of
NO, and O> content. During each NO, and
OOi determination, a separate measurement
of SOa emissions is made, using Method 6, or
it equivalent. The O, determination is used to
adjust the NO. and SOt concentrations to a
reference condition.
2. Definitions
2.1 Measurement System. The total
equipment required for the determination of a
gas concentration or a gas emission rate. The
system consists of the following major
subsystems:
2.1.1 Sample Interface. That portion of a
system that is used for one or more of the
following: sample acquisition, sample
transportation, sample conditioning, or
protection of the analyzers from the effects of
the stack effluent.
2.1.2 NO, Analyzer. That portion of the
system that senses NO, and generates an
output proportional to the gas concentration.
2.1.3 O, Analyzer. That portion of the
system that senses O» and generates an
output proportional to the gas concentration.
2.2 Span Value. The upper limit of a gas
concentration measurement range that is
specified for affected source categories in the
applicable part of the regulations.
2.3 Calibration Gas. A known
concentration of a gas in an appropriate
diluent gas.
2.4 Calibration Error. The difference
between the gas concentration indicated by
the measurement system and the known
concentration of the calibration gas.
2.5 Zero Drift. The difference in the
measurement system output readings before
end after a stated period of operation during
which no unscheduled maintenance, repair,
or adjustment took place and the input
concentration at the time of the
measurements was zero.
2.6 Calibration Drift. The difference in the
measurement system output readings before
and after a stated period of operation during
which no unscheduled maintenance, repair,
or adjustment took place and the input at the
time of 4he measurements was a high-level
value.
2.7 Residence Time. The elapsed time
from the moment the gas sample enters ihe
probe tip to the moment the same gas sample
reaches the analyzer inlet.
2.8 Response Time. The amount of time
required for the continuous monitoring
system to display on the data output 95
percent of a step change in pollutant
concentration.
2.9 Interference Response. The output
response of the measurement system to a
component in the sample gas, other than the
gas component being measured.
3. Measurement System Performance
Specifications
3.1 NOi to NO Converter. Greater than 90
percent conversion efficiency of NO* to NO.
3.2 Interference Response. Less than ± 2
percent of the span value.
3.3 Residence Time. No greater than 30
seconds.
3.4 Response Time. No greater than 3
minutes.
3.5 Zero Drift. Less than ± 2 percent of
the span value.
3.6 Calibration Drift. Less than ± 2
percent of the span value.
4. Apparatus and Reagents
4.1 Measurement System. Use any
measurement system for NO, and Oj that is
expected to meet the specifications in this
method. A schematic of an acceptable
measurement system is shown in Figure 20-1.
The essential components of the
measurement system are described below:
N02 TO NO 1 - '
CONVERTER! - 1
V
S
\
CALIBRATION
GAS
SAMPLE GAS
MANIFOLD
Figure 20 1. Measurement system design for stationary gas turbines.
EXCESS
SAMPLE TO VENT
4.1.1 Sample Probe. Heated stainless
steel, or equivalent, open-ended, straight tube
of sufficient length to traverse the sample
points.
4.1.2 Sample Line. Heated (>95'C)
stainless steel or Teflon* bing to transport
the sample gas to the sample conditioners
and analyzers.
4 1.3 Calibration Valve Assembly. A
three-way valve assembly to dirc-<:t llit cero
and calibration gases to the sample
conditioners and to the anaiyzpis. The
calibration valve assen.blj sh,il! be capable
of blocking the samp-lo gas fov. ,ind of
introducing calibration gases to '.he
measurement system when in the calibration
mode.
4.1.4 NOZ to NO Converter. That portion
of the system that converts tlie nitrogen
dioxide (NOi) in Ihe sample j;as to nitrogen
oxide (NO). Some analyzers *re designed to
measure NO, as NOj on a wet basis and can
be used without an NOj to NO converter or a
moisture removal Irap provided the sample
line to the analyzer is heated (>95'C) to the
inlet of the analyzer. In addition, an NOi to
NO converter is not necehsai v if the NOS
portion of the exhaust gas is. less than 5
percent of the total NO, concentration. As a
guideline, an NO, to NO converter is not
necessary if the gas turbine IE operated at 90
percent or more of peak load r.apscity. A
converter is necessary undc' lower load
conditions.
4.1.5 Moisture Removal Tr«p. A
refrigerator-type condenser designed to
continuously remove condf-.i>s;ite from the
sample gas. The moisture n im-vol trap is not
necessary for analyzers that c,;m measure
NO, concentrations on a wet basis; for these
analyzers, (a) heal the (sample line up to the
inlet of the analyzers, (b) determine the
moisture content using methods subject to th«
approval of the Administrator, arid (c) correc!
the NO, and O, concentrations to a dry basis
4.1.6 Paniculate Filter. An in-stack or an
out-of-stack glass fiber filter, of the type
specified in EPA Reference1 Method 5:
however, an out-of-slack ijlter is
recommended when the stark gas
temperature exceeds 2SO to 300'C.
4.1.7 Sample Pump. A nonreactive leak-
free sample pump to pull the sample gas
through the system at a flow rate sufficient ic
minimize transport delay. The pump shall be
made from stainless steel or coated with
Teflon or equivalent.
4.1.8 Sample Gas Manifold A sample gas
manifold to divert portions of the sample gas
stream to the analyzers. The manifold may be
constructed of glass, Teflon, type 316
stainless steel, or equivalent.
4.1.9 Oxygen and Analyzer. An analyzer
to determine the percent Oa concentration of
the sample gas stream.
4.1.10 Nitrogen Oxides Analyzer. An
analyzer to determine the ppm NO, \
concentration in the sample gas stream.'
4.1.11 Data Output. A strip-chart recorder,
analog computer, or digital recorder for 1
recording measurement data.
4.2 Sulfur Dioxide Analysis. EPA
Reference Method 6 apparatus and reagents.
4.3 NO, Caliberation Gases. The
calibration gases for the NO, analyzer may
be NO in N,, NO, in air or Nj, or NO and NO,
11-70
-------
in N... For NOX meHsurement analyzers that
require oxidrition of NO to NO..-, the
calibration gases must be in the form of NO
in N-. Use four calibration gas mixtures as
specified below:
. 4.3.1 High-level Gas. A gas concentration
that is equivalent to 80 to 90 percent of the
span value.
J 4.3.2 Mid-level Gas. A gas concentration
that is equivalent to 45 to 55 percent of the
sp;m value.
4.3.3 Low-level Gas. A gas concentration
that is equivalent to 20 to 30 percent of the
span value.
4.3.4 Zero Gas. A gas concentration of
less than 0.25 percent of the span value.
Ambient air may be used for the NO, zero
gas.
4.4 O» Calibration Gases. Use ambient air
at 20.9 percent as the high-level O. gas. Use a
g.is concentration that is equivalent to 11-14
pprcrnt O, for the mid-level gas. Use purified
nitrogen for the zero gas.
4.5 NOa/NO Gas Mixture. For
determining the conversion efficiency of the
NOj to NO converter, use a calibration gas
mixture of N'O, and NO in N,. The mixture
iv.,i \-,n kmmit i:unc»n trillions of 40 to t>U pptu
NOi and 90 to 110 ppni NO and certified by
the gay manufacturer. This certification of gas
concentration must include a brief
(Inscription nf the procedure followed in
determining the concentrations.
5. Mt'a'ntn'n
-------
5.3 Calibration Check. Conduct the
calibration checks for both the NO, and ihe •
Oj analyzers as follows:
5.3.1 After the measurement system has
been prepared for use (Section 5.2). introduce
zero gates and the mid-level calibration
gases; set the analyzer output responses to
the appropriate levels. Then introduce each
of the remainder of the calibration gases
described in Sections 4.3 or 4.4. one at s time.
to the measurement system. Record the
responses on a form similar to Figure 20-3.
5.3.2 If the linear curve determined from
the z«ro and mid-level calibration gas
responses dot-s not predict the arliul
response of the low-level (not applicable for
the O, analyzer) and high-level gases within
±2 percent of the span value, the calibration
shall be considered invalid. Take corrective
measures on the measurement system before
proceeding with the test
5.4 Interference Response. Introduce the
gaseous components listed in Table 20-1 into
the measurement system separately, or as gas
mixtures. Determine the total interference
output response of the system to these
components in concentration units; record the
values on a form similar to Figure 20-4. If the
sum of the interference responses of the test
gases for either the NO, or O., dna'v/t-rs is
greater than 2 percent of the applicable spun
value, take corrective measure on the
measurement system.
Table 20-1.— Interference Test Gas Concentration
500-60 ppm
200 ~20 ppm.
10- 1 percent
percent
Turbine type:.
Date:
Identification number
Test number
Analyzer type:.
Identification number.
Cylinder Initial analyzer Final analyzer Difference:
value, response, responses, initial-final,
ppm or % ppm or % ppm or % ppm or %
Zero gas
Low - level gas
Mid - level gas
High - level gas
Percent drift =
Figure 20-3.
Absolute difference
X 100.
Span value
Zero and calibration data.
Conduct an interference response lest of
each analyzer prior to its initial use in the
field. Thereafter, recheck the measurement
system if changes are made in the
instrumentation that could alter the
interference response, e.g., changes in the
type of gas detector.
In lieu of conducting the interference
response test, instrument vendor data, which
demonstrate that for the test gases of Table
20-1 the interference performance
specification is not exceeded, are acceptable.
5.5 Residence and Response Time.
5.5.1 Calculate the residence time of the
sample interface portion of the measurement
system using volume and pump flow rate
information. Alternatively, if the response
time determined as defined in Section 5.5.2 is
less than 30 seconds, the calculations are not
necessary.
5.5-2 To determine response time, first
introduce zero gas into the system at the
11-72
-------
calibration valve until al! readings are stable;
thon. switch to monitor the stack effluent
until a stable reading can be obtained.
Record the upscale response time. Next,
introduce high-level calibration gas into the
system. Once jhe system has stabilized at the
high-level concentration, switch to monitor
the stack effluent and wait until a stable
value is reached. Record the downscale
response time.'Repeat the procedure three
times. A stable value is equivalent to a
change of less than 1 percent of span value
for 30 seconds or less than 5 percent of the
measured average concentration for 2
minutes. Record the response time data on a
form similar to Figure 20-5, the readings of
the upscale or downscale reponse time, and
report the greater time as the "response time"
for the analyzer. Conduct a response time
test prior to the initial field use of the
measurement system, and repeat if changes
are made in the measurement system.
Date of test.
Analyzer type.
Span gas concentration.
Analyzer span setting —
Upscale
1.
2.
3.
. S/N_
.ppm
ppm
.seconds
.seconds
.seconds
Average upscale response.
1
Downscale 2
3
.seconds
.seconds
.seconds
. seconds
Average downscale response.
.seconds
System response time = slower average time
.seconds.
Figure 20-5. Response time
5.0 NOi NO Conversion Kffic.iency.
Introduce to fht> system ;it the calibration
valve assembly, the NO=/I\O gris mixture
(Section 4 5). Kccord the response of the NO.
.m.-.h •-•• 'f !h:-iristri;rr"nt irvjonse indu-.ih'S
luhS i ,.in '.«' j' "i-< r.t N'Oj w NO K'nuTsum.
niakp curroitumi !o thp rni:.i«uipment system
.ind repeat ihf check Al'ernrttively. the NOi
to NO convei trr rheck described in Title 40
r.irl 83: CiT!:':::c:icn and /Vs.' Procedures for
Hciavy-Uuty Eng.nes for 197,U and Later
Model Years may be used. Other alternate
procedures may be used with approval of the
Administrator.
6. Emission Measurement Test Procedure
6.1 Preliminaries.
6.1.1 Selection of a Sampl;ng Site. Select a
siiniplin^ siti! as close as practical to ihe
exhaust of the turbine. Turbine geometry,
stack cmfiguration. internal baffling, and
point of introduction of dilution air will vary
for different turbine designs. Thus, each of
these factors must be given special
consideration in order to obtain a
representative sample. Whenever possible,
the sampling site shall be located upstream of
the point of introduction of dilution air into
the duct. Sample ports may be located before
or after the upturn elbow, in order to
accommodate the configuration of the turning
vanes and baffles and to permit a complete.
unobstructed traverse of the stack. The
sample ports shall not be located within 5
feet or 2 diameters (whichever is less) of the
gas discharge to atmosphere. For
supplementary-fired, combined-cycle plants.
the sampling site shall be located between
the gas turbine and the boiler. The diameter
of the sample ports shall be sufficient to
allow entry of the sample probe*.
6.1.2 A preliminary d traverse is made
for the purpose of selecting low O> values.
Conduct this test at the turbine condition that
is the lowest percentage of peak load
operation included in the program. Follow the
procedure below or alternative procedures
subject to the approval of the Administrator
may be used:
6.1.2.1 Minimum Number of Points. Select
a minimum number of points as follows: (1)
eight, for stacks having cross-sectional areas
less than 1.5 m" (16.1 ft1): (2) one sample point
for each 0.2 m*(2.2 ft1 of areas, for stacks of
1.5 m7 to 10.0 m1 (16.1-107.6 ft2) in cross-
sectional area: and (3) one sample point for
each 0.4 m- (4.4 ft-1) of area, for slacks greater
than 10.0 m * (107.6 ft *) in cross-sectional
area. Note that for circular ducts, the number
of sample points must be a multiple of 4. and
for rectangular ducts, the number of points
must be one of those listed in Table 20-2;
therefore, round off the number of points
(upward), when appropriate.
6.1.2.2 Cross-sectional Layout and
Location of Traverse Points. After the number
of traverse points for the preliminary O1
sampling has been determined, use Method 1
to located the traverse points.
6.1.2.3 Preliminary O* Measurement.
While the gas turbine is operating at the
lowest percent of peak load, conduct a
preliminary O1 measurement as follows:
Position the probe at the first traverse point
and begin sampling. The minimum sampling
time at each point shall be 1 minute plus the
average system response time. Determine the
average steady-state concentration of O1 at
each point and record the data on Figure 20-
6.
6.1.2.4 Selection of Emission Test
Sampling Points. Select the eight sampling
points at which the lowest O'2 concentration
were obtained. Use these same points for all
the test runs at the different turbine load
conditions. More than eight points may be
used, if dusired.
Table 2Q-2.—CrcsS'Sectional Layout for
Rectangular Stacks
Man
No. d traverse jicJ
9
12
16
20
25
30 _
36
42
43. _
3.3
4x3
4x4
5>4
SxS
6*5
8x6
7«S
7x7
11-73
-------
Location:
Plant.
Date.
City, State.
Turbine identification:
Manufacturer
Model, serial number.
Sample point
Oxygen concentration, ppm
Figure 20-6. Preliminary oxygen traverse.
6.2 NQX and O« Measurement. This test is
to be conducted at each of the specified load
conditions. Three test runs at each load
condition constitute a complete test.
6.2.1 At the beginning of each NO. test
run and, as applicable, during the run, record
turbine data as indicated in Figure 20-7. Also,
record the location and number of the
traverse points on a diagram.
BILLING CODE 6SM-01-M
6.2.2 Position the probe at the first point
determined in the preceding section and
begin sampling. The minimum sampling time
at each point shall be at least 1 minute plus
the average system response time. Determine
the average steady-state concentration of O»
and NO, at each point and record the data on
Figure 20-8.
IT.T-74
-------
Test operator ______
I
Turbine identification:
Tytfe
Serial No
Location:
Plant
City
TURBINE OPERATION RECORD
Date
Ultimate fuel
Analysis C
H
N
Ambient temperature.
Ambient humidity
Test time start _____
Ash
H2O
Trace Metals
Na
Test time finish.
Fuel flow rntea_
Va
etc0
Water or steam.
Flow rate3
Ambient Pressure.
Operating load.
aDescribe measurement method, i.e.. continuous flow meter,
start finish volumes, etc.
bi.e., additional elements added for smoke suppression.
Figure 20-7. Stationary gas turbine data.
Turbine identification: Test operator name.
Manufacturer ____________________
O2 instrument type.
Serial No
Model, serial No..
Location:
Plant
NOw instrument type.
Serial No..
City. State.
Ambient temperature.
Ambient pressure
Date
Test time - start.
Sample
point
*»
Time,
min.
s
ol.
%
NO;.
ppm
Test time • finish.
3 Aver age steady-state value from recorder or
instrument readout.
BHUHO cooe esw-ot-c
Figure 20-8. Stationary gas turbine sample point record.
11-75
-------
6.2 3 After sampling the last point.
conclude the test run by recording the final
turbine operating parameters and by
deterrrining the zero and calibration drift, as
follows:
Immediately following the test run at each
load condition, or if adjustments are
necessary for the measurement system during
the testy, reiatroduce the zero and mid-level
calibration gases as described in Sections 4.3,
and 4 4, one at a time, to the measurement
sysUr-. st the cal.bretion valve assembly.
(Make no Adjustments to the measurement
system urt:l after the drift checks are madej.
Record the analyzers' responses on a form
similar to Figure 20-3. If the drift values
exceed the specified limits, the test run
preceding the check is considered invalid and
will be repeated following conections to the
measurement system. Alternatively, the test
results may be accepted provided the
measurement system is recalibrated and the
calibration data that result in the highest
corrected emission rate are used.
6.3 SO, Measurement. This test is
conducted only at the 100 percent peak load
condition. Determine SOt using Method 6, or
equivalent during the test. Select a minimum
of six total points from those required for the
NO. measurements; use two points for each
sample run. The sample time at each point
shall be at least 10minutes. Average the O,
readings taken during the NO, test runs at
sample points corresponding to the SO2
traverse points (see Section 6.2.2) and use
this average O, concentration to correct the
integrated SO» concentration obtained by
Method 6 to 15 percent O, (see Equation 20-
If the applicable regulation allows fuel
sampling and analysis for fuel sulfur content
to demonstrate compliance with sulfur
emission unit, emission sampling with
Reference Me-hod 6 is not required, provided
the fuel sulfur content meets the limits of the
regulation.
7 Emission Calculations
7.1 Correction to 15 Percent Oxygen.
Using Equation 20-1, calculate the NO, and
SO2 concentrations (adjusted to 15 percent
O:). The correction to 15 percent Oj is
sensitive to the accuracy of the O2
measurement. At the levd of an.ih nor drift
specified in the method (±2 peiren! of full
seals), the change in the O; conct:!tt,;tion
correction can exceed 10 percent when the O2
content of the exhaust is above 16 percent O2.
Therefore O, analyzer stability and careful
calibration are necessary.
adj * rccs * -jj--5—!'~, (Equation 20-1)
°2
Where:
C.«j=Pollutant concentration adjusted to
15 percent O, (ppm)
CD)<,,= Pollutant concentration measured,
dry basis (ppm)
5.9=20.9 percent O.-15 percent O,. the
defined Oa correction basis
Percent O, = Percent O, measured drv
basis (%) *
7.2 Calculate the average adjusted NO,
concentration by summing the point values
and dividing by the number of sample points.
8. Citations
8.1 Curtis, f. A Method for Analyzing NO
Cylinder Gases-Specific Ion Electrode
Procedure, Monograph available from
Emission Measurement Laboratory, ESED,
Research Triangle Park. N.C. 27711, October
19/O.
(FR Doc. 78-27993 Filed &-7-T9. 8 45 am]
BILLING CODE 6S60-01-M
11-76
-------
APPENDIX B—PERFORMANCE SPECIFICATIONS
Performance Specification 1—Performaiice
specifications and specification test proce-
dures for transmi&someter systems for con-
tinuous measurement of the opacity of
stack emissions .
1. Principle and Applicability
1.1 Principle The opacity of paniculate
matter In stack emissions is measured by a
continuously operating emission measure-
ment system. These systems are based upon
the principle of transmlssometry which is a
direct measurement of the attenuation cf
visible radiation (opacity) by paniculate
matter In a stack effluent. Light having spe-
cfic spectral characteristics Is projected from
a lamp across the stack of a pollutant source
to a light sensor. The light Is attenuated due
to absorption and scatter by the paniculate
matter In the effluent. The percentage of
risible light attenuated Is denned as the
opacity of the emission. Transparent stack
emissions that do not attenuate light will
have a transmlttance of 100 or an opacity of
0. Opaque stack emissions that attenuate all
of the visible light will have a transmlttance
of 0 or an opacity of 100 percent. The trans-
mlssometer Is evaluated by use of neutral
density filters to determine the precisian of
the continuous monitoring system. Tests of
the system are performed to determine zero
drift, calibration drift, and response time
characteristics of the system.
1.2 Applicability. This performance' spe-
cification is applicable to the continuous
monitoring systems specified In the subparts
for measuring opacity cf emissions. Specifi-
cations tor continuous measurement of vis-
ible emissions are elven In terms of design.
performance, and Installation parameters.
These specifications contain tot procedures.
Installation requirements, and data compu-
tation procedures for evaluating the accept-
ability of the continuous monitoring systems
subject to approval by the Administrator.
2. Apparatus.
2.1 Calibrated Filters. Optical filters with
neutral spectra! characteristics and known
optical densities to risible light or screens
known to produce specified optical densities.
Calibrated filters with accuracies certified by
the manufacturer to within =±3 percent
opacity shall be used. Filters required are
low. mid, and high-range filters with nom-
inal optical densities as follows when the
transmlssometer is spanned at opacity levels
specified by applicable subparts:
BfMtlTt
(percent op
SO
«i
70
SO
fO
100 ..
C»Iibr»t*d filter optical densiricf
with rqulTtlem opacity In
<" parenthesis
Low-
ranee
0 1 (20)
) (20)
1 (20)
. . 1 (20)
1 (°0)
1 (20)
Mid-
ranee
• 0 5 (37)
2 (37)
3 (50)
3 (SO)
4 (CO)
« <«o>
Hiph-
r»nce
as (SO)
.3 (SO)
.4 (ffil
.6 (75)
.7 <(,'>
.« (67%
It Is recommended that filter calibrations
be- checked with a well-eollimated photopic
transmissometer of known linearity prior to
use. The filters sbal) be of sufficl-nt size
to attenuate the entire light beam of the
transmlssometer.
2.3 Data Recorder. Analog chart recorder
or other suitable device with Input voltage
range compatible with the tnalyzer system
output. The resolution of the recorder's
datfc output shall be sufficient to allow com-
pletion of the test procedures within this.
specification.
2.3 Opacity measurement System. An In-
rt*ck transmlssometer (folded or single
path) with the optical design specifications
designated below, associated control units
and apparatus to keep optical surfaces clean.
3. Definitions.
3.1 Continuous Monitoring System. The
total equipment required for the determina-
tion of pollutant opacity In a source effluent
Continuous monitoring systems consist of
major subsystems as follows:
3.1.1 Sampling Interface. The portion of a
continuous monitoring system for opacity
that protects the analyzer from the effluent
3.1.2 Analyzer. That portion of the con-
tinuous monitoring system which senses the
pollutant and generates a signal output thai
Is a function of the pollutant opacity.
3.1.3 Data Recorder. That portion of the
continuous monitoring system that processes
the analyzer output and provides a perma-
nent record of the output Hgna] in terms of
pollutant opacity.
32 Transmlssometer. The portions of &
continuous monitoring eystem for opacity
that Include the sampling interface and the
analyzer.
33 Span. The value of opacity at which
the continuous monitoring system Is set to
produce the maximum data display output.
The span shall be set at an opacity specified
In each applicable subparl.
3.4 Calibration Error. The difference be-
tween the opacity reading Indicated by the
continuous monitoring system and the
known values of a series of test standards
For this method the test standards are a
aeries of calibrated optical filters or screens.
3.S Zero Drift. The change In continuous
monitoring system output over a stated pe-
riod of time of normal continuous operation
whan tbe pollutant concentration at the
Mm* of the measurements 1s aero.
3.6 Calibration Drtft. Tbe change In tbe
continuous monitoring system output over
a stated period of time of normal continuous
operation when the pollutant concentration
at the time of the measurements U the same
known upscale value.
3.7 System Response. The time Interval
from a step change In opacity In the stack
at the Input to tbe continuous monitoring
system to the time at which 95 percent of
tbe corresponding final value la reached as
displayed on tbe continuous monitoring sys-
tem data recorder.
3.8 Operational Test Period. A minimum
period of time over which a continuous
monitoring system Is expected to operate
within certain performance specifications
without unscheduled maintenance, repair.
or adjustment.
S.9 lYansxnittance. The fraction of Incident
light that Is transmitted through an optical
medium of Interest.
8.10 Opacity. The fraction of Incident light
that Is attenuated by an optical medium of
Interest Opacity (O) and transmlttance (T)
are related as'follows:
O=1-T
• 3.11 Optical Density. A logarithmic meas-
ure of the amount of light that It attenuated
by an optical medium of Interest. Optical
density (D) Is related to the transmlttance
and opacity as follows:
D=-logIOT
D=-log,,(l-0)
8.12 Peak Optical Response. The wave-
length of maximum' sensitivity.of the Instru-
ment.
8.13 Mean Spectral Response. Tbe wave-
length which bisects the total area under
the curve obtained pursuant to paragraph
f.8.1.
8.14 Angle of View. The maximum (total)
angle of radiation detection by the photo-
detector assembly of the analyzer.
8.16 Angle of Projection. Tbe maximum
(total) angle that contains 95 percent of
the radiation projected from tbe lamp assem-
bly of the analyser.
8.16 Pathlenfth The depth of effluent In
Sbe light beam between the receiver and the
transmitter of the single-pass transmlssom-
eter, or the depth of effluent between the
transceiver and reflector of a double-pass
transmlssometer Two pathlengths are refer-
enced by this specification:
8.16.1 Monitor Pathlength. The depth of
effluent at the Installed location of tbe con-
tinuous monitoring system
3.162 Emission Outlet Pathlength The
depth of effluent at tbe location emissions are
released to the atmosphere
4. Installation Specification
4.1 Location. The tranamlssometer must
be located across a section of duct or stack
that will provide a paniculate matter flow
through the optical volume of the trans-
mlssometer that is representative of the par-
tlculate matter flow through the duct or
stack. It Is recommended that the monitor
pathlength or depth of effluent for the trans-
mlasometer Include the entire diameter of
tbe duct or stack. In installations using a
shorter pathlength, extra caution must be
used in determining the measurement loca-
tion representative of the paniculate matter
now through the duct or stack.
4.1.1 The transmlssometer location shall
be downstream from all paniculate control
equipment.
4.1.2 Tbe transmlssometer shall be located
as far from bends and obstructions as prac-
tical.
4.1.3 A transmlssometer that is located
in the duct or stack following a bend shall
be Installed in the plane defined by the
bend where possible
4.1.4 .The tranamiasometer should be In-
stalled in an accessible location.
4.1.5 When required by the Administrator.
the owner or operator of a source must
demonstrate that the tranamlssometer is lo-
cated In a section of duct or stack where
a representative paniculate matter distribu-
tion exists. The determination shall be ac-
complished by examining the opacity profile
of the effluent at a aeries of positions across
the duct or stack while the plant Is In oper-
ation at maximum or reduced operating rates
or by other testa, acceptable to the Adminis-
trator. .
42 Slotted Tube. Installations that require
the use of a slotted tube shall use a slotted
tube of sufficient size and blackness so as
not to Interfere with the free flow of effluent
through the entire optical volume of the
transmlsaometer or reflect light Into the
transmissometer photodetector. Light re-
flections may be prevented by using black-
ened baffles within the slotted tube to pre-
vent the lamp radiation from impinging upon
the tube walls, by restricting the angle of
projection of the light and the angle of view
of the photodetector assembly to less than
the cross-sectional area of the alotted tube.
or by other methods The owner or operator
must show that the manufacturer of the
monitoring system has used appropriate
methods to minimize light reflections for
systems using slotted tubes.
4.3 Data Recorder Output. The continuous
monitoring system output shall permit ex-
panded display of the span opacity on a
standard 0 to 100 percent scale. Since all
opacity standards are based on the opacity
of the effluent exhausted to the atmosphere.
the system output shall be based upon the
emission outlet pathlength and permanently
recorded. Por affected facilities whose moni-
tor pathlength Is different from the facility's
emission outlet pathlength, a graph shall be
provided with the Installation.to show the
relationships between the continuous moni-
toring system recorded opacity based upon
tbe emission outlet pathlength and tbe opac-
ity of'the effluent at tbe analyzer location
{monitor pathlength). Tests for measure-
ment of opacity that are required by this
performance specification are baaed upon tbe
11-77
-------
monitor pathlength. The graph Decenary to
convert the data recorder output to the
Monitor pathlength-bads shall be wtakllabed
as follows:
•Id-*)
0, = the opacity of the effluent baaed upon
li-
,,0,=th« opacity of the effluent baaed upon
lr
l, = the emlaslon outlet pathlength.
l,=ttoe monitor pathlength.
6. Optical Design Specifications
The optical design specifications set forth
in Section 0.1 shall be met In order for a
measurement system to comply with the
requirements of this method.
6. Determination of Conformance with De-
sign Specifications
e.i The continuous monitoring system for
measurement of opacity shall be demon-
strated to conform to the design specifica-
tions set forth as follows:
8.1.1 Peak Spectral Response. The peak
spectral response of the continuous moni-
toring systems shall occur between 600 nm
and 800 nm. Response at any wavelength be-
low 400 nm or above 700 nm shall be less
than 10 percent of the peak response of the
continuous monitoring system.
6.12 Mean Spectral Response. The mean
spectral response of the continuous monitor-
Ing system shall occur between 600 nm and
•00 nm.
•.1.3 Angle of View. The total angle of view
ahall be no greater than 6 degrees.
•.1.4 Angle of Projection The total angle
•f projection ahall be no greater than t de-
62 Conformant* with the requirements
of section 6.1 may be demonstrated by the
owner or operator of the affected facility by
testing each analyzer or by obtaining a cer-
tificate of conformance from the Instrument
manufacturer. The certificate must certify
that at least one analyzer from each month's
production was tested and satisfactorily met
all applicable requirements. The certificate
must state that the first analyzer randomly
sampled met all requirements of paragraph
• of this specification. If any of the require-
ments were not met, the certificate must
•bow that the entire month's analyzer pro-
duction was resampled according to the mili-
tary standard 105D sampling procedure
(MIL-8TD-106D) Inspection level II; was re-
torted for each of the applicable require-
ments under paragraph 6 of this specifica-
tion; and was determined to be acceptable
under MIL-STD-105D procedures. The certifi-
cate of conformance must show the result*
of each teat performed for the analyser*
sampled during the month the analyzer be-
ing installed was produced.
8.3 The general test procedures to be fqj-
lowed to demonstrate conformance with Sec-
tion 6 requirements are given as follows
(These procedures will not be applicable to
all designs and will require modification In
some cases. Where analyzer and optical de-
sign is certified by the manufacturer to con-
form with the angle of view or angle of pro-
jection specifications, the respective pro-
cedures may be omitted.)
6.3.1 Spectral Response. Obtain spectral
data for detector, lamp, and filter components
used In the measurement system from their
respective manufacturers. .
63.1 Angle of View. Set the received up
as specified by the manufacturer. Dri » an
arc with radius of 3 meters Measure the re-
ceiver response to a small (less than 8
centimeters) non-dlre:tlonal light source at
4-centlmeter Intervals on the arc for 36 centi-
meters on either side of the detector center-
line. Repeat the test In the vertical direction.
6.3S Angle of Projection. Set the projector
up as specified by the manufacturer. Draw
an arc with radius of 3 meters Using a small
photoelectric light detector (leas than 3
centimeters), measure the light intensity at
•-centimeter Intervals on the arc for 98
centimeters on either side of the light source
eenterllne of projection. Repeat the test In
the vertical direction
T Continuous Monitoring Brstem Per-
formance Specifications
The continuous monitoring system shall
meet the performance specification* in Table
1-1 to be conaldered acceptable under this
method
TABLE 1-1. — Perform* nrr
Parameter
Spedficatimt
a. .Calibration error ................. <» pet opacity '
bZwodrlft (24 h) .................. <2 pet opacity '
e.C»llbr»tl on drift (24 h) ........... <2 pet opadt\ '
d. Responw time ................... 10 s (maximum)
». Operational test period ........... l«8h.
i Expressed as sum of absolute mean value and the
(6 pet confidence interval of a series of tests.
8. Performance Specification Test
s. The following test procedures shall be
"to determine conformance with the re-
quirements of paragraph 7 :
•.1 Calibration Error and Response Time
Tsst. These tests are to be performed prior to
installation of the system on the stack and
may be performed at the affected facility or
at other locations provided that proper notifi-
cation is given. Set up and calibrate the
measurement system as specified by the
manufacturer's written Instructions for the
monitor pathlength to be used In the In-
stallation. Span the analyzer as specified In
applicable subparts.
8.1.1 Calibration Error Test. Insert a series
of calibration filters In the transmlssometer
path at the midpoint. A minimum of three
calibration filters (low, mid, and high-
range) selected In accordance with the table
under paragraph 2.1 and calibrated -within
S percent must be used Make a total of five
nonconsecutlve readings for each filter.
Record the measurement lyctem output
readings In percent opacity. (See Figure 1-1.)
8.1.2 "System Response Tsst. Insert the
high -range filter In the transmlssometer
path five times and record the time required
for the system to respond to 95 percent of
final zero and high-range filter values. (See
Figure 1-2.)
8.2 Field- Test for Zero Drtf t and Calibra-
tion Drift. Install the continuous monitoring
system on the affected facility and perform
the following alignments:
82.1 Preliminary Alignments. As soon as
possible after installation and once a year
thereafter when the facility Is not In opera-
tion, perform the following optical and zero
alignments:
82.1.1 Optical Alignment. Align the light
beam from the trausmlssometer upon the op-
tical surfaces located across the effluent (1*,
the retroflector or pbotodetector as applica-
ble) In accordance with the manufacturer's
Instructions.
82.12 Zero Alignment. After the trancmls-
someter has been optically aligned and the
transrnlssoroeter mounting la mechanically
stable (I.e.. no movement of the mounting
due to thermal contraction of the stack.
duct, etc.) and a clean stack condition has
been determined by a steady zero opacity
condition, perform the zero alignment. This
alignment la performed by balancing the con-
tinuous monitor system response so that any
simulated zero check coincides with an ac-
tual zero check performed across the moni-
tor pathlength of tb» clean stack.
82.1.3 Span. Span the continuous monitor-
ing system at the opacity specified In sub-
parts' and offset the zero setting at least 10
percent ol span so that negative drift can be
quantified.
8.22. Final Alignments. After the prelimi-
nary alignments have been completed and the
affected facility has been started up and
reaches normal operating temperature, re-
check the optical alignment In accordance
with 82.1.1 of this specification. If the align-
ment has shifted, realign the optics, record
any detectable shin In the opacity measured
by the system that can be attributed to the
cptlcal realignment, and notify the Admin-
istrator. This condition may not be objec-
tionable If the a3ected facility operates with-
in a fairly constant and adequately narrow-
range of operating temperatures that does
not produce significant shift* in optical
alignment during normal operation of the
facility Onder circumstances where the facil-
ity operations produce fluctuations In the
effluent gas temperature that result in sig-
nificant misalignments, the Administrator
may require improved mounting structures or
auother location for installation of the trans-
mlssometer.
82.3 Conditioning Period. After complet-
ing the post-startup alignments, operate the
system for an Initial 168-hour conditioning
period In a normal operational manner
82.4 Operational Test Period. After com-
pleting the conditioning period, operate the
system for an additional 168-hour period re-
taining the zero offset. The system shall mon-
itor the source effluent at all times except
when being zeroed or calibrated At 24-hour
Intervals the zero and span shall be checked
according to the manufacturer's Instructions
Minimum procedures used ahall provide a
system check of the analyzer internal mirrors
and all electronic circuitry including the
lamp and photodetector assembly and shall
include a procedure for producing a simu-
lated zero opacity condition and a simulated
upscale (span) opacity condition as viewed
by the receiver. The manufacturer's written
instructions may be used providing that they
equal or exceed these minimum procedures.
Zero and span the transmissometer, clean all
optical surfaces exposed to the effluent, rea-
lign optics, and make any necessary adjust-
ments to the calibration of the system dally.
These zero and calibration adjustments and
optical realignments are allowed only at 24-
hour intervals or at such shorter Intervals as
the manufacturer's written Instructions spec-
ify. Automatic corrections made by the
measurement system without operator Inter-
vention are allowable at any time. The mag-
nitude of any zero or span drift adjustments
ahall be recorded. During this 168-hour op-
erational test period, record the following at
24-hour intervals: (a) the zero reading and
•pan readings after the system is calibrated
(these readings should be set at the same
value at the beginning of each 24-hour pe-
riod);, (b) the zero reading after each 24
hours of operation, but before cleaning and
adjustment; and (c) t*e soan readme after
cleaning and zero adlustment, but before
span adlustment. (See Fieure 1-3.)
e. Calculation, Data Analysis, and Report -
^T.l Procedure for Determination of Mean
Values and Confidence Intervals.
0.1.1 The mean value of the data set is cal-
culated according to equation 1-1.
n i-i Equation 1-1
where x,= absolute value of the individual
measurements,
:=sum of the Individual values.
x=mean value, and
D=number of data points.
9.1.2 The G5 percent confidence' interval
(tm-o-slded) Is calculated according to equa-
tion 1-2:
nyn - 1
Equation 1-2
irhcre
£j;i=sum of all data points,
1*75=11 — 01/2, and
C.I.»j=95 percent confidence interval
estimate of the average mean
value.
The values In this table are already cor-
rected for n-I degrees of freedom. Use n equal
to the number of sample* as data points.
11-78
-------
Values for '.575
n
2 .
3
4
5 ...
6
7
g
«
-.975
12 "Ofi
4 303
8 18"
2 776
2 571
2 447
2 865
1*00
n
50
11
12
13
14
15
16
'.975
1 Vil
2 226
2 201
2.179
2 160
S 145
2.131
92 Data Analysis and Reporting.
9.2.1 Spectral Response. Combine the
spectral data obtained In accordance with
paragraph 6.3.1 to develop the effective spec-
tral response curve of the transmlssometer.
Report the wavelength at which the peak
response occurs, the wavelength at which the
mean response occurs, and the maximum
response at any wavelength below 400 nm
aiid above 70C nm expressed as a percentage
of the peak response as required under para-
graph 6.2
9.2.2 Angle of View Using the data obtained
in accordance with paraerapb 6.32. calculate
the response of the receiver as a function of
viewing angle in the horizontal and vertical
directions (26 centimeters of arc with &
radius of 3 meters equal S degrees). Report
relative angle of view curves as required un-
der paragraph 6.2.
9.2.3 Angle of Projection. Using the data
obtained in accordance with paragraph 6.3.3.
calculate the response of the photoelectric
detector as a function of projection angie in
tbe horizontal and vertical directions Report
relative angle of projection curves ae required
under paragraph 6.2.
9.2 4 Calibration Error. Using the data from
paragraph 81 (Figure 1-1), subtract the
known filter opacity value from the va:ue
shown by the measurement system for each
of tbe IS readings. Calculate tbe mean and
95 percent confidence Interval of tbe five dif-
ferent values at each test filter value accord-
Low
Range
Span Value
% opacity
X opacity
M1d
Range % opacity
High
Range X opacity
Date of Test
Location of Test
Calibrated Filter
.1
Analyzer Reading
% Opacity
Differences
% Opacity
n
T3
14
15
Mean difference
Confidence Interval
Calibration error » Mean Difference + C.I.
Low Hid High
Low, mid or high range
Calibration filter opacity - analyzer reading
Absolute value
Figure 1-1. Calibration Error Test
Ing to equatjriis 1-1 and 1-2 Reoort the sum
of the absolute mean difference and the 65
percent confidence Interval for each of tie
'three test filters
9.2.5 Zero Drift Using tbe «ero opacity
values measured every 24 hours during the
field test (paragraph 8.2). calculate the dif-
ferences between the zero point after clean-
ing. aligning, and adjustment, and the zero
value 24 hours later Just prior to cletnjng.
aliening. and adjustment Calculate the
mean value of these points B J the confi-
dence interval using equations 1-1 and 1-2
Report tbe sum of the Absolut* mean value
and the 95 percent confidence Interval
9.26 Calibration Drift. Using the span
value measured every 24 hours during the
field test, calculate the differences between
the span value after cleaning, aligning, and
adjustment of zero and span, and the spar.
value 24 bours later Just after clearJr.p
aligning, and adjustment of zero and before
adjustment of span Calculate the mecr.
value of these points and the conf.der.co
interval using equations 1-1 and 1-2 Report
the sum of the absolute mean value and the
confidence Interval.
92 7 Response Time. Using the data from
paragraph 8.1. calculate tbe time interval
from filter Insertion to 95 percent of the final
stable value for all upscale and downscaie
traverses Report tbe mean of tbe 10 upscale
and downscaie test times.
9.2.8 Operational Test Period. During the
168-hour operational test period, tbe con-
tinuous monitoring system shall not require
any corrective maintenance, repair, replace-
ment. or adjustment other than tbat clean?
specified as required in tbe manufacturer's
operation and maintenance manuals as rou-
tine and expected during a one-week period.
If the continuous monitoring system is oper-
ated within the specified performance pa-
rameters and does not require corrective
maintenance, repair, replacement, or adjust-
ment other than as specified above during
tbe 168-hour test period, the operational
test period shall have been successfully con-
cluded. Failure of the continuous monitor-
Ing system to meet these requirements shall
call for a repetition of the 168-hour test
period Portions of tbe tests which were sat-
isfactorily completed need not be repeated
Failure to meet any performance specifica-
tion (s) shall call for a repetition of the
one-week operational test period and that
specific portion of the tests required by
paragraph 8 related to demonstrating com-
pliance with the failed specification. All
maintenance and adjustments required shall
be recorded Output readings sbal! be re-
corded before and after all adjustments.
^
ExDerlmental Statistics," Department
of Commerce, National Bureau of Standards
Handbook PI, 1063. pp. 3-31, paragraphs
3-3.1.4.
102 "Performance Specifications for Sta-
tionary-Source Monitoring Systems for Oases
and Visible Emissions," Environmental Pro-
tection Agency. Research Triangle Park.
N.C.. EFA-650/3-74-018. January 1674.
11-79
-------
Zero Sitting
it»n Sitting
(Sec pr«t10n Drift • Nun Spin Drift*
.+ CI (Sp«n)
Akltlvtt Mint
PBFOBMANCE SPECIFICATION 2—PnroBMANCz
•PECOTCATIONS AND SPECIFICATION TEST PRO-
CEDtmES FOR MONITORS OF SO} AND NOx
FROM STATIONARY SOUBCES
1 Principle and Applicability.
1.1 Principle The concentration of sulfur
dioxide or oxides of nitrogen pollutants in
•tack emissions is measured by a continu-
ously operating emission measurement sys-
tem. Concurrent with operation of the con-
tinuous monitoring system, tbe pollutant
concentrations are also measured with refer-
ence methods (Appendix A). An average of
the continuous monitoring system data Is
computed for each reference method testing
period and compared to determine the rela-
tive accuracy of the continuous monitoring
system Other tests of the continuous mon-
itoring system are also performed to deter-
mine calibration error, drift, and response
characteristics of the system
13 Applicability. This performance spec-
ification is applicable to evaluation of con-
tinuous monitoring systems for measurement
of nitrogen oxides or sulfur dioxide pollu-
tants. These specifications contain test pro-
cedures, installation requirements, and data
computation procedures for evaluating the
acceptability of the continuous monitoring
systems.
1. Apparatus
94 Calibration Oas Mixtures. Mixtures of
Icnown concentrations of pollutant gas in a
diluent gas shall be prepared. The pollutant
gas shall be sulfur dloxjde or tbe appropriate
oxide(s) of nitrogen specified by paragraph
6 and within subparts. For sulfur dioxide gas
mixtures, the diluent gas may be air or nitro-
gen. For nitric oxide (NO) gas mixtures, the
diluent gas shall be oxygen-free «10 ppm)
nitrogen, and for nitrogen dioxide (NO,) gas
mixtures the diluent gas shall be air. Concen-
trations of approximately SO percent and 90
percent of span are required. Tbe 80 percent
gas mixture la used to set and to check tbe
•pan and is referred to as the span gas.
93 Zero Oas. A gas certified by the manu-
facturer to contain less than 1 ppm of the
pollutant gas or ambient air may be used.
3.3 equipment for measurement of the pol-
lutant gas concentration using the reference
method specified in the applicable standard.
2.4 Data Recorder. Analog chart recorder
or other suitable device with input voltage
range compatible with analyzer system out-
put. The resolution of the recorder's data
output shall be sufficient to allow completion
of the test procedures within this speclfl-
catlon.
2.5 Continuous monitoring system for SO,
or NOi pollutants as applicable.
8. Definitions
3.1 Continuous Monitoring System. The
total equipment required for the determina-
tion of a pollutant gas concentration In a
source effluent. Continuous monitoring cys-
tems consist of major subsystems as follows:
3.1.1 Sampling Interface—That portion of
an extractive continuous monitoring system
that performs one or more of tbe following
operations: acquisition, transportation, and
conditioning of a sample of tbe source efflu-
ent or that portion of an in-sltu continuous
monitoring system that protects the analyzer
from the effluent.
3.12 Analyzer—That portion of the con-
tinuous monitoring system which senses the
pollutant gas and generates a signal output
that Is a function of the pollutant concen-
tration.
3.1.3 Data Recorder—That portion of tbe
continuous monitoring system that provides
a permanent record of the output signal In
terms of concentration units.
3J2 Span. The value of pollutant concen-
tration at which the continuous monitor-
ing system Is set to produce the maximum
data display output. The span shall be act
at the concentration specified in each appli-
cable subpart
3.3 Accuracy (Relative). The degree of
correctness with wbtch the continuous
monitoring system yields the value of (as
concentration of a sample relative to tbe
value given by a defined reference method.
This accuracy is expressed in terms of error.
which Is tbe difference between the paired
concentration measurements expressed a* a
percentage of tbe mean reference value.
8.4 Calibration Irror. The difference be-
tween the pollutant concentration Indi-
cated by the continuous monitoring syBterr
and the known concentration ol the te»:
(as mixture
S.B Zero Drift The change In the continu-
ous monitoring system output over a stated
period of time of normal continuous opera-
tion when the pollutant concentration at
tbe time for the measurements is zero
3.8 Calibration Drift The change In the
continuous monitoring system output over
a rtated time period of normal continuous
operations when the pollutant concentra-
tion at tbe time of the measurements IE the
acme known upscale value
8.7 Response Time Tbe time Interval
from a step change in pollutant concentra-
tion at the Input to the continuous moni-
toring system to the time at which 95 per-
cent of the corresponding final value is
reached as displayed on the continuous.
monitoring system data recorder.
8.8 Operational Period. A minimum period
of time over which a measurement system
!• expected to operate within certain per-
formance specifications without unsched-
uled maintenance, repair, or adjustment
8.9 Stratification A condition identified
toy a difference In excess of 10 percent be-
tween the average concentration in the duct
or stack and the concentration at any point
more than l.O meter from the duct or stack
wall.
« Installation Specifications Pollutant
continuous monitoring systems (SO, and
NO,) shall be Installed at a sampling* loca-
tion where measurements can be made which
are directly representative (4.1), or which
can be corrected so as to be representative
(4.2) of the total emissions from the affected
facility Conformance with this requirement
•ball be accomplished as follows-
4.1 Effluent gases may be assumed to be
•onstratlfied If a sampling location eight or
more stack diameters (equivalent diameters)
downstream of any air in-leakage is se-
lected. This assumption and data correction
procedures under paragraph 4.2.1 may not
be applied to sampling locations upstream
of an air preheater In a •team generating
facllltv under Subpart D of this part. For
sampling locations where effluent gases are
either demonstrated (4.3) or may be as-
sumed to be nonstratlfled (eight diameters).
a point (extractive systems) or path (in-sltu
•ymtems) of average concentration may be
monitored.
4.2 For sampling locations where effluent
(ases cannot be assumed to be nonstratl-
fled (less than eight diameters) or have been
shown under paragraph 4.3 to be stratified,
results obtained must be consistently repre-
sentative (e.g. a point of average concentra-
tion may shirt with load changes) or the
data generated by sampling at a point (ex-
tractive systems) or across a path (In-sltu
systems) must be corrected (4.2.1 and 122)
eo as to be representative of the total emls-
•lons from the affected facility. Conform-
ance with this requirement may be accom-
plished In either of the following ways-
4.2.1 Installation of a diluent continuous
monitoring system (O. or CO. as applicable)
In accordance with the procedures under
paragraph 4.2 of Performance Specification
8 of thl appendix. If the pollutant and
diluent monitoring systems are not of the
same type (both extractive or both In-sltu)
the extractive system must use a multipoint
probe.
4.1.2 Installation of extractive pollutant
monitoring systems using multipoint sam-
pling probes or In-sltu pollutant monitoring
systems that sample or view emissions which
are consistently representative of tbe total
emissions for tbe entire cross eection. The
Administrator may require data to be «ub-
11-80
-------
ml tied to demonstrate that the «miaslons
sampled or viewed an consistently repre-
sentative for several typical facility procen
operating conditions.
4-3 Tbe owner or operator may perform a
traverse to characterize an; stratification of
effluent gases that might exist In a stack or
duct. If no stratification Is present, sampling
procedures under paragraph 4.1 may be ap-
plied even though the eight diameter criteria
Is not met.
4.4 When single point sampling probes for
extractive systems are Installed within the
stack or duct under paragraphs 4.1 and 4.2.3.
the sample may not be extracted at any point
less than 1.0 meter from the (tack or duct
wall. Multipoint sampling probes Installed
under paragraph 4.2.2 may be located at any
points necessary to obtain consistently rep-
resentative samples.
5. Continuous Monitoring System Perform-
ance Specifications.
The continuous monitoring system shall
meet the performance specifications In Table
3-1 to be considered acceptable under "this
method.
6.2.3.3 Adjustments. Zero and calibration
correction* and adjustment are allowed oaly
at 24-hour intervale or at s-uch shorter In-
tervals as the manufacturer's written In-
structions specify. Automatic corrections
made by the measurement system without
operator Intervention or Initiation are allow-
able at any time. During the entire 168-hour
operational test period, record on the ex-
ample sheet shown in Figure 2-5 the values
given by zero and span gas pollutant con-
centrations before and after adjustment at
24-hour Intervals.
6.3 Field Test for Response Time.
63.1 Scope of Test. Use the entire continu-
ous monitoring system as Installed. Including
sample transport lines If used. Flow rates,
line diameters, pumping rates, pressures (do
not allow the pressurized calibration gas to
change the normal operating pressure to the
;. Calibration error' Ss'pit of each (50 pet, 90 pet) cab braUon gas mixture "fPle Hne), etc.. shall be at the nominal
value. values for normal operation
S. Zero drift (2 b) i 2pctofspan
4. Zero drift (24 h)' Do.
5. Calibration drift (2h)' Do.
6. Calibration drift (24 b)' „ 2.5 pet. of span
7. Ffjtpfrnw time................. ............. . 15 rnln maximum.
8. Operational period 168 b minimum.
1 Expressed a> sum of absolute mean value plus 95 pet confidence Interval of a series of. tests.
TABLE 2-1.—Performance ipeciflcations
ftmuter
Spietfieatum
i. Accuracy'
e mean value of the reference method test
6. Performance Specification Test Proce-
dures:. The following test procedures shall be
used to determine conformance with the
requirements of paragraph 5. For NO. an-
requlrements of paragraph 5. For NO. an-
alyzers that oxidize nitric oxide (NO) to
nitrogen dioxide (NO,), the response time
test under paragraph 6.3 of this method shall
be performed using nitric oxide (NO) span
gas. Other tests for NO, continuous monitor-
Ing systems under paragraphs 6.1 and 6.2 and
all tests for sulfur dioxide systems shall be
performed using the pollutant span gas spe-
cified by each subpart.
6.1 Calibration Error Test Procedure. Set
up and calibrate the complete continuous
monitoring system according to the manu-
facturer's wrlten Instructions. This may be
accomplished either In the laboratory or In
the field.
6.1.1 Calibration Gas Analyses. Triplicate
analyses of the gas mixtures shall be per-
formed within two weeks prior to use using
Reference Methods 6 for SO, and 7 for NO..
Analyze each calibration gas mixture (50%,
GO^o) and record the results on the example
sheet shown in Figure 2-1. Each sample test
result must be within 20 percent of the aver-
aged result or the tests shall be repeated.
This step may be omitted for non-extractive
monitors where dynamic calibration gas mix-
tures are not used (6.12).
6.1.3 Calibration Error Test Procedure.
Make a total of 15 nonconsecutlve measure-
ments by alternately using zero gas and each
:allberatlon gas mixture concentration (e.g
3-r. 50%. 0%. 90%. 50%, 90%. 50%. 0%,
etc.). For nonextractive continuous monitor-,
Ing systems, this test procedure may be per-
formed by using two or more calibration gas
~ells whose concentrations are certified by
the manufacturer to be functionally equiva-
lent to these gas concentrations. Convert the
continuous monitoring system output read-
ings to ppm and record the results on the
example sheet shown In Figure 2-2.
62 Field Test for Accuracy (Relative).
Zero Drift, and Calibration Drift. Install and
operate the continuous monitoring system In
accordance with the manufacturer's written
Instructions and drawings as follows:
6.2.1 Conditioning Period. Offset the zero
setting at least 10 percent of the span ao
that negative zero drift can be quantified.
Operate the system for an Initial 168-hour
conditioning period In normal operatlne
manner.
8.2.2 Operational Te«t Period. Operate the
continuous monitoring system for an addi-
tional 168-hour period retaining the zero
offset. The system shall monitor the source
effluent at all times except when being
zeroed, calibrated, or backpurged.
6.2.2.1 Field Test for Accuracy (Relative).
For continuous monitoring systems employ-
Ing extractive sampling, the probe tip for the
continuous monitoring system and the probe
tip for the Reference Method sampling train
should be placed at adjacent locations In the
duct. For NO, continuous monitoring sys-
tems, make 27 NOX concentration measure-
ments, divided Into nine sets, using the ap-
plicable reference method. No more than one
set of tests, consisting of three Individual
measurements, shall be performed in any
one hour. All Individual measurements of
each set shall be performed concurrently,
or within a three-minute Interval and the
results averaged. For SO, continuous moni-
toring systems, make nine SO. concentration
measurements using the applicable reference
method. No more than one measurement
shall be performed in any one hour. Record
the reference method test data and the con-
tinuous monitoring system concentrations
on the example data sheet shown in Figure
2-3.
6.2.22 Field Test for Zero Drift and Cali-
bration Drift. For extractive systems, deter-
mine the values given by zero and span gas
pollutant concentrations at two-hour Inter-
vals until 15 sets of data are obtained. For
nonextractive measurement systems, the zero
value may be determined by mechanically
producing a zero condition that provides a
system check of the analyzer Internal mirrors
and all electronic circuitry Including the
radiation source and detector assembly or
by inserting three or more calibration gas
cells nnd computing the zero point from the
upscale measurements. If this latter tech-
nique is used, a graph(s) must be retained
by the owner or operator for each measure-
ment system that shows the relationship be-
tween the upscale measurements and the
zero point. The span of the system shall be
checked by using a calibration gas cell cer-
tified by the manufacturer to be function-
ally equivalent to 50 percent of span concen-
tration. Record the zero and span measure-
ments (or the computed zero drift) on the
example data sheet shown In Figure 3-4.
The two-hour periods over which measure-
ments are conducted need not be consecutive
but may not overlap. AU measurements re-
quired under this paragraph may be con-
ducted concurrent with tests under para-
graph 6.2.2.1.
as specified Hi
the manufacturer's written Instructions. If
the analyzer is used to sample more than one
pollutant source (stack), repeat this test for
each sampling point.
8.3.2 Response Time Test Procedure. In-
troduce zero gas Into the continuous moni-
toring system sampling Interface or as close
to the sampling Interface as possible. When
the system output reading has stabilized,
switch quickly to a known concentration of
pollutant gas. Record the time from concen-
tration switching to 95 percent of final stable
response. For non-extractive monitors, the
highest available calibration gas concentra-
tion shall be switched Into and out of the
sample path and response times recorded.
Perform this test sequence three (3) umes.
• Record the results of each test on the
example sheet shown In Figure 2-6.
7- Calculations. Data Analysis and Reran.
Ing. -
7.1 Procedure for determination of mean
values and confidence intervals.
7.1.1 The mean value of a data set Is
calculated according to equation 2-1.
*-' Equation '}.- )
where:
x, = absolute value of the measurements,
2 = sum of the Individual values,
S= mean value, and
n = number of data points.
7.1 2 The 95 percent confidence interval
(two-sided) Is calculated according to ecua-
tlon 2-2: -MU--
CT ••
.I.M=—r.
1.175
Equation 2-2
where:
Zx,— sum of all data points,
t.t7i=ti— a/2, and
C.I.M=95 percent confidence interval
estimate of the average mean
value.
Values for ».97S
n •.975
2 ............. „ 12.708
3 ............... 4. SOB
4 ............... 1182
5 --- : ........... 1778
6 .......... --- . 2.571
7 ............... 1447
| ............... 1J85
S ----- .-. ....... 2.806
W ............... 2.282
JT-— ........ — 2.228
12 ....... ~ ...... 2,201
1» ...... . ........ 1179
J4 ......... ----- 2. 180
15 ............... 2.145
Tbe value* in this table are already cor-
rected (or n-1 degree* of freedom. Use n
11-81
-------
*qutl to tbe number of samples a« data
point*.
72 Data Analysis and Reporting.
7.2.1 Accuracy (Relative). For each of the
nine reference method test points, determine
the average pollutant concentration reported
by the continuous monitoring system. These
average concentrations snail be determined
from the continuous monitoring system data
recorded under 7.2.3 by Integrating or aver-
aging the pollutant concentrations over each
at the time Intervals concurrent with each
reference method testing period. Before pro-
ceeding to the next step, determine the basis
(wet or dry) of the continuous monitoring
system data and reference method test data
concentrations. If the bases are not con-
sistent, apply a moisture correction to either
reference method concentrations or the con-
tinuous monitoring system concentrations
as appropriate. Determine the correction
factor by moisture tests concurrent with the
reference method testing periods. Report the
moisture test method and the correction pro-
cedure employed. For each of the nine test
runs determine the difference for each test
run by subtracting the respective reference
method test concentrations (use average of
each set of three mr -urement* for NO.)
from the continuous monitoring system inte-
grated or averaged c, \centrstlons. Using
these data, compute the mean difference and
the 95 percent confidence Interval of the dif-
ferences (equations 9-1 and 2-2). Accuracy
Is reported a- the sum of the absolute value
of the mean difference and the 95 percent
confidence Interval of the differences ex-
pressed as a percentage of the mean refer-
ence method value. Use the example sheet
shown In Figure 2-3
122 Calibration Error. Using the data
from paragraph 6.1, subtract the measured
pollutant concentration determined under
paragraph e.1.1 (Figure 3-1) from the value
shown by the continuous monitoring system
for each of the five readings at each con-
centration measured under 6.13 (Figure 2-2).
Calculate the mean of these difference values
and the 65 percent confidence Intervals ac-
cording to equations 2-1 and 2-2. Report the
calibration error (the sum of the absolute
value of the mean difference and the 95 per-
cent confidence interval) as a percentage of
each respective calibration gas concentra-
tion. Use example sheet shown in Figure 2-2.
7.2J Zero Drift (2-hour). Using the zero
concentration values measured each two
hours during the field test, calculate the dif-
ference* between consecutive two-hour read-
Ings expressed In ppm. Calculate the mean
difference and the confidence interval using
equations 2-1 and 2-2. Report ta« zero drift
as the sum of the absolute mean value and
the confidence interval as a percentage of
span. Use example tbeet shown In Figure
2-4.
7.2.4 Zero Drift (24-hour). Using the zero
concentration values measured every 24
hours during the field test, calculate the dif-
ferences between the zero point after zero
adjustment and the cero value 24 hours later
just prior to zero adjustment.-Calculate the
mean value of these points and the confi-
dence interval using equations 2-1 and 2-2.
Report the zero drift (the sum of the abso-
lute mean and confidence interval) as a per-
centage of span. Use example sheet shown In
Figure 2-5.
7.2.5 Calibration Drift (2-hour). Using
the calibration values obtained at two-hour
intervale during the field test, calculate the
differences between consecutive two-hour
readings expressed as ppm. These values
should be corrected for the corresponding
cero drift during that two-hour period. Cal-
culate the mean and confidence Interval of
these corrected difference values using equa-
tions 2-1 and 2-2. Do not use the differences
between non-consecutive readings. Report
the calibration drift as the sum of the abso-
lute mean and confidence Interval as e. per-
centage of span. Use the example sheet shown
in Figure 2-4.
7.2.6 C-lIbratlon Drift (24-hour). Using
the calibration values measured every 24
hours during the field test, calculate the dif-
ferences between the calibration concentra-
tion reading after zero and calibration ad-
justment, and the calibration concentration
reading 24 hours later after zero adjustment
but before calibration adjustment. Calculate
the mean value of these differences and the
confidence iuterval using equations 2-1 and
2-2. Report the calibration drift (the sum of
the absolute mean and confidence Interval)
as a percentage of span. Use the example
sheet shown in Figure 2-5.
7.2.7 Response Time. Using the charts
from paragraph 6.3, calculate the time inter-
val from concentration switching to 95 per-
cent to the *<"«' stable value for all upscale
and downecal« testa. Report the mean of the
three upscale test times and the mean of the
three downscale test times. The two aver-
age times should not differ by more **»" 15
percent of the slower time. Report the slower
time as the system response time. Use the ex-
ample sheet shown in Figure 2-0.
7.2.8 Operational Test Period. During the
108-hour performance and operational test
period, 'the continuous monitoring system
shall not require any corrective maintenance.
repair, replacement, or adjustment other than
that clearly specified as required xc the op-
eration ind maintenance manuals ajs routine
and expected during a one-week period If
the continuous monitoring system operates
within the specified performance parameters
and does not require corrective maintenance,
repair, replacement or adjustment other than
as specified above during the 168-hour test
period, the operational period will be success-
fully concluded. Failure of the continuous
monitoring system to meet this requirement
shall call for a repetition of the 168-hour test
period. Portions of the test which were satis-
factorily completed need not be repeated
Failure to meet any performance specifica-
tions shall call for a repetition of the one-
week performance test period and that por-
tion of the testing which is related to the
failed specification All maintenance and ad-
justments required shall be recorded Out-
put readings shall be recorded before and
after all adjustments
8. References.
8.1 "Monitoring Instrumentation for the
Measurement of Sulfur Dioxide in Stationary
Source Emissions," Environmental Protection
Agency, Research Triangle Park, N.C., Feb-
ruary 1973.
82 "Instrumentation for the Determina-
tion of Nitrogen Oxides Content of Station-
ary Source Emissions," Environmental Pro-
tection Agency. Research Triangle Park. N.C..
Volume l.APTD-0847. October 1971; Vol-
ume 2, APTD-0942. January 1972.
3.3 "Experimental Statistics." Department
of Commerce, Handbook 91. 1903. pp. 3-31.
paragraphs 3-3.1.4.
8.4 "Performance Specifications for Sta-
tionary-Source Monitoring Systems for Cases
and Visible Emissions," Environmental Pro-
tection Agency. Research Triangle Park, N C.,
EPA-650/3-74-013, January 1974.
r Il'ltrillo Ul
'i»r.tif Hi
' •> bllMtlw iM M««T>
11-82 ,
-------
Calibration Gas Mixture Data (From Figure 2-1)
Mid (505) ppn High (901) ppni
Run I
Calibration Gas
Concentration.ppm
Measurement System
Reading, ppn
Differences, ppm
12
J3
14
15
Hid High
Mean Difference + C.I.
Mean difference
Confidence interval
Calibration error =
Calibration gas concentration - measurement system reading
'Absolute value
calibration Gas Concentration
•x 100
Figure 2-2. Calibration Error Determination
nt
No.
1
,
<
S
7
f
*
Idfl
fit
ISJ (
iccur
fcu
BM
•cfcrtnc* Hctnoti Stnpiti
til'1
'
i
rtf«r»nct •
Ml* (SO,
Mftitnei <
•Owe
•»«» if
W
NO ; NO
We ? ! te«U s
(ppn) (W»)
t
NM* rtf*rti
tttt «1«
W SMpll
««lr>tr 1-llhir
*.«••* (PP.)'
SO, «,
:
»C< VtllM
n I
(JO.) • •
th* iifftmcfi * K( eenfi«tftct"tnitrv*l _ t^ _
"'" • - - -' "It,,,, rtftrcnct Mthod ».lv» ' '" -
lilt wrf rtport mtunt UM« u 4«trm1u Inugrturt »mt<>
plfformet
(PI-)
*°2 »,
Nun of
MM,
) • I («0,)
Mtlw (SO, M< Ka)
11-83
-------
»u
*t
Ttat
t*t<« End
•MtC tM*1l<)
Zir*
Drift
S««l
tailing
SHfl
(iiwO
«r1ft
( »P»»- 2m)
Zn-o fri't -THe«n Jero Drift*
Drift • [MM* S»«n OrMt*
•Absolute VllM.
* CI Ut-o)
. * tl
2-4.2rro
-------
0«U of Tist
Span Gas Concentration
Analyzer Span Setting _
_Ppn
pp™
Upscale
_stconds
_seconds
seconds
Averagt upscale response_
seconds
Downscale
1
2
-3
^seconds
_seconds
seconds
Average downscale response
System average response 'tine (slower time) • _
Deviation from slower
system average response
_seconds
seconds.
average upscale minus av'eraqe downseale
slower tine
I"
x 100J -
Figure 2-6. Response Time
jlgnj}—Performance
Icatlon test proce-
dures for monitors of CO, and O, from sta-
tionary sources.
1. Principle and Applicability.
1.1 Principle. Effluent gases are continu-
ously sampled and are analyzed for carbon
dioxide or oxygen by a continuous monitor-
ing system. Tests of the system are performed .
during a minimum operating period to deter-
mine zero drift, calibration drift, and re-
sponse time characteristics.
1.2 Applicability. This performance speci-
fication is applicable to evaluation of con-
tinuous monitoring systems for measurement
of carbon dioxide or oxygen. These specifica-
tions contain test procedures, Installation re-
quirements, and data computation proce-
dures for evaluating the acceptability of the
continuous monitoring systems subject to
approval by the Administrator. Sampling
may include either extractive or non-extrac-
tive (in-sltu) procedures.
2. Apparatus.
2.1 Continuous Monitoring System for
Carbon Dioxide or Oxygen.
2.2 Calibration Gas Mixtures. Mixture of
known concentrations of carbon dioxide or
oxygen in nitrogen or air. Mldrange and 90
percent of span carbon dioxide or oxygen
concentrations are required. The 90 percent
of span gas mixture Is to be used to set and
check the analyzer span and Is referred to
ao span gas. For oxygen analyzers, if the
span Is higher than 21 percent O,. ambient
air may be used in place of the 90 percent of
span calibration gas mixture. Triplicate
analyses of the gas mixture (except ambient
air) shall be performed within two weeks
prior to use using Reference Method 3 of
this pan.
2.3 Zero Oas. A gas containing less than 100
ppm of carbon dioxide or oxygen.
3.4 Data Recorder. Analog chart recorder
or other suitable device with Input voltage
range compatible with analyzer system out-
put. The resolution of the recorder's data
output shall be sufficient to allow completion
or the test procedures within this specifica-
tion.
3. Definitions.
S.I Continuous Monitoring System. The
total equipment required for the determina-
tion of carbon dioxide or oxygen in a given
source effluent. The system consists of three
major subsystems:
3.1.1 Sampling Interface. That portion of
the continuous monitoring system that per-
forms one' or more of the following opera-
tions: delineation, acquisition, transporta-
tion, and conditioning of a sample of the
source effluent or protection of the analyzer
from the hostile aspects of the sample or
source environment.
3.1.2 Analyzer. That portion of the con-
tinuous monitoring system which senses the
pollutant gas and generates a signal output
that is a function of the pollutant concen-
tration.
3.1.3 Data Recorder. That portion of the
continuous monitoring system that provides
a permanent record of -the output signal in
terms of concentration units.
32 Span. The value of oxygen or carbon di-
oxide concentration at which the continuous
monitoring system Is set that produces the
maximum data display output. For the pur-
poses of this method, the span shall be set
no less than 1.5 to 2.5 times the normal car-.
Don dioxide or normal oxygen concentration
In the stack gas of the affected facility.
3.3 Mldrange. The value of oxygen or car-
bon dioxide concentration that Is representa-
tive of the normal conditions in the stack
gas of. the affected facility at typical operat-
ing rates.
3.4 Zero Drift. The change In the contin-
uous monitoring system output over a stated
period of time of normal continuous opera-
tion when the carbon dioxide or oxygen con-
centration at the time for the measurements
Is zero.
3.5 Calibration Drift. The change in the
' continuous monitoring system output over a
stated time period of normal continuous op-
eration when the carbon dioxide or oxygen
continuous monitoring system is measuring
the concentration of span gas. . •
3.6 Operational Test Period. A minimum
period of time over which the continuous
monitoring system Is expected to* operate
within Certain performance specifications
without unscheduled maintenance, repair, or
' adjustment.
. 3.7 Response time. The time interval from
a step change in concentration at the input
to the continuous monitoring system to the
time at which 98 percent of the correspond-
ing final value to displayed on the continuous
snonltortng system data recorder.
4. Installation Specification.
Oxygen or carbon dioxide continuous mon-
itoring systems! shall-be installed at a loca-
tion where measurements are directly repre-
sentative of the total effluent from the
• affected facility or representative of the same
effluent sampled by a SO, or NO. continuous
monitoring system. Ibis requirement shall
be compiled with by use of applicable re-
quirements in Performance Specification 3 of
this appendix as follows:
4.1 Installation of Oxygen or Carbon Dl-
'oxlde Continuous Monitoring Systems Not
Used to Convert Pollutant Data. A sampling
location shall be selected In accordance with
the procedures under • paragraphs 4.3.1 or
. 4.2.2. or Performance Specification 3 of this
appendix. . •
45 Installation of Oxygen or Carbon Di-
oxide Continuous Monitoring Systems Used
to Convert Pollutant Continuous Monitoring
System- Data to Units of Applicable Stand-
ards. The diluent continuous monitoring sys-
tem (oxygen or carbon dioxide) 'shall be In-
stalled at a sampling location where measure-
ments that can be made are representative of
the effluent gases sampled by the pollutant
continuous monitoring system(s). Conform-
ance with this requirement may be accom-
plished in any of the following ways:
4.2.1 The sampling location for the diluent
system shalfbe near the sampling location for
the pollutant continuous monitoring system
such that the same' approximate point (s)
(extractive systems) or path (In-sltu sys-
tems) in the cross section is sampled or
viewed.
4.2.2 The diluent aad pollutant continuous
monitoring systems may be installed at dif-
ferent locations if the effluent gases at both
sampling locations are nonstrstlned as deter-
mined under paragraphs 4.1 or 43, Perform-
ance Specification 3 of this appendix and
there is no in-leakage occurring between the
two sampling locations. If the effluent gases
are stratified at either location, the proce-
dures under paragraph 4.2.2, Performance
Specification 2 of this appendix shall be used
for Installing continuous monitoring systems
at that location.
6. Continuous Monitor^ng 8vstem Pertorm-
tlnu
cine
ance Specifications.
The continuous monitoring system shall
meet the performance specifications in Table
3-1 to be considered acceptable under this
method.
6. Performance Specification Test Proee*
dures.
The following test procedures shall be used
to determine conformance with the require-
ments of paragraph 4. Due to the wide varia-
tion existing In analyzer designs and princi-
ples of operation, these- procedures are not
applicable to all analyzers. Where this occurs,
alternative procedures, subject to the ap-
proval of the Administrator, may be em-
ployed. Any such alternative procedures must
fulfill the same purposes (verify response,
drift, and accuracy) as the following proce-
dures, and must clearly demonstrate con-
formance with specifications In Table 8-1.
' 6.1 Calibration Check. Establish a cali-
bration curve for the continuous moni-
toring system using zero, midrange, and
span concentration gas mixtures. Verify
that the resultant curve of analyzer read-
Ing compared with the calibration gas
value is consistent with the expected re-
sponse curve as described by the analyzer
manufacturer. If the expected response
curve is not produced, additional cali-
bration gas measurements (hall be made,
or additional step* undertaken to verify
11-85
-------
the accuracy of the response curve of the
analyzer.
«.2 Field Test for Zero Drift and Cali-
bration Drift. Install and operate the
continuous monitoring system in accord-
ance with the manufacturer's written in-
structions and drawings as follows:
TABLE 3-1.—Performance tpecificalions
Pvnuttr
Sptdfattim
1. Zero drift (7 h)' <0.4 pet O. or CO).
2. Zero drift (24 b^ > *O.S pet Otor COi.
i. Calibration drift (5 h)'.. §0.4 pet O: or CGi
4. Calibration rtritt (24 b) >. <0-5 pel Ot or COj.
A. OpenUonal period IV b minimum.
C. Response tlaic........... lOnun. •
i Expressed at nm of absolute mean Talue plus AS pet
confidence Inwrral of a (cries of tests.
6.2.1 Conditioning Period. Offset tbe zero
setting at least 10 percent ol span so that
negative zero drift may be quantified. Oper-
ate the continuous monitoring system for
an initial 168-hour conditioning period In a
normal operational manner.
622.~Operational Test Period. Operate the
continuous monitoring system for an addi-
tional 168-hour period maintaining tbe zero
ofiset. The system shall monitor the source
effluent at all times except when - being
zeroed, calibrated, or backpurged.
6.2.3 Field Test for Zero Drift and Calibra-
tion Drift. Determine the values given by
rero and mldrange gas concentrations at two-
hour Inteivals until 19 sets of data are ob-
tained. For non-extractive continuous moni-
toring systems, determine the s*ro value
given by a mechanically produced zero con-
dition cr by computing the zero value from
upscale measurements using calibrated gas
cells certified by tbe manufacturer. The mid-
range checks snail be performed by using
certified calibration gas cells functionally
equivalent to less than SO percent of span.
Record these readings on tbe example sheet
shown In Figure 3-1. These two-hour periods
need not be consecutive, but may not overlap.
In-situ CO. or O, analyzers which cannot be
fitted with a calibration gas cell may be cali-
brated by alternative procedure* acceptable
to tbe Administrator. Zero and calibration
corrections and adjustments are allowed
only at 24-hour Intervals or at such shorter
intervals as tbe manufacturer's written in-
structions specify. Automatic corrections
made by the continuous monitoring system
without operator intervention or Initiation
arc allowable at any time. During the en-
tire 168-hour test period, record the values
given by zero and span gas concentrations
before and after adjustment at 24-hour In-
tervals In the example sheet shown In Figure
3-2.
63 Field Test for Response Time.
6.3.1 Scope of Test.
This teat shall be accomplished -using the
continuous monitoring system as Installed,
including sample transport lines If used.
now rates, line diameters, pumping rates,
pressures
-------
TIM
EM
(Mdlng
Or)ft Spin
S»««
Drift
bllkratttr
Drtn
Cillbrttlon Drift • [Mtwi Spot DrTTf
•Abuluti Vilu*.
Flgur* J-1. Z«n> »nd UltSrjtlon Drift (2 Hour).
«te Zero Span Calibration
and Zero Drift Reading Drift
Time Reading (iZero) (After zero adjustment) (aSpan)
iero Drift « [Mean Zero Drift*
.+ C.I. (Zero)
:a11brat1on Drift » [Mean Span Drift*
.* C.I. (Span)
Absolute value
Figure 3-2. Zero and Calibration Drift (24-hour)
11-87
-------
D»u of Test
Span Gas Concentration
Analyzer Span Setting
1.
Upscale 2.
3.
Average
1.
Downscale 2.
3.
Average
ppm
ppm
. seconds
seconds
seconds
upscal: response
seconds
seconds
seconds
downscale response
System average response time (slower tiire) =
seconds
seconds
seconds
system average response slower tine
Figure 3-3. Response
(Sac. 114 of U» a«*B Air Act
(O UAC. }S57e-»).).
11-88
-------
NSPS OPERATIONAL MONITORING REQUIREMENTS - PROMULGATED
11-89
-------
Subpart N — Standards of Performance for
Iron and SU*I Plants »
S 60.140 AppUeabilitr and designation '
of affected facility. 6 4
(a) The affected facility to which the
provisions of this subpart apply is each
basic oxygen process furnace.
(b) Any facility under paragraph (a)
of this section that commences construc-
tion or modification after June 11. 1973.
is subject to the requirements of this
subpart.
1 60.141 Definition*.
As used In this subpart, an terms not
defined herein shall have the meaninc
given them in. the Act and in subpart A
c.r this part.
(a) "Basic oxygen process furnace*
a. ~>PF) means any furnace producing
•; • v by charging scrap steel, hot metal,
B..CI flux materials into a vessel and in-
troducing a high volume of an oxygen-
rich gas.
(b> "Steel production cycle" means
the rperattons required to produce each
batch of steel and includes the following
major- (unctions: Scrap charging, pre-
heating (when used), hot metal charg-
ing, primary oxygen blowing, additional
•oxygen blowing (when used), and tap-
"Startup means the setting into
operation for the first steel production
ey«le of a relived BOPP or a BOPP
which has been out of production for a
continuous time period of
eigtot hours.
| 60.142 Standard for paniculate- mat-
ter.
{a) On and after the date on which
the performance test-required to be con-
ducted by | M.8 is completed, no owner
or operator subject to the provisions of
this subpart shall discharge or cause
trie discharge into the atmosphere from
any affected facility any gases which.:
(1) Contain particulate matter in ex-
cess of SO mg/dscm (0.022 gr/dscf).
(2) Exit from * control device ana
exhibit 10 percent opacity or greater.
except that an opacity of greater than
It) percent but less than 20 percent
may occur once per steel production
cycle.
§•0.143 Monitoring of operations.
(a) The owner or operator of tn af-
fected facility shall maintain a single
time-measuring instrument which
shall be used In recording daily the
time and duration of each steel pro-
duction cycle, and the time and dura-
tion of any diversion of exhaust gases
from the main stack servicing the
BOPP.
(b) The owner or operator of any af-
fected facility that uses venturi scrub-
ber emission control equipment shall
install, calibrate, maintain,- and con-
tinuously operate monitoring devices
as follows:
(DA monitoring device for the con-
tinuous measurement of the pressure
loss through the venturi constriction
of the control equipment. The moni-
toring device is to be certified by the
manufacturer to be accurate within
±250 Pa (±1 inch water).
(2) A monitoring device for the con-
tinous measurement of the water
supply pressure to the control equip-
ment. The monitoring device is to be
certified by the manufacturer to be ac-
curate within ±5 percent of the design
water supply pressure. The monitoring
device's pressure sensor or pressure
tap must be located dose to the water
discharge point. The Administrator
may be consulted for approval of alter-
native locations for the pressure
sensor or tap.
(3) AU monitoring devices shall be
synchronized each day with the time-
measuring instrument used under
paragraph (a) of this section. The
chart recorder error directly after syn-
chronization shall not exceed 0.08 cm
(Mi. inch).
(4) AU monitoring devices shall use
chart recorders which are operated at
a Vninimiim chart speed of 3.8 cm/hr
(1.5 in/hr). !
(5) All monitoring devices are to be
recalibreated annually, and at other
times as the Administrator may re-
quire, in accordance with the proce-
duces under 5 60.13(bX3).
(c) Any owner or operator subject to
requirements under paragraph (b) of
this section shall report for each cal-
endar quarter all measurements over
any three-hour period that average
more than 10 percent below the aver-
age levels maintained during the most
recent performance test conducted
under § 60.8 in which the affected fa-
cility demonstrated compliance with
the standard under §60.142(a)(l). The
accuracy of the respective measure-
ments, not to exceed the values speci-
fied in paragraphs (bXl) and (b)(2) of
this section, may be taken into consid-
eration when determining the mea-
surement results that must be report-
ed.
References
60,
60,
60,
60,
60.
2
7
8
11
13
Reference Method
Specifications 1
11-90
-------
Subpart T—Standards of Performance for
the Phosphate Fertilizer Industry: Wet-
Process Phosphoric Acid Plants
§60.200 Applicability and deaignation
of affected facility.
(a) The affected facility to which the
provisions of this subpart apply to each
wet-process phosphoric acid plant For
the purpose of this subpart, the affected
facility includes «.ny combination of:
reactors, filters, evaporators, and hot-
wens.
(b) Any facility under paragraph (a)
of this section that commences con-
struction or modification after October
22, 1974, is subject to the requirements
of *h*T subpart.
{60.201 Definition*.
As used in this subpart, all terms not
defined herein shall have the meaning
given them in the Act and in Subpart A
of this part.
(a) "Wet-process phosphoric acid
plant" means any facility manufactur-
ing phosphoric acid by reacting phos-
phate rock and acid.
(b) "Total fluorides" means elemental
fluorine and all fluoride compounds as
measured by reference methods specified
in J 60.204, or equivalent or alternative
methods.
(c) "Equivalent P.O. feed" means tha
quantity of phosphorus, expressed as
phosphorous pentoxide, fed to the proc-
| 60.203 Monitoring of operation*.
(c) The owner or operator of any wet-
process phosphoric acid subject to the
provisions of this part shall install, cali-
brate, maintain, and operate a monitor-
ing device which continuously measures
and permanently records the total pres-
sure drop across the process scrubbing
system. The monitoring device shall have
an accuracy of ±5 percent over its op-
erating range.
(8ae. iu at tb« Ctoaa Air Act a*
-------
SubMrt U—Standards of Performance for
the Phosphate Fertilizer Industry: Super-
phosphoric Acid Plants
160.210 Applicability aod de*ign«tion
•f affected facility.
(a) The affected facility to which the
provisions of this subpart apply is each
superphosphoric acid plant For the
purpose of this subpart, the affected
facility includes any combination of:
evaporators, hotwells, acid sumps, and
cooling tanks.
(b) Any faculty under paragraph (a)
of this section that commences con-
struction or modification after October
22, 1974, is subject to the requirements
of this subpart
160.211 Definition*.
As used in this subpart, all terms not
denned herein shall have the meaning
given them in the Act and In Subpart A
of this part.
(a) "Superphosphoric acid plant"
means any facility which concentrates
wet-process phosphoric acid to 66 per-
cent or greater PiOi content by weight
for eventual consumption as a fertilizer.
(b) 'Total fluorides" means elemen-
tal fluorine and all fluoride compounds
as measured by reference methods spe-
cified in 8 60.214, or equivalent or alter-
native methods.
(c) "Equivalent P.O. feed" means the
quantity of phosphorus, expressed as
phosphorous pentoxide, fed to the
process.
| 60.21S Monitoring of operation*.
(c) The owner or operator of any
superphosphoric acid plant subject to the
provisions of this part shall install, cali-
brate, maintain, and operate a monitor-
ing device which continuously measures
and permanently records the total pres •
sure drop across the process scrubbing
system. The monitoring device shall have
an accuracy of ± 5 percent over its
operating range.
(Sac. 114 Of th* a**a Air Act M «tn«n
-------
Subpart V—Standards of Performance for
the Phosphate Fertilizer Industry: Warn-
monium Phosphate Plants
160.220 Applicability and
of affected facility.
(a) The affected facility to whteh toe
provisions of tills sutopart apply to each
granular dtammonium phosphate plant.
For the purpose of this subpart, the ef-
fected facility includes any combination
of: reactors, granulators, dryers, coolers,
screens, and mills.
(b) Any facility under paragraph (a)
of this section that commences construc-
tion or modification after October 22.
1974. is subject to the requirements of
this subpart.
160.221 Definitions.
As used in this subpart, all terms not
denned herein shall have the meaning
given them in the Act and in Subpart A
of this part.
(a) "Granular diammonium phos-
phate plant" means any plant manu-
facturing granular diammonium phos-
phate by reacting phosphoric acid with
ammonia.
(b) "Total fluorides" means elemental
fluorine and all fluoride compounds as
measured by reference methods speci-
fied in S 60.224, or equivalent or alter-
native methods.
(c) -Equivalent P,O6 feed" means the
quantity of phosphorus, expressed as
phosphorous pentoxlde, fed to the proc-
| 60.223 Monitoring of operation*.
*****
(c) The owner or operator of any
granular diammonium phosphate plant
subject to the provisions of this part shall
install, calibrate, maintain, and operate
a monitoring device which continuously
measures and permanently records the
total pressure drop across the scrubbing
system. The monitoring device shall have
an accuracy of ±5 percent over its op-
erating range.
(B*c. 114 of th» Ctaan Air Act M
(43 U8C. l»7c-«).).
References:
60
60
60,
60.
2
7
8
11
60.13
11-93
-------
Subpart W—Standards of Parformanca for
the Phosphate Fertilizer Industry: Triple
Superphosphate Plants
160.230 Applicability mmd
of effected facility.
(a> The affected facility to which the
provisions of this aubpart apply is each
triple superphosphate plant. For the pur-
pose of this subpart, the affected facility
includes any combination of: mixers,
curing belts (dens), reactors, granula-
tors, dryers, cookers, screens, mills, and
facilities which store run-of-pile triple
superphosphate.
(b) Any facility under paragraph (a)
of this section that commences construc-
tion or modification after October 22,
1974, is subject to the requirements of
this subpart
160.231 Definition*.
As used In this subpart, all terms not
defined herein shall have the meaning
given them in the Act and In Subpart A
of this part.
(a) "Triple superphosphate plant*
means any facility manufacturing triple
superphosphate by reacting phosphate
rock with phosphoric acid. A run-of-pile
triple superphosphate plant Includes
curing and storing.
(b) "Run-of-pile triple superphos-
phate" means any triple superphosphate
that has not been processed in a granu-
lator and is composed of particles at
least 25 percent by weight of which
(when not caked) will pass through a II
mesh screen.
(c) "Total fluorides" means ele-
mental fluorine and all fluoride com-
pounds as measured by reference
methods specified In 160.234, or
lent or alternative methods.
| 60.233 Monitoring of operation*.
(c) The owner or operator of any triple
superphosphate plant subject to the pro-
visions of this part shall install, calibrate.
maintain, and operate a monitoring de-
vice which continuously measures and
permanently records the total pressure
drop across the process scrubbing system.
The monitoring device shall have an ac-
curacy of ±5 percent over its operating
range.
-------
Subpart X—Standards of Performance for
the Phosphate Fertilizer Industry: Gran-
ular Triple Superphosphate Storage Fa-
cilities
{60.240 Applicability and aWignation
•f affected facility.
(•) The effected faculty to which the
provisions of this subpart apply is each
granular triple superphosphate storage
facility. For the purpose of this subpart.
the affected facility includes any combi-
nation of: storage or curing piles, con-
veyors, elevators, screens, and mills.
(b) Any facility under paragraph (a)
of this section that commences construc-
tion or modification after October 22,
1974. is subject to the requirement* of
this subpart.
160.241 Definition*.
As used in this subpart, all terms not
defined herein shall have the meaning
given them in the Act and in Subpart A
of this part.
(a) "Granular triple superphosphate
storage facility" means any facility cur-
tag or storing granular triple superphos-
phate.
(b) "Total fluorides" means elemental
fluorine and all fluoride compounds as
measured by reference methods specified
In { 60.244, or equivalent or alternative
methods.
(c) "Equivalent P.O* stored" means
the quantity of phosphorus, expressed as
phosphorus pentoxide, being cured or
stored in the affected facility.
(d) "Fresh granular triple superphos-
phate" means granular triple superphos-
phate produced no more than 10 days
prior to the date of the performance test
§ 60.243 Monitoring of operation*.
(c) The owner or operator of any
granular triple superphosphate storage
facility subject to the provisions of this
part shall install, calibrate, maintain,
and operate a monitoring device which
continuously measures and permanently
records the total pressure drop across the
process scrubbing sytem. The monitoring
device shall have an accuracy of ±5 per-
cent over Its operating range.
(Sac. 114 or th« ci«aa Air Act M
(49 U.8C. 185TC-*).).
References:
60.2
60.7
60.8
60.11
60.13
11-95
-------
gubpsrt Y—Standards of Performance tor
Coal Preparation Plants
(1*0.250 Applicability and dMicaation
of affected facility.
-------
Subpart GG—Standards of
Performance for Stationary Gas
Turbines
§60.330 Applicability and designation of
affected facility.
The provisions of this subpart are
applicable to the following affected
facilities: all stationary gas turbines
with a heat input at peak load equal to
or greater than 10.7 gigajoules per hour,
based on the lower heating value of the
fuel Bred.
§ 60.331 Definitions.
As used in this subpart, all terms not
defined herein shall have the meaning
given them in the Act and in subpart A
of this part.
(a) "Stationary gas turbine" means
any simple cycle gas turbine,
regenerative cycle gas turbine or any
gas turbine portion of a combined cycle
steam/electric generating system that is
not self propelled. It may, however, be
mounted on a vehicle for portability.
(b) "Simple cycle gas turbine" means
any stationary gas turbine which does
not recover heat from the gas turbine
exhaust gases to preheat the inlet
combustion air to the gas turbine, or
which does not recover heat from the
gas turbine exhaust gases to heat water
or generate steam.
(c)."Regenerative cycle gas turbine"
means any stationary gas turbine which
recovers heat from the gas turbine
11-97
-------
exhaust gases to preheat the inlet
combustion air to the gas turbine. ^
(d'i "Combined cycle gas turbine
means any stationary gas turbine which
recovers heat from the gas turbine
exhaust gases to heat water or generate
steam.
(e) "Emergency gas turbine' means
any stationary ges turbine which
operates as a mechanical or electrical
power source only when the primary
power source for a facility has been
rendered inoperable by an emergency
situation.
(f) "Ice fog" means an atmospheric
suspension of highly reflective ice
crystals. • t
(g) "ISO standard day conditions
means 288 degrees Kelvin, 60 percent
relative humidity and 101.3 kilopascals
pressure.
(h) "Efficiency" means the gas turbine
manufacturer's rated heat rate at peak
load in terms of heat input per unit of
power output based on the lower
heating value of the fuel.
(i) "Peak load" means 100 percent of
the manufacturer's design capacity of
the gas turbine at ISO standard day
conditions.
fj) "Base load" means the load level at
which a gas turbine is normally
operated.
(k) "Fire-fighting turbine" means any
stationary gas turbine that is used solely
to pump water for extinguishing fires.
(1) "Turbines employed in oil/gas ^
production or oil/gas transportation"
means any stationary gas turbine used
to provide power to extract crude oil/
natural gas from the earth or to move
crude oil/natural gas. or products
refined from these substances through
pipelines.
(m) A "Metropolitan Statistical Area"
or "MSA" as defined by the Department
of Commerce
(n) "Offshore platform gas turbines"
means any stationary gas turbine
located on a platform in an ocean.
(o) "Garrison facility" means any
permanent military installation.
(p) "Gas turbine model" means a
group of gas turbines having the same
nominal air flow, combuster inlet
pressure, combuster inlet temperature,
firing temperature, turbine inlet
temperature and turbine inlet pressure.
§60.332 Standard for nitrogen oxides.
(a) On and after the date on which the
performance test required by § 60.6 >a
completed, every owner or operator
subject to the provisions of this subpart,
as specified in paragraphs (b), (c), and
(d) of this section, shall comply with one
of the following, except as provided in
paragraphs (e), (f). (g). PO. and (i) of this
section.
(1) Xo owner or operator subject to
ihe provisions of this subpart shall
cause to be discharged into the
atmosphere from any stationary gas
turbine, any gdseb which contain
nitrogen oxides in excess of:
STD - 0.0075
(14.4)
— —
+ F
32
where:
STD= allowable NOx emissions (percent by
voliime at 15 percent oxygen and on a
dry basis).
Y = manufacturer's rated heat rate at
manufdcturer's rated load (kilojoules per
wett hour) or, actual measured heat rate
based on lower heating value of fuel as
measured at actual peak load for the
facility. The value of Y shall not exceed
14.4 kilojoules per watt hour.
F=NO, emission allowance for fuel-bound
nitrogen as defined in part (3) of this
paragraph.
(2) No owner or operator subject to the
provisions of this subpart shall cause to be
discharged into the atmosphere from any
stationary gas turbine, any gases which
con'ain nitrogen oxides in excess of:
STD = 0.0150 (-) + F
where:
STD=al!owable NO. emissions (percent by
volume at 15 percent oxygen and on a
dry basis).
Y=manuf8cturer's rated heat rate at
manufacturer's rated peak load
(kilojoules per watt hour), or actual
measured heat rate based on lower
heating value of fuel as measured at
actual peak load for the facility. The
value of Y shall not exceed 14.4
kilojoules per watt hour.
F=NO, emission allowance for fuel-bound
nitrogen as defined in part (3) of this
paragraph.
(3) F shall be defined according to the
nitrogen content of the fuel as follows:
Fuel-Bound Nitrogen
jjerger.t by weight)
percent by volume)
0
0.04(N)
0.004 + 0.0067(N-0.1)
0.005
where:
N=the nitrogen content of the fuel (percent
by weight).
on
Manufacturers may develop custom
fuel-bound nitrogen allowances for each
gas turbine model they manufacture.
These fuel-bound nitrogen allowances
shall be substantiated with data and
must be appnned for use by the
Administrator before the initial
performance test required by § 00.8.
Notices of approval of custom fuel-
bound nitrogen allowances will be
published in the Federal Register.
(b) Stationary gas turbircs with a heat
input at peak load ;;riMlei i'um 107.2
gigajoules per hour (101) ir.iliion Bin/
hour) based on the lov>er heanr.!1 wlue
ot the fuel hred e>.^p; ^ \:-''-'- '^ ::'
§ G0.332(d) shall comply with the
provisions of §fa0.332(a)i 1 ]
(c) Stationary gas tuibiinis with a heat
input at peak load equal to or gieater
than 10.7 gigajoules per hour (10 million
Btu/hour) but less then or equal to 107.2
gigajoules per hour (100 million Btu/
hour) based on the lower heating value
of the fuel fired, bhall comply with the
provisions of § 60.332(a |(2).
(d) Stationary gas tuibines employed
in oil/gas production or oil/gas
transportation and not located in
Metropolitan Statistical Areas; and
offshore platform turbines shall comply
with the provisions of | 60.332{a)(2).
(e) Stationary gas turbines with a heat
input at peak load equal to or greater
than 10.7 gigajoules pel hour (10 million
Btu/hour) but less limn or tqual to 107.2
gigajoules per hour (100 million Htu/
hour) based on the Umi-r heating value
of the fuel fired and that luive
commenced construction prior to
October 3,1982 are exempt fiom
paragraph (a) of this section.
(f) Stationary gas turbine s usirip, water
or steam injection for control of NO,
emissions are exempt from paragraph
(a) when ice fog is deemed a traffic
hazard by the owner or opcr&li.r o. the
gas turbine.
(g) Emergency gas turbines, military
gas turbines for use in other than a
garrison facility, military gas turbines
installed for use as military training
facilities, and fire fighting gas turbines
are exempt from paragraph (a) of this
section.
(h) Stationary gas turbines engaged by
manufacturers in research and
development of equipment for both gas
turbine emission control techniques and
gas turbine efficiency improvements are
exempt from paragraph (a) on a case-by-
case basis as determined by the
Administrator.
(i) Exemptions from the requirements
of paragraph (a) of this section will be
granted on a case-by-case basis as
determined by die Administrator in
specific geographical areas where
mandatory water restrictions are
required by governmental agencies
because of drought conditions. These
11-98
-------
exemptions will be allowed only while
the mandatory water restrictions are in
effect.
§ 60.333 Standard for sulfur dioxide.
On and after the date on which the
performance test required to be
conducted by § 60.8 is completed, every
owner or operator subject to the
provision of this subpart shall comply
with one or the other of the following
conditions:
(a) No owner or operator subject to
the provisions of this subpart shall
cause to be discharged into the
atmosphere from any stationary gas
turbine any gases which contain sulfur
dioxide in excess of 0.015 percent by
volume at 15 percent oxygen and on a
dry basis.
(b) No owner or operator subject to
the provisions of this subpart shall burn
in any stationary gas turbine any fuel
which contains sulfur in excess of 0.8
percent by weight.
§ 60.334 Moriitoiing of operations.
(a) The owner or operator of any
stationary gas turbine subject to the
provisions of this subpart and using
water injection to control NO, emissions
shall install and operate a continuous
monitoring system to monitor and record
the fuel consumption and the ratio of
water to fuel being fired in the turbine.
This system shad be accurate to within
±5.0 percent and shall be approved by
the Administrator.
(b) The owner or operator of any
stationary gas turbine subject to the
' provisions of this subpart shall monitor
sulfur content and nitrogen content of
the fuel being fired in the turbine. The
frequency of determination of these
values shall be as follows:
(1) If the turbine is supplied its fuel
from a bulk storage tank, the values
shall be determined on each occasion
that fuel is transferred to the storage
tank from any other source.
(2J If the turbine is supplied its fuel
without intermediate bulk storage the
values shall b« determined and recorded
daily. Owners, operators or fuel vendors
may develop custom schedules for
determination of ihe values based on the
design and operation of the affected
facility and the characteristics of the
fuel supply. These custom schedules
shall be substantiated with data and
must be approved by the Administrator
betore they can be used to comply with
paragraph (b) of this section.
(c) For the purpose of reports required
under § 60.7(c), periods of excess
emissions that shall be reported are
defined as follows:
(1) Nitrogen oxides. Any one-hour
period during which the average water-
to-fuel ratio, as measured by the
continuous monitoring system, falls
below the water-tq-fuel ratio determined
to demonstrate compliance with § 60.332
by the performance test required in
§ 60.8 or any period during which the
fuel-bound nitrogen of the fuel is greater
than the maximum nitrogen content
allowed by the fuel-bound nitrogen
allowance used during the performance
test required in § 60.8. Each report shall
include the average water-to-fuel ratio,
average fuel consumption, ambient
conditions, gas turbine load, and
nitrogen content of the fuel during the
period of excess emissions, and the
graphs or figures developed under
§ 60.335(a).
(2) Sulfur dioxide. Any daily period
during which the sulfur content of the
fuel being fired in the gas turbine
exceeds 0.8 percent.
(3) Ice fog. Each period during which
an exemption provided in § 60.332(g) is
in effect shall be reported in writing to
the Administrator quarterly. For each
period the ambient conditions existing
during the period, the date and time the
P
air pollution control system was
deactivated, and the date and time the
air pollution control system was
reactivated shall be reported. All
quarterly reports shall be postmarked by
the 30th day following the end of each
calendar quarter.
(Sec. 114 of the Clean Air Act as amended [42
U.S.C. 1857C-9]).
§ 60.335 Test methods and procedures.
(a) The reference methods in
Appendix A to this part, except as
provided in § 60.8(b). shall be used to
determine compliance with the
standards prescribed in § 60.332 as
follows:
(1) Reference Method 20 for the
concentration of nitrogen oxides and
oxygen. For affected facilities under this
subpart, the span value shall be 300
parts per million of nitrogen oxides.
(i) The nitrogen oxides emission level
measured by Reference Method 20 shall
be adjusted to ISO standard day
conditions by the following ambient
condition correction factor
NO = (N0y )
x xobs
ref\0.5
p - ;
obs
e"(H - 0.00633)
'AMB j.53
where:
NO. Demissions of NO, at 15 percent oxygen
and ISO standard ambient conditions.
NO,obi=measured NO, emissions at 15
percent oxygen, ppmv.
Pref=reference combuster inlet absolute
pressure at 101.3 kilopascals ambient
pressure.
Pob,=measured combustor inlet absolute
pressure at test ambient pressure.
Hob.=specific humidity of ambient air at test
e = transcendental constant (2.718).
TAM8= temperature of ambient air at test.
The adjusted NO. emission level shall
be used to determine compliance with
§ 60.332.
(ii) Manufacturers may develop
" custom ambient condition correction
factors for each gas turbine model they
manufacture in terms of combustor inlet
pressure, ambient air pressure, ambient
air humidity and ambient air
temperature to adjust the nitrogen
oxides emission level measured by the
performance test as provided for in
§ GO.8 to ISO standard day conditions.
These ambient condition correction
factors shall be substantiated with data
and must be approved for use by the
Administrator before the initial
performance test required by § 60.8.
Notices of approval of custom ambient
condition correction factors will be
published in the Federal Register.
(iii) The water-to-fuel ratio necessary
to comply with § 60.332 will be
determined during the initial
performance test by measuring NO,
emission using Reference Method 20 and
obs
the water-to-fuel ratio necessary to
comply with § 60.332 at 30,50, 75. and
100 percent of peak load or at four
points in the normal operating range of
the gas turbine, including the minimum
point in the range and peak load. All
loads shall be corrected to ISO
conditions using the appropriate
equations supplied by the manufacturer.
(2) The analytical methods and
procedures employed to determine the
nitrogen content of the fuel being Fired
shall be approved by the Administrator
and shall be accurate to within ±5
percent.
(b) The method for determining
compliance with § 60.333, except as
provided in § 60.8(b). shall be as
follows:
(1) Reference Method 20 for the
concentration of sulfur dioxide and
oxygen or
(2) ASTM D2880-71 for the sulfur
content of liquid fuels and ASTM
D1072-70 for the su'.fur content of
gaseous fuels. These methods shall also
be used to comply with § 60.334(b>.
(c) Analysis for the purpose of
determining the sulfur content and the
nitrogen content of the fuel as required
by § 60.334(b). this subpart. may be
performed by the owner/operator, a
service contractor retained by the
owner/operator, the fuel vendor, or any
other qualified agency provided that the
analytical methods employed by these
agencies comply with the applicable
paragraphs of this section.
11-99
-------
NSPS REGULATIONS - PROPOSED
11-100
-------
ENVIRONMENTAL PROTECTION
AGENCY
40 CFR Part 60
IFRL 1276-4)
Standards of Performance for New
Stationary Sources; Continuous
Monitoring Performance
Specifications
AGENCY: Environmental Protection
Agency (EPA).
ACTION: Proposed Revisions.
SUMMARY: On October 6,1975 (40 FR
46250). the EPA promulgated revisions to
40 CFR Part 60. Standards of
Performance for New Stationary
Sources, to establish specific
requirements pertaining to continuous
emission monitoring. An appendix to the
regulation contained Performance
Specifications 1 through 3. which
detailed the continuous monitoring
instrument performance and equipment
specifications, installation requirements.
and test and data computation
procedures for evaluating the
acceptability of continuous monitoring
systems. Since the promulgation of these
performance specifications, the need for
a number of changes which would
clarify the specification test procedures.
equipment specifications, and
monitoring system installation
requirements has become apparent. The
purpose of the revisions is to
incorporate these changes into
Performance Specifications 1 through 3.
The proposed revisions would apply
to all monitoring systems currently
subject to performance specifications 1.
2. or 3, including sources subject to
Appendix P to 40 CFR Part 51.
DATES: Comments must be received on
or before December 10.1979.
ADDRESSES: Comments. Comments
should be submitted (in duplicate if
possible) to the Central Docket Section
(A-130). Attn: Docket No. OAQPS-79-4.
U.S. Environmental Protection Agency.
401 M Street. S.W.. Washington. D.C.
20400.
Docket. Docket No. OAQPS-79-4,
containing material relevant to this
rulemaking. is located in the U.S.
Environmental Protection Agency.
Central Docket Section. Room 2903B. 401
M Street. S.W.. Washington. D.C. The
docket may be inspected between 8
A.M. and 4 P.M. on weekdays, and a
reasonable fee may be charged for
copying.
FOR FURTHER INFORMATION CONTACT:
Don R. Goodwin. Director. Emission
Standards and Engineering Division
(MD-13). Environmental Protection
Agency. Research Triangle Park. North
Carolina 27711. telephone number (919)
541-5271.
SUPPLEMENTARY INFORMATION: Changes
common to all three of the performance
specifications are the clarification of the
procedures and equipment
specifications, especially the
requirement for intalling the continuous
monitoring sample interface and of the
calculation procedure for relative
accuracy. Specific changes to the
specifications are as follows:
Performance Specification
1. The optical design specification for
mean and peak spectral responses and
for the angle of view and projection
have been changed from "500 to 600 nm"
range to "515 to 585 nm" range and from
•'5'" to "3"'. respectively.
2. The following equipment
specifications have been added:
a. Optical alignment sight indicator
for readily checking alignment.
b. For instruments having automatic
compensation for dirt accumulation on
exposed optical surfaces, a
compensation indicator at the control
panel so that the permissible maximum
4 percent compensation can be
determined.
c. Easy access to exposed optical
surfaces for cleaning and maintenance.
d. A system for checking zero and
upscale calibration (previously required
in paragraph 60.13).
e. For systems with slotted tubes, a
slotted portion greater than 90 percent of
effluent pathlength (shorter slots are
permitted if shown to be equivalent).
f. An equipment specification for the
monitoring system data recorder
resolution of <5 percent of full scale.
3. A procedure for determining the
acceptability of the optical alignment
sight has been specified: the optical
alignment sight must be capable of
indicating that the instrument is
misaligned when an error of ±2 percent
opacity is caused by misalignment of the
instrument at a pathlength of 8 meters.
4. Procedures for calibrating the
attenuators used during instrument
calibrations have been added; these
procedures require the use of a
laboratory spectrophotometer operating
in the 400-700 nm range with a detector
angle view of <10 degrees and an
accuracy of 1 percent.
5. The following changes have been
made to the procedures for the
operational test period:
a. The requirement for an analog strip
chart recorder during the performance
tests has been deleted: all data are
collected on the monitoring system data
recorder.
b. Adjustment of the zero and sp.in at
24-hour intervals during the drift K>sls is
optional: adjustments are required only
when the accumulated drift exceeds the
24-hour drift specification.
c. The amount of automatic zero
compensation for dirt accumulation
must be determined during the 24-hour
zero check so that the actual zero drift
can be quantified. The automatic zero
compensation system must be operated
during the performance test.
d. The requirement for offsetting the
data recorder zero during the
operational test period has been deleted.
e. Off the slack "zero alignment" of
the instrument prior to installation is
permitted.
Performance Specification 2
1. "Continuous monitoring system"
has been redefined to include the
diluent monitor, if applicable. The
change requires that the relative
accuracy of the system be determined in
terms of the emission standard, e.g..
mass per unit calorific value for fossil-
fuel fired steam generators.
2. The applicability of the lest
procedures excludes single-pass, in-situ
continuous monitoring systems. The
procedures for determining the
acceptability of these systems are
evaluated on a case-by-case basis.
3. For extractive systems with diluent
monitors, the pollutant and diluent
monitors are required to use the same
sample interface.
4. The procedure for determining the
acceptability of the calibration gases
has been revised, and the 20 percent
(with 95 percent confidence interval)
criterion has been changed to 5 percent
of mean value with no single value being
over 10 percent from the mean.
5. For low concentrations, a 10 percent
of the applicable standard limitation for
the relative accuracy has been added.
6. An equipment specification for the
system data recorder requiring that the
chart scale be readable to within <0.50
percent of full-scale has been added.
7. Instead of spanning the instrument
at 90 percent of full-scale, a mid-level
span is required.
8. The response time test procedure
has been revised and the difference
limitation between the up-scale and
down-scale time has been deleted.
9. The relative accuracy test
procedure has been revised to allow
different tests (e.g.. pollutant, diluent.
moisture) during a 1-hour period to be
correlated.
10. A low-level drift may be
substituted for the zero drift test.
11-101
-------
Performance Specification 3
1. The applicability of the test
procedures has been limited to those
monitors that introduce calibration
gases directly into the analyzer and are
used as diluent monitors. Alternative
procedures for other types of monitors
are evaluated on a case-by-case basis.
2. Other changes were made to be
consistent with the revisions under
Performance Specification 2.
The proposed revised performance
specifications would apply to all sources
subject to Performance Specifications 1,
2, or 3. These include sources subject to
standards of performance that have
already been promulgated and sources
subject to Appendix-P to 40 CFR Part 51.
Since the purpose of these revisions is to
clarify the performance specifications
which were promulgated on October 6,
1975. not to establish more stringent
requirements, it is reasonable to
conclude that most continuous
monitoring instruments which met and
can continue to meet the October 6.
1975. specifications can also meet the
revised specifications.
Under Executive Order 12044. the
Environmental Protection Agency is
required to judge whether a regulation is
"significant" and therefore subject to the
procedural requirements of the Order or
whether it may follow other specialized
development procedures. EPA labels
these other regulations "specialized". I
have reviewed this regulation and
determined that it is a specialized
regulation not subject to the procedural
requirements of Executive Order 12044.
Dated: October 1.1979.
Douglas M. Costle,
Administrator.
It is proposed to revise Appendix B,
Part 60 of Chapter 1, Title 40 of the Code
of Federal Regulations as follows:
Appendix B—Performance
Specifications
Performance Specification 1—
Specifications and Test Procedures For
Opacity Continuous Monitoring Systems
in Stationary Sources
1. Applicability and Principle
1.1 Applicability. This Specification
contains instrument design.
performance, and installation
requirements, and test and data
computation procedures for evaluating
the acceptability of continuous
monitoring systems for opacity. Certain
design requirements and test procedures
established in the Specification may not
be applicable to all instrument designs:
equivalent systems and test procedures
may be used with prior approval by the
Administrator.
1.2 Principle. The opacity of
participate matter in stack emissions is
continuously monitored by a
measurement system based upon the
principle of transmissometry. Light
having specific spectral characteristics
is projected from a lamp through the
effluent in the stack or duct and the
intensity of the projected light is
measured by a sensor. The projected
light is attenuated due to absorption and
scatter by the particulate matter in the
effluent; the percentage of visible light
attenuated is defined as the opacity of
the emission. Transparent stack
emissions that do not attenuate light will
have a transmittance of 100 percent or
an opacity of zero percent. Opaque
stack emissions that attenuate all of the
visible light will have a transmittance of
zero percent or an opacity of 100
percent.
This specification establishes specific
design criteria for the transmissometer
system. Any opacity continuous '
.monitoring system that is expected to
meet this specification is first checked to
verify that the design specifications are
met. Then, the opacity continuous
monitoring system is calibrated.
installed, an operated for a specified
length of time. During this specified time
period, the system is evaluated to
determine conformance with the
established performance specifications.
2. Definitions
2.1 Continuous Monitoring System.
The total equipment required for the
determination of opacity. The system
consists of the following major
subsystems:
,2.1.1 Sample Interface. That portion
of the system that protects the analyzer
from the effects of the stack effluent and
aids in keeping the optical surfaces
clean.
2.1.2 Analyzer. That portion of the
system that senses the pollutant and
generates a signal oirtput that is a
function of the opacity.
2.1.3 Data Recorder. That portion of
the system that processes the analyzer
output and provides a permanent record
of the output signal in terms of opacity.
The data recorder may include
automatic data reduction capabilities.
2.2 Transmissometer. That portion of
the system that includes the sample
interface and the analyzer.
2.3 Transmittance. The fraction of
incident light that is transmitted through
an optical medium.
2.4 Opacity. The fraction of incident
light that is attenuated by an optical
medium. Opacity (Op) and
transmittance (Tr) are related by:
Op = l-Tr.
2.5 Optical Density. A logarithmic
measure of the amount of incident light
attenuated. Optical density (D) is
related to the transmittance and opacit
as follows:
D=-log,. Tr=-log,. (1-Op).
2.6 Peak Spectral Response. The
wavelength of maximum sensitivity of
the transmissometer.
2.7 Mean Spectral Response. The
wavelength which bisects the total are
under the effective spectral response
curve of the transmissometer.
2.8 Angle of View. The angle that
contains all of the radiation detected b
the photodetector assembly of the
analyzer at a level greater than 2.5
percent of the peak detector response.
2.9 Angle of Projection. The angle
that contains all of the radiation
projected from the lamp assembly of tl
analyzer at a level of greater than 2.5
percent of the peak illuminace.
2.10 Span Value. The opacity value
at which the continuous monitoring
system is set to produce the maximum
data display output as specified in the
applicable subpart.
2.11 Upscale Calibration Value. Th
opacity value at which a calibration
check of the monitoring system is
performed by simulating an upscale
opacity condition as viewed by the
receiver.
2.12 Calibration Error. The
difference between the opacity values
indicated by the continuous monitorin
system and the known values of a sen
of calibration attenuators (filters or
screens).
2.13 Zero Drift. The difference in
continuous monitoring system output
readings before and after a stated peri
of normal continuous operation durinf
which no unscheduled maintenance,
repair, or adjustment took place and
when the opacity (simulated) at the tir
of the measurements was zero.
2.14 CaJibralion Drift. The differen
in the continuous monitoring system
output readings'before and after a sta
period of normal continuous operation
during which no unscheduled
maintenance, repair, or adjustment to<
place and when the opacity (simulatet
at the time of the measurements was t
same known upscale calibration valut
2.15 Response Time. The amount c
time it takes the continuous monitorin
system to display on the data recordei
95 percent of a step change in opacity.
2.16 Conditioning Period. A perioc
time (168 hours minimum) during whic
the continuous monitoring system is
operated without unscheduled
maintenance, repair, or adjustment pr
to initiation of the operational test
period.
11-102
-------
2.17 Operational Test Period. A
period of lime (168 hours) during which
the continuous monitoring system is
expected to operate within the
established performance specifications
without any unscheduled maintenance,
repair, or adjustment.
2.18 Pathlength. The depth of
effluent in the light beam between the
receiver and the transmitter of a single-
pass transmissometer, or the depth of
effluent between the transceiver and
reflector of a double-pass
transmissometer. Two pathlengths are
referenced by this Specification as
follows:
2.iai Monitor Pathlength. The
pathlength at the installed location of
the continuous monitoring system.
2.18.2 Emission Outlet Pathlength.
The pathlength at the location where
emissions are released to the
atmosphere.
3. Apparatus
3.1 Continuous Monitoring System.
Use any continuous monitoring system
for opacity which is expected to meet
the design specifications in Section 5
and the performance specifications in
Section 7. The data recorder may be an
analog strip chart recorder type or other
suitable device with an input signal
range compatible with the analyzer
output.
3.2 Calibration Attenuators. Use
optical filters with neutral spectral
characteristics or screens known to
prbduce specified optical densities to
visible light. The attenuators must be of
sufficient size to attenuate the entire
light beam of the transmissomeler.
Select and calibrate a minimum of three
attenuators according to the procedures
in Sections 8.1.2. and 8.1.3.
3.3 Upscale Calibration Value
Attenuator. Use an optical filter with
neutral spectral characteristics, a
screen, or other device that produces an
opacity value (corrected for pathlength,
if necessary) that is greater than the sum
of the applicable opacity standard and
one-fourth of the difference between the
opacity standard and the instrument
span value, but less than the sum of the
opacity standard and one-half of the
difference between the opacity standard
and the instrument span value.
3.4 Calibration Spectrophotometer.
To calibrate the calibration attenuators
use a laboratory Spectrophotometer
meeting the following minimum design
specification:
Pw»«ne!flr Speof«=»hon
W»,tl»ngth l
. 400-700 ran
. S10-
.SOS pel
4. Installation Specifications
Install the continuous monitoring
system where the opacity measurements
are representative of the total emissions
from the affected facility. Use a
measurement path that represents the
average opacity over the cross section.
Those requirements can be met as
follows:
4.1 Measurement Location. Select a
measurement location that is (a)
downstream from all particulate control
equipment; (b) where condensed water
vapor is not present: (c) accessible in
order to permit routine maintenance;
and (d) free of interference from.
ambient light (applicable only if
transmissometer is responsive to
ambient light).
4.2 Measurement Path. Select a
measurement path that passes through
the centroid of the cross section.
Additional requirements or
modifications must be met for certain
locations as follows:
4.2.1 If the location is in a straight
vertical section of stack or duct and is
less than 4 equivalent diameters
downstream or 1 equivalent diameter
upstream from a bend, use a path that is
in the plane defined by the bend.
4.2.2 If the location is in a vertical
section of stack or duct and is less than
4 diameters downstream and 1 diameter
upstream from a bend, use a path in the
plane defined by the bend upstream of
the transmissometer.
4.2.3 If the location is in a horizontal
section of duct and is at least 4
diameters downstream from a vertical
bend, use a path in the horizontal plane
that is one-third the distance up the
vertical axis from the bottom of the duct.
4.2.4 If the location is in a horizontal
section of duct and is less than 4
diameters downstream from a vertical
bend, use a path in the horizontal plane
that is two-thirds the distance up the
vertical axis from the bottom of the duct
for upward flow in the vertical section,
and one-third the distance up the
vertical axis from, the bottom of the duct
for downward flow.
4.3 Alternate Locations and
Measurement Paths. Other locations and
measurement paths may be selected by
demonstrating to the Administrator that
the average opacity measured at the
alternate location or path is equivalent
(± 10 percent) to the opacity as
measured at a location meeting the
criteria of Sections 4.1 and 4.2. To
conduct this demonstration, measure the
opacities at the two locations or paths
for a minimum period of two hours. The
opacities of the two locations or paths
may be measured at different times, but
must be measured at the same process
operating conditions.
5. Design Specifications
Continuous monitoring systems for
opacity must comply with the following
design specifications:
5.1 Optics.
5.1.1 Spectral Response. The peak
and mean spectral responses will occur
between 515 nm and 585 nm. The
response at any wavelength below 400
nm or above 700 nm will be less than 10
percent of the peak spectral response.
5.1.2 Angle of View. The total angle
of view will be no greater than 4
degrees.
5.1.3 Angle of Projection. The total
angle of projection will be no greater
than 4 degrees.
5.2 Optical Alignment sight. Each
analyzer will provide some method for
visually determining that the instrument
is optically aligned. The system
provided will be capable of indicating
that the unit is misaligned when an error
of ± 2 percent opacity occurs due to
misalignment at a monitor pathlength of
eight (8) meters.
5.3 Simulated Zero and Upscale
Calibration System. Each analyzer will
include a system for simulating a zero
opacity and an upscale opacity value for
the purpose of performing periodic
checks of the transmissometer
calibration while on an operating stack
or duct. This calibration system will
provide, as a minimum, a system check
of the analyzer internal optics and all
electronic circuitry including the lamp
and photodetector assembly.
5.4 Access to External Optics. Each
analyzer will provide a means of access
to the optical surfaces exposed to the
effluent stream in order to permit the
surfaces to be cleaned without requiring
removal of the unit from the source
mounting or without requiring optical
realignment of the unit.
5.5 Automatic Zero Compensation
Indicator. If the monitoring system has a
feature which provides automatic zero
compensation for dirt accumulation on
exposed optical surfaces, the system
will also provide some means of
indicating that a compensation of
4 ± 0.5 percent opacity has been
exceeded: this indicator shall be at a
location accessible to the operator (e.g..
the data output terminal). During the
operational test period, the system must
provide some means for determining the
actual amount of zero compensation at
the specified 24-hour intervals so that
the actual 24-hour zero drift can be
determined (see Section 8.4.1).
5.6 Slotted Tube. For
transmissomelers that use slotted tubes,
the length of the slotted porlion(s) must
11-103
-------
be equal to or greater than 90 percent of
the monitor pathlength. and the slotted
tube must be of sufficient size and
orientation so as not to interfere with
the free flow of effluent through the
entire optical volume of the
transmissometer photodetector. The
manufacturer must also show that the
transmissometer uses appropriate
methods to minimize light reflections; as
a minimum, this demonstration shall
consist of laboratory operation of the
transmissometer both with and without
the slotted tube in position. Should the
operator desire to use a slotted tube
design with a slotted portion equal to
less than 90 percent of the monitor
pathlength. the operator must
demonstrate to the Administrator that
acceptable results can be obtained. As a
minimum demonstration, the effluent
opacity shall be measured using both
the slotted tube instrument and another
instrument meeting the requirement of
this specification but not of the slotted
tube design. The measurements must be
made at the same location and at the
same process operating conditions for a'
minimum period of two hours with each
instrument. The shorter slotted tube may
be used if the average opacity measured
is equivalent (± 10 percent) to the
opacity measured by the non-slotted
tube design.
6. Optical Design Specifications
Verifciation Procedure.
These procedures will not be
applicable to all designs and will require
modification in some cases; all
modifications are subject to the
approval of the Administrator.
Test each analyzer for conformance
with the design specifications of
Sections 5.1 and 5.2 or obtain a
certificate of conformance from the
analyzer manufacturer as follows:
6.1 Spectral Response. Obtain
detector response, lamp emissivity and
filter transmittance data for the
components used in the measurement
system from their respective
manufacturers.
6.2 Angle of View. Set up the
receiver as specified by the
manufacturer's written instructions.
Draw an arc with radius of 3 meters in
the horizontal direction. Using a small
(less than 3 centimeters) non-directional
light source, measure the receiver
response at 4 entimeter intervals on the
arc for 24 centimeters on either side of
the detector centerline. Repeat the test
in the vertical direction.
6.3 Angle of Projection. Set up the
projector as specific J L-y the
'lanuf.-cU're.'1; written in '-unions.
Draw m arc with radii, - f 3 rnelers in
the horizontal direction. Using a small
(less than 3 centimeters) photoelectric
light detector, measure the light
intensity at 4-centimeter intervals on the
arc for 24 centimeters on either side of
the light source centerline of projection.
Repeat the test in the vertical direction.
6.4 Optical Alignment Sight. In the
laboratory set up the instrument as
specified by the manufacturers written
instructions for a monitor pathlength of
8 meters. Assure that the instrument has
been properly aligned and that a proper
zero and span have been obtained.
Insert an attenuator of 10 percent
(nominal) opacity into the instrument
pathlength. Slowly misalign the
projector unit until a positive or negative
shift of two percent opacity is obtained
by the data recorder. Then, following
the manufacturer's written instructions.
check the alignment and assure that the
alignment procedure does in fact
indicate that the instrument is
misaligned. Realign the instrument and
follow the same procedure for checking
misalignment of the receiver or
retroreflector unit
6.5 Manufacturer's Certificate of
Conformance (Alternative to above).
Obtain from the manufacturer a
certificate of conformance which
certifies that the first analyzer randomly
sampled from each month's production
was tested according to Sections 6.1
through 6.3 and satisfactorily met all
requirements of Section 5 of this
Specification. If any of the requirements
were not met, the certificate must state
that the entire month's analyzer-
production was resampled according to
the military standard 105D sampling
procedure (MIL-SJD-105D) inspection
level II; was retested for each of the
applicable requirements under Section 5
of this Specification: and was
determined to be acceptable under MIL-
STD-105D procedures, acceptable
quality level 1.0. The certificate of
conformance must include the results of
each test performed for the analyzer(s)
sampled during the month the analyzer
being installed was produced.
7. Performance Specifications
The opacity continuous monitoring
system performance specifications are
listed in Table 1-1.
Table 1-1.—Perforrmnce specific* lions
Table 1-1.—Perlormancf spaciticitions—ConUnu
Parameter
SpeofiCabon*
V t-»Wx*lKX* »rror *
2 fi«KX>o** IKTMI
3 CxxxfcUx^»g p*oodto
4 Op**»t«o*x«t i**i p*ood*_
n rrwiuloo
? pel opac*ir
0 W pel ol fc* »c
tpan valua
mMd at »um o* abtotuia maan and In* M par
ln» corxMioronj and oparalwnaJ l*tt pcrodt.
Conbnuou* mrxwonog Jyslem that no( raqu*a any CO»'»C
mamenanc*. repa'. raplac»m«nl or ad«j»lmenl otiar '
at routma and ra
-------
attenuators having the values given in
Table 1-2 or having values closest to
those calculated by Equation 1-1.
Table 1-2.—Required Calibrated Attenuator^ Values
(Nominal)
SpanvakM
(percent opacity)
CaUxated attenuator
epical density
nparenfhesa)
Low-iange D, Mid-range Hign-rangc
50 - 0
60 _ -
70 -
80 - -
too •
(20)
(20)
(20)
(20)
(20)
(20)
0.2
2
a
j.
.4
.4
(37)
(37)
(SO)
(50)
(60)
|60)
03 (50)
.3 (50)
.« (60)
.6 (75)
.7 (80)
S (87V4)
D, = D, (L./U)
Equation 1-1
Where:
D, = Nominal optical density value of
required mid. low. or high range
calibration attenuators.
D, = Desired attenuator optical density
output value from Table 1-2 at the span
required by the applicable subpart.
Li = Monilor pathlength.
L. = Emission outlej pathlength.
8.1.3 Attenuator Calibration.
Calibrate the required fillers or screens
using a laboratory spectrophotometer
meeting the specifications of Section 3.4
to measure the transmittance in the 400
to 700 nm wavelength range; make
measurements at wavelength intervals
of 20 nm or less. As an alternate
procedure use an .instrument meeting the
specifications of Section 3.4 to measure
the C.l.E. Daylightc Luminous
Transmittance of the attenuators. During
the calibration procedure assure that a
minimum of 75 percent of the total area
of the attenuator.is checked. The
attenuator manufacturer must specify
the period of time over which (he
attenuator values can be considered
stable, as well as any special handling
and storing procedures required to
enhance attenuator stability. To assure
stability, attenuator values must be
rechecked at intervals less than or equal
to the period of stability guaranteed by
the manufacturer. However, values must
be rechecked at least every 3 months. If
desired, testability checks may be
performed on an instrument other than
that initially used for the attenuator
calibration (Section 3.4). However, if a
different instrument is used, the
instrument shall be a high quality
laboratory transmissometer or
spectrophotometer and the same
instrument shall always be used for the
stability checks. If a secondary
instrument is to be used for stability
checks, (he value of the calibrated
attenuator shall be measured on this
secondary instrument immediately
following calibration and prior to being
used. If over a period time an attenuator
value changes by more than ±2 percent
opacity, it shall be recalibrated or
replaced by a new attenuator.
If this procedure is conducted by the
filter or screen manufacturer or
independent laboratory, obtain a
statement certifying the values and that
the specified procedure, or equivalent,
was used.
8.1.4 -Calibration Error Test. Insert
the calibrated attenuators (low, mid, and
high range] in the transmissometer path
at or as near to the midpoint as feasible.
The attenuator must be placed in the
measurement path at a point where the
effluent will be .measured; i.e.. do not
place the calibrated attenuator in the
instrument housing. While inserting the
attenuator, assure that the entire
projected beam will pass through the
attenuator and that the attenuator is
inserted in a manner which minimizes
interference from reflected light. Make a
total of five nonconsecutive readings for
each filter. Record the monitoring
system output readings in percent
opacity (see example Figure 1-1).
8.1.5 System Response Test. Insert
the high-range calibrated attenuator in
the transmissometer path five times and
record the time required for the system
to respond to 95 percent of final zero
and high-range filter values (see
example Figure 1-2).
8.2 Preliminary Field Adjustments.
Install the continuous monitoring system
on the affected facility according to the
manufacturer's written instructions and
perform the following preliminary
adjustments;
8.2.1 Optical and Zero Alignment.
When the facility is not in operation,
conduct the optical alignment by
aligning the light beam from the
transmissometer upon the optical
surface located across the duct or stack
(i.e.. the retroflector or photodetector, as
applicable) in accordance with the
manufacturer's instructions. Under clear
stack conditions, verify the zero
alignment (performed in Section 8.1.1)
by assuring that the monitoring system
response for the simulated zero check
coincides with the actual zero measured
by the transmissometer across the clear
stack. Adjust the zero alignment, if
necessary. Then, after the affected
facility has been started up and the
effluent stream reaches normal
operating temperature, recheck the
optical alignment. If the optical
alignment has shifted realign the optics.
8.2.2 Optical and Zero Alignment
(Alternative Procedure). If the facility is
already on line and a zero stack
condition cannot practicably be
obtained, use the zero alignment
obtained during the preliminary
adjustments (Section 8.1.1) prior to
installation of the transmissomeler on
the stack. After completing al! the
preliminary adjustments and tests
'required in Section 8.1. install the
system at the source and align the
optics, i.e.. align the light beam from the
transmissometer upon the optical
surface located across the duct or stack
in accordance with the manufacturer's
instruction. The zero alignment
conducted in this manner shall be
verified and adjusted, if necessary, the
first time the facility is not in operation
after the operational test period has
been completed.
8.3 Conditioning Period. After
completing the preliminary field
adjustments (Section 8.2), operate the
system according to the manufacturer's
instructions for an initial conditioning
period of not less than 168 hours while
the source is operating. Except during
times of instrument zero and upscale
calibration checks, the continuous
monitoring system will analyze the
effluent gas for opacity and produce a
permanent record of the continuous
monitoring system output. During this
conditioning period there shall be no
unscheduled maintenance, repair, or
adjustment. Conduct daily zero
calibration and upscale calibration
checks, and. when accumulated drift
exceeds the daily operating limits, make
adjustments and/or clean the exposed
optical surfaces. The data recorder shall
reflect these checks and adjustments. At
the end of the operational test period,
verify that the instrument optical
alignment is correct. If the conditioning
period is interrupted because of source
breakdown (record the dates and times
of process shutdown), continue the 168-
hour period following resumption of
source operation. If the conditioning
period is interrupted because of monitor
failure, restart the 168-hour conditioning
period when the monitor becomes
operational.
8.4 Operational Test Period. After
completing the conditioning period
operate the system for an additional
168-hour period. It is not necessary that
the 168-hour operational test period
immediately follow the 168-hour
conditioning period. Except during times
of instrument zero and upscale
calibration checks, the continuous
monitoring system will analyze the
effluent gas for opacity and will produce
a permanent record of the continuous
monitoring system output. During this
period, there will be no unscheduled
maintenance, repair, or adjustment. Zero
and calibration adjustments, optical
surface cleaning, and optical
realignment may be performed
(optional) only at 24-hour intervals or at
11-105
-------
such shorter intervals as the
manufacturer's written instructions
specify. Automatic zero and calibration
adjustments made by the monitoring
system without operator intervention or
initiation are followable at any time. If
the operational test period is interrupted
because of source breakdown, continue
the 165-hour period following
resumption of source operation. If the
test period is interrupted because of
monitor failure, restart the 168-hour
period when the monitor becomes
operational. During the operational test
period, perform the following test
procedures:-
8.4.1 Zero Drift Test. At the outset of
the 168-hour operational test period,
record the initial simulated zero and
upscale opacity readings (see example
Figure 1-3). After each 24-hour interval
check and record the final zero reading
before any optional or required cleaning
and adjustment. Zero and upscale
calibration adjustments, optical surface
cleaning, and optical realignment may
be performed only at 24-hour intervals
(or at such shorter intervals as the
manufacturer's written instructions
specify) but are optional. However.
adjustments and/or cleaning must be
performed when the accumulated zero
calibration or upscale calibration drift
exceeds the 24-hour drift specifications
(±2 percent opacity). If no adjustments
are made after the zero check the final
zero reading is recorded as the initial
reading for the next 24-hour period. If
adjustments are made, the zero value
after adjustment is recorded as the
initial zero value for the next 24-hour
period. If the instrument has an
automatic zero compensation feature for
dirt accumulation on exposed lens, and
the zero value cannot be measured
before compensation is entered then
record the amount of automatic zero
compensation for the final zero reading
of each 24-hour period. (List the
indicated zero values of the monitoring
system in parenthesis.)
8.4.2 Upscale Drift Test. At each 24-
hour interval, after the zero calibration
value has been checked and any
optional or required adjustments have
been made, check and record the
simulated upscale calibration value. If
no further adjustments are made to the
calibration system at this time, the final
upscale calibration value is recorded as
the initial upscale value for the next 24-
hour period. If an instrument span
adjustment is made, the upscale value
after adjustment is recorded as the
Initial upscale for the next 24-hour
period.
During the operational test period
record all adjustments, realignments and
lens cleanings.
9. Calculation. Data Analysis, and
Reporting
9.1 Arithmetic Mean. Calculate the
mean of a set of data as follows:
1 "
x • i r »j
n.i-i '
Equation 2-1
Where:
~x = mean value.
n = number of data points.
Ixi = algebraic sum of the individual
measurements, x,
9.2 Confidence Interval. Calculate
the 95 percent confidence interval (two-
sided) as follows:
Equation 2-?
Where:
C.I.» = 95 percent confidence interval
estimate of the average mean value.
'.975 = lttr-a/2).
T»We 1-3— '-975 Values
'.975
'.•75
'.975
2
3
»
5
6
12706
4303
3182
2776
2571
7
a
•
10
11
2447
2395
2306
2262
2.228
12
13
14
IS
16
2201
2179
2 160'
2145
2 131
The values in this table are already
corrected for n-1 degrees of Freedom.
Use n equal to the number of data
points.
9.3 Conversion of Opacity Values
from Monitor Pathlength to Emission
Outlet Pathlength. When the monitor
pathlength is different than the emisson
outlet pathlength. use either of the
following equations to convert from one
basis to the other (this conversion may
be automatically calculated by the
monitoring system):
log(l-Op,) = (U/L,) Log (1,-Op,) Equation l-«
D, = (U/Li) Equation 1-5
Where:
Op, = opacity of the effluent based upon L,
Op> = opacity of the effluent based upon L,
Li = monitor pathlength
L, = emission outlet pathlength
D, = optical density of the effluent based
upon Li
D. = optical density-of the effleunt based
upon U
9.4 Spectral Response. Using the
spectral data obtained in Section 6.1,
develop the effective spectral response
curve of the transmissometer. Then
determine and report the peak spectral
response wavelength, the mean spectral
response wavelength, and the maximum
response at any wavelength below 400
nm and above 700 nm expressed as a
percentage of the peak response.
9.5 Angle of View. For the horizontal
and vertical directions, using the data
obtained in Section 6.2, calculate the
response of the receiver as a function of
viewing angle (21 centimeters of arc
with a radius of 3 meters equal 4
degrees), report relative angle of view
curves, and determine and report the
angle of view.
9.6 Angle of Projection. For the
horizontal and vertical directions, using
the data obtained in Section 6.3,
calculate the response of the
photoelectric detector as a function of
projection angle, report relative angle of
projection curves, and determine and
report the angle of projection.
9.7 Calibration Error. See Figure 1-1.
If the pathlength is not adjusted by the
measurement system, subtract the
actual calibrated attenuator value from
the value indicated by the measurement
system recorder for each of the 15
readings obtained pursuant to Section
8.1.4. If the pathlength is adjusted by the
measurement system subtract the "path
adjusted" calibrated attenuator values
from the values indecated by the
measurement system recorder the "path
adjusted" calibrated attenuator values
are calculated using equation 1—4 or 1-
5). Calculate the arithmetic mean
difference and the 95 percent confidence
interval of the five tests at each
attenuator value using Equations 1-2
and 1-3. Calculate the sum of the
absolute value of the mean difference
and the 95 percent confidence interval
for each of the three test attenuators;
report these three values as the
calibration error.
9.8 Ze^-o and Upscale Calibration
Drifts. Using the data obtained in
Sections 8.4.1 and 8.4.2 calculate the
zero and upscale calibration drifts. Then
calculate the arithmetic means and the
95 percent confidence intervals using
Equations 1-2 and 1-3. Calculate the
sum of the absolute value of the mean
and the 95 percent confidence interval
and report these values as the 24-hour
zero drift and the 24-hour calibration
drift.
9.9 Response Time. Using the data
collected in Section 8.1.5. calculate the
mean time of the 10 upscale and
downscale tests and report this value as
the system response limev
9.10 Reporting. Report the following
(summarize in tabular form where
appropriate).
9.10.1 General Information.
a. Instrument Manufacturer.
b- Instrument Model Number.
c. Instrument Serial Number.
11-106
-------
d. Person(s) responsible for
operational and conditioning test
periods and affiliation.
e. Facility being monitored.
f. Schematic of monitoring system
measurement path location.
g. Monitor pathlength. meters.
h. Emission outlet pathlength, meters.
i. System span value, percent opacity.
j. Upscale calibration value, percent
opacity.
k. Calibrated Attenuator values (low.
mid. and high range), percent opacity.
9.10.2 Design Specification Test
Results
a. Peak spectral response, nra.
b. Mean spectral response, am.
c. Response above 700 nm. percent of
peak.
d. Response below 400 nm, percent of
peak.
e. Total angle of view, degrees.
f. Total angle of projection, degrees.
9.10.3 Operational Test Period
Results.
a. Calibration error, high-range,
percent opacity.
b. Calibration error, mid-range.
percent opacity.
c. Calibration error, low-range.
percent opacity.
d. Response time, seconds.
e. 24-hour zero drift, percent opacity.
f. 24-hour calibratton drift, percent .
opacity.
g. Lens cleaning, clock time.
h. Optical alignment adjustment, clock
time.
9.10.4 Statements. Provide a
statement that the conditioning and
operational test periods were completed
according to the requirements of
Sections &3 and 8.4. In Ihis statement.
include the time periods during which
the conditioning and operational test
periods were conducted.
9.10.5 Appendix. Provide the data
tabulations and calculations for the
above tabulated results.
9.11 Retest. If the continuous
monitoring system operates within the
specified performance parameters of
Table 1-1. the operational test period
will be successfully concluded. If the
continuous monitoring system fails to
meet any of the specified performance
parameters, repeat the operational test
period with a system that meets the
design specifications and is expected to
meet the performance specifications.
10. Bibliograpny.
10.1 "Experimental Statistics,"
Department of Commerce. National
Bureau of Standards Handbook 91,1963,
pp. 3-31. paragraphs 3-3.1.4.
10.2 "Performance Specifications for
Stationary-Source Monitoring Systems
for Cases and Visible Emissions."
Environmental Protection Agency.
Research Triangle Park. N. C.. EPA-650/
2-74-013. January 1974.
11-107
-------
Person Conducting Test
Affiliation
Date
Analyzer Manufacturer
Model/Serial No
Location
Monitor Pathlength, Lj . Emission Outlet Pathlength. L2
Monitoring System Output Pathlength Corrected? Yes No
Calibrated Neutral Density Filter Values
Actual Optical Density (Opacity):
Low Range ( )
Mid Range ( )
High Range.
J
Path Adjusted Optical Density (opacity)
Low Range -( —)
Mid Range -( )
High Range -( -)
Run
Number
Calibration Filter
Value
(Path Adjusted Percent Opacity)
Instrument Reading
(Percent Opacity)
Arithmetic Difference
(% Opacity)
Low
Mid
High
1 — Low
2-Mid
3 - High
4 — Low
5-Mid
6 - High
7 — Low
8 - Mid
9 - High
10-Low
11-Mid
12-High
13-Low
14-Mid
15-High
Arithmetic Mean
Confidence Interval
Calibration Error
(Equation 1-2): A
(Equation 1 — 3): B
Figure 1 — 1. Calibration error determination
11-108
-------
Person Conducting Test
Affiliation .
Date.
Analyzer Manufacturer
Model/Serial No
Location
High Range Calibration Filter Value:
Actual Optical Density (Opacity).
Path Adjusted Optical Density (Opacity).
Upscale Response Value ( 0.95 x filter value)—
Downscale Response Value (0.05 x filter value).
.percent opacity
.percent opacity
Upscale
Downscale
3
4
1
2
4
5
seconds
seconds
seconds
seconds
seconds
seconds
seconds
Average response
seconds
seconds
Figure 1-2. Response Time Determination
11-109
-------
Person Conducting Test
Affiliation —
Date
Analyzer Manufacturer
Model/ Serial No
Location.
. Emission Outlet Pathlength, L2
Monitoring System Output Pathlength Corrected: ? Yes No
Monitor Pathlength,
Upscale Calibration Value : Actual Optical Density (Opacity)
Date
Time
Begin
End
Path Adjusted Optical Density (Opacity)
Percent Opacity
Zero Reading*
Initial
A
Final
B
Arithmetic Mean (Eq. 1—2)
Confidence Interval (Eq. 1—3)
Zero Drift
Zero
Drift
C = B-A
Upscale Calibration
Reading
Initial
D
Final
E
Upscale
Drift
F = E-D
Calibration Drift
Cali-
bration
Drift
G = F-C"
Align-
ment
IN-
TO
0)
.*
u
-------
Performance Specification 2—
Specifications and Test Procedures for
SO* and NO, Continuous Monitoring
Systems in Stationary Sources
1. Applicability and Principle
1.1 Applicability. This Specification
contains (a) installation requirements,
(b) instrument performance and
equipment specifications, and (c) test
procedures and data reduction
procedures for evaluating .the
acceptability of SO. and NO, continuous
monitoring systems, which may include,
for certain stationary sources, diluent
monitors. The,test procedures in item
(c). above, are not applicable to single-
pass, in-situ continuous monitoring
systems; these systems will be
evaluated on a case-by-case basis upon
written request to the Administrator and
alternative test procedures will be
issued separately.
1.2 Principle. Any SO, or NO,
continuous monitoring system that is
expected to meet this Specification is
installed, calibrated, and operated for a
specified length of time. During this
specified time period, the continuous
monitoring system is evaluated to
determine conformance with the
Specification.
2. Definitions
2.1 Continuous Monitoring System.
The total equipment required for the
determination of a gas concentration or
a gas emission rate. The system consists
of the following major sub-systems:
2.1.1 Sample Interface. That portion
of a system that is used for one or more
of the following: sample acquisition,
sample transportation, sample
conditioning, or protection of the
monitor from the effects of the stack
effluent.
2.1.2. Pollutant Analyzer. That
portion of the system that senses the
pollutant gas and generates an output
that is proportional to the gas
concentration.
2.1.3. Diluent Analyzer (if
applicable). That portion of the system
that senses the diluent gas (e.g., CO, or
Oj) and generates an output that is
proportional to the gas concentration.
2.1.4 Data Recorder. That portion of
the monitoring system that provides a
permanent record of the analyzer
output. The data recorder may include
automatic data reduction capabilities.
2.2 Types of Monitors. Continuous
monitors are categorized as "extractive"
or "in-situ." which are further
categorized as "point," "multipoint,"
"limited-path," and "path" type
monitors or as "single-pass" or "double-
pass" type monitors.
2.2.1 Extractive Monitor. One that
withdraws a gas sample from the stack
and transports the sample to the
analyzer.
2.2.2 In-situ Monitor. One that
senses the gas concentration in the
stack environment and does not extract
a sample for analysis.
2.2.3 Point Monitor. One that
measures the gas concentration either at
a single point or along a path which is
less than 10 percent of the length of a
specified measurement line.
2.2.4 Multipoint Monitor. One that
measures the gas concentration at 2 or
more points.
2.2.5 Limited-Path Monitor. One that
measures the gas concentration along a
path, which is 10 to 90 percent of the
length of a specified measurement line.
2.2.6 Path Monitor. One that
measures the gas concentration along a
path, which is greater-than 90 percent of
the length of a specified measurement
line.
2.2.7 Single-Pass Monitor. One that
has the transmitter and the detector on
opposite sides of the stack or duct.
2.2.8 Double-Pass Monitor. One that
has the transmitter and the detector on
the same side of the stack or duct.
2.3 Span Value. The upper limit of a
gas concentration measurement range
which is specified for affected source
categories in the applicable subpart of
the regulations.
2.4 Calibration Cases. A known
concentration of a gas in an appropriate
diluent gas.
2.5 Calibration Gas Cells or Filters.
A device which, when inserted between
the transmitter and detector of the
analyzer, produces the desired output
level on the data recorder.
2.6 Relative Accuracy. The degree of
correctness including analytical
variations of the gas concentration or
emission rate determined by the
continuous monitoring system, relative
to the value determined by the reference
method(s).
2.7 Calibration Error. The difference
between the gas concentration indicated
by the continuous monitoring system
and the known concentration of the
calibration gas, gas cell, or filter.
2.8 Zero Drift. The difference in the
continuous monitoring system output
readings before and after a stated period
of operation during which no
unscheduled maintenance, repair, or
adjustment took place and when the
pollutant concentration at the time of
the measurements was zero (i.e., zero
gas, or zero gas cell or filter).
2.9 Calibration Drift. The difference
in the continuous monitoring system.
output readings before and after a stated
period of operation during which no
unscheduled maintenance, repair or
adjustment took place and when the
pollutant concentration at the time of
the measurements was a high-level
value (i.e., calibration gas, gas cell or
filter).
2.10 Respons'e Time. The amount of
time it takes the continuous monitoring
system to display on the data recorder
95 percent of a step change in pollutant
concentration.
2.11 Conditioning Period. A
minimum period of time over which the
continuous monitoring system is
expected to operate with no
unscheduled maintenance, repair, or
adjustments prior to initiation of the
operational test period.
2.12 Operational Test Period. A
minimum period of time over which the
continuous monitoring system is
expected to operate within the
established performance specifications
with no unscheduled maintenance,
repair or adjustment.
3. Installation Specifications
Install the continuous monitoring
system at a location where the pollutant
concentration measurements are
representative of the total emissions
from the affected facility and are
representative of the concentration over
the cross section. Both requirements can
be met as follows:
3.1 Measurement Location. Select an
accessible measurement location in the
stack or ductwork that is at least 2
equivalent diameters downstream from
the nearest control device or other point
at which a change in the pollutant
concentration may occur and at least 0.5
equivalent diameters upstream from the
effluent exhaust. Individual subparts of
the regulations may contain additional
requirements. For example, for steam
generating facilities, the location must
be downstream of the air preheater.
3.2 Measurement Points or Paths.
There are two alternatives. The tester
may choose either (a) to conduct the
stratification check procedure given in
Section 3.3 to select the point, points, or
path of average gas concentration, or (b)
to use the options listed below without a
stratification check.
Note.—For (he purpose of this section, the
"centroidal area" is defined as a concentric
area that is geometrically similar to the stack
cross section and is no greater than 1 percent
of the slack cross-sectional area.
3.2.1 SOi and NO, Path Monitoring
Systems. The tester may choose to
centrally locate the sample interface
(path) of the monitoring system on a
measurement line that passes through
the "centroidal area" of the cross
section.
11-111
-------
3.2.2 SO, and NO, Multipoint
Monitoring Systems. The tester may
choose to space 3 measurement points
along a measurement line that passes
through the "centroidal area" of the
stack cross section, at distances of 16.7,
50.0, and 83.3 percent of the way across
it (see Figure 2-1).
11-112
-------
••CENTROIDAL
AREA"
POINT DISTANCE
NO. (% OF L)
1 16.7
2 50.0
3 83.3
"CENTROIDAL
AREA" \
Figure 2-1. Location of an example measurement line (L) and measurement points.
11-113
-------
The following sampling strategies, or
equivalent, for measuring the
concentrations at the 3 points are
acceptable: (a) The use of a 3-probe or a
3-hole single probe arrangment,
provided that the sampling rate in each
of the 3 probes or holes is maintained
within 10 percent of their average rate
(This option requires a procedure,
subject to the approval of the
Administrator, to demonstrate that the
proper sampling rate is maintained); or
(b) the use of a traversing probe
arrangement, provided that a
measurement at each point is made at
least once every 15 minutes and all 3
points are traversed and sampled for
equal lengths of time within 15 minutes.
3.2.3 SOt Single-Point and Limited-
Path Monitoring Systems. Provided that
(a) no "dissimilar" gas streams (i.e.,
having greater than 10 percent
difference in pollutant concentration
from the average) are combined
upstream of the measurement location.
and (b) for steam generating facilities, a
CO» or Oi cotinuous monitor is installed
in addition to the SOi monitor,
according to the guidelines given in
Section 3.1 or 3.2 of Performance
Specification 3. the tester may choose to
monitor SO, at a single point or over a
limited path. Locate the point in or
centrally locate the limited path over the
"centroidal area." Any other location
within the inner 50 percent of the stack
cross-sectional area that has been
demonstrated (see Section 3.4) to have a
concentration within 5 percent of the
concentration at a point within the
"centroidal area" may be used.
3.2.4 NO, Single-Point and Limited-
Path Monitoring Systems. For NO,
monitors, the tester may choose the
single-point or limited-path option
described in Section 3.2.3 only in coal-
burning steam generators (does not
include oil and gas-fired units) and nitric
acid plants, which have no dissimilar
gas streams combining upstream of the
measurement location.
3.3 Stratification Check Procedure.
Unless specifically approved in Section
3.2., conduct a stratification check and
select the measurement point, points, or
path as follows:
3.3.1 Locate 9 sample points, as
shown in Figure 2-2. a or b. Tie tester
may choose to use more than 9 points,
provided that the sample points are
located in a similar fashion as in Fgure
2-2.
332 Measure at least twice the
pollutant and. if applicable (as in the
case of steam generators). COt or O,
concentrations at each of the sample
points. Moisture need not be determined
for this step. The following methods are
acceptable for the measurements: (a)
Reference Methods 3 (grab-sample). 6 or
7 of this part; (b) appropriate
instrumental methods which give
relative responses to the pollutant (i.e..
the methods need not be absolutely
correct), subject to the approval of the
Administrator; or (c) alternative
methods subject to the approval of the
Administrator. Express all
measurements, if applicable, in the units
of the applicable standard.
3.3.3 Calculate the mean value and
select a point, points, limited-path, or
path which gives an equivalent value to
the mean. The point or points must be
within, and the limited-path or path
must pass through, the inner 50 percent
of the stack cross-sectional area. All
other locations must be approved by the
Administrator.
11-114
-------
POINT
NO.
DISTANCE
(% OF D)
1.9
2.8
C
3.7
4.6
10.0
30.0
50.0
70.0
90.0
C 8 9
(a)
•
4
•
2
•
3
(b)
Figure 22. Location of 9 sampling points for stratification check.
11-115
-------
3.4 Acceptability of Single Point or
Limited Path Alternative Location. Any
of the applicable measurement methods
mentioned in Section 3.3.2. above, may
be used. Measure the pollutant and. if
applicable. Cd or d concentrations at
both the centroidal area and the
alternative locations. Moisture need not
be measured for this test. Collect a 21-
minute integrated sample or 3 grab-
samples, either at evenly spaced (7 ± 2
min.) intervals over 21 minutes or all
within 3 minutes, at each location. Run
the comparative-tests either
concurrently or within 10 minutes of
each other. Average the results of the 3
grab-samples.
Repeat the measurements until a
minimum of 3 paired measurements
spanning a minimum of 1,hour of
process operation are obtained.
Determine the average pollutant
concentrations at the centroidal area
and the alternative locations. If
applicable, convert the data in terms of
the standard for each paired set before
taking the average. The alternative
sampling location is acceptable if each
alternative location value is within ± 10
percent of the corresponding centroidal
area value and if the average at the
alternative location is within 5 percent
of the average of the centroidal area.
4. Performance and Equipment
Specifications
The continuous monitoring system
performance and equipment
specifications are listed in Table 2-1. To
be considered acceptable, the
continuous monitoring system must
demonstrate compliance with these
specifications using the test procedures
of Section 6.
5. Apparatus
5.1 Continuous Monitoring System.
Use any continuous monitoring system
of Sd or NO, which is expected to meet
the specifications in Table 2-1. For
sources which are required to convert
the pollutant concentrations to other
emission units using diluent gas
measurements, the diluent gas
continuous monitor, as described in
Performance Specification 3 of this
Appendix, is considered part of the
continuous monitoring system. The data
recorder may be an analog strip chart
recorder typ" or other suitable device
with an input signal range compatible
with the analyzer output.
5.2 Calibration Gases. For
continuous monitoring systems that
allow the introduction of calibration
gases to the analyzer, the calibration
gases may be Sd in air or N>. NO in N»,
and NO. in air or N». Two or more
calibration gases may be combined in
the same gas cylinder, except do not
combine the NO and air. For NO,
monitoring systems that oxidize NO to
NO,, the calibration gases must be in the
form of NO. Use three calibration gas
mixtures as specified below:
5.2.1 High-Level Gas. A gas
concentration that is equivalent to 80 to
90 percent of the span value.
Table 2-1.—Continuous Monitoring System
Performance and Equipment Specifications
Parameter
Specification
1. Conditioning
2. Operation*) test
period*.
3. Cahbrabon error •.
4. Response tone—
5. Zero drift 12-
hour)".
6. Zero dnn (24-
hour)".
7. Cattvabon drift
(2-hour)'.
• Calibration Onft
(24-hour) ».
0 Relative
accuracy'.
10 Calibration gal
cells or tillers.
11. Dall recorder
chart resolution.
12. Extractive
systems with driuent
monitors.
»166 hours.
»16* hour*.
« 5 pet of each mid-level and high-
level catoration value.
C IS mnutes (5 minutes tor 3-poinl
traversing probe arrangement).
a* 2 pel of span value.
< 2 pel of span value.
« 2 pet of span value.
« 2.5 pet of span value,
< 20 pet of the mean value ol
reference meihod(s) test data in
terms of errassion standard or 10
percent of the applicable
standard, whichever a greater.
Must provide a check ol an analyzer
niemal nwrors and lenses and aH
electronic orcmtry including the
radiation source and detector
assembly which are normally use
in sampling and analysis
Chart scales must be readable to
withm CO SO pel of lull-scale
Must usejhe same sample interface
lo sample both the pollutant and
rWuent gases. Place n series
(drfuent after pollutant analyzer) or
use a "T.~* During the
conditioning and operational lest
periods, the continuous monitoring
system sha> not require any
corrective maintenance, repair.
replacement or adjustment other
than rhal clearly specified as
routine and reputed m the
operation and maintenance
manuals. ' Expressed as the sum
of the absolute mean value plus
the 95 percent conhdence interval
of a senes of tests dmded by a
relerence value • A tow-level (5-
15 percent of span value) drill test
may be substituted lor the zero
Drift tests.
5.2.2 Mid-Level Gas. A gas
concentration that is equivalent to 45 to
55 percent of the span value.
5.2.3 Zero Gas. A gas concentration
of less than 0.25 percent of the span
value. Ambient air may be used for the
zero gas.
5.3 Calibration Gas Cells or Filters.
For continuous monitoring systems
which use calibration gas cells or filters
use three certified calibration gas cells
or filters as specified below:
5.3.1 High-Level Gas Cell or Filter.
One that produces an output equivalent
to 80 to 90 percent of the span value.
5.3.2 Mid-Level Gas Cell or Filter.
One that produces an output equivalent
to 45 to 55 percent of the span value.
5.3.3 Zero Gas Cell or Filter. One
that produces an output equivalent to
zero. Alternatively, an analyzer may
produce a zero value check by
mechanical means, such as a movable
mirror.
5.4 Calibration Gas—Gas Cell or
Filter Combination. Combinations of thi
above may be used.
6. Performance Specification Test
Procedures.
6.1 Pretest Preparation.
6.1.1 Calibration Gas Certification.
The tester may select one of the
following alternatives: (a) The tester
may use calibration gases prepared
according to the protocol defined in
Citation 10.5. i.e. These gases may be
used as received without reference
method analysis (obtain a statement
from the gas cylinder supplier certifyin
that the calibration gases have been
prepared according to the protocol): or
(b) the tester may use calibration gases
not prepared according to the protocol.
In case (b), he must perform triplicate
analyses of each calibration gas (mid-
level and high-level, only) within 2
weeks prior to the operational test
period using the appropriate reference
methods. Acceptable procedures are
described in Citations 10.6 and 10.7.
Record the results on a data sheet
(example is shown in Figure 2-3). Each
of the individual analytical results mus
be within 10 percent (or 15 ppm,
whichever is greater) of the average;
otherwise, discard the entire set and
repeat the triplicate analyses. If the
avarap. of the triplicate reference
method test results is within 5 percent i
the calibration gas manufacturer's tag
value, use the tag value; otherwise,
conduct at least 3 additional reference
method test analyses until the results c
6 individual runs (the 3 original plus 3
additional) agree within 10 percent or'
ppm. whichever is greater, of the
average. Then use this average for the
cylinder value.
11-116
-------
Figure 2-3. Analysis of Calibration Gases'
Date (Must be within 2 weeks prior to the
operational test period)
Reference Method Used
Sample Run
1
2
3
Werage
Maximum % Deviation
Mid-level5
ppm
High-level0
ppm
Not necessary if the protocol in Citation 10.5 is used
to prepare the gas cylinders.
Average must be 45 to 55 percent of span value.
Average must be 80 to 90 percent of span value.
Must be < + 10 percent of applicable average or 15 ppm,
whichever Ts greater.
6.1.2 Calibration Gas Cell or Filter
Certification. Obtain (a) a statement
from the manufacturer certifying that the
calibration gas cells or filters (zero, mid-
level, and high-level) will produce the
stated instrument responses for the
continuous monitoring system, and (b) a
description of the test procedure and
equipment used to calibrate the cells or
filters. At a minimum, the manufacturer
must have calibrated the gas cells or
fillers against a simulated source of
known concentration.
6.2 Conditioning Period. Prepare the
monitoring system for operation
according to the manufacturer's written
instructions. At the outset of the
conditioning period, zero and span the
system. Use the mid-level calibration
gas (or gas cell or filter) to set the span
at 50 percent of recorder full-scale. If
necessary to determine negative zero
drift, offset the scale by 10 percent. (Do
not forget to account for this when using
the calibration curve.) If a zero offset is
not possible or is impractical, a low-
level drift may be substituted for the
zero drift by using a low-level {5 to 15
percent of span value) calibration gas
(or gas cell or filter). This low-level
calibration gas (or gas cell or filter) need
not be certified. Operate the continuous
monitoring system for an initial 168-hour
period in the manner specified by the
manufacturer. Except during times of
instrument zero, calibration checks, and
system backpurges. the continuous
monitoring system shall collect and
condition the effluent gas sample (if
applicable), analyze the sample for the
appropriate gas constituents, and
produce a permanent record of the
system output Conduct daily zero and
mid-level calibration checks and, when
drift exceeds the daily operating limits.
make adjustments. The data recorder
shall reflect these checks and
adjustments. Keep a record of any
instrument failure during this time. If the
conditioning period is interrupted
because of source breakdown (record
the dates and times of process
shutdown), continue the 168-hour period
following resumption of source
operation. If the conditioning period is
interrupted because of monitor failure,
restart the 168-hour conditioning period
when the monitor becomes functional.
6.3 Operational Test Period. Operate
the continuous monitoring system for an
additional 168-hour period. The
continuous monitoring system shall
monitor the effluent, except during
periods when the system calibration and
response time are checked or during
system backpurges; however, the system
shall produce a permanent record of all
operations. Record any system failure
during this time on the data recorder
output sheet.
It is not necessary that the 168-hour
operational test period immediately
follow the 168-hour conditioning period.
During the operational test period,
perform the following test procedures:
6.3.1 Calibration Error
Determination. Make a total of 15
nonconsecutive zero, mid-level, and
high-level measurements (e.g., zero, mid-
level, zero, high-level, mid-range, etc.).
11-117
-------
This will result in a set of 5 each of zero,
mid-level, and high-level measurements.
Convert the data output to concentration
units, if necessary, and record the
results on a data sheet (example is
shown in Figure 2-4). Calculate the
differences between the reference
calibration gas concentrations and the
measure-men! system reading. Then
calculate the mean, confidence interval,
and calibration errors separately for the
mid-level and high-level concentrations
using Equations 2-1. 2-2, and 2-3. In
Equation 2-3, use each respective
calibration gas concentration for R.V.
11-118
-------
Figure 2-4. Calibration Error Determination
Run
no.
1
2
3
4 j
5
6
7
8
9
10
11
12
13
14
15
Calibration gas
concentration3
ppm
A
Measurement system
reading
ppm
B
Arithmetic Mean (Eq. 2-1) «
Confidence Interval (Eq. 2-2) =
Calibration Error (Eq. 2-3)b «
Arithmetic 1
differences
PPm
A-B
Mid 1 High
I
— J
i
1 1
j I
1
a Calibration Data from Section 6.1.1 or 6.1.2
Mid-level: C = ppm
High-level: D = ppm
b Use C or D as R.V. 1n Eq. 2-3
Date
Figure 2-5. Response Time
High-level
_ppm
Test Run
1
2
3
Average
Upscale
min.
A *
Down scale
min.
B =
System Response Time (slower of A and B)
min.
11-119
-------
6.3.2 Response Time Test Procedure.
At a minimum, each response time test
shall provide a check of the entire
sample transport line (if applicable), any
sample conditioning equipment (if
applicable), the pollutant analyzer, and
the data recorder. For in-situ systems.
perform the response time check by
introducing the calibration gases at the
sample interface (if applicable), or by
introducing the calibration gas cells or
filters at an appropriate location in the
pollutant analyzer. For extractive
monitors, introduce the calibration gas
at the sample probe inlet in the stack or
at the point of connection between the
rigid sample probe and the sample
transport line. If an extractive analyzer
is used to monitor the effluent from more
than one source, perform the response
time test for each sample interface.
To begin the response time test.
introduce zero gas (or zero cell or filter)
into the continuous monitor. When the
system output has stabilized, switch to
monitor the stack effluent and wait until
a "stable value" has been reached.
Record the upscale response time. Then.
introduce the high-level calibration gas
(or gas cell or filter). Once the system
has stabilized at the high-level
concentration, switch to monitor the
stack effluent and wait until a "stable
value" is reached. Record the downscale
response time. A "stable value" is
equivalent to a change of less than 1
percent of span value for 30 seconds or 5
percent of measured average
concentration for 2 minutes. Repeat the
entire procedure three times. Record the
results of each test on a data sheet
(example is shown in Figure 2-5).
Determine the means of the upscale and
downscale response times using
Equation 2-1. Report the slower time as
the system response time.
6.3.3 Field Test for Zero Drift and
Calibration Drift. Perform the zero and
calibration drift tests for each pollutant
analyzer and data recorder in the
continuous monitoring system.
6.3.3.1 Two-hour Drift. Introduce
consecutively zero gas (or zero cell or
filler) and high-level calibration gas (or
gas cell or filter) at 2-hour intervals until
15 sets (Before and after) of data are
obtained. Do not make any zero or
calibration adjustments during this time
unless otherwise prescribed by the
manufacturer. Determine and record the
amount that the output had drifted from
th-, recorder zero and high-level value
on a data sheet (example is shown in
Figure 2-6). The 2-hour periods over
which the measurements are conducted
;:• r-d not b' consecutive, but must not
o -irlap. Calculate the zero and
calibration drifts for each set. Then
calculate the mean, confidence interval,
and zero and calibration drifts (2-hour)
using Equations 2-1. 2-2. and 2-3. In
Equation 2-3. use the span value for R.V.
6.3-3.2 Twenty-Four Hour Drift. In
addition to the 2-hour drift tests, perform
a series of seven 24-hour drift tests as
follows: At the beginning of each 24-
hour period, calibrate the monitor, using
mid-level value. Then introduce the
high-level calibration gas (or gas cell or
filter) to obtain the initial reference
value. At the end of the 24-hour period.
introduce consecutively zero gas (or gas
cell or filter) and high-level calibration
gas (or gas cell or filter); do not make
any adjustments at this time. Determine
and record the amount of drift from the
recorder zero and high-level value on a
data sheet (example is shown in Figure
2-7). Calculate the zero and cab'bration
drifts for each set. Then calculate the
mean, confidence interval, and zero and
calibration drifts (24-hour) using
Equations 2-1. 2-2, and 2-3. In Equation
2-3, use the span value for R.V.
11-120
-------
Date
set
no.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
Date
Time
Begin
End
Zero Rdg
In1t. F1n.
A
B
Arithmetic Mean (EQ. 2-1)
Confidence Interval (Eq. 2-2)
Zero Drift3
Zero
drift
C-B-A
H1 -level
Rdq
nit.
D
Ca
:in.
L
Span
drift
F-E-D
Hbratlon.
dr1fta
Callb.
drift
G*F-C
Data
set
no.
1
2
3
4
5
6
7
Date
T1m
Begin
End
Zero
Ink.
A
Rdq
FMn.
B
Arithmetic Mean (Eq. 2-1)
Confidence Interval (Eq. 2-2)
Zero drift
Zero
drift
C-B-A
H1-level
Rdg
In1t. F1n.
D
E
Span
drift
F=E-D
Calibration
H*-1fta
Callb.
drift
G=F-C
Use Equation 2-3. with the span value for R. V.
Figure 2-7. Zero and Calibration Drift (24-hour)
Use Equation 2-3, with span value for R. V.
Figure 2-6. Zero and Calibration Drift (2 hour)
-------
Note.—Automatic zero and calibration
adjustments made by the monitoring system
without operator intervention or initiation are
allowable at any time. Manual adjustments.
however, are allowable only at 24-hour
intervals, unless a shorter time is specified by
the manufacturer.
6.4 System Relative Accuracy.
Unless otherwise specified in an
applicable subpart of the regulations.
the reference methods for SO,, NO,,
diluent (O, or CO,), and moisture are
Reference Methods 6, 7, 3, and 4,
respectively. Moisture may be
determined along with SO, using
Method 6. See Citation 10.8. Reference
Method 4 is necessary only if moisture
content is needed to enable comparison
between the Reference Method and
monitor values. Perform the accuracy
test using the following guidelines:
6.4.1 Location of Pollutant Reference
Method Sample Points. The following
specifies the location of the Reference
Method sample points which are on the
same cross-sectional plane as the
monitor's. However, any cross-sectional
plane within 2 equivalent diameter of
straight runs may be used, by using the
projected image of the monitor on the
selected plane in the following criteria.
6.4.1-1 For point monitors, locate the
Reference Method sample point no
further than 30 cm (or 5 percent of the
equivalent diameter of the cross section,
whichever is less) from the pollutant
monitor sample point.
6.4.1.2 For multipoint monitors,
locate each Reference Method sample
traverse point no further than 30 cm (or
5 percent of the equivalent diameter of
the cross section, whichever is less)
from each corresponding pollutant
monitor sample point.
6.4.1.3 For limited-path and path
monitors, locate 3 sample points on a
line parallel to the monitor path and no
further than 30 cm (or 5 percent of the
equivalent diameter of the cross section.
whichever is less) from the centerline of
the monitor path. The three points of the
Reference Method shall correspond to
points in the monitor path at 16.7, 50.0,
and 83.3 percent of the effective length
of the monitor path.
6.4.2 Location of Diluent and
Moisture Reference Method Sample
Points.
6.4.2.1 For sources which require
diluent monitors in addition to pollutant
monitors, locate each of the sample
points for the diluent Reference Method
measurements within 3 cm of the
corresponding pollutant Reference
Method sample point as defined in
Sections 6.4.1.1, 6.4.1.2, or 6.4.1.3. In
addition. locate each pair of diluent and
pollutant Reference Method sample
points no further than 30 cm (or 5
percent of the equivalent diameter of the
cross section, whichever is less) from
both the diluent and pollutant
continuous monitor sample points or
paths.
6.4.2.2 If it is necessary to convert
pollutant and/or diluent monitor
concentrations to a dry basis for
comparison with the Reference data,
locate each moisture Reference Method
sample point within 3 cm of the
corresponding pollutant or diluent
Reference Method sample point as
defined in Sections 6.4.1.1. 6.4.1.2, 6.4.1.3.
or 6.4.2.1.
6.4.3 Number of Reference Method
Tests.
6-4-3.1 For NO, monitors, make a
minimum of 27 NO, Reference Method
measurements, divided into 9 sets.
6.'4.3.2 For SO, monitors, make a
minimum of 9 SO, Reference Method
tests.
6.4.3.3 For diluerjt monitors, perform
one diluent Reference Method test for
each SO, and/or NO, Reference Method
test(s).
6.4.3.4 For moisture determinations.
perform one moisture Reference Method
test for each or each set of pollutant(s)
and diluent (if applicable) Reference
Method tests.
Note.—The tester may choose to perform
more than 9 sets of NO, measurements or
more than 9 SOi reference method diluent, or
moisture tests. If this option is chosen, the
tester may, at his discretion, reject up to 3 of
the set or test results, so long as the total
number of set or test result* used to
determine the relative accuracy is greater
than or equal to 9. Report all data including
rejected data.
6.4.4 Sampling Strategy for
Reference Method Tests. Schedule the
Reference Method tests so that they will
not be in progress when zero drift,
calibration drift, and response time data
are being taken. Within any 1-hour
period, conduct the following tests: (a)
one set, consisting of 3 individual
measurements, of NO, and/or one SO,;
(b) one diluent, if applicable: and (c) one
moisture (if needed). Whenever two or
more reference tests (pollutant, diluent,
and moisture) are conducted, the tester
may choose to run all these reference
tests within a 1-hour period. However, it
is recommended that the tests be run
concurrently or consecutively within a
4-minute interval if two reference tests
employ grab sampling techniques. Also
whenever an integrated reference test is
run together with grab sample reference
tests, it is recommended that the
integrated sample be started one-sixth
the test period before the first grab
sample is collected.
In order to properly correlate the
continuous monitoring system and
Reference Method data, mark the
beginning and end of each Reference
Method test period (including the exact
time of day) on the pollutant and diluent
(if applicable) chart recordings. Use one
of the following strategies for the
Reference Method tests:
6.4.4.1 Single Point Monitors. For
single point sampling, the tester may: {a
take a 21-minute integrated sample (e.g.
Method 6. Method 4, or the integrated
bag sample technique of Method 3); lb)
take 3 grab samples (e.g. Method 7 or
the grab sample technique of Method 3),
equally spaced at 7-minute (±2 min)
intervals (or one-third the test period);
or (c) take 3 grab samples over a 3-
minute test period.
. 6.4.4.2 Multipoint or Path Monitors.
For multipoint sampling, the tester may
either (a) make a 21-minute integrated
sample traverse, sampling for 7 minutes
(±2 min) (or one-third the test period) a
each point: or (b) take grab samples at
each traverse point, scheduling the grab
samples to that they are an equal
interval (7±2 minutes) of time apart (or
one-third the test period).
Note.—If the number of sample points is
greater than 3. make appropriate adjustment
to the individual sampling time intervals. At
time* NSPS performance test data may be
used as part of the data base of the
continuous monitoring relative accuracy
tests. In these cases, other test periods as
specified in the applicable subparts of the
regulations may be used.
6.4.5 Correlation of Reference
Method and Continuous Monitoring
System Data. Correlate the continuous
monitoring system data with the
Reference Method test data, as to the
time and duration of the Reference
Method tests. To accomplish this, first
determine from the continuous
monitoring system chart recordings, the
integrated average pollutant and diluer
(if applicable) concentration(s) for eacV
Reference Method test period. Be sure
consider system response time. Then,
compare each integrated average
concentration against the correspondin
average concentration obtained by the
Reference Method; use the following
guidelines to make these comparisons:
6.4.5.1 If the Reference Method is ai
integrated sampling technique (e.g..
Method 6). make a direct comparison o
the Reference Method results and the
continuous monitoring system integral
average concentration.
6.4.5.2 If the Reference Method is a
grab-sampling technique (e.g.. Method
7), first average the results from all gra
samples taken during the test period,
and then compare this average value
against the integrated value obtained
from the continuous monitoring system
chart recording.
TI-122
-------
6.5 Data Summary for Relative
Accuracy Tests. Summarize the results
on a data sheet: example is shown in
figure 2-8. Calculate the arithmetic
differences between the reference
method and the continuous monitoring
output sets. Then calculate the mean.
confidence interval, and system relative
accuracy, using Equation 2-1. 2-2. and
2-3. In Equation 2-3, use the average of
the reference method test results for
R.V.
7. Equations
7.1 Arithmetic Mean. Calculate the
mean of a data set as follows:
£ I x. Equation 1-2
" 1-1 '
Where:
x = arithmetic mean.
n = number of data points.
Ix, = algebraic sum of the individual
values. X|.
When the mean of the differences of
pairs of data is calculated, be sure to
correct the data for moisture.
7.2 Confidence Interval. Calculate
the 95 percent confidence interval (two-
sided) as follows:
l.-c • - v/nlx,2 - (Ix.)2 Equation 1-3-
95 V f '
Where:
C.I.M = 95 percent confidence interval
estimate of mean value.
t..rs = ti,-./D (see Table 2-2)
BILLING CODE 856O-01-M
Table 2-2.—I ~ Values
if '.975 n" '.975 if '.975
2
3
4
5
6
12706
4303
3182
2.776
2571
7
•
•
10
11
2447
2365
23O6
2262
2228
12
13
14
IS
16
2.201
2179
2 16O
2145
2.131
• The values n INj tabto •>• already corrected tor r>-1 de-
gree* of freedom. Uu
-------
I
1N3
Run
no.
1
2
3
4
5
6
7
8
9
10
n
12
Date and
time
Average
S0?
RM
i
M IrHff
PPma
Confidence Interval
Accuracyc
N0xb
RM
M . Iniff
ppm°
C02 or 02a
RM, I M,
%d %d'
so2a
RM 1
M fcUff
mass/GCV
1
NO/
.RM .
M
niff
mass/GCV
a For steam generators Average of 3 samples c Use average of reference method test results for R.V.
Make sure that RM and M data are on a consistent basis, either wet or dry
Figure 2-8. Relative accuracy determination
-------
7.3 Relative Accuracy. Calculate the relative accuracy of a set of data as
follows:
R.A.
x 100 Equation 2-3
Where: R. A.
1*1
|c.i-95l
R.V.
* relative accuracy
- absolute value of the arithmetic mean
(from Equation 2-1).
« absolute value of the 95 percent confi-
dence Interval (from Equation 2-2).
* reference value, as defined in Sections
6.3.1, 6.3.3.1, 6.3.3.2, and 6.5.
8. Reporting
At a minimum [check with regional
offices for additional requirements, if
any) summarize the following results in
tabular form: calibration error for mid-
level and high-level concentrations, the
slower of the upscale and downscale
response times, the 2-hour and 24-hour
zero and calibration drifts, and the
system relative accuracy. In addition,
provide, for the conditioning and
operational test periods, a statement to
the effect that the continuous monitoring
system operated continuously for a
minimum of 168 hours each, except
during times of instrument zero,
calibration checks, system backpurges.
and source breakdown, and that no
corrective maintenance, repair,
replacement, or adjustment other than
that clearly specified as routine and
required in the operation and
maintenance manuals were made. Also
include the manufacturer's certification
statement (if applicable) for the
calibration gas, gas cells, or filters.
Include all data sheets and calculations
and charts (data outputs), which are
necessary to substantiate that the
system met the performance
specifications.
9 Retest
If the continuous monitoring system
operates within the specified
performance parameters of Table 2-1,
the operational test period will be
successfully concluded. If the
continuous monitoring system fails to
meet any of the specifications, repeat
that portion cf the testing which is
related to the failed specification.
10. Bibliography
10.1 "Monitoring Instrumentation for
the Measurement of Sulfur Dioxide in
Stationary Source Emissions,"
Environmental Protection Agency,
Research Triangle Park. N.C., February
1973.
10.2 "Instrumentation for the
Determination of Nitrogen Oxides
Content of Stationary Source
Emissions," Environmental Protection
Agency, Research Triangle Park, N.C.,
Volume 1, APTD-0847, October 1971;
Volume 2. APTD-0942, January 1972.
10.3 "Experimental Statistics,"
Department of Commerce, Handbook 91,
1963, pp. 3-31. paragraphs 3-3.1.4.
10.4 "Performance Specifications for
Stationary-Source Monitoring Systems
for Gases and Visible Emissions,"
Environmental Protection Agency,
Research Triangle Park, N.C., EPA-650/
2-74-013. January 1974.
10.5 Traceability Protocol for
Establishing True Concentrations of
Cases Used for Calibration and Audits
of Continuous Source Emission Monitors
(Protocol No. 1). June 15,1978.
Environmental Monitoring and Support
Laboratory, Office of Research and
Development, U.S. EPA, Research
Triangle Park. N.C. 27711.
10.6 Westlin. P. R. and J. W. Brown.
Methods for Collecting and Analyzing
Gas Cylinder Samples. Emission
Measurement Branch, Emission
Standards and Engineering Division,
Office of Air Quality Planning and
Standards. U.S. EPA. Research Triangle
Park. N.C., July 1978.
10.7 Curtis, Foston. A Method for
Analyzing NOX Cylinder Gases—
Specific Ion Electrode Procedure.
Emission Measurement Branch.
Emission Standards and Engineering
Division. Office of Air Quality and
Standards. U.S. EPA. Research Triangle
Park. N.C.. October 1978.
10.8 Stanley. Jon and P. R. Westlin.
An Alternative Method for Stack Gas
Moisture Determination. Emission
Measurement Branch. Emission
Standards and Engineering Division,
Office of Air Quality Planning and
Standards. U.S. EPA, Research Triangle
Park. N.C.. August 1978.
Performance Specification 3—
Specifications and Test Procedures for
CO, and Oj Continuous Monitors in
Stationary Sources
1. Applicability and Principle
1.1 Applicability. This Specification
contains (a) installation requirements,
(b) instrument performance and
equipment specifications, and (c) test
procedures and data reduction
procedures for evaluating the
acceptability of continuous CO7 and Oi
monitors that are used as diluent
monitors. The test procedures are
primarily designed for systems that
introduce calibration gases directly into
the analyzer other types of monitors
(e.g., single-pass monitors, as described
in Section 2.2.7 of Performance
Specification 2 of this Appendix) will be
evaluated on a case-by-case basis upon
written request to the Administrator,
and alternative procedures will be
issued separately.
1.2 Principle. Any CO, or O,
continuous monitor, which is expected
to meet this Specification, is operated
for a specified length of time. During this
specified time period, the continuous
monitor is evaluated to determine
conformance with the Specification.
2. Definitions
The definitions are" the same as those
listed in Section 2 of Performance
Specification 2.
3. Installation Specifications
3.1 Measurement Location and
Measurement Points or Paths. Select and
install the continuous monitor at the
same sampling location used for the
pollutant monitor(s). Locate the
measurement points or paths as shown
in Figure 3-1 or 3-2.
3.2 Alternative Measurement
Location and Measurement Points or
Paths. The diluent monitor may be
11-125
-------
installed at a different location from that
of the pollutant monitor, provided that
the diluent gas concentrations at both
locations differ by no more than 5
percent from that of the pollutant
monitor location for COi or the quantity,
20.9-percent O.. for O». See Section 3.4
of Performance Specification 2 for the
demonstration procedure.
4. Continuous Monitor Performance and
Equipment Specifications
The continuous monitor performance
and equipment specifications are listed
in Table 3-1. To be considered
acceptable, the continuous monitor must
demonstrate compliance with these
specifications, using the test procedures
in Section 6.
5. Apparatus
5.1 CO» or Oi Continuous Monitor.
Use any continuous monitor, which is
expected to meet this Specification. The
data recorder may either be an analog
strip-chart recorder or other suitable
device having an input voltage range
compatible with the analyzer output.
5.2 Calibration Gases. Diluent gases
shall be air or N» for CO, mixtures, and
shall be Ni for O. mixtures. Use three
calibration gases as specified below:
11-126
-------
GEOMETRICALLY
SIMILAR
AREA
( 1%OF STACK
CROSS-SECTION)
(a)
GEOMETRICALLY
SIMILAR
AREA
(<;1%OF STACK
CROSS-SECTION)
Figure 3-1. Relative locations of pollutant (P) and diluent (D) measurement points in (a) circular
and (b) rectangular ducts. P is located at the centroid of the geometrically similar
area. Note: The geometrically similar area need not be concentric.
11-127
-------
GEOMETRICALLY
SIMILAR
AREAS
( <1% OF STACK
CROSS-SECTION)
GEOMETRICALLY
SIMILAR
AREAS
( <1% OF STACK
CROSS-SECTION)
PARALLEL
MEASUREMENT
LINES
(a)
PARALLEL
MEASUREMENT
LINES
(b)
F.oure 3-2 Relative locat.ons of pollutant (P) and diluent (D) measurement paths for (a) c.rcular
* and b) rectangular ducts. P is located at the centroid of both the Qeometr.cal.y .,m.-
lar areas and the pollutant monitor path cross sectional areas. D is located at the cen-
troid of the diluent monitor path cross sectional area.
11-128
-------
Table 3-1.—Performance and Equipment
Specifications
Parameter Speofccahon
1. Condrwnng > 168 hours.
penod*.
2 Operational test > 160 hour*.
3. Cakbrabon error •_ < 5 pet ol each |rrad-range and
high-canoe, only) cafcbrabon gas
value.
4. FUpontetme «; 15 mnute*.
E Zerodntl'2- < 04 pet CO. or O,
hour)"-'.
6. Zero drift (24- < 10-S pd CO, Of
-------
Date
Figure 3-3. Analysis of Calibration Gases'
(Must be within 2 weeks prior to the opera-
tional test period)
Reference Method Used_
Sample run
Average
Maximum %
deviation
Mid-range
ppm
High-range
ppm
a Not necessary if the protocol in Citation 10.5 of Perfor-
mance Specification 2 is used to prepare the gas cylinders.
c Average must be 11.0 to 14.0 percent; for 02, see Section
5.2.2.
d Average must be 20.0 to 22.5 percent; for 02, see Section
5.2.1.
e Must be i + 10 percent of applicable average or 0.5 percent,
whichever Ts greater.
11-130
-------
Figure 3-4. Calibration Error Determination
Run
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
\5
Calibration Gas
Concentration3
ppm
A
Measurement System
Reading
ppm
B
Arithmetic Mean (Eq. 2-1 )b =
Confidence Interval (Eq. 2-2)b =
Calibration Error (Eq. 2-3)b'C =
Arithmetic
Differences
ppm
A-B
Mid
High
Calibration Data from Section 6.1
Mid-level: C = ppm
High-level: D = ppm
5 See Performance Specification 2
: Use C or D as R. V.
11-131
-------
Figure 3-5. Response Time
Date
High-Range =
ppm
Downscale
min
System Response Time (slower of A and B) =
mm.
11-132
-------
Data
set
no
Date
Time
Begin
End
Zero Rd.
Init.
A
Fin.
B
Arithmetic Mean (Eq. 2-l)a
Confidence Interval (Eq. 2-2)a
Zero drift
Zero
drift
C=B-A
Hi-Range
Rdq.
Init.
D
Fin.
E
Span
drift
F=E-D
Calibration drift
Calib.
drift
G=F-C
t
From Performance Specification 2.
Use Equation 2-3 of Perfonnance Specification 2 and 1.0 for R. V.
Figure 3-6. Zero and Calibration Drift (2 hour)
11-133
-------
Calibration drift
Arithmetic Mean (Eq. 2-1)
Confidence Interval (Eq. 2-2)
Zero drift
a From Performance Specification 2.
Use Equation 2-3 of Performance Specification 2, with 1.0 for R. V.
Figure 3-7. Zero and Calibration Drift (24-hour)
11-134
-------
6.4 System Relative Accuracy. (Note:
The relative accuracy is not determined
separately for the diluent monitor, bat is
determined for the pollutant-diluent
system.) Unless otherwise specified in
an applicable subpart of the regulations,
the Reference Methods for the diluent
concentration determination shall be
Reference Method 3 for CO, or O>. For
this test. Fyrite analyses may be used
for COt and O, determinations. Perform
the measurements using the guidelines
below (an example data sheet is shown
in Figure 2-S of Performance
Specification 2):
6.4.1 Location of Reference Method 3
Sampling Points. Locate the diluent
Reference Method sampling points
according to the guidelines given in
Section 6.4.2.1 of Performance
Specification 2.
6.4.2 Number of Reference Method
Tests. Perform one Reference Method 3
test according to the guideline in
Performance Specification 2.
6.4.3 Sampling Strategy for
Reference Method Tests. Use the basic
Reference Method sampling strategy
outlined in Section 6.4.4 (and related
sub-sections) of Performance
Specification 2.
6.4.4 Correlation of Reference
Method and Continuous Monitor Data.
Use the guidelines given in Section 6.4.5
of Performance Specification 2.
7. Equations. Reporting. Retest, and
Bibliography. The procedure and
citations are the same as in Sections 7
through 10 of Performance Specification
2.
|FR Doc. 79-31033 Filed 10-0-7* 645 am)
11-135
-------
ENVIRONMENTAL PROTECTION
AGENCY
40CFR Part 60
[AD-FRL 1625-7]
Standards of Performance for New
Stationary Sources; Proposed
Revisions to General Provisions and
Additions to Appendix A, and
Reproposal of Revisions to Appendix
B
AGENCY: Environmental Protection
Agency (EPA).
ACTION: Proposed Rule and Notice of
Public Hearing. ^__
SUMMARY: This proposed rule (1) revises
the monitoring requirements (§ 60.13) of
the General Provisions. (2) adds
Methods 6A and 6B to Appendix A, and
(3) reproposes revisions to Performance
Specifications 2 and 3 to Appendix B of
40 CFR Part 60. The proposed revisions
to § 60.13 are being made to make this
section consistent with the proposed
revisions to Appendix B. Methods 6A
and 6B are being proposed because they
simplify the determination of the SO,
emission rates in terms of ng/J.
Performance Specifications 2 and 3
revisions are being reproposed because
the changes that have been made to the
performance specifications as a result of
comments received on the original
proposal of October 10.1979 (44 FR
58602) are substantial and involve an
entirely new concept.
DATES: Comments. Comments must be
received on or before March 27,1981.
Public Hearing. A public hearing will
be held on February 19.1981 beginning
at 9 a.m.
Request to Speak at Hearings.
Persons wishing to present oral
testimony must contact EPA by
February 12.1981 (1 week before
hearing).
ADDRESSES: Comments. Comments
should be submitted (in duplicate if
possible) to: Central Docket Section (A-
130). Attention: Docket Number
OAQPS-79-4. U.S. Environmental
Protection Agency. 401 M Street, SW..
Washington. D.C. 20460.
Public Hearing. The public hearing
will be held at Emission Measurement
Labatory, R.T.P. North Carolina. Persons
wishing to present oral testimony should
notify Ms. Vivian Phares, Emission
Measurement Branch (MD-13), U.S.
Environmental Protection Agency.
Research Triangle Park. North Carolina
27711 telephone number (919) 541-5423.
Docket. Docket Number OAQPS-79-4
(Performance Specifications 2 and 3)
and Docket Number A-SO-30 (Methods
6A and 6B). containing supporting
information used in developing the
proposed rulemaking are located in the
U.S. Enviromental Protection Agency,
Central Docket Section. West Tower
Lobby. Gallery 1, Waterside Mall, 401 M
Street. S.W.. Washington. D.C. 20460.
The docket may be inspected between 8
a.m. and 4 p.m. on weekdays, and a
reasonable fee may be charged for
copying.
FOR FURTHER INFORMATION CONTACT:
Mr. Roger T. Shigehara (MD-19). U.S.
Environmental Protection Agency,
Research Triangle Park. North Carolina
27711. telephone number (919) 541-2237.
SUPPLEMENTARY INFORMATION: The
discussion in this section has been
divided into three separate parts. Part A
discusses proposed changes to the
General Provisions of 40 CFR Part 60.
Part B discusses the addition of
proposed Methods 6A and 6B to
Appendix A. and Part C discusses
reproposal of revisions to Performance
Specifications 2 and 3 to Appendix B.
Part A
The proposed revisions to § 60.13 of
the General Provisions are being made
to make this section consistent with the
proposed revisions to Appendix B. Since
the reproposal to Appendix B uses the
concept of evaluating the continuous
emission monitors as a system, based on
relative accuracy test results, the use of
certified cylinder gases, optical filters, or
gas cells is not necessary. The
requirement for quantification of the
zero and span drifts is not a change, but
a clarification of what is required under
the existing performance specifications.
Part B
Two reference methods (Methods 6A
and 6B) are proposed. Method 6A.
"Determination of Sulfur Dioxide.
Moisture, and Carbon Dioxide
Emissions from Fossil Fuel Combustion
Sources." combines the sampling and
analysis of SOt and CO,. The SO, is
collected in a hydrogen peroxide
solution and analyzed by the barium-
thorin titration procedure described in
Method 6. The CO, is collected by a
solid absorbent and analyzed
gravimetrically. The sample gas volume
is measured to allow determination of
SO, concentration. CO, concentration
moisture, and emission rate from
combustion sources in ng/J. If the only
measurement needed is in terms of
emission rate or if the CO, and moisture
concentrations are not needed, e.g., to
convert NOE concentration to ng/J, the
volume meter is not required- It is
intended that Method 6A be.used as an
alternative to Methods 6 and 3 for the
purpose of determining SO, emission
rates in ng/J.
Method 6B. "Determination of Sullu
Dioxide and Carbon Dioxide Daily
Average Emissions from Fossil Fuel
Combustion Sources." employs the sa
sampling train and analysis procedur
as Method 6A, but the operation of th
train is controlled on an intermittent
basis by a timer or on a continuous
basis by using a low, constant flow-n
pump. This allows an extended
sampling time period and the
determination of an average value foi
that time period of SO, concentration
CO, concentration, and emission rate
from combustion sources in ng/J.
Method 6B is proposed as an accepta
proce'dure for compliance with § 60.41
(f) of 40 CFR Part 60. Subpart Da. This
paragraph (f) requires that in the ever
of GEMS breakdown, emission data v
be obtained by using other monitorin
systems or reference methods approv
by ihe Administrator.
PartC
Revisions to Performance
Specifications 2 and 3 for the initial
evaluation of continuous emission
monitoring systems (GEMS) for SO,.
NO., and diluent gases were propose
on October 10.1979 (44 FR 58602).
Comments received as a result of this
proposal led to reevaluation of the
provisions and a change in the overa
approach to the performance
specifications. The reproposed
performance specifications deempha:
instrument equipment specifications
add emphasis to the evaluation of th(
GEMS and its location as a system. T
specification requirements are limitei
calibration drift tests and relative
accuracy tests. The acceptability lim
for relative.accuracy remain the sam
in the previously proposed revisions
the performance specifications.
CEMS guidelines will also be
published in a separate document at
time of proposal to provide vendors,
purchasers, and operators of CEMS v
supplementary equipment and
performance specifications. The -
guidelines will contain additional
procedures and specifications that m
provide further evaluation of the CEf
beyond that required by Performanci
Specifications 2 and 3. e.g.. response
time. 2-hour zero and calibration dri
sampling locations, and calibration
value analyses.
Applicability
The proposed revisions would app
to all CEMS currently subject to
Performance Specifications 2 and 3.
These include sources subject to
standards of performance that have
11-136
-------
already been promulgated and sources
subject to Appendix P to 40 CFR Part 51.
Since the requirements of the
reproposed performance specification
revisions are limited to daily calibration
drift tests and relative accuracy tests.
existing CEMS that met the
specifications of the current
Performance Specifications 2 and 3 also
meet the requirements of these revised
specifications and. therefore, do not
require retesting.
This reproposal has retained the
definition of a "continuous emission
monitoring system" and includes the
diluent monitor, if applicable. This
definition requires the relative accuracy
of the CEMS to be determined in terms
of the emission standard, e.g- mass per
unit calorific value for fossil fuel-fired
steam generators. Several commenters
felt that the limits of relative accuracy
should be relaxed from the present 20
percent because of the addition of the
diluent analyzer output Others added
that errors with the manual reference
methods could increase the possibility
of poor relative accuracy determinations
now that an additional measurement is
required. The Administrator has
reviewed a number of relative accuracy
tests and has concluded that the
variations in the manual reference
method determinations are not the
major cause of failure, but that the
difference between the mean of the
reference method and the CEMS values
is the most probable cause. This
situation is correctable.
Comments on Proposal
Numerous commenters noted that the
jroposed revisions go far beyond
clarification and considered them as
significant changes. A large part of this
concern WES because they felt that
many existing CEMS were not installed
according to the proposed installation
specifications. In addition, many
;ommenters felt the need for greater
lexibility in selecting alternative CEMS
•ncasurement locations. Several
:ommen'f rs desired the inclusion of test
procedures to evaluate single-pass, in
;ilu CEMS. Others objected to the length
md cost of testing. Opposing views
vere presented on the need for
itratification checks. Many commenters
call with specific parts of the proposal
ind a few raised issues beyond the
cope of the revisions! Because the
Administrator has changed the overall
pproach to performance specifications
s mentioned in the beginning of Part C,
nany of these comments no longer
pply and many of the objections have
ieen resolved.
The quality assurance requirement*
ar CEMS and associated issues were
raised by many commenters. Most
commenters stated that there was a
need for EPA to issue guidelines or
requirements for quality assurance. EPA
is developing such procedures, and they
will be published later this year or early
next year as Appendix E to 40 CFR Part
60. Some commenlers erroneously
assumed that the quality assurance
procedures were an integral part of the
specifications. Although related, this
specification should be evaluated on the
basis of its adequacy in evaluating a
CEMS after their initial installation.
The reproposed performance
specifications include a provision that
the relative accuracy of a CEMS must be
within ±20 percent of the mean
reference value or ±10 percent of the
applicable standard, whichever is
greater. Several commenters endorsed
this change, while one felt the change to
allow an accuracy of ±10 percent of the
applicable standard is too lenient at low
emission rates. The Administrator feels
that it is restrictive to require a high
degree of relative accuracy when the
actual emission levels are equivalent to
50 percent or less of the applicable
emission standard.
Request for Comments on Other Views
A number of suggestions were
received which were not incorporated in
these revisions. Because they represent
differing views, EPA requests comments
on them to determine what course of
action should be taken in the final rule
making. The suggestions are as follows:
1. Section 60.13(b) was revised to
exclude the mandatory 7-day
conditioning period used to verify the
CEMS operational status. Once
commenter feels that the mandatory
conditioning period should not only be
retained, but should be made longer
depending on how the CEMS is used
(i.e., for operation and maintenance
requirements or for compliance/
enforcement purposes) as follows:
a. The presently required 7-day
conditioning period should be retained
for CEMS used for operation and
maintenance requirements.
b. If the CEMS is used for compliance/
enforcement purposes, a 30-day
conditioning period should be required
an,d that the relative accuracy tests
should be spread over 3 days instead of
one.
c. All CEMS. whether for operation
and maintenace requirements or for
compliance/enforcement purposes.
should be installed and operational for
60 or 90 days prior to the initial NSPS
test
If the above are done, the commenter
feels that (1) the owner/operator/agency
would be aware of the progress made by
the control system in complying with the
emission standards. (2) there would be a
greater chance of the CEMS passing the
performance specification test and of
the facility complying with the
regulations within the time requirements
of § 60.8. and (3) the operator/vendor/
tester/agency would minimize loss of
valuable resources and time.
2. Once commenter feels that
{ 60.13{c) should require all CEMS
Performance Specification Tests to be
done concurrent with NSPS tests under
5 60.8. This would streamline the
process and save resources for owners
and agencies alike.
3. Section 60.13(d) was revised to
delete the requirements listed under
(d)(l) and (d)(2) because EPA felt that
the relative accuracy test would validate
the CEMS system which includes the
calibration gases or devices. One
commenter. however, feels that the
requirement to introduce zero and span
gas mixtures into the measurement
system at the probe at the stack wall
should be retained and conducted in
such a way that the entire system
including the sample interface is
checked. This requirement would
provide a means to check the CEMS on
a daily basis. In addition, the commenter
feels that the requirement for checking
the calibration gases at 6-month
intervals may be deleted provided that
the values used for replacement gas
cylinders, calibration gas cells or optical
filters are approved by the control
agency.
4. One commenter feels that the
following specifications should be
added in Section 4 of Performance
Specification 2:
a. The CEMS relative accuracy should
be relaxed by using a sliding function of
the allowable emission standard and/or
the reference method tesls for very lo\v
emission limits, e.g.. 0.10 pounds per 10*
Btu emission limit under PSD permits.
b. Each new compliance/enforcement
CEMS installed after 1983 must have an
external means of checking the
calibration of the instrument using
separate calibration/audit materials.
c. A minimum data recovery
specification of at least 18 hours in at
least 22 out of 30 days (or similar)
should be included. This would mean
that a performance specification test
would not be officially completed until
after the 30 days.
5. One commenter feels that EPA
should consider using Section 7.1 of
Performance Specification 2 to specify
that daring the CEMS performance
specification test all data be recorded
both in separate units of measurements
(ppm end percent CO, or O,) as well as
combined units of the standard.
11-137
-------
6. In Performance Specification 2, the
definition of "Relative Accuracy" is
incorrect Instead of a degree of
correctness, it i« actually a measure of
"relative error." One commenter feels
that "relative accuracy" should be
changed to "relative error."
7. In Section 7.3 of Performance
Specification 2, the tester is allowed to
reject up to three samples provided that
the total number of test results used to
determine the relative accuracy is
greater than or equal to nine. EPA had
considered using statistical techniques
to reject outliers, but found that these
techniques were too restrictive. One
commenter feels that statistical
techniques should be used. At a
minimum, the commenter feels that the
control agencies should be consulted
before any data is rejected.
Miscellaneous
. Authority: This proposed rule making is
issued under the authority of sections 111.
114 and 301(a) of the Clean Air Act as
amended (42 U.S.C. 7411. 7414. and 7601{a)).
Da ted: January 13.1981.
Douglas M. Costle.
Administrator.
It is proposed that 55 60.13. 60.46. and
60.47a. Appendix A, and Appendix B of
40 CFR Part 60 be amended as follows:
1. By revising 5 60.13(b). 60.13(c)(2)(ii).
and 60.13(d). by removing
subparagraphs (1). (2). and (3) of
§ 60.13(b). and by removing
subparagraphs (1). (2). and (3) of
§ 60.13(d) as follows:
( 60.13 Monitoring requirements.
. . • • •
(b) All continuous monitoring systems
and monitoring devices shall be
installed and operational prior to
conducting performance tests under
§ 60.8. Verification of operational status
shall, as a minimum, include completion
of the manufacturer's written
requirements or recommendations for
installation, operation, and calibration
of the device.
(c) * ' '
PI"* . . ,
(ii) Continuous monitoring systems lor
measurement of nitrogen oxides or
sulfur dioxide shall be capable of
measuring emission levels within ±20
percent with a confidence level of 95
percent The performance tests and
calculation procedures set forth in
Performance Specification 2 of
Appendix B shall be used for .
demonstrating compliance with this
specification.
» • • • •
(d) Owners and operators of all
continuous emission monitoring systems
installed in accordance with the
provisions of this part shall check the
zero and span drift at least once daily in
accordance with the method prescribed
by the manufacturer of such systems
unless the manufacturer recommends
adjustments at shorter intervals In
which case such recommendations shall
be followed. The zero and span shall, as
a minimum, be adjusted whenever the
24-hour zero drift of 24-hour span drift
limits of the applicable performance
specifications in Appendix B are
exceeded. The amount of excess zero
and span drift measured at the 24-hour
interval checks shall be quantified and
recorded. For continuous monitoring
systems measuring opacity of emissions.
the optical surfaces exposed to the
effluent gases shall be cleaned prior to
performing the zero and span drift
adjustments except that for systems
using automatic zero adjustments, the
optical surfaces shall be cleaned when
the cumulative automatic zero
compensation exceeds 4 percent
opacity. Unless otherwise approved by
the Administrator, the following
procedures shall be followed for
continuous monitoring systems
measuring opacity of emissions.
Minimum procedures shall include a
method for producing a simulated zero
opacity condition and an upscale(span)
opacity condition using a certified
• neutral density filter or other related
technique to produce a known
obscuration of the light beam. Such
procedures shall provide a system check
of the analyzer internal optical surfaces
and all electronic circuitry including the
lamp and photodelector assembly.
2. By revising § 60.46(a)(4) as follows:
{ 60.46 Test methods and procedures.
(a) * * '
(4) Method 6 for concentration of SOa-
Method 6A may be used whenever
Methods 6 and 3 data are used to
determine the SO, emission rate in ng/J.
and
3. By revising 5 60.47a(h)(l) as follows:
§ 60.47* Emission monitoring.
(h) * * *
(1) Reference Methods 3, 6, and 7 as
applicable, are used. Method 6B may be
used whenever Methods B and 3 data
are used to determine the SO, emission
rate in ng/J. The sampling location(s)
are the same as those used for the
continuous monitoring system.
4. By adding to Appendix A of 40 CFR
Part 60 two new methods. Methods 6A
and Method 68, to read as follows:
Appendix A—Reference Test Melhodi
• « • • •
Method 6A—Determination of Sulfur
Dioxide. Moisture, and Carbon Dioxide
Emissions from Fossil Fuel Combustion
Sources
1. Applicability and Principle
1.1 Applicability. This method applies
the determination of sulfur dioxide (SO,)
emissions from fossil fuel combustion sour
In terms of concentration [mg/m*)and in
terms of emission rate (ng/J) and to the
determination of carbon dioxide (CJ,)
concentration (percent). Moisture, if desire
may also be determined by this method.
The minimum detectable limit, the uppei
limit, and the interferences of the method
the measurement of SO. are the same as f<
Method 6. For a 20-liter sample, the metho
has a precision of 0.5 percent COi for
concentrations between 2.5 and 25 percen
CO, and 1.0 percent moisture for moisture
concentrations greater than 5 percent.
1.2 Principle. The principle of sample
collection is the same as for Method 6 exc
that moisture and CO, are collected In
addition to SO. in the same sampling train
Moisture and CO, fractions are determine
gravimelrically.
2. Apparatus
2.1 Sampling. The sampling train is
shown in Figure BA-1: the equipment
required is the same as for Method 6. exce
as specified below:
2.1.1 Midget Impingers. Two 30-ml mic
impingers with a 1-mxn restricted tip.
2.1.2 Midget Bubb'.er. One 30-ml midge
bubbler with an unrestricted tip.
2.1.3 CO, Absorber. One 250-ml
Erlenmeyer bubbler with an unrestricted
or equivalent.
2.2 Sample Recovey and Analysis. Thi
equipment needed for sample recovery an
analysis is the same as required for Meth(
6. In addition, a balance to measure withii
0.05 g is needed for analysis.
3. Reagents
Unless otherwise indicated, all reagents
must conform to the specifications
established by the Committee on Analytic
Reagents of the American Chemical Socie
Where such specifications are not availat
use the best available grade.
3.1 Sampling. The reagents required ft
tampling are the same as specified in Me
6, except that 80 percent isopropanol and
percent potassium iodide solutions are no
required. In addition, the following reager
are required:
11-138
-------
PROBE (END PACKED ^
WITH QUARTZ OR
PVREX WOOL)
STACK WALL
THERMOMETER
MIDGET BUBBLERS
MIDGET IMPINGERS
ICE BATH
THERMOMETER
RATE METER NEEDLE VALVE
DRY
GAS METER
Figure 6A-1. Sampling train.
PUMP
SURGE TANK
11-139
-------
3 1.1 Drierite'.' Anhydrous calcium sulfate
(CaSO.) desiccant, 8 mesh.
3 1.2. Ascarite. Sodium hydroxide.coated
asbestos for absorption of CO,. 8 to 20 mesh
3.2 Sample Recovery and Analysis. The
reagents needed for sample recovery and
analysis are the same as for Method 6,
Sections 3.2 and 3.3, respectively.
4. Procedure
4.1 Sampling
4.1.1 Preparation of Collection Train.
Measure IS ml of 3 percent hydrogen
peroxide into each of the first two midget
iropingers. Into the midget bubbler, place
about 25 g of drierite. Clean the outsides of
the impingers and the drierite bubbler and
weigh (at room temperature, ~ 20" C) to the
nearest 0.1 g. Weigh the three vessels
simultaneously and record this initial mass.
Place a small amount of glass wool In the
Erlenmeyer bubbler. The glass wool should
cover the entire bottom of the flask and be
about 1-cm thick. Place about 100 g of
ascarite on top of the glass wool and
carefully insert the bubbler top. Plug the
bubbler exhaust leg and invert the bubbler to
remove any ascarite fom the bubbler rube. A
wire may be useful in assuring that no
ascarite remains in the tube. With the plug
removed and the outside of the bubbler
cleaned, weigh (at room temperature (at room
temperature. - 20' C), to the nearest 0.1 g.
Record this initial mass.
Assemble the train as shown in Figure 6A-
1. Adjust the probe heater to a temperature
sufficient to prevent water condensation.
Place crushed ice and water around the
irnpingers and bubblers.
Note.—for stack gas streams with high
p.articulate loadings, an in-stack or heated
out-of-stack glass fiber mat filter may be used
in place of the glass wool plug in the probe.
4.1.2 Leak-Check Procedure and Sample
Collection. The leak-check procedure and
sample collection procedure are the same as
specified in Method 6, Sections 4.1.2 and
4.1.3, respectively.
4.2 Sample Recovery.
4.2.1 Moisture Measurement. Disconnect
the peroxide impingers and the drierite
bubbler from the sample train. Allow time
(about 10 minutes) for them to reach room
temperature, clean the outsides and then
weigh them simultaneously in the same
manner as in Section 4.1.1. Record this final
mass.
4.2.2 Peroxide Solution. Pour the contents
of the midget impingers into a leak-free
polyethylene bottle for shipping. Rinse the
two midget impingers and connecting tubes
with deionized distilled water, and add the
washings to the same storage container.
•Mention of trade namei or specific products
dots not constitute endorsement by the U.S.
Environmental Protection Agency.
4.2 3 CO, Absorber. Allow the Erlenmeyer
bubbler to warm to room temperature (about
10 minutes), cleen the outside, and weigh to
the nearest 0.1 g in the same manner as in
Section 4.1.1. Record this final mass and
discard the used ascarite.
4.3 Sample Analysis. The sample analysis
procedure for SO, is the same as specified in
Method 6. Section 4 J.
5. Calibration
The calibrations and checks are the same
as required in Method 0. Section 5.
8. Calculations
Carry out calculations, retaining at least 1
extra decimal figure beyond that of the
acquired data. Round off figures after final
calculation. The calculation nomenclature
and procedure are the same as specified in
Method 6 with the addition of the following.
6.1 Nomenclature.
CHHo = Concentration of moisture, percent.
co^ = Concentration of COt. dry basis.
percent.
mw1 = InitiaJ mass of peroxide impingers and
drierite bubbler, g.
mw<=Final mass of peroxide impingers and
drierite bubbler, g.
m^ = Initial mass of ascarite bubbler, g.
m»,= Final mass of ascarile bubbler, g.
Vcofi(,1-) = Standard equivalent volume of
COt collected, dry basis, ms.
6.2 COi volume collected, corrected to
standard conditions.
Vco, <.u>=5.467xO-"(m./-m.) (Eq. 6A-1)
6.3 Moisture volume collected, corrected
to standard conditions.
Xstd
-3
) = 1.336 x 10" J (m
'wf
- m .)
wi'
(Eq. 6A-2)
6.4 SO- concentration.
(V -
* VC02(std)
(Eq. 6A-3)
6.5 CO- concentration.
*C02(std)
C02 V.(std) +
x 100
(Eq. 6A-4)
6.6 Moisture concentration.
VH,0(std)
Q = *•
H2° Vm(std) + VH20(std) + VC02(std)
(Eq. 6A-5)
7. Emission Rate Procedure
If the only emission measurement desired
is in terms of emission rate of SO, (ng/J), an
abbreviated procedure may be used. The
differences between Method 6A and the
abbreviated procedure are described below.
7.1 Sample Train. The sample train is the
same as shown in Figure 6A-1 and as
described in Section 4. except that the dry
gas meter is not needed.
7.2 Preparation of the collection train.
Follow the same procedure as in Section
4.1.1. except that the peroxide impingers and
drierite buboler need not be weighed before
or after t\e test run.
7.3 Sampling. Operate the train as
described in Section 4.1.3. except that dry gas
11-140
-------
meler readings. barom=lric pressure, and dry
gas meler temperature* need not be recorded.
7.4 Sample Recovery. Follow the
procedure in Section 4.2. except that the
peroxide Irapingers and drierile bubbler need
not be weighed.
ms()
32.03
- Ytfa)
7.5 Sample Analysis. Analysis of the
peroxide solution Is the same as described In
Section 4.3.
7.6 Calculations.
7.0.1 SOi mass collected.
(Eq. 6A-7)
Where:
Mass
of S02 collected, mg.
7.6.2 Sulfur dioxide emission rate.
Where:
Ev)U = Ermss'on rate of SOt. ng/J.
F«=Carbon F factor for the fuel burned,
m'/J. fr°m Method 19.
8. Bibliography
8.1 Same as for Method 6, citations 1
through 8, with the addition of the following:
8.2 Stanley. Jon and P.R. Westlin. An
Alternate Method for Stack Gas Moisture
Determination. Source Evaluation Society
Newsletter. Volume 3, Number 4. November
1978.
8.3 Whittle. Richard N. and P.R. Westlin.
Air Pollution Test Report: Development and
Evaluation of an Intermittent Integrated
SOi/CO. Emission Sampling Procedure.
Environmental Protection Agency,
Emission Standard and Engineering
Division. Emission Measurement
Branch. Research Triangle Park, North
Carolina. December 1979.14 Daces.
m
'SO,
»af ' mai'
(Eq. 6A-8)
Method 6B—Determination of Sulfur Dioxide
and Carbon Dioxide Daily A veroge
Emissions From Fossil Fuel Combustion
Sources
1. Applicability and Principle
1.1 Applicability. This method applies to
the determination of sulfur dioxide (SO,)
emissions form combustion sources in terms
of concentration (nag/M") and emission rate
(ng/J), and for the determination of carbon
dioxide (CO,) concentration (percent) on a
daily (24 hours) basis.
The minimum detectable limit, upper limit.
and the interferences for Sd measurements
are the same as for Method 0. For a 20-liter
•ample, the method hns a precision of 0.5
percent COi for concentrations between 2.5
and 25 percent CO..
1.2 Principle. A gas sample is extracted
from the sampling point in the stack
intermittently over a 24-hour or other
specified time period. Sampling may also be
conducted continuously if the apparatus and
procedure ere modified (see the note in
Section 4.1.1). The SO, and CO, are separated
and collected in the sampling train. The SO,
fraction i» measured by the barium-thorin
titration method and CO, is determined
gravimetricaUy.
2. Apparatus
The equipment required for this method is
the same as specified for Method 6A. Section
2. with the addition of an industrial timer-
swilch designed to operate In the "on"
position from 3 to 5 continuous minutes and
"off the remaining period over a repeating.
2-hour cycle.
3. Reagents
All reagents for sampling and analysis are
the same as described in Method 6A, Section
3.
4. Procedure.
4.1 Sampling
4.1.1 Preparation of Collection Train.
Preparation of the sample train is the same as
described in Method 6A. Section 4.1.4 with
the addition of the following:
Assemble the train as shown in Figure 6B-
1. The probe must be heated to a temperature
sufficient to prevent water condensation and
must include a filter (either in-slack, out-of-
stack. or both) to prevent particulate
entrainment in the perioxide impingers. The
electric supply for the probe heat should be
continuous and separate from the timed
operation of the sample pump.
Adjust the timer-switch to operate in the
"on" position form 2 to 4 minutes on a 2-hour
repeating cycle. Other timer sequences may
be used provided there are at least 12 equal.
evenly spaced periods of operation over 24
hours and the total sample volume is
between 20 and 40 liters for the amounts of
sampling reagents prescribed in this method.
Add cold water to the tank until the
impingera and bubblers are covered at least
two-thirds of their length. The impingcrs and
bubbler tank must be covered and protected
from intense heat and direct sunlight I/
freezing conditions exist the impinger
solution and the water bath must be
protected.
11-141
-------
PRODE (END PACKED^
WITH QUARTZ OR
PYREX WOOL)
STACK WALL
THERMOMETER
MIDGET BUBBLERS
MIDGET IMPINGERS
ICE OATH''
THERMOMETER
Tl , RATE METER NEEDLE VALVE
DRY
GAS METER
Figure 6B-1. Sampling train. SURGE TANK
-------
Note.—Sampling may be conducted
continuously If a low flow-rate »ample pump
(>24ml/min) It used. Then the timer-switch
ii not necessary. In addition, if the sample
pump is designed for constant rate sampling.
the rate meter may be deleted. The total gas
volume collected should be between 20 and
40 liters for the amounts of sampling reagents
prescribed in this method.
4.1.2 Leak-Check Procedure. The leak-
check procedure is the same as describedf in
Method 6. Section 4.1.2.
4.1.3 Sample Collection. Record the initial
dry gas meter reading. To begin sampling.
position the tip of the probs at the sampling
point, connect the probe to the first impinger
(or filter), and start the timer and the sample
pump. Adjust the sample flow to a constant
rate of approximately 1.0 liter/min as
indicated by the rolameler. Assure that the
timer is operating as Intended. i.e, in the "on"
position 3 to 5 minutes at 2-hour intervals, or
other time interval specified.
During the 24-hour sampling period, record
the dry gas meter temperature between 9.00
a.m. and 11:00 aja, and the barometric
pressure.
At the conclusion of the run. turn off the
timer and the sample pump, remove the probe
from the stack, and record the final gas meter
volume reading. Conduct a leak check as
described in Section 4.1.2. If a leak is found.
void the test run or use procedures
acceptable to the Administrator to adjust the
snmplc volume for leakage. Repeat the steps
in this Section (4.1.3) for successive runs.
4.2 Sample Recovery. The procedures for
sample recovery (moisture measurement.
peroxide solution, and ascarile bubbler) are
the same as in Method 6A. Section 4.2.
4.3 Sample Analysis. Analysis of the
peroxide impinger solutions is the same as in
Method 6, Section 4.3.
5. Calibration
5.1 Metering System.
5.1.1 Initial Calibration. The initial
calibration for the volume metering system is
the same as for Method 6, Section 5.1.1.
5.1.2 Periodic Calibration Check. After 30
days of operation of the test train conduct a
calibration check as in Section 5.1.1 above.
except for the following variations: (1) The
leak check is not be conducted. (2) three or
more revolutions of the dry gas meter may be
used, and (3) only two independent runs need
be made. If the calibration factor does not
deviate by more than 5 percent from the
initial calibration factor determined in
Section 5.1.1, then the dry gas meter volumes
obtained durinylhe test series are acceptable
and use of the train can continue. If the
calibration factor deviates by more than 5
percent recalibrate the metering system as in
Section 5.1.1: and for the calculations for the
preceding 30 days of data, use the calibration
factor (initial orrecalibralion) that yields the
lower gas volume for each test run. Use the
latest calibration fact or for succeeding tests.
SJ Thermometer*. Calibrate against
mercury-in-glad thermometers initially and
• l3CH3ay intervals.
5.3 Jiolameter. The rolameler need not be
calibrated, but should be cleaned and
maintained according to the manufacturer's
instruction.
5.4 Barometer. Calibrate against a
mercury barometer Initially and at 30-day
intervals.
5.5 Barium Perchlorate Solution.
Standardize the barium perchlorale solution
against 25 ml of standard sulfuric acid to
which 100 ml of 100 percent isopropanal has
been added.
6. Calculations
The nomenclature and calculation
procedures are the seme as in Method 6A
with the following exceptions:
P*a = Initial barometric pressure for the lest
period, mm Hg.
T-=Absolute meter temperature for the
lest period. "K.
7. Emission Rate Procedure
The emission rate procedure is the same as
described in Method 6A, Section 7, except
that the timer is needed and is operated as
described in this method.
8. Bibliography
The bibliography is the same as described
in Method 6A. Section 8.
• •*•••
5. By revising Performance 2 and
Performance 3 of Appendix B of 40 CFR
Part 60 to read as follows:
Appendix B—Performance Specifications
. • • • •
Performance Specification 2—Specifications
and Test Procedures for SO, and A'O,
Continuous Emission Monitoring Systems in
Stationary Sources
1. Applicability and Principle
1.1 Applicability. This specification is to
be used for evaluating the acceptability of
SO. and NO, continuous emission monitoring
systems (CEMS) after the initial installation
end whenever specified in an applicable
subpart of the regulations. The CEMS may
include, for certain stationary sources.
diluent (O« or CO,) monitors.
1.2 Principle. Installation and
measurement location specifications.
performance and equipment specifications,
test procedures, and data reduction
procedures are included in this specification.
Reference method (RM) tests and calibration
drift tests are conducted to determine
conformance of the CEMS with the
specification.
2. Definitions
2.1 Continuous Emission Monftoring
System (CEMS). The total equipment
required for the determination of a gas
concentration or emission rate. The system
consists of the following major subsystems:
2.1.1 Sample Interface. That portion of the
CEMS that is used for one or more of the
following: Sample acquisition, sample
transportation, and sample conditioning, or
protection of the monitor from the elfects of
the slack effluent
2.1.2 Pollutant Analyzer. That portion of
the CEMS that senses the pollutant gas and
generates an output that is proportional to the
gas concentration.
2.1 J Diluent Analyzer (if applicable).
That portion of the CEMS that senses the
diluent gas (e.g.. CO. or O>) and generates an
output that is proportional to the gas
concentration.
2.1.4 Data Recorder. That portion of the
CEMS that providei a permanent record of
the analyzer output. The data recorder may
include automatic data reduction capabilities.
2.2 Point CEMS. A CEMS that measures
the gas concentration either at a single point
or along a path that it equal to or less than 10
percent of the equivalent diameter of the
stack or duct cross section.
23 Path CEMS. A CEMS that mesures the
gas concentration along a path that is greater
than 10 percent of the equivalent diameter of
the slack or duct cross section.
2.4 Span Value. The upper limit of a gas
concentration measurement range that is
specified for affected source categories in the
applicable subpart of the regulations.
2J Relative Accuracy. (RAJ. The absolute
mean difference between the gas
concentration or emission rate determined by
the CEMS and the value determined by the
reference method(s) plus the 2.5 percent error
confidence coefficient of a series of tests
divided by the mean of the reference method
(RM] tests or the applicable emission limit
2JB Calibration Drift (CD). The difference
In the CEMS output readings from the
established reference value after a staled
period of operation during which no
unscheduled maintenance, repair, or
adjustment took place.
U Centroidal Area. A concentric area
thai is gecmeiricnlly fcirnilar to the stack or
duct cross section and is no greater than 1
percent of the stack or d-.icl cross-scctio:ial
area,.
2.8 Representative Results. As defined by
the RM lest procedure outlined in this
specification.
3. Installation and Measurement Location
Specifications
3.1 CEMS Installation and Measurement
Location. Install the CEMS at an accessible
location where the pollutant concentration or
emission rate measurements ere directly
representative or can be corrected so as to be
representative of the total emissions from the
affected facility. Then select representative
measurement points or paths for monitoring
such that the CEMS will pass the relative
accuracy (RA) test (see Section 7). If the
cause of failure to meet the RA test is
determined to be the measurement location.
the CEMS may be required to be relocated.
Suggested measurement locations and
points or paths are listed below; other
locations and points or paths may be less
likely to provide data thai will meet the RA
requirements.
3.1.1 CEMS Location. It is suggested that
the measurement location be at least two
equivalent diameters downstream from the
nearest control device or other point at whicb
a change in the pollutant concentration or
emission rate may occur and at least a half
equivalent diameter upstream from Ihe
effluent exhaust
3.1 JZ Point CEMS. It b suggested that the.
measurement point.be (1) no less than 1.0
meter from the slack or duct wnfl. or (2)
within or centrally located over the
centroidal area of the slack or docl cross
•ection.
11-143
-------
3.1-3 Path CEMS. It li §ugge0led lhal the
effective measurement path (1) be totally
within the Inner area bounded by a line 1.0
meter from the stack or duel wall, or (2) have
•I least 70 percent of the path within tha
Inner 50 percent of the stack or duct cross-
•ectiona] area, or (3} be centrally located
over any pert of the centroidal area.
3.2 RM Measurement Location.and
Traverse Points. Select an RM measurement
point that ii accessible and at least (wo
equivalent diameter* downstream from the
nearest control device or other point at which
a change in the pollutant concentration or
emission rate may occur and at least a half
equivalent diameter upstream from the
effluent exhaust The CEMS and RM
locations need not be the same.
Then select traverse points that assure
acquisition of representative samples over
the stack or duct cross section. The minimum
requirements are as follows: Establish a
"measurement line" that passes through the
centroidal area. If this line Interferes with the
CEMS measurements, displace the line up to
30 cm (or 5 percent of the equivalent diameter
of the cross section, whichever is less) from
the centroidal area. Locate three traverse
points at 18.7. 50.0, and S3.3 percent of the
measurement line. If the measurement line is
longer than 2.4 meters, the three traverse
points may be located on the line at 0.4.1-2;
and 2.0 meters from the stack or duct wall.
The tester may select other traverse points.
provided that they can be shown to the
satisfaction of the Administrator to provide a
representative sample over the stack or duct
cross section. Conduct all necessary RM tests
within 3 cm [but no less than 3 cm from the
stack or duct wall) of the traverse points.
4. Performance and Equipment
Specifications
4.1 Instrument Zero and Span. The CEMS
recorder span must be set at 90 to 100 percent
of recorder full-scale using a span level of 90
to 100 percent of the span value (the
Administrator may approve other span
levels). The CEMS design must also allow the
determination of calibration drift at the zero
and span level points on the calibration
curve. If this is not possible or is impractical.
the design must allow these determinations
to be conducted al a low-level (0 to SO
percent of spaa value] point and at a high-
level (60 to 100 percent of span value) point
In special cases, if not already approved, the
Administrator may approve a single-point
calibration-drift determination.
42 Calibration Dp'ft. The CEMS
calibration must not drift or deviate from the
reference value of the gas cylinder, gas cell,
or optical filter by more than 2.5 percent of
the span value. If the CEMS includes
pollutant and diluent monitors, the
calibration drift must be determined
separately for each in terms of concentrations
(see Performance Specification 3 for the
diluent specifications).
4J3 CEMS Relative Accuracy. The RA of
the CEMS must be no greater than 20 percent
of the mean value of the RM test data in
terms of the units of the emission standard or
10 percent of the applicable standard.
whichever Is greater.
5. Performance Specification Test
Procedure
5.1 Pretest Preparation. Install the CEMS
and prepare the RM test site according to the
specifications in Section 3. and prepare the
CEMS for operation according to the
manufacturer's written instructions.
5.2 Calibration Drift Test Period. While
the affected facility is operating at more than
50 percent capacity, or as specified in an
applicable tubpart, determine the magnitude
of the calibration drift (CD) once each day (at
24-hour intervals] for 7 consecutive days
according to the procedure given in Section 6.
To meet the requirement of Section 4.2. none
of the CD's must exceed the specification.
5.3 RA Test Period. Only, after the CEMS
passes the CD test, conduct the RA test
according to the procedure given in Section 7
while the affected facility is operating at
more than 50 percent capacity, or as specified
in an applicable tubpart. To meet the
specifications, the RA must be equal to or
less than 20 percent or 10 percent of the
applicable standard, whichever is greater.
For Instruments that use common
components to measure more than one
effluent gas constituent, ail channels must
simultaneously pass the RA requirement.
unless it can be demonstrated that any
adjustments made to one channel did not
affect the others.
6. CEMS Calibration Drift Test Procedure
The CD measurement is to verify the ability
of the CEMS to conform to the established
CEMS calibration used for determining the
emission concentration or emission rate.
Therefore, if periodic automatic, or manual
adjustments are made to the CEMS zero and/
or calibration settings, conduct the CD test
Immediately before these adjustments.
Conduct the CD test at the two points
specified In Section 4.1. Introduce to the
CEMS the reference gases, gas cells, or
optical filters (these need not be certified).
Record the CEMS response and subtract this
value from the reference value (see example
data sheet in Figure 2-1).
If an Increment addition procedure is used
to calibrate the CEMS. a single-point CD test
may be used as follows: Use an increment
cell or calibration gas ith a value that will
provide a total CEMS response (i.e.. stack
plus cell concentrations) between 80 and 95
percent of the span value. Compare the
difference between the measured CEMS
response and the expected CEMS response
with the increment value to establish the CD.
11-144
-------
o>
>
oc
Day
Date and
time
Calibration
value
Monitor
value
Difference
Figure 2-1. Calibration drift detenni nation.
11-145
-------
Relative Accuracy Test Procedure
7.1 Sampling Strategy (or RM Tests.
Conduct the RM tests cuch that they will
yield results representative of the emissions
from the source and can be correlated to the
GEMS data. Although it It preferable to •
conduct the diluent (if applicable), moisture
(if needed}, and pollutant measurement!
limullaneously. the diluent and moisture
measurements that are taken within a 30- to
60-mlnute period, which Includes the
pollutant measurements, may be used to
calculate dry pollutant concentration and
emission rate.
In order to correlate the CEMS and RM
data properly, mark the beginning and end of
each RM test period of each run (including
the exact time of the day) on the CEMS chart
recordings or other permanent record of
output. Use the following strategies for the
RM tests:
7.1.1 For integrated camples, e.g.. Method
0 and Method 4, make a sample traverse of at
least 21 minutes, sampling for 7 minutes at
each traverse point
7.1.2 For grab samples, e.g. Method 7.
take one sample at each traverse point.
scheduling the grab samples so that they are
taken simultaneously (within a 3-minute
period) or are an equal interval of time apart
over a 21-minute (or less) period.
Note.—At times. CEMS RA tests are
conducted during NSPS performance tests. In
these cases, RM results obtained during
CEMS RA tests may be used to determine
compliance as long as the source and test
conditions are consistent with the applicable
regulations.
7.2 Correlation of RM and CEMS Data.
Correlate the CEMS and the RM test data as
to the time and duration by first determining
from the CEMS final output (the one used for
reporting) the integrated average pollutant
concentration or emission rate for each
pollutant RM test period. Consider system
response time, if important, and confirm that
the pair of results are on a consistent
moisture, temperature, and diluent
concentration basis. Then, compare each
integrated CEMS value against the
corresponding average RM value. Use the
following guidelines to make these
comparisons.
7.2.1 If the RM has an Integrated sampling
technique, make a direct comparison of the
RM results and CEMS integrated average
value.
7_2-2 If the RM has a grab sampling
technique, first average the results from all
grab camples taken during the test run and
then compare this average value against the
integrated value obtained from the CEMS
chart recording during the. run.
7.3 Number of RM Tests. Conduct a
minimum of nine sets of all necessary RM
tests. For grab samples, e.g. Method 7, a set
is made up of at least three separate
measurements. Conduct each set within a
period of 30 to 60 minutes.
Note.—The tester may choose to perform
more than nine sets of RM testa. If this option
is chosen, the tester may, at his descretion.
reject a maximum of three sets of the test
results 10 long as the total number of test
results used to determine the relative
accuracy is greater than or equal to nine, but
he must report all data including the rejected
data.
7.4 Reference Methods. Unless otherwise
specified in an applicable subpart of the
regulations, Methods 6, 7, 3. and 4. or their
approved alternatives, are the reference
methods for SO,. NO,, diluent (O, or CO,).
and moisture, respectively.
7.5 Calculations. Summarize the results
on a data sheet; an example is shown in
Figure 2-2. Calculate the mean of the RM
values. Calculate the arithmetic differences
between the RM and the CEMS output sets.
Then calculate the mean of the difference,
standard deviation, confidence coefficient,
and CEMS RA, using Equations 2-1, 2-2. 2-3.
and 2-4.
8. Equations
E.1 Arithmetic Mean. Calculate the
arithmetic mean of the difference, d. of a data
set as follows:
i «
n .• i
di
(Eq. 2-1)
Where:
n
£ d.
i-1 1
Number of data points.
Algebraic sum of the individual differences, d.,
When the mean of the differences of pain
of data Is calculated, be sure to correct the
data for moisture, if applicable.
11-146
-------
Run
No.
1
2
3
4
5
6
7
8
9
10
n
12
Date and
time
Average
Confidence Interval
Accuracy**
so2
RM 1 M IDiff
ppmc
N0xb
RM
M \NTT
ppmc
C02 or 02a
RM
M
*d *d
so2a
RM
M
Diff
mass/GCV
aFor steam generators; b Average of three samples; c Make sure that RM and M data are
either wet or dry.
NO/
RM
M
Diff
mass/GCV
on a consistent basis
Figure 2-2. Relative accuracy determination.
-------
8.2 Standard Deviation Calculate the
standard deviation St as followi:
Where:
«O.975 = t-valuei (tee Table 2-1)
Table 2-1.1-VALUES
If 'OB7S
(to- 2-2)
8 3 Confidence Coefficient. Calculate the J
2.5 percent error confidence coefficient (one-
tailed) CC as follows:
12.708 7 2.«47 12 2-201
4JJ03 • ZJ6* « «-"•
3 182 • 2.308 1« 2.160
2.776 10 2-262 15 2145
2.571 11 2-228 16 2.131
nlurl In tfill Ublt
of
•J vajurft.
ctnr«ctcd lot R-l
l lo
CC • 1:0.97S —
8.4 Relative Accuracy. Calculate the RA
(In. 2-3) otmfel of dala as follows:
M
x 100
(Eq. 2-4)
VJhere:
ffl
|CC|
= Absolute value of the mean of differences
(from Equation 2-1).
= Absolute yalue of the confidence coefficient
(from Equation 2-3).
= Average RM value or applicable standard.
calculations, and charts (record of data
outputs] that are necessary to substantiate
that the performance CEMS met the
performance specification.
10. Bibliography
10.1 "Experimental Statistics,"
Department of Commerce. Handbook 91,
1963. pp. 3-31. paragraphs 3-3.1.4.
Performance Specification 3 — Specifications
9. Reporting
At a minimum (check with the appropriate
regional office, or Stale or local agency for
rCBIOnBl OllIC-". UI OIOIC «J1 JW^ai D^»-'««-J *w* - ^-_/ _ — t y-- - i .
additional requirements, if any) summarize in ond Test Procedures for O, ajid CO,
tabular form the calibration drift tests and
the RA tests. Include all data sheets.
Continuous Emission Monitoring Systems in
Stationary Sources
1. Applicability ond Principle
1.1 Applicability. This specification is lo
be used for evaluating tbe acceptability of O,
and CO, continuous emission monitoring
systems (CEMS) after Initial installation and
whenever specified in an applicable subpart
of the regulations. The specification applies
lo O, and CO, monitors that are not included
under Performance Specification 2.
The definitions, installation measurement
location specifications, test procedures, data
reduction procedures, reporting requirements.
and bibliography are the same as in
Performance Specification Z, Sections 2, 3. 5.
6. 8. 9. and 10. and also apply lo O, and COi
CEMS under this specification. The
performance and equipment specifications
and the relative accuracy (RA) lest
procedures for O, and CO, CEMS differ from
SO, and NO, CEMS. unless otherwise noted.
and are therefore included here.
1.2 Principle. Reference method (RM)
tests and calibration drift tests are conducted
to determine conformance of the CEMS with
the specification.
2. Performance and Equipment
Specifications
2.1 Instrument Zero and Span. Thi«
specification is the same as Section 4.1 of
Performance Specification 2.
2-2 Calibration Drift. The CEMS
cab'bration must not drift by more than 0.5
percent O, or CO, from the reference value of
the gas, gas cell, or optical filter.
2.3 CEA/S Relative Accuracy. The RA of
the CEMS roust be no greater than 20 percent
of the mean value of the RM test data or 1.0
percent O, or CO,, whichever is greater.
3. Relative Accuracy Test Procedure
3.1 Sampling Strategy for HM Tests.
correlation of KM ond CEAfS data, dumber
ojRM Tests, and Calculations. This is the
same as Performance Specification 2,
Sections 7.1. 7.2. 73. and 7.5. respectively.
33. Reference Method. Unless otherwise
specified in an applicable Bubpart of the
regulations. Method 3 of Appendix A or any
approved alternative is the reference method
for O, or CO».
(Sec. 114. Clean Air Act, as amended (42
U.S.C. 7414))
|TX Dot S1-2KJ7 Filed l-23-«l: B *S «m]
148
-------
SIP MONITORING REQUIREMENTS - PROMULGATED
11-149
-------
Title 40—Protection of Environment
CHAPTER I—ENVIRONMENTAL
PROTECTION AGENCY
SUBCHAPTER C—AIR PROGRAMS
|PRL 423-6|
PART 51—REQUIREMENTS FOR THE
PREPARATION. ADOPTION AND SUB-
MITTAL OF IMPLEMENTATION PLANS
Emission Monitoring of Stationary Sources
On September 11, 1974. the Environ-
mental Protection Agency (EPA) pro-
posed revisions to 40 CFR Part 51. Re-
quirements for the Preparation, Adop-
tion, and Submittal of Implementation
Plans. EPA proposed to expand 5 51.19 to
require States to revise their State Im-
plementation Plans (SIP's) to include
legally enforceable procedures requiring
certain specified categories of existing
stationary sources to monitor emissions
on a continuous basis. Revised SIP's sub-
mitted by States in response to the pro-
posed revisions to 40 CFR 51.19 would
• have (1) required owners or operators
of specified categories of stationary
sources to install emission monitoring
equipment within one year of plan ap-
proval. (2) specified the categories of
sources subject to the requirements. (3)
identified for each category of sources
the pollutant(s) which must be moni-
tored, (4) set forth performance specifi-
cations for continuous emission monitor-
ing instruments. (5) required that such
Instruments meet performance specifi-
cations through on-site testing by the
owner or operator, and (6) required that
data derived from such monitoring be
summarized and made available to the
State on a quarterly basis.
As a minimum, EPA proposed that
States must adopt and implement legally
enforceable procedures to require moni-
toring of emissions for existing sources
in the following source categories cbut
only for sources required to limit emis-
sions to comply with an adopted regula-
tion of the State Implementation Plan):
(a) Coal-fired steam generators of
more than 250 million BTU per hour heat
input (opacity, sulfur dioxide, oxides of
nitrogen and oxygen);
(b) Oil-fired steam generators of more
than 250 million BTU per hour heat in-
put (sulfur dioxide, oxides of nitrogen
and oxygen). An opacity monitor was re-
quired only if an emission control device
Is needed to meet particulate emission
regulations, or if violations of visible
emission regulations are noted:
(c) Nitric acid plants (oxides of
nitrogen);
(d) Sulfuric acid plants (sulfur di-
oxide); and
Petroleum refineries' fluid catalj' .c
cracking unit catalyst regenerators
(opacity).
Simultaneously, the Agency proposed
similar continuous emission monitoring
requirements for new sources for each of
the previously identified source categor-
ies, subject to the provisions of federal
New Source Performance Standards set
forth in 40 CFR Part 60. Since many of
the technical aspects of the two proposals
were similar, if not the same, the pro-
RULES AND REGULATIONS
posed regulations for Part 51 (ie._those
relating to SIP« and existing sources!
included by refeionre many specific tech-
nical details set forth in 40 CFR Part 60,
(39 FR 32852).
At the time of the proposal of the con-
tinuous emission monitoring regulations
in the FEDERAL REGISTER, the Agency in-
vited comments on the proposed rule-
making action Many interested parties
submitted comments Of the T6 comments
received. 35 were from electric utility
companies, 26 were from oil refineries or
other industrial companies, 12 were from
governmental agencies, and 3 were from
manufacturers and'or suppliers of emis-
sion monitors. No comments were re-
ceived from environmental groups. Fur-
ther, prior to the proposal of the regula-
tions in the FEDERAL REGISTER, the Agency
sought comments from various State and
local air pollution control agencies and
Instrument manufacturers. Copies of
each of these comments are available
for public inspection at the EPA Freedom
of Information Center, 401 M Street,
S.W., Washington. D.C. 20460. These
comments have been considered, addi-
tional information collected and assessed,
and where determined by the Adminis-
trator to be appropriate, revisions and
amendments have been made in for-
mulating these regulations promulgated
herein.
General Discussion o/ Comments. In
general, the comments received by the
Agency tended to raise various objections
with specific portions of the regulations.
Some misinterpreted the proposed reg-
ulations, not realizing that emission
monitoring under the proposal was not
required unless a source was required to
comply with an adopted emission limita-
tion or sulfur in fuel limitation that was
part of an approved or promulgated State
Implementation Plan. Many questioned
the Agency's authority and the need to
require sources to use continuous emis-
sion monitors. Others stated that the
proposed regulations were inflationary,
and by themselves could not reduce emis-
sions to the atmosphere nor could they
improve air quality. A relatively common
comment was that the benefits to be de-
rived from the proposed emission moni-
toring program were not commensurate
with the costs associated with the pur-
chase, installation, and operation of such
monitors. Many'stated that the proposed
regulations were not cost-eflectively ap-
plied and they objected to all sources
within an identified source category be-
ing required to monitor emissions, with-
out regard for other considerations. For
instance, some suggested that it was un-
necessary to monitor emissions from
steam generating plants that may soon
be retired from operation, or steam gen-
erating boilers that are infrequently used
(such as for peaking and cycling opera-
tions) or for those sources located in
areas of the nation which presently have
ambient concentrations better than na-
tional ambient air quality standards. This
latter comment was especially prevalent
in relation to the need for continuous
emission monitors designed to measure
emissions of oxides of nitrogen. Further,
commentors generally suggested that
state and local control agencies, rather
than EPA should be responsible for
determining which sources should moni-
tor emissions. In this regard, the corn-
mentors suggested that a determination
of the sources which should install con-
tinuous monitors should be made on a
case-by-case basis. Almost all objected to
the data reporting requirements stating
that the proposed requirement of sub-
mission of all collected data was excessive
and burdensome Comments from state
and local air pollution control agencies in
general were similar to those from the
utility and industrial groups, but in addi-
tion, some indicated that the manpower
needed to implement the programs re-
quired by the proposed regulations was
not available.
Rationale for Emission Monitoring
Regulation. Presently, the Agency's reg-
ulations setting forth the requirements
for approvable SIP's require States to
have legal authority to require owners
or operators of stationary sources to in-
stall, maintain, and use emission moni-
toring devices and to make periodic
reports of emission data to the State
(40 CFR Sl.IHa) (6)). This requirement
was designed to partially implement the
requirements of Sections 110
Mi) and (iii) of the Clean Air Act, which
state that implementation plans must
provide "requirements for installation
of equipment by owners or operators of
stationary sources to monitor emissions
from such sources", and "for periodic
reports on the nature and amounts of
such emissions". However, the original
implementation plan requirements did
not require SIP's to contain legally en-
forceable procedures mandating contin-
uous emission monitoring and recording.
At the time the original requirements
were published, the Agency had accumu-
lated little data on the availability and
reliability of continuous monitoring de-
vices. The Agency believed that the
state-of-the-art was such that It was
not prudent to require existing sources
to install such devices.
Since that time, much work has been
done by the Agency and others to field
test and compare various continuous
emission monitors. As a result of this
work, the Agency now believes that for
certain sources, performance specifica-
tions for accuracy, reliability and dura-
bility can be established for continuous
emission monitors of oxygen, carbon
dioxide, sulfur dioxide, and oxides of
nitrogen and for the continuous meas-
urement of opacity. Accordingly, it is
the Administrator's judgment that Sec-
tions 110(a)(2)(F) and (iii) should
now be more fully imnlemented.
The Administrator believes that a
sound program of continuous emission
monitoring and reporting will play an
Important role in the effort to attain
and maintain national standards. At the
present time, control agencies rely upon
infrequent manual source tests and
periodic field Inspections to provide
much of the enforcement information
necessary to ascertain compliance of
sources with adopted regulations. Man-
ual source tests are generally performed
on a relatively infrequent basis, such as
FtDHAL IEGISTEK, VOL. 40, NO. 1«—MONDAY, OCTOIES t, WS
11-150
-------
once per year, and in some cases, affected
sources probably have never been tested.
Manual stack tests are generally per-
formed under optimum operating con-
ditions, and as such, do not reflect the
full-time emission conditions from a.
source. Emissions continually vary with
fuel firing rates, process material feed
rates and various other operating condi-
tions. Since manual stack tests are only
conducted for a relatively short period
of time (e.g.. one to three hours', they
cannot be representative of all operating
conditions. Further, frequent manual
stack tests (such as conducted on n
quarterly or more frequent basis' are
costly and may be more expensive than
continuous monitors that provide much
more information. State Agency en-
forcement by field Inspection is also
sporadic, with only occasional inspection
of certain sources, mainly for visible
emission enforcement.
Continuous emission monitoring and
recording systems, on the other hand,
can provide a continuous record of emis-
sions under all operating conditions. The
continuous emission monitor is a good
indicator of whether a source is using
good operating and maintenance prac-
tices to minimize emissions to the at-
mosphere and can also provide a valu-
able record to indicate the performance
of a source in complying with applicable
emission control regulations. Addition-
ally, under certain instances, the data
from continuous monitors may be suf-
ficient evidence to issue a notice of vio-
lation. The continuous emission record
can also be utilized to signal a plant
upset or equipment malfunction so that
the plant operator can take corrective
action to reduce emissions. Use of emis-
sion monitors can therefore provide val-
uable information to-minimize emissions
to the atmosphere and to assure that
full-time control efforts, such as good
maintenance and operating conditions,
are being utilized by source operators.
The,Agency believes that it is necessary
to establish national minimum require-
ments for emission monitors for specified
sources rather than allow States to de-
'termine on a case-by-case basis the spe-
cific sources which need to continuously
monitor emissions. The categories speci-
fied in the regulations represent very sig-
nificant sources of emissions to the at-
mosphere. States in developing SIP's
have generally adopted control regula-
tions to minimize emissions from these
sources. Where such regulations exist, the
Agency believes that continuous emission
monitors are necessary to provide infor-
mation that may be used to provide an
Indication of source compliance. Further,
it is believed that if the selection of
tources on a case-by-case basis were left
to the States, that some States would
probably not undertake an adequate
emission monitoring program. Some
State Agencies who commented on the
proposed regulations questioned the
•Ute-of-the-art of emission monitoring
and iUt«J their opinion that the pro-
P»«d requirements were premature.
T^trttore. It U the Administrator's
IttOcmcat that, in order to assure an
RULES AND REGULATIONS
adequate nationwide emission moni-
torinc procrnm. minimum emission mon-
itorinp requirements must bo established
The source categories affected by the
regulations were selected because they
are significant sources of emissions and
because the Agency's work at the time of
the proposal of these regulations in the
field of continuous emission monitoring
evaluation focused almost exclusively on
these source categories The Agency is
continuing to develop data on monitoring
devices for additional source categories.
It is EPA's intent to expand the minimum
continuous emission monitoring require-
ments from time to tune when the eco-
nomic and technological feasibility of
continuous monitoring equipment is
demonstrated and where such monitor-
ing is deemed appropriate for other sig-
nificant source categories.
Discussion of Major Comments. Many
r-ommentors discussed the various cost
aspects of the proposed regulations, spe-
cifically stating that the costs of con-
tinuous monitors were excessive and in-
flationary A total of 47 commentors ex-
pressed concern for the cost and/or cost
effectiveness of continuous monitors.
Further, the Agency's cost estimates for
purchasing and installing monitoring
systems and the costs for data reduction
and reporting were questioned. In many
cases, sources provided cost estimates for
installation and operation of continuous
monitors considerably in excess of the
cost estimates provided by the Agency.
In response to these comments, a fur-
ther review was undertaken by the Agen-
cy to assess the cost impact of the regu-
lations. Three conclusions resulted from
this review. First, it was determined that
the cost ranges of the various emission
monitoring systems provided by the
Agency are generally accurate for new
sources. Discussions with equipment
manufacturers and suppliers confirmed
this cost information. Approximate in-
vestment costs, which include the cost
of the emission monitor, installation cost
at a new facility, recorder, performance
testing, data reporting systems and asso-
ciated engineering costs are as follows:
for opacity. $20,000; for sulfur dioxide
and oxygen or oxides of nitrogen and
oxygen, $30.000: and for a source that
monitors opacity, oxides of nitrogen, sul-
fur dioxide and oxygen, $55,000 Annual
operating costs, which include data re-
duction and report preparation, system
operation, maintenance, utilities, taxes,
insurance and annualized capital costs
at IQV for 8 years are: $8.500; $16,000;
and $30.000 respectively for the cases
described above.(l)
Secondly, the cost review indicated
that the cost of installation of emission
monitors for existing sources could be
considerably higher than for new sources
because of the difficulties in providing
access to a sampling location that can
provide a representative sample of emis-
sions. The cost estimates provided by the
Agency in the proposal were specifically
developed for new sources whose in-
stallation costs are relatively stable since
provisions for monitoring equipment can
be incorporated at the time of plant de-
•ign. This feature is not available for ex-
isting sources, hence higher costs gei
erally result Actual costs of installatir
at existing sources may vary from 01
to five times the cost of normal install"
tion at new sources, and in some cas<
even higher costs can result For exam
pie, discussions with instrument suppli
ers indicate that a typical cost of instal
lation of an opacity monitor on an exist
ing source may be two to three times tlv
purchase price of the monitor. Difftcul
ties also exist for installation of gaseou
monitors at existing sources
It should be noted that these installn
tion costs Include material costs for scaf
folding, ladders, sampling ports an>
other items necessary to provide acces
to a location where source emissions cai
be measured. It is the Agency's opinio:
that such costs cannot be solely attrib
uted to these continuous emission mom
toring regulations. Access to samplini
locations is generally necessary to dc
termine compliance with applicable stati
or local emission limitations by routine
manual stack testing methods. There-
fore, costs of providing access to a rep-
resentative sampling location are more
directly attributed to the cost of com-
pliance with adopted emission limita-
tions, than with these continuous emis-
sion monitoring regulations.
Lastly, the review of cost information
indicated that a numbsr of commented
misinterpreted the extent of the pro-
posed regulations, thereby providing cosl
estimates for continuous monitors which
were not required Specifically, all com-
mentors did not recognize that the pro-
posed regulations required emission mon-
itoring for a source only if an applicable
State or local emission limitation of an
approved SIP affected such a source. For
example, if the approved SIP did not
contain an adopted control regulation to
limit oxides of nitrogen from steam-
generating, fossil fuel-fired boilers of a
capacity in excess of 250 million BTU per
hour heat input, then such source need
not monitor oxides of nitrogen emis-
sions. Further, some utility industry com-
mentors included the costs of continuous
emission monitors for sulfur dioxide The
propos2d regulations, however, generally
allowed the use of fuel analysis by speci-
fied ASTM procedures as an alternative
which, in most cases, is less expensive
than continuous monitoring. Finally, the
proposed regulations required the con-
tinuous monitoring of oxygen in the
exhaust gas only if the source must
otherwise continuously monitor oxides of
nitrogen or sulfur dioxide. Oxygen in-
formation is used solely to provide a cor-
rection for excess air when converting
the measurements of gaseous pollutants
concentrations in the exhaust gas stream
to units of an applicable emission limi-
tation Some commentors did not recog-
nize this point (which was not specifical-
ly stated in the proposed regulations)
and provided cost estimates for oxygen
monitors when thev were not required by
the proposed regulations.
While not all commentors' cost esti-
mates were correct, for various reasons
noted above, it is clear that the costs
associated with implementing these
emission monitoring regulations are sig-
FtDEKAl IICISTtl, VOL 40, NO. If4—MONDAY, OCTOIEt «. It75
11-151
-------
RULES AND REGULATIONS
nificant The Administrator, however.
believes that the benefits to be derived
from emission monitoring are such that
the costs are not unreasonable The Ad-
ministrator does, however, agree with
many commentors that the proposed reg-
ulations, in some cases, were not applied
cost-effectively and, as such, the regula-
tions promulgated herein have been
modified to provide exemptions to cer-
tain sources from these minimum re-
quirements.
One comment from another Federal
Agency concerned the time period that
emissions are to be averaged when re-
porting excess emissions Specifically, the
commentor assumed that the emission
control regulations that have been
adopted by State and local agencies were
generally designed to attain annual am-
bient air quality standards. As such, the
commentor pointed out that short-term
emission levels in excess of the adopted
emission standard should be acceptable
for reasonable periods of time.
The Administrator does not agree with
this rationale for the following reasons.
First, it is not universally true that an-
nual ambient standards were the design
basis of emission control regulations. In
many cases, reductions to attain short-
term standards require more control
than do annual standards. Even if the
regulations were based upon annual
standards, allowing excess emissions of
the adopted emission control regulation
on a short-term basis could cause non-
compliance with annual standards. More
importantly, however, a policy of legally
allowing excesses of adopted control reg-
ulations would in effect make the current
emission limitation unenforceable If the
suggestion were implemented, a question
would arise as to what is the maximum
emission level that would not be consid-
ered an excess to the adopted regulation.
The purpose of the adopted emission lim-
itation was to establish the acceptable
emission level. Allowing emissions In ex-
cess of that adopted level would cause
confusion, ambiguity, and in many cases
could result in an unenforceable situa-
tion. Hence the Administrator does not
concur with the commentor's suggestion.
Modifications to the Proposed Regu-
lations. The modification to the regu-
lations which has the most significant
impact involves the monitoring require-
ments for oxides of nitrogen at fossil
fuel-fired steam generating boilers and
at nitric acid plants. Many commentors
correctly noted that the Agency in the
past (June 8, 1973, 38 FR 15174) had in-
dicated that the need for many emis-
sion control regulations for oxides of
nitrogen were based upon erroneous
data Such a statement was made after
a detailed laborato.v analysis of the ref-
erence ambient measurement method
for nitrogen dioxide revealed the method
to give false measurements The
sampling technique generally indicated
concentration of nitrogen dioxide
higher than actually existed in the
atmosphere. Since many control agen-
cies prior to that announcement had
adopted emission regulations that were
determined to be needed based upon
'these erroneous data, and since new datrx.
collected by other measurement tech-
niques, indicated that in most areas of
the nation such control regulations were
not necessary to satisfy the requirements
of the SIP. the Agency suggested that
States consider the withdrawal of
adopted control regulations for the con-
trol of oxides of nitrogen from their SIP's
(May 8, 1974, 39 FR 16344). In many
States, control agencies have not taken
action to remove these regulations from
the SIP. Hence, the commentors pointed
out that the proposed regulations to re-
quire continuous emission monitors on
sources affected by such regulations is
generally unnecessary.
Because of the unique situation in-
volving oxides of nitrogen control regu-
lations, the Administrator has deter-
mined that the proposed regulations to
continuously monitor oxides of nitrogen
emissions may place an undue burden on
source operators, at least from a stand-
point of EPA specifying minimum moni-
toring requirements. The continuous
emission monitoring requirements for
such sources therefore have been modi-
fied The final regulations require the
continuous emission monitoring of
oxides of nitrogen only for those sources
in Air Quality Control Regions (AQCR's >
where the Administrator has specifically
determined that a control strategy for
nitrogen dioxide is necessary. At the
present time such control strategies are
required only for the Metropolitan Los
Aneeles Intrastate and the Metropoli-
tan Chicago Interstate AQCR's.
It should be noted that a recent com-
pilation of valid nitrogen dioxide air
quality data suggests that approximately
14 of the other 245 AQCR's in the nation
may need to develop a control strategy
for nitrogen dioxide. These AQCR's are
presently being evaluated by the Agency.
If any additional AQCR's are identified
as needing a control strategy for nitro-
gen dioxide at that time, or any time
subsequent to this promulgation, then
States in which those AQCR's are lo-
cated must also revise their SIP's to
require continuous emission monitoring
for oxides of nitrogen for specified
sources. Further, it should be noted that
the regulations promulgated today are
minimum requirements, so that States,
if they believe the control of oxides of
nitrogen from sources is necessary may,
as they deem appropriate, expand the
continuous emission monitoring require-
ments to apply to additional sources not
affected by these minimum requirements.
Other modifications to the proposed
regulation resulted from various com-
ments A number of commentors noted
that the proposed regulations included
some sources whose emission impact or.
air quality was relatively minor. Specifi-
cally, they noted that fossil fuel-fired
steam generating units that were used
solely for peaking and cycling purposes
should be exempt from the proposed reg-
ulations. Similarly, some suKfrested that
smaller sized units, particularly steam-
generating units less than 2,500 million
BTU per hour heat input, should also
be exempted. Others pointed out that
units soon to be retired from operation
should not be required to install con-
tinuous monitoring devices and that
sources located in areas of the nation
that already have air quality better than
the national standards should be relieved
of the required monitoring and reporting
requirements The Agency has considered
these comments and has made the fol-
lowing judgments.
In relation to fossil fuel-fired steam
generating units, the Agency has deter-
mined that such units that have an an-
nual boiler capacity factor of 30% or less
as currently defined by the Federal Power
Commission shall be exempt from the
minimum requirements for monitoring
and reporting. Industrial boilers used at
less than 30 7r of their annual capacity,
upon demonstration to the State, may
also be granted an exemption from these
monitoring requirements. The rationale
for this exemption is based upon the fact
that all generating units do not produce
power at their full capacity at all times.
There are three major classifications of
power plants based on the degree to
which their rated capacity is utilized on
an annual basis. Baseload units are de-
signed to run at near full capacity almost
continuously. Peaking units are operated
to supply electricity during periods of
maximum system demand. Units which
are operated for intermediate service
between the extremes of baseload and
peaking are termed cycling units.
Generally accepted definitions term
units generating 60 percent or more of
their annual capacity as baseload, those
generating less than 20 percent as peak-
ing and those between 20 and 60 percent
as cycling. In general, peaking units are
older, smaller, of lower efficiency, and
more costly to operate than base load or
cycling units. Cycling units are also gen-
erally older, smaller and less efficient
than base load units. Since the expected
life of peaking units is relatively short
and total emissions from such units are
small, the benefits gained by installing
monitoring instruments are small in
comparison to the cost of such equip-
ment. For cycling units, the question of
cost-effectiveness is more difficult to as-
certain. The units at the upper end of
the capacity factor range (i.e., near 60%
boiler capacity factor) are candidates for
continuous emission monitoring whiie
units at the lower end of the range (i.e.,
ne?r 207, boiler capacity factor^ do not
represent good choices for continuous
monitors. Based upon available emission
information, it has been calculated that
fossil fuel-firrd steam generating plants
with a 307, jr less annual boiler capacity
factor contribute approximately less
than 5O of the total sulfur dioxide from
all such power plants. (2> Hence, the
finnl regulations do not affert any boiler
! lat has an annual boiler capacity factor
of less than 3Qr/r. Monitoring require-
ments will thus be more cost effectively
applied to the newer, larger, and more
efficient units that burn a relatively
larftcr portion of the total fuel supply.
Some commentors noted that the age
of the facility should be considered in
relation to whether a source nee^ com-
FEPERAl REGISTER, VOL. 40, NO. 194—MONDAY, OCTOIER 6, 1*75
11-152
-------
ply with the proposed reflations. For
fossil fuel-fired steam generating units.
the exemption relating to the annual
boiler capacity factor previously dis-
cussed should generally provide relief for
older units. It is appropriate, however,
that the age of the facility be consid-
ered for other categories of sources af-
fected by the proposed regulations. As
such, the final regulations allow that any
source that is scheduled to be retired
within five years of the inclusion of mon-
itoring requirements for the source in
Appendix P need not comply with the
minimum emission monitoring require-
ments promulgated herein In the Ad-
ministrator's judgment, the selection of
five years as the allowable period for
this exemption provides reasonable re-
lief for those units that will shortly be
retired. However, it maintains full re-
quirements on many older unite with a
number of years of service remaining.
In general, older units operate less effi-
ciently and arc less well controlled than
newer units so that emission monitoring
Is generally useful. The exemption pro-
vided in the final regulations effectively
allows such retirees slightly more than a
two-year period of relief, since the sched-
ule of implementation of the regulations
would generally require the installation
of emission monitors by early 1978.
States must submit, for EPA approval.
the procedures they will implement to
use this provision. States are advised
that such exemptions should only be pro-
vided where a bona fide intent to rease
operations has been clearly established.
In cases where such sources postpone
retirement. Slates shall have established
procedures to require such sources to
monitor and report emissions. In this re-
gard, it should be noted that Section
H3
-------
RULES AND REGULATIONS
ted to the State. It was generall> indi-
rated by the commentors that the data
reporting requirements were excessive.
Commentors questioned the purpose of
reporting all measuied data while some
State agencies indicated they have lim-
ited resources to handle such informa-
tion. EPA believes that, in some cases.
the commentors misconstrued the data
reporting requirements for existing
sources. In light of each of these com-
ments, the final regulations, with respect
to the data reporting requirements for
gaseous pollutants and opacity, have
been modified.
For gaseous emissions, the proposed
regulations required the reporting of all
one-hour averages obtained by the emis-
sion monitor. Because of the comments
- on this provision, the Agency has reex-
amined the proposed data reporting re-
quirements. As a result, the Agency has
determined that only information con-
cerning emissions in excess of emission
limitations of the applicable plan is nec-
essary to satisfy the intent of these reg-
ulations Therefore, the data reporting
requirements for gaseous pollutants
have been modified. The final regulations
require that States adopt procedures that
would require sources to report to the
State on emission levels in excess of the
applicable emission limitations 'i.e., ex-
cess emissions) for the time period spec-
ified in the regulation with which com-
pliance is determined. In other words, if
an applicable emission limitation re-
quired no more than 1.0 pounds perJiour
SO, to be emitted for any two-hour aver-
aging period, the data to be reported by
the source should identify the emission
Jevel (i.e., emissions stated in pounds per
hour) averaged over a two-hour time
period, for periods only when this emis-
sion level was in excess of the 1.0 pounds
per hour emission limitation. Further,
sources shall be required to maintain a
record of all continuous monitoring ob-
servations for gaseous pollutants (and
opacity measurements) for a period of
two years and to make such data avail-
able to the State upon request. The final
regulations have also been amended to
add a provision to require sources to re-
port to the State on the apparent reason
for all noted violations of applicable reg-
ulations.
The proposed data reporting require-
ments for opacity have also been modi-
fied Upon reconsideration of the extent
of the data needed to satisfy the intent
of these regulations, it is the Adminis-
trator's judgment that for opacity States
must -obtain excess emission measure-
ments during each hour of operation.
However, before determining excess
emissions, the number of minutes gen-
erally exempted by State opacity rer -
lations should be considered. For ex-
ample, where a regulation allows two
minutes of opacity measurements in
excess of the standard, the State
need only require the source to re-
. port all opacity measurements in excess
of the standard during any one hour,
minus the two-minute exemption. The
excess measurements shall be reported
in actual per cent opacity averaged for
one clock minute or such other time pe-
riod deemed appropriate by the State.
Averages may be calculated either by
arithmetically averaging a minimum of
4 equally spaced data points per minute
or by integration of the monitor output
Some commentors raised questions
concerning the provisions in the proposed
regulations which allow the use of fuel
analysis for computing emissions of sul-
fur dioxide in lieu of installing a con-
tinuous monitoring device for this pol-
lutant. Of primary concern with the fuel
analysis approach among the com-
mentors was the frequency of the analy-
sis to determine the sulfur content of the
fuel. However, upon inspection of the
comments by the Agency, a more sig-
nificant issue has been uncovered. The
issue involves the determination of what
constitutes excess emissions when a fuel
analysis is used as the method to measure
source emissions. For example, the sulfur
content varies significantly within a load
of coal. i.e.. while the average sulfur
content of a total load of coal may be
within acceptable limits in relation to a
control regulation which restricts the
sulfur content of coal, it is probable that
portions of the coal may have a sulfur
content above the allowable level. Simi-
larly, when fuel oils of different specific
gravities are stored within a common
tank, such fuel oils tend to stratify and
may not be a homogeneous mixture.
Thus, at times, fuel oil in excess of allow-
able limits may be combusted. The ques-
tion which arises is whether the combus-
tion of this higher sulfur coal or oil is a
violation of an applicable sulfur content
regulation. Initial investigations of this
issue have indicated a relative lack of
specificity on the subject.
The Agency is confronted with this
problem not only in relation to specifying
procedures for the emission reporting re-
quirements for existing sources but also
in relation to enforcement considerations
for new sources affected by New Source
Performance Standards. At this time, a
more thorough investigation of the situ-
ation in necessary prior to promulgation
of procedures dealing with fuel analysis
for both oil and coal. At the conclusion
of this investigation, the Agency will set
forth its findings and provide guidance
to State and local control agencies on
this issue. In the meantime, the portion
of the proposed regulations dealing with
fuel analysis is being withheld from pro-
mulgation at this time. As such, States
shall not be required to adopt provisions
dealing with emission monitoring or re-
porting of sulfur dioxide emissions from
those sources where the States may
choose to allow the option of fuel anal-
ysis as an alternative to sulfur dioxide
monitoring. However, since the fuel
analysis alternative may not be utilized
by a source that has installed sulfur di-
oxide control equipment (scrubbers).
States shall set forth legally enforceable
procedures which require emission moni-
tors on such sources, where these emis-
sion monitoring regulations otherwise
require their installation.
Other Modifications to Proposed Reg-
ulations. In addition to reducing the
number of monitors required under the
proposed regulations, a number of modi-
fications to various procedures in the
proposed regulations have been con-
sidered and are included in the final
regulations. One modification which has
been made is the deletion of the require-
ment to install continuous monitors at
"the most representative" location The
final regulations require the placement
of an emission monitor at "a representa-
tive" location in the exhaust gas system.
In many cases "the most representative"
location may be difficult to locate and
may be inaccessible without new plat-
forms, ladders, etc.. being installed. Fur-
ther, other representative locations can
provide adequate information on pollut-
ant emissions if minimum criteria for
selection of monitoring locations are ob-
served. Guidance in determining a repre-
sentative sampling' location is contained
within the Performance Specification
for each pollutant monitor in the emis-
sion monitoring regulations for New
Source Performance Standards (Appen-
dix B. Part 60 of this Chapter). While
these criteria are designed for new
sources, they are also useful in deter-
mining representative locations for ex-
isting sources.
A further modification to the proposed
regulation is the deletion of the require-
ment for new performance tests when
continuous emission monitoring equip-
ment is modified or repaired. As pro-
posed, the regulation would have re-
quired a new performance test whenever
any part of the continuous emission
monitoring system was replaced. This
requirement was originally incorporated
in the regulations to assure the use of
a well-calibrated, finely tuned monitor.
Commentors pointed out that the re-
quirement of conducting new perform-
ance tests whenever any part of an in-
strument is changed or replaced is costly
and in many cases not required. Upon
evaluation of this comment, the Admin-
istrator concurs that performance tests
are not required after each repair or re-
placement to the system. Appropriate
changes have been made to the regula-
tions to delete the requirements for new
performance tests. However, the final
regulations require the reporting of the
various repairs made to the emission
monitoring system durine each quarter
to the State. Further, the State must
have Procedures to require sources to re-
port to the State on a quarterly basis in-
formation on the amount of time and the
reason why the continuous monitor was
not in operation. Also the State must
have legally enforceable procedures to
reouire a source to conduct a new per-
formance test whenever, on the basis of
available information, the State deems
sui-h test is necessary.
Trip timp period proposed for the in-
stallation of the required monitoring
system, i e.. one vpar after plan approval.
wns thought hv 21 commentors to be too
hripf. primarily because of lack of avail-
able instruments, the lack of trained per-
sonnel and the time available for instal-
lation of the required monitors. Eouip-
mcnt suppliers were contacted by the
Agp.ncv nnd thev confirmed the avail-
ability of emission monitors. However.
FEDERAL ICCISTER. VOL. 40, NO 1*4—MONDAY. OCTOBER 6, 197S
11-154
-------
RULES AND REGULATIONS
the Administrator has dctcimined that
the time necessary for purchase, instal-
lation and performance testniE of such
monitors may require more than one
year for certain installations, especially
where gaseous monitors arc required. In
order to provide sources with ample time.
the Agency has modified the final regula-
tions to allow States to adopt procedures
that will provide sources 18 months after
the approval or promulgation of the re-
vised SIP to satisfy the installation and
performance testing procedures required
by these continuous monitoring regula-
tions. A provision is also included to al-
low, on a case-by-case basis, additional
extensions for sources where good faith
efforts have been undertaken to purchase
and install equipment, but where such
installation cannot be accomplished
within the time period prescribed by
the regulations.
A number of State and local agencies
also commented on the lack of time pro-
vided sources to install the monitors re-
quired by the proposed regulations.
These agencies also indicated that they
must Acquire sufficient skilled manpower
to implement the regulations, such as
personnel to provide guidance to sources.
to monitor performance tests and to
analyze the emission data that are to be
submitted by the sources. Further, some
State agencies indicated that more than
six months was needed to develop the
necessary plan revisions. Most State
agencies who commented stated that one
year should be provided to allow States
to revise their SIP's The Administrator
is aware of the various priorities which
confront State and local agencies at this
time 'e.g . compliance schedules, enforce-
ment actions, litigation proceedings, re-
evaluation of adequacy of SIP's to attain
and maintain national standards, etc.)
and, as such, believes that a six-month
postponement in the submittal of plan
revisions to require emission monitoring
and reporting is justified and prudent.
Hence, States must submit plan revisions
to satisfy the requirements of this sec-
tion within one year of promulgation of
these regulations in the FEDERAL REGIS-
TER. However. States are advised that
such plan revisions may be submitted
any time prior to the final date, and are
encouraged to do so where possible.
The proposed regulations provided the
States with the option of allowing sources
to continue to use emission monitoring
equipment that does not meet perform-
ance specifications set forth in the regu-
lations for up to five years from the date
of approval of the State regulations or
EPA promulgation. Some commenters
asked that this provision be extended
indefinitely. In some cases they indicated
they had recently purchased and had
already installed monitoring systems
which were only marginally away from
meeting the applicable performance spec-
ifications. The Agency believes, how-
ever, that such a modification to the pro-
posed regulations should not be allowed.
It is believed that such a provision would
result in inadequate monitoring systems
being maintained after their useful life
has ended. Though some monitoring sys-
tems will probably last longer than five
years, it IK belie\cd that tins time period
\iill provide adequate time to amortize
the cost of such equipment In cases
where existing emission monitors arc
known not to provide reasonable esti-
mates of emissions. States should con-
sider more stringent procedures to pro-
vide a more speedy retirement of such
emission monitoring systems.
Some commentors raised the question
of whether existing oxygen monitors
which are installed in most fossil fuel-
fired steam generating boilers to monitor
excess oxygen for the purposes of com-
bustion control could be used to satisfy
the requirement for monitoring oxygen
under the proposal Upon investigation.
it has been determined that, in some
cases, such oxygen monitors may be used
provided that they are located so that
there is no influx of dilution air between
the oxygen monitor and the continuous
pollutant monitor In some cases, it may
be possible to install the continuous
monitoring device at the same location
as the existing oxygen monitor Care
should be taken, however, to assure that
a representative sample is obtained Be-
cause of the various possibilities that
may arise concerning the usefulness of
existing oxygen monitors, the State
should determine, after a case-by-case
review, the acceptability of existing oxy-
gen monitors.
Another technical issue which was
raised suggested that continuous emis-
sion monitors which provide direct
measurements of pollutants in units com-
parable to the emission limitations and
other devices not specifically identified
in the proposed regulations are avail-
able for purchase and installation The
Agency is aware that various monitor-
ing systems exist but has not as yet de-
termined specific performance specifica-
tions for these monitoring systems that
are directly applicable to the source
categories covered by these regulations.
However, it is not EPA's intent to deny
the use of any equipment that can be
demonstrated to be reliable and accurate.
If monitors can be demonstrated to pro-
vide the same relative degree of accuracy
and durability as provided by the per-
formance specifications in Appendix B
of Part 60, they shall generally be ac-
ceptable to satisfy the requirements of
these regulations under Section 3.9 of
Appendix P. Further, where alternative
procedures (e.g.. alternate procedures
for conversion of data to units of appli-
cable regulations) can be shown by the
State to be equivalent to the procedures
set forth in Appendix P of these regula-
tions, then such alternate procedures
may be submitted by the State for ap-
proval by EPA Section 3 9 of Appendix P
identifies certain examples where alter-
native emission monitoring systems or
alternative procedures will generally be
considered by the Agency for approval.
It should be noted that some sources
may be unable to comply with the regu-
lations because of technical difficulties,
(e.g, the presence of condensed water
vapor In the flue gas), physical limita-
tions of accessibility at the plant facility,
or. in other cases, because of extreme
economic hardship States should use
their judgment in implementing these
requirements in such cases Section 6 of
Appendix P of this Part provides various
examples where the installation of con-
tinuous emission monitors would not be
feasible or reasonable. In such cases
alternate emission monitoring (and re-
porting' by more routine methods, such
as manuai stack testing, must be re-
quired States in preparing their revised
SIP must set forth and describe the cri-
teria they will use to identify such un-
us'jal cases, and must further describe
the alternative procedures they will im-
plement to otherwise satisfy the intent of
these regulations States are advised that
this provision is intended for unusual
cases, and, as such, should not be widely
applied.
It was pointed out by some com-
mentors that carbon dioxide monitors
could probably be used in lieu of oxygen
monitors to provide information to con-
vert emission data to the units of the
applicable State regulation Detailed
discussion of the technical merits and
limitations of this approach is discussed
in the Preamble to the Part 60 Regula-
tions As pointed out in that Preamble.
such monitors may be used in certain
situation-; Modifications have therefore
been made 'to the Part 51 regulations to
allow the use of such monitors which in-
clude references to technical specifica-
tions contained in Part 60 for carbon di-
oxide monitors. Also, the cycling time for
oxygen monitors has been changed from
one hour to 15 minutes to correspond to
the specification in Part 60. The differ-
ence between cycling times in the two
proposals was an oversight. The cycling
time for carbon dioxide monitors will
also be 15 minutes as in Part 60.
A number of other miscellaneous tech-
nical comments were also received. Com-
mentors indicated that the proposed ex-
emption for opacity monitoring require-
ments that may be granted to oil-fired
and gas-fired steam generators should
also apply to units burning a combina-
tion of these fuels. The Administrator
concurs with this suggestion and an ex-
emption for such sources burning oil and
pas has ben provided in the final regu-
lations subject to the same restrictions
as are imposed on oil-fired steam
generators.
As previously indicated, the regula-
tions for emission monitoring for exist-
ing sources refer in many cases to the
specific performance specifications set
forth in the emission monitoring regula-
tions for new. sources affected by Part 60
Many of the comments received on the
proposed reeulations in effect pointed to
issues affecting both proposals. In many
cases, more specific technical issues are
discussed in the Preamble to the Part 60
Regulations and as such the reader Is
referred to that Preamble Specifically,
the Part 60 Preamble addresses the fol-
lowing topics: data handling and report-
ing techniques: requirements for report-
ing repairs and replacement parts used;
location of monitoring instruments;
changes to span requirements, operating
HDHAL UGISTM, VOL. 40, NO. 1*4—MONDAY, OCTOIU *, 1*75
11-155
-------
RULES AND REGULATIONS
frequency requirements, sulfuric ncid and
nitric arid plant conversion factors:
and, for opacity monitoring equipment.
changes in the cycling time and in alipn-
ment procedures The reader is cau-
tioned, however, that specific reference
to regulations in the Part 60 Preamble
is strictly to federal New Source Perform-
ance Regulations rather than State and
local control agency regulations which
affect existing sources and which are part
of an applicable plan
In addition to the many technical
comments received, a number of legal
issues were raised Several commentors
questioned EPA's statutory authority to
promulcate these regulations and pointed
out other alleged legal defects in the pro-
posal. The Administrator has considered
these comments, and has found them un-
persuasive.
One commentor argued that new 40
CFR 51.19(e> will require "revisions" to
existing state plans: that'"revisions" may
be called for under Section 110(a> (2(H>
of the Clean Air Act only where EPA has
found that there are "improved or more
expeditious methods" for achieving am-
bient standards or that a state plan Is
"substantially inadequate" to achieve the
standards: that the new regulation is
based upon neither of these findings; and
that therefore there is no statutory au-
thority for the regulation. This argu-
ment fails to take cognizance of Section
JllO(a) (21 (F> (ii) of the Act, which man-
dates that all state implementation plans
contain self-monitoring requirements.
The fact that EPA originally accepted
plans without these requirements be-
cause of substantial uncertainty as to the
reliability of self-monitoring equipment
does not negate the mandate of the
litatute.
In essence, new 5 51.19(e) does not call
lor "revisions" as contemplated by the
Act. but for supplements to the original
plans to make them complete. At any
rate, it is the Administrator's judgment
that the new self-monitoring require-
ments will result in a "more expeditious"
achievement of the ambient standards.
Since these requirements are valuable
enforcement tools and indicators of mal-
functions, they should lead to a net de-
crease in emissions.
Other commentors argued that even if
EPA has statutory authority to require
self-monitoring, it has no authority to
impose specific minimum requirements
lor state plans, to require "continuous"
monitoring, or to require monitoring of
oxygen, which is not a pollutant These
comments fail to consider that a basic
precept of administrative law is that an
agency may fill in the broad directives of
legislation with precise regulatory re-
quirements. More specifically, the Ad-
ministrator has authority under Section
30Ha) of the Clean Air Act to promul-
gate "such regulations as are necessary
to carry out his functions under the Act".
Courts have long upheld the authority of
agencies to promulgate more specific re-
quirements than are set forth in en-
abling legislation, so long as the require-
ments are reasonably related to the pur-
poses of the legislation. Since the Act
requires self-monitoring without further
guidance. EPA surely has the authority
to set specific rp(|uirements in order to
carry out its function of assuring that the
Act is properly implemented
In EPA's Judcnient. the requirements
set forth in 5 51 19 are necessary to
assure that each state's self-monitoring
program is sufficient to comply with the
Act's mandate The fact that oxygen and
carbon dioxide are not air pollutants
controlled under the Act is legally ir-
relevant, since in EPA's judgment, they
must be monitored in order to convert
measured emission data to units of emis-
sion standards
Other commentors have argued that
the self-monitoring requirements violate
the protection against self-incrimination
provided in the Fifth Amendment to the
U S. Constitution, and that the informa-
tion obtained from the monitoring is so
unreliable as to be invalid evidence for
use in court.
There are two reasons why the self-
incrimination argument is invalid First,
the self-incrimination privilege does not
apply to corporations, and it is probable
that a great majority of the sources cov-
ered by these requirements will be owned
by corporations. Secondly, courts have
continually recognized an exception to
the privilege for "records required by
law", such as the self-monitoring and
reporting procedures which are required
by the Clean Air Act. As to the validity
of evidence issue, in EPA's opinion, the
required performance specifications will
assure that self-monitoring equipment
will be sufficiently reliable to withstand
attacks in court.
Finally, some comments reflected a
misunderstanding of EPA's suggestion
that states explore with counsel ways to
draft their regulations so as to automati-
cally incorporate by reference future
additions to Appendix P and avoid the
time-consuming plan revision process.
(EPA pointed out that public participa-
tion would still be assured, since EPA's
proposed revisions to Appendix P would
always be subject to public comment on
a nation-wide basis.)
EPA's purpose was merely to suggest
an approach that a state may wish to
follow if the approach would be legal
under that state's law. EPA offers no
opinion as to whether any state law
would allow this. Such a determination
is up to the individual states.
Summary of Revisions and Clarifica-
tions to the Proposed Regulations.
Briefly, the revisions and clarifications to
the proposed regulations include:
(DA clarification to indicate that con-
tinuous emission monitors are not re-
quired for sources unless such sources
are subject to an applicable emission
limitation of an approved SIP.
(2> A revision to require emission
monitors for oxides of nitrogen in only
those AQCR's where the Administrator
has specifically called for a control
strategy for nitrogen dioxide.
(3) A revision to include a general pro-
vision to exempt any source that clearly
demonstrates that it will cease operation
ixithm fi\p years of the inclusion of moni-
tonnf: icquircments for the source in
Appendix P
'4> Revisions to exempt smaller-sized
sources and infrequently used sources
within the specified source categories
<5> A reusion to the data reporting
requirements to-require the submitlal bv
the source of the State, emission data in
excess of the applicable emission limita-
tion for both opacity and gaseous pol-
lutants, rather than all measured data, as
proposed A provision has been added to
require information on the cause of all
noted violations of applicable regulations.
'61 A clarification to indicate that the
continuous monitoring of oxygen is not
required unless the continuous monitor-
ing of sulfur dioxide and/or nitrogen
oxides emissions is required by the appli-
cable SIP
(7) A revision to allow the placement
of continuous emission monitors at "a
representative location" on the exhaust
gas system rather than at "the most
representative location" as required by
the proposed regulations.
A modification to provide sources
18 months rather than one year after
approval or promulgation of the revised
SIP to comply with the continuous moni-
toring regulations adopted by the States.
(10) A modification to provide States
one year, rather than the six months
after the promulgation of these regula-
tions in the FEDERAL REGISTER to submit
plan revisions to satisfy the requirements
promulgated herein.
Requirements of States. States shall be
required to revise their SIP's by Octo-
ber 6, 1976 to include legally enforceable
procedures to require emission monitor-
ing, recording and reporting, as a mini-
mum for those sources specified in the
regulations promulgated herein. While
minimum requirements have been estab-
lished. States may, as they deem appro-
priate, expand these requirements.
The regulations promulgated herein
have been revised in light of the various
comments to generally provide a more
limited introduction into this new meth-
odology Cooperation among affected
parties, i.e., State and local control agen-
cies, sources, instrument manufacturers
and suppliers and this Agency is neces-
sary to mrv-e successfully forward in
these areas of emission monitoring and
reporting prescribed in the Clean Air
Act. Assistance can be obtained from the
EPA Regional Offices in relation to the
technical and procedural aspects of these
i egulations.
Copies of documents referenced in this
Preamble are available for public inspec-
tion at the EPA Freedom of Information
Center. 401 M Street, S.W., Washington,
D.C. 20460. The Agency has not pre-
pared an environmental impact state-
ment for these regulations since they
HDIIAl REGISTER, VOL. 40, NO 1*4—MONDAY, OCTOIER 6, 1*75
II-156
-------
RULES AND REGULATIONS
were proposed (September 11, 19741 prior
to the effective date for requirme volun-
tary environmental impact statement.1;
on EPA's regulatory actions (see 39 FR
16186, May 7, 1974).
The regulations set forth below are
promulgated under the authority of sec-
tions 110(a>(2)(FHii)-(iii) and 301(a>
of the Clean Air Act, as amended [42
U.S.C. 1857c-5(FMii>-(iu>. 1857g
(*) 1 and are effective November 5, 1975.
Dated: September 23.1975.
JOHN QUARLES,
Acting Administrator.
REFERENCES
1. Jenkins. R E . Strategies and Air Stand-
ards Division. OAQPS. EPA. Memo to R L.
AJax, Emission Standards and Engineering
Division. OAQPS. EPA. Emission Monitoring
Costs February 27. 1975
2. Young. D. E.. Control Programs Develop-
ment Division, OAQPS, EPA Memo to E. J.
LlllIs. Control Programs Development Di-
vision, OAQPS, EPA. Emission Source Data
for In-StacK Monitoring Regulations. June 4,
1975.
1. Section 51.1 is amended by adding
paragraphs (z), (aa). (bb), Such procedures shall require the
source owner or operator to submit in-
formation relating to emissions and
operation of the emission monitors to the
State to the extent described in Appendix
P as frequently or more frequently RS
described therein.
(5) Such procedures shall provide that
sources subject to the requirements of
551.19(e>(2> of this section shall have
installed all necessary equipment and
shall have begun monitoring and record-
ing within 18 months of (1) the approval
of a State plan requiring monitoring for
that source or (2) promulgation by the
Agency of monitoring requirements for
that source. However, sources that have
made good faith efforts to purchase, in-
stall, and begin the monitoring and re-
cording of emission data but who have
been unable to complete such installa-
tion within the time period provided may
be given reasonable extensions of time as
deemed appropriate by the State.
< 6) States shall submit revisions to the
applicable plan which implement the
provisions of this section by October 6,
1976.
3. In Part 51. Appendix P is added as
follows:
• • • • •
APPENDIX P—MINIMUM EMISSION MONITORING
REQUIREMENTS
1.0 Purpose. This Appendix P sets forth
the minimum requirements for continuous
emission monitoring and recording that each
State Implementation Plan must Include In
order to be approved under the provisions of
40 CFR 51 10(e). These requirements Include
the source categories to be affected: emission
monitoring, recording, and reporting re-
quirements Jor these sources; performance
specifications for accuracy, reliability, and
durability of acceptable monitoring systems:
and techniques to convert emission data to
units of the applicable State emission stand-
ard Such data must be reported to the State
as an Indication of whether proper mainte-
nance and operating procedures arc befog
utilized by nourri* operators to maintain
emission levels at or below emission stand-
ards Such data may be used directly or in-
directly for compliance determination or any
other purpose deemed appropriate by the
State Though the monitoring requirements
are specified In detail. States are ghen some
flexibility to resolve difficulties that may
arise during the Implementation of these
regulations
1 1 Applicability
The State plan shall require the owner or
operator of i«.n emission source In a category
listed In this Appendix to: (1) Install, cali-
brate, operate, and maintain all monitoring
equipment necessary for continuously moni-
toring the pollutants specified In this Ap-
pendix for the applicable source category.
and (2) complete the Installation and per-
formance tests of such equipment and begin
monitoring and recording within 18 months
of plan approval or promulgation. The source
categories and the respective monitoring re-
quirements are listed below.
1.1.1 Fossil fuel-fired steam generators, as
specified In paragraph 2 1 of this appendix.
shall be monitored for opacity, nitrogen
oxides emissions, sulfur dioxide emissions,
and oxygen or carbon dioxide.
1.1.2 Fluid bed catalytic cracking unit
catalyst regenerators, as specified in para-
graph 2.4 of this appendix, shall be moni-
tored for opacity.
1.1.3 Sulfuric acid plants, as specified In
paragraph 2.3 of this appendix, shall be
monitored for sulfur dioxide emissions
1.1.4 Nitric acid plants, as specified In
paragraph 2.2 of this appendix, shall be
monitored for nitrogen oxides emissions.
1.2 Exemption!;.
The States may Include provisions within
their regulations to grant exemptions from
the monitoring requirements of paragraph
1.1 of this appendix for any source which Is:
1.2.1 subject to a new source performance
standard promulgated In 40 CFR Part 60
pursuant to Section 111 of the Clean Air
Act: or
1.2 2 not subject to an applicable emission
standard of an approved plan; or
1.2 3 scheduled for retirement within 5
years after Inclusion of monitoring require-
ments for the source In Appendix P. provided
that adequate evidence and guarantees are
provided that clearly show that the source
will cease operations prior to such date.
1.3 Extensions
States may allow reasonable extensions of
the time provided for Installation of monitors
for facilities unable to meet the prescribed
tlmeframe (1 e. 18 months from plan ap-
proval or promulgation) provided the owner
or operator of such facility demonstrates that
good faith efforts have been made to obtain
and Install such devices within such pre-
scribed tlmeframe.
1.4 Monitoring System Mai I unction.
The State plan may provide a temporary
exemption from the monitoring and report-
Ing requirements of this appendix during any
period of monitoring system malfunction,
provided that the source owner or operator
shows, to the satisfaction of the State, that
the malfunction was unavoidable and Is
being repaired as e\pedltlously as practicable
20 Minimum Monitoring Requirement
States must, as a minimum, require the
sources listed in paragraph 1.1 of this appen-
dix to meet the following basic requirements
2 1 Fossil furl-fired steam generators.
Each fossil fuel-fired steam generator, ex-
cept as provided In the following subpara-
graphs. with an annual average capacity fac-
tor of greater than 30 percent, as reported to
the Federal Power Commission for calendar
year 1074. or as otherwise demonstrated to
the State by the owner or operator, shall con-
form with the following monitoring require-
ments when such facility Is subject to an
emission standard of an applicable plan for
the pollutant In question.
FEDERAL REGISTER, VOL 40, NO. 194—MONDAY, OCTOBER t. 1f7S
11-157
-------
RULES AND REGULATIONS
211 A continuous monitoring system for
the measurement of opacity which meets the
performance' specifications of paragraph
3.1.1 of this appendix shall be Installed, cali-
brated, maintained, and operated In accord-
ance with the procedures of this appendix bj
the owner or operator of any such stenm
generator of greater than 250 million BTU
per hour heat Input except where-
a 1.1.1 gaseous fuel In the only fuel burned.
or
2.1.1.2 oil or a mixture of gas and oil are
the only fuels burned and the source Is able
to comply with the applicable paniculate
matter and opacity regulations without utili-
zation of paniculate matter collection
equipment, and where the source has never
been found, through any administrative or
Judicial proceedings, to be In violation of any
visible emission standard of the applicable
plan.
2.1.2 A continuous monitoring system for
the measurement of sulfur dioxide which
meets the performance specifications of para-
graph 3.1.3 of this appendix shall be Installed.
calibrated, maintained, and operated on any
fossil fuel-fired sieam generator of greater
than 250 million BTU per hour heat Input
which has Installed sulfur dioxide pollutant
control equipment
2.1.3, A continuous monitoring system for
the measurement of nitrogen oxides which
meets the performance specification of para-
graph 3 1.2 of this appendix shall be Installed.
calibrated, maintained, and operated on fos-
sil fuel-fired steam generators of greater
than 1000 million BTU per hour heat Input
when such facility Is located In an Air Qual-
ity Control Region where the Administrator
has specifically determined that a control
strategy for nitrogen dioxide Is necessary to
mttaln the national standards, unless the
•ource owner or operator demonstrates dur-
ing source compliance tests as required by
the State that such a source emits nltroRen
oxides at levels 30 percent or more below the
emission standard within the applicable
plan.
2.1 4 A continuous monitoring system for
the measurement of the percent oxygen or
cnrbon dioxide which meets the perform-
ance specifications of paragraphs 3 1 4 or
3 1.5 of this appendix shall be Installed, cali-
brated, operated, and maintained on fossil
fuel-fired steam generators where measure-
ments of oxygen or carbon dioxide in the flue
gas are required to convert either sulfur di-
oxide or nitrogen oxides continuous emis-
sion monitoring data, or both, to units of
the emission standard within the applica-
ble plan
2.2 Nitric aria plants.
Each nitric acid plant of greater than 300
tons per day production capacity, the pro-
duction capacity being expressed as 100 per-
cent acid, located in an Air Quality Control
Region where the Administrator has specif-
ically determined that a control strategy for
nitrogen dioxide Is necessary to attain the
national standard shall Install, calibrate.
maintain, and operate a continuous moni-
toring system for the measurement of nitro-
gen oxides which meets the performance
specifications of paragraph 3.12 for each
nitric acid producing facility within such
plant.
2 3 Sill/uric acid plants
Each Sulfurlc acid plant of greater than
300 tons per day production capacity, the
production being expressed as 100 percent
acid, shall Install, calibrate, maintain and
operate a continuous monitoring system for
the measurement of sulfur dioxide which
meet* the performance specifications of 3 1.3
for each sulfurlc acid producing facility
within such plant.
24 Fluid bed catalytic cracking unit cata-
lyst regenerators at petroleum reflnerie's.
Each catalyst regenerator for fluid bed
catalytic cracking units of greater than 20,-
000 barrels per day fresh feed capacity shall
Install, calibrate, maintain, and operate a
continuous monitoring system for the meas-
urement of opacity which meets the per-
formance specifications of 3 1.1
30 Minimum specifications
All State plans shall require owners or op-
erators of monitoring equipment Installed
to comply with this Appendix, except as pro-
vided In paragraph 3 2, to demonstrate com-
pliance with the following performance spec-
ifications
3 1 Performance specifications
The performance specifications set forth
in Appendix B of Part 60 are Incorporated
herein by reference, and shall be used by
States to determine acceptability of monitor-
Ing equipment Installed pursuant to this
Appendix except that (1) where reference Is
made to the "Administrator" In Appendix B.
Part 60, the term "State" should be Inserted
for the purpose of this Appendix (e.g.. In
Performance Specification 1. 1.2. " . . moni-
toring systems subject to approval by the
Administrator," should be interpreted as.
". . . monitoring systems subject to approval
by the State"), and (2) where reference is
made to the "Reference Method" In Appendix
B. Part 60, the State may allow the use of
either the State approved reference method
or the Federally approved reference method
as published In Part 60 of this Chapter. The
Performance Specifications to be used with
each type of monitoring system are listed
below.
3.1.1 Continuous monitoring systems for
measuring opacity shall comply with Per-
formance Specification ].
312 Continuous monitoring systems for
measuring nitrogen oxides shall comply with
Performance Specification 2
3.1.3 Continuous monitoring systems for
measuring sulfur dioxide shall comply with
Performance Specification 2.
3.1 4 Continuous monitoring systems for
measuring oxygen shall comply with Per-
formance Specification 3.
3.1 5 Continuous monitoring systems for
measuring carbon dioxide shall comply with
Performance Specification 3.
3.2 Exemptions.
Any source which has purchased an emis-
sion monitoring system(s) prior to Septem-
ber 11, 1974, may be exempt from meeting
such test procedures prescribed In Appendix
B of Part 60 for a period not to exceed five
years from plan approval or promulgation.
3.3 Calibration Gases.
For nitrogen oxides monitoring systems In-
stalled on fossil fuel-fired steam generators
the pollutant gas used to prepare calibration
gas mixtures (Section 2 1, Performance Spec-
ification 2, Appendix B, Part 60) shall be
nitric oxide (NO). For nitrogen oxides mon-
itoring systems, installed on nitric acid plants
the pollutant gas used to prepare calibration
gas mixtures (Section 2.1, Performance Spec-
ification 2. Appendix B. Part 60 of this Chap-
ter) shall be nitrogen dioxide (NO,). These
gases shall also be used for dally checks under
paragraph 3.7 of this appendix as applicable
For sulfur dioxide monitoring systems In-
stalled on fossil fuel-fired steam generators
or sulfuric acid plants the pollutant gas used
to prepare calibration gas mixtures (Section
2.1. Performance Specification 2. Appendix B.
Part, 60 of this Chapter) shall be sulfur di-
oxide (SO_.) Span and zero gases should be
traceable to National Bureau of Standards
reference, gases whenever these reference
gases are available. Every six months from
dnte of manufacture, span and zero gases
shall be reanalyzed by conducting triplicate
analyses using the reference methods In Ap-
pendix A. Part 60 of this chapter as follows:
for sulfur dioxide, use Reference Method 6:
for nitrogen oxides, use Reference Method 7:
and for carbon dioxide or oxygen, use Ref-
erence Method 3 The gases may b; analyzed
at less frequent Intervals if longer shelf lives
are guaranteed by the manufacturer
3 4 Cycling times
Cycling times include the total time a
monitoring system requires to sample.
analyze and record an emission measurement
3.4 1 Continuous monitoring systems for
measuring opacity shall complete a mini-
mum of one cycle of operation (sampling.
analyzing, and data recording) for each suc-
cessive 10-second period
342 Continuous monitoring systems for
measuring oxides of nitrogen, carbon diox-
ide, oxygen, or sulfur dioxide shall complete
a minimum of one cycle of operation (sam-
pling, analyzing and data recording) for
each successive 15-mlnute period.
3 5 Monitor location
State plans shall require all continuous
monitoring systems or monitoring devices to
be installed such that representative meas-
urements of emissions or process parameters
(I e, oxygen, or carbon dioxide) from the af-
fected facility are obtained. Additional guid-
ance for location of continuous monitoring
systems to obtain representative samples are
contained in the applicable Performance
Specifications of Appendix B of Part 60 of
this Chapter.
3.6 Combined effluents
When the effluents from two or more af-
fected facilities of similar design and operat-
ing characteristics are combined before being
released to the atmosphere, the State plan
may allow monitoring systems to be Installed
on the combined effluent When the affected
facilities are not of similar design and operat-
ing characteristics, or when the effluent from
one aflected facility is released to the atmos-
phere through more than one point, the State
should establish alternate procedures to Im-
plement the Intent of these requirements
3.7 Zero and drift
State plans shall require owners or opera-
tors of all continuous monitoring systems
Installed In accordance with the require-
ments of this Appendix to record the 7,ero and
spun drift In accordance with the method
prescribed by the manufacturer of such In-
struments: to subject the Instruments to the
manufacturer's recommended zero and span
check at least once dally unless the manu-
facturer has recommended adjustment* at
shorter Intervals, in which case such recom-
mendations shall be followed: to adjust the
zero and span whenever the 24-hour zero
drift or 24-hour calibration drift limits of
the applicable performance specifications in
Appendix B of Part 60 are exceeded: and to
adjust continuous monitoring systems refer-
enced bv paragraph 3.2 of this Appendix
whenever the 24-hour zero drift or 24-hour
calibration drift exceed 10 percent of the
emission standard.
3 8 Span.
Instrument span should be approximately
200 per cent of the expected Instrument data
dlsplnv output corresponding to the emission
standard for the source
3.9 Altcrnafii'c procedures and require-
ments.
In cases where States wish to utilize differ-
ent, but equivalent, procedures and require-
ments for continuous monitoring systems.
the State plan must provide a description of
such alternative proceduers for approval by
the Administrator Some examples of-situa-
tions that may require alternatives follow:
3.9.1 Alternative monitoring requirements
to accommodate continuous monitoring sys-
tems that require corrections for stack mois-
ture conditions (eg , an Instrument measur-
ing steam generator SO. emissions on a wet
basis could be used with an Instrument mea-
suring oxygen concentration on a dry basis
if acceptable methods of mei"' ' ~ itacx
moisture conditions are useu to anow ac-
FtDEKAl IIGISTH. VOL. 40. NO. 194—MONDAY. OCTOIER », I9T5
11-158
-------
RULES AND REGULATIONS
curate adjustment of the measured SO, con-
centration to dry basis )
3 9.2 Alternative locations for Installing
continuous monitoring systems or monltor-
Jng devices when the owner or operator can
demonstrate thai Installation at alternative
locations will enivble accurate and represent-
ative measurements.
3.9 3 Alternative procedures for perform-
ing calibration checks (eg. some Instruments
may demonstrate superior drift characteris-
tics that require checking at less frequent
Intervals).
394 Alternative monitoring requirement*!
when the effluent from one affected facility or
the combined effluent from two or more
Identical affected facilities Is released to the
atmosphere through more than one point
(e.g.. an extractive, gaseous monitoring sys-
tem used at several points may be approved
If the procedures recommended arc suitable
for generating accurate emission averages)
3 9 5 Alternative continuous monitoring
systems that do not meet the spectral re-
sponse requirements In Performance Speci-
fication ]. Appendix B of Part 60, but ade-
quately demonstrate a definite and consistent
relationship between their measurements
and the opacity measurements of a system
complying with the requirements In Per-
formance Specification 1 The State may re-
quire that such demonstration be performed
(or each affected facility.
4 0 Minimum data requirements
The following paragraphs set forth the
minimum data reporting requirements neces-
sary to comply with 551 19(e) (3) and (4).
4 1 The State plan shall require owners
or operators of facilities required to Install
continuous monitoring systems to submit a
written report of excess emissions for each
calendar quarter and the nature and cause of
the excess emissions. If known The averaging
period used for data reporting should be
established by the State to correspond to the
averaging period specified In the emission
test method used to determine compliance
with an emission standard for the pollutant'
source category In question. The required re-
port shall Include, as a minimum, the data
stipulated In this Appendix.
4.2 For opacity measurements, the sum-
mary shall consist of the magnitude In actual
percent opacity of all one-minute (or such
other time period deemed appropriate by the
State) averages of opacity greater than the
opacity standard In the applicable plan for
each hour of operation of the facility. Aver-
age values may be obtained by Integration
over the averaging period or by arithmeti-
cally averaging a minimum of four equally
spaced, instantaneous opacity measurements
per minute. Any time period exempted shall
be considered before determining the excess
averages of opacity (e.g. whenever a regu-
lation allows two minutes of opacity meas-
urements In excess of the standard, the State
shall require the source to report all opacity
averages. In any one hour. In excess of the
standard, minus the two-minute exemp-
tion). If more than one opacity standard
applies, excess emissions data must be sub-
mitted In relation to all such standards
4.3 For gaseous measurements the sum-
mary shall consist of emission averages. In
the units of the applicable standard, for each
averaging period during which the appli-
cable standard was exceeded.
4.4 The' date and time Identifying each
period during which the continuous moni-
toring system was Inoperative, except for
zero and span checks, and the nature of
svstem repairs or adjustments shall be re-
ported. Th* State may require proof of con-
tinuous monitoring system performance
whenever system repairs or adjustments have
been made.
4 5 When no excess emissions have oc-
curred and the continuous monitoring sjs-
temls) ha\e not been Inoperative, repaired.'
or adjusted, such Information shall be In-
cluded In the report.
4 6 The State plan shall require owners or
operators of affected facilities to maintain
a file of all Information reported In the quar-
terly summaries, and all other data collected
either by the continuous monitoring system
or as necessary to convert monitoring data
to the units of the applicable standard for
a minimum of two years from the elate of
collection of such data or submission of
such summaries
6.0 Data Rcduftton
The State plnn shall require owners or
operators of affected facilities to use the
following procedures for convening moni-
toring data to units of the standard where
necessary- .
5.1 For fossil fuel-fired steam generators
the following procedures Khali be used to
convert gaseous emission monitoring dntn In
parts per million to g 'million cal lib 'million
BTU ) where necessary :
51.1 When the owner or operator of a
fossil fuel-fired steam generator elects under
subparagraph 2 1.4 of this Appendix to meas-
ure oxygen In the flue gases, the measure-
ments of the pollutant concentration and
oxygen concentration shall ench be on a dry
basis and the following conversion procedure
used •
( 2
Vsnii
5.1.2 When the owner or operator elects
under subparagraph 2.1 4 of this Appendix
to measure carbon dioxide In the flue gases.
the measurement of the pollutant concen-
tration and the carbon dioxide concentration
shall each be on a consistent basis (wet or
dry) and the following conversion procedure
used:
100
5 1.3 The values used In the equations un-
der paragraph 5 1 are derived as follows-
E = pollutant emission, g/mllllon
cal (Ib/mllllon BTU).
C = pollutant concentration, g'
' dscm (Ib/dscf). determined by
multiplying the average concen-
tration (ppm) for each hourly
period by 4.16V 10-' M g/dscm
per ppm (264-- 10-" M Ib/dscf
per ppm) where M = pollutant
molecular weight, g/g-mole lib/
Ib-mole) M = 64 for sulfur di-
oxide and 46 for oxides of nitro-
gen.
r,'rO., rnCO, = Oxygen or carbon dioxide vol-
ume (expressed as percent) de-
termined with equipment spec-
ified under paragraph 4.1.4 of
this appendix.
F, Fr = a factor representing a ratio of
the volume of dry flue gases
generated to the calorific value
of the fuel combusted (F), and
a factor representing a ratio of
the volume of carbon dioxide
generated to the calorific value
of the fuel combusted (F.) re-
spectively. Values of F and F.
are given in I 60.45U) of Part
60. as applicable
5.2 For sulfurlc acid plants the owner or
operator shall:
5 2 1 establish a conversion factor three
times dally according to the procedures to
I 6084(b) of this chapter,
5.2.2 multiply the conversion factor by the
average sulfur dioxide concentration In the
flue gases to obtain average sulfur dioxide
emissions In Kg/metric ton (Ib/short ton):
and
5.2 3 report the average sulfur dioxide
emission for each averaging period In excess
of the applicable emission standard in the
quarterly summary
S3 For nitric acid plants the owner or
operator shall.
53 1 establish a conversion factor accord-
Ing to the procedures of |6073(b) of this
chapter.
5 3.2 multiply the conversion factor by the
average nitrogen oxides concentration In the
flue gases to obtain the nitrogen oxides emis-
sions in the units of the applicable standard.
533 report the average nitrogen oxides
emission for each averaging period In excess
of the applicable emission standard. In the
quarterly summary
5 4 Any State may allow data reporting
or reduction procedures varying from those
set forth In this Appendix If the owner or
operator of a source shows to the satisfaction
of the State that his procedures are at least
as accurate as those In this Appendix Such
procedures may Include but are not limited
to. the following'
5.4 1 Alternative procedures for computing
emission averages that do not require Inte-
gration of data (e.g.. some facilities may dem-
onstrate that the variability of their emis-
sions Is sufficiently small to allow accurate re-
duction of data based upon computing aver-
ages from equally spaced data points over the
averaging period).
5 4.2 Alternative methods of converting pol-'
lutant concentration measurements to the
units of the emission standards
6 0 Special Consideration
The State plan may provide for approval, on
a case-by-case basis, of alternative monitor-
ing requirements different from the provi-
sions of Parts 1 through 5 of this Appendix If
the provisions of this Appendix (l.e . the In-
stallation of a continuous emission monitor-
ing system) cannot be Implemented by a
source due to physical plant limitations or
extreme economic reasons To make use of
this provision. States must Include In their
plan specific criteria for determining those
physical limitations or extreme economic.
situations to be considered by the State. In
such cases, when the State exempts any
source subject to this Appendix by use of this
provision from Installing continuous emis-
sion monitoring systems, the State shall set
forth alternative emission monitoring and
reporting requirements (e.g.. periodic manual
stack tests) to satisfy the Intent of these
regulations. Examples of such special cues
Include, but are not limited to, the following:
6.1 Alternative monitoring requirement*
may be prescribed when Installation of a con-
tinuous monitoring system or monitoring de-
vice specified by this Appendix would not pro-
vide accurate determinations of emissions
(e.g., condensed, uncomblned water vapor
may prevent an accurate determination of
opacity using commercially available con-
tinuous monitoring systems).
6.2 Alternative monitoring requirements
may be prescribed when the affected facility
Is Infrequently operated (e.g.. some affected
facilities may operate less than one month
per year).
63 Alternative monitoring requirements
may be prescribed when the State determines
that the requliements of this Appendix would
Impose an extreme economic burden on the
source owner or operator.
64 Alternative monitoring requirements
may be prescribed when the State determines
that monitoring systems prescribed by this
Appendix cannot be Installed due to physical
limitations at the facility.
|FK Doc 75-26566 Filed 10-3-75:8:45 am]
KDilAl IIGISTH, VOL. 40, NO IM—MONDAY. OCTOKR 6. 1*75
11-159
-------
SUMMARY OF TABLES OF MONITORING REGULATIONS
11-160
-------
Subpart
D
Da
TABLE #1
NSPS SOURCE CATEGORIES WHICH ARE
REQUIRED TO MONITOR CONTINUOUSLY
Source Category
STEAM GENERATORS
Solid Fossil Fuel
Liquid Fossil Fuel
Gaseous Fossil Fuel
ELECTRIC UTILITY STEAM
GENERATING UNITS
Solid Fossil Fuel
Liquid Fossil Fuel
Pollutant
Opacity
S02
NOX
Opacity
S02
NOX
NOV
Process
02 or C02
02 or C02
02 or C02
Opacity 02 or C02
S02 (at inlet and
outlet of control
device)
NOX
Opacity 02 or C02
S02 (at inlet and
outlet of control
device)
G
H
J
Gaseous Fossil Fuel
NITRIC ACID PLANTS
SULFURIC ACID PLANTS
PETROLEUM REFINERIES
FCCU
Combustion of Fuel
Gases
NO,
02 or C02
NO
'x
S02
Opacity
CO
S02 or
H2S
11-161
-------
Table #1, continued
Subpart
(cont'd)
TUVWX
AA
Source Category Pollutant
PETROLEUM REFINERIES (cont'd)
Sulfur Recovery Plant S02a, H2Sb, TRSb
IRON AND STEEL PLANTS
Process
PRIMARY COPPER SMELTERS
PRIMARY ZINC SMELTERS
PRIMARY LEAD SMELTERS
PHOSPHATE FERTILIZER PLANTS
COAL PREPARATION PLANTS
FERROALLOY PRODUCTION
FACILITIES
STEEL PLANTS:
ELECTRIC ANC FURNACES
Opacity
S02
Opacity
S02
Opacity
S02
Opacity
Opacity
Pressure loss
through venturi
scrubber water
supply pressure
Total pressure
drop across pro-
cess scrubbing
systems.
Exit gas temp.
pressure loss
through venturi
water supply
pressure to con-
trol equipment
Flowrate through
hood
Furnace power
input
Volumetric flow
rate through each
separately ducted
hood. Pressure
in the free space
inside the elect-
ric arc furnace.
a For oxidation control systems.
b For reduction control systems not followed by incineration.
11-162
-------
Table #1, continued
Subpart Source Category Pollutant Process
BB KRAFT PULP MILLS
Recovery Furnace Opacity
TRS (dry basis) 02 (dry basis)
Lime kiln, digester TRS (dry basis) 02 (dry basis)
system, brown stock washer
system, multiple effect evapo-
rator system, black liquor oxi-
dation system, or condensate
stripper system
Point of incineration of Temperature
effluent gases, brown stock
washer system, multiple effect
evaporator system, black liquor
oxidation system, or condensate
stripper system
Lime kiln or smelt dissolving Pressure loss of
tank using a scrubber the gas stream
through the con-
trol equipment
Scrubbing liquid
supply pressure
HH LIME MANUFACTURING PLANTS
Rotary Lime Kilns Opacity3 Pressure loss
of steam through
the scrubber
Scrubber liquid
supply pressure
Does not apply when there is a wet scrubbing emission control device.
-------
Table #1, continued
Subpart Source Category Pollutant Process
HH LIME MANUFACTURING PLANTS
(cont'd)
Lime Hydrator Scrubbing liquid
flow rate
Measurement of
the electric
current (amperes)
used by the
scrubber
11-164
-------
Subpart
TABLE #2
OPERATIONAL MONITORING REQUIREMENTS (NSPS)
(Non-Continuous)
Requirement
E.
F.
Incinerators
Portland Cement
Plants
Daily charging rates and hours of operation.
Daily procuction rates and kiln feed rates.
G. Nitric Acid Plants
H. Sulfuric Acid Plants
J. Petroleum Refineries
K. Storage Vessels for
Petroleum Liquids
0. Sewage Treatment
Plants
P. Primary Copper
Smelter
S. Primary Aluminum
Reduction Plants
Daily production rate and hours of operation.
The conversion factor shall be determined, as a
minimum, three times daily by measuring the con-
centration of sulfur dixoide entering the con-
verter.
Record daily the average coke burn-off rate and
hours of operation for any fluid catalytic
cracking unit catalyst regenerator subject to the
particulate or carbon monoxide standard.
Maintain a file of each type of petroleum liquid
stored and the dates of storage. Show when
storage vessel is empty. Determine and record
the average monthly storage temperature and true
vapor pressure of the petroleum liquid stored if:
(1) the petroleum liquid, as stored, has a vapor
pressure greater than 26 mm Hg but less than
78 mm and is stored in a storage vessol other
than one equipped with a floating roof, a vapor
recovery system or their equivalents; or (2) the
petroleum liquid has a true vapor pressure, as
stored, greater than 470 mm Hg and is stored in a
storage vessel other than one equipped with a
vapor recovery system or its equivalent.
Install, calibrate, maintain, and operate a flow
measuring device which can be used to determine
either the mass or volume of sludge charged to
the incinerator.
Keep a monthly record of the total smelter charge
and the weight percent (dry basis) of arsenic,
antimony, lead, and zinc contained in this
charge.
Determine daily, the weight of aluminum and anode
produced. Maintain a record of daily production
rates of aluminum and anodes, raw material feed
rates, and cell or potline voltages.
11-165
-------
Subpart
TABLE #2 (cont'd)
OPERATIONAL MONITORING REQUIREMENTS (NSPS)
(Non-Continuous)
Requirement
T. Phosphate Fertilizer
Industry: Wet-
Process Phosphoric
Acid Plants
U. Phosphate Fertilizer
Industry: Super-
phosphoric Acid
Plants
V. Phosphate Fertilizer
Industry: Diammon-
ium Phosphate Plants
W. Phosphate Fertilizer
Industry: Triple
Superphosphate
Plants
X. Phosphate Fertilizer
Industry: Granular
Triple Superphos-
phate Storage
Facilities
Z.
Ferroalloy Production
Facilities
AA.
Steel Plants:
Electric Arc
Furnaces
Determine the mass flow of phosphorus-bearing
feed material to the process. Maintain a daily
record of equivalent P205 feed.
Determine the mass flow of phosphorus-bearing
feed material to the process. Record daily the
equivalent ^2^5 feed.
Determine the mass flow of phosphorus-bearing
feed material to the process. Maintain a daily
record of equivalent ?2°5 feed.
Determine the mass flow of phosphorus-bearing
feed material to the process. Maintain a daily
record of equivalent ?2®5 feed.
Maintain an accurate accpunt of triple super-
phosphate in storage. Maintain a daily record
of total equivalent ?2®5 stored.
Maintain daily records of (1) the product;
(2) description of constitutents of furnace
charge, including the quantity, by weight;
(3) the time and duration of each tapping period
and the identification of material tapped (slag
or product); (4) all furnace power input data;
and (5) all flow rate data or all fan motor power
consumption and pressure drop data.
Maintain daily records of (1) the time and
duration of each charge; (2) the time and
duration of each tap; (3) all flow rate data;
and (4) all pressure data.
11-166
-------
TABLE #3
EMISSION LIMITATIONS (NSPS)
SUBPART
D Fossil Fuel-Fired
Steam Generators
Liquid fossil fuel
Solid fossile fuel
Gaseous fossil fuel
Mixture of fossil
fuel
POLLUTANT
Particulate
Opacity
S02
NOX
Particulate
Opacity
S02
NOX
Particulate
Opacity
NOX
Particulate
Opacity
S02
EMISSION LEVELS
43 ng/joule
(0.10 lb/106 Btu)
20% except 27% for 6 rain/hr
340 ng/joule
(0.80 lb/106 Btu)
130 ng/joule
(0.30 lb/106 Btu)
43 ng/joule
(0.10 lb/106 Btu)
20% except 27% for 6 min/hr
520 ng/joule
(1.2 lb/106 Btu)
300 ng/joule
(0.70 lb/106 Btu)
43 ng/joule
(0.10 lb/106 Btu)
20% except 27% for 6 min/hr
86 ng/joule
(0.20 lb/106 Btu)
43 ng/joule
(0.10 lb/106 Btu)
20% except 27% for 6 min/hr
y(340) + z(520) *
y + z
x(86) + y(130) + z(300)
x + y + z
* x = percentage of total heat input from gaseous fossil fuel
y = percentage of total heat input from liquid fossil fuel
z = percentage of total heat input from solid fossil fuel
11-167
-------
TABLE #3 (cont'd)
EMISSION LIMITATIONS (NSPS)
SUBPART
G Nitric Acid Plants
H Sulfuric Acid Plants
J Petroleum Refineries
Fluid catalytic
cracking unit
Glaus sulfur recovery
plant
N Iron and Steel Plants
(BOPF)
POLLUTANT
NO 2
Opacity
SO 2
H2S04 mist
Particulate
Opacity
CO
SO 2
TRS
H2S
Particulate
Opacity
P Primary Copper Smelters
Dryer Particulate
EMISSION LEVELS
1.5 kg/metric tons of acid
produced (4.0 Ib/ton of
acid produced)
10%
2 kg/metric tons of acid
produced (4.0 Ib/ton of
acid produced)
0.075 kg/metric tons of
acid produced (0.15 Ib/ton)
1.0 kg/1000 of coke burn-
off
30%
0.050%
0.025%
0.030%
0.0010%
50 mg/dscm
10%
>10% but <20% may occur
once per steel production
cycle
50 mg/dscm (0.022 gr/dscf)
11-168
-------
TABLE #3 (cont'd)
EMISSION LIMITATIONS (NSPS)
SUBPART
Roaster, smelting
furnace, copper
converter
Q Primary Zinc Smelters
Sintering machine
Roaster
R Primary Lead Smelters
Blast or reverberatory
furnace, sintering
machine discharge end
POLLUTANT
Opacity
SO 2
Sintering machine,
electric smelting
furnace, converter
T Phosphate Fertilizer
Industry: Wet Process
Phospheric Acid Plants
U Phosphate Fertilizer
Industry: Super-Phos-
phoric Acid Plants
V Phosphate Fertilizer
Industry: Diammonium
Phosphate
W Phosphate Fertilizer
Industry: Triple Super-
Phosphate
Particulate
Opacity
SO 2
Opacity
Particulate
Opacity
SO 2
Opacity
Total Fluorides
Total Fluorides
Total Fluorides
Total Fluorides
EMISSION LEVELS
20%
0.065%
50.mg/dscm (0.022 gr/dscf)
20%
0.065%
20%
50 mg/dscm (0.022 gr/dscf)
20%
0.065%
20%
10 g/metric ton of
(0.020 Ib/ton)
feed
5 g/metric ton of ?2°5 feed
(0.020 Ib/ton)
30 g/metric ton of P2°5 feed
(0.060 Ib/ton)
100 g/metric ton of equival-
ent P20s feed (0.20 Ib/ton)
11-169
-------
TABLE #3 (cont'd)
EMISSION LIMITATIONS (NSPS)
SUBPART
X Phosphate Fertilizer
Industry: Granular
Triple Superphosphate
POLLUTANT
Total Fluorides
EMISSION LEVELS
0.25 g/hr/metric ton of
equivalent P2C>5 stored
(5.0 x 10-4 lb/hr/ton)
Y Coal Preparation Plants
Thermal Dryer
Pneumatic coal
cleaning equipment
Processing and
conveying equipment,
storage systems, trans-
fer and loading systems
Z Ferroalloy Production
Facilities
Electric submerged
Particulate
Opacity
Particulate
Opacity
Opacity
Particulate
Dust handling
equipment
Opacity
CO
Opacity
0.070 g/dscm (0.031 gr/dscf)
20%
0.040 g/dscm (0.031 gr/dscf)
10%
20%
0.45 kg/MW-hr (0.99 Ib/MW-hr)
(high silicon alloys)
0.23 kg/MW-hr (0.51 Ib/MW-hr)
(chrome and manganese alloys)
15%
20%
10%
11-170
-------
TABLE #3 (cont'd)
EMISSION LIMITATIONS (NSPS)
SUBPART
POLLUTANT
AA Steel Plants
Electric Arc furnaces Particulate
Control device Opacity
Shop roof Opacity
Dust handling^
equipment
BB Kraft Pulp Mills
Recovery Furnace
Straight recovery
furnace
Cross recovery
furnace
Smelt dissolving
tank
Lime kiln
gaseous fuel
liquid fuel
Opacity
Particulate
Opacity
TRS
TRS
Particulate
TRS
TRS
Particulate
Particulate
Digester system, brown
stock washer system,
multiple-effect vaporation
system, black liquor
oxidation system or
condensate stripper TRS
EMISSION LEVELS
12 mg/dscm (0.0052 gr/dscf)
3%
0%, except:
20% - charging
40% - tapping
10%
0.10 g/dscm
35%
5 ppm
25 ppm
0.Ig/kg black liquor
(dry out)
0.0084 g/kg black liquor
(dry out)
8 ppm
0.15g/dscm
0.30g/dscm
5 ppm
11-171
-------
TABLE //3 (cont'd)
EMISSION LIMITATIONS (NSPS)
SUBPART
POLLUTANT
EMISSION LEVELS
HH Lime Manufacturing
Plants
Rotary Lime Kiln
Lime Hydrator
Particulate
Opacity
Particulate
0.15 kg/megagram of lime-
stone feed
10%
0.075 kg/megagram of lime
feed
11-172
-------
TABLE #4
PROPOSAL AND PROMULGATION DATES OF EMISSION LIMITATIONS FOR NSPS SOURCE CATEGORIES
Subpart
D
Da
E
F
G
H
I
J
K
L
M
N
0
P
Q
R
S
TUVWX
Y
Z
AA
BB
DD
HH
Source
Fossil Fuel Fired Steam Generators
Electric Utility Steam Generators
Incinerators
Portland Cement Plants
Nitric Acid Plants
Sulfuric Acid Plants
Asphalt Concrete Plants
Petroleum Refineries
Storage Vessels for Petroleum Liquids
Secondary Lead Smelters
Brass and Bronze Production
Iron and Steel. Plants
Sewage Treatment Plants
Primary Copper Smelter
Primary Zinc Smelter
Primary Lead Smelter
Primary Aluminum Reduction Plants
Phosphate Fertilizer Industry
Coal Preparation Plants
Ferroalloy Production Plants
Steel Plants: Electric Arc Furnaces
Kraft Pulp Mills
Grain Elevators
Lime Manufacturing
Promulgation
Date
12/23/71
6/11/79
12/23/71
12/23/71
12/23/71
12/23/71
3/08/74
3/08/74
3/08/74
3/08/74
3/08/74
3/08/74
3/08/74
1/15/76
1/15/76
1/15/76
1/26/76
8/06/75
1/15/76
5/04/76
9/23/75
2/23/78
8/03/78
3/07/78
Proposed
Date
8/17/71
9/18/78
8/17/71
8/17/71
8/17/71
8/17/71
6/11/73
6/11/73
6/11/73
6/11/73
6/11/73
6/11/73
6/11/73
10/16/74
10/16/74
10/16/74
10/23/74
10/22/74
10/24/74
10/21/74
10/21/74
9/24/76
1/03/773
8/03/78
3/03/77
a Suspended on 6/24/77.
11-173
-------
TABLE #5
NSPS CONTINUOUS MONITORING REQUIREMENTS
I. Installed and operational prior to conducting performance tests.1
II. Conduct monitoring system performance evaluations during performance
tests or 30 days thereafter.
III. Check zero and span drift at least daily (see Table #8).
IV. Time for cycle of operations (sampling, analyzing, and data recording).
A. Opacity - 10 seconds
B. Gas Monitors - 15 minutes
V. Installed to provide representative sampling
VI. Reduction of data.
A. Opacity - 6-minute average
B. Gaseous Pollutants - hourly average
VII. Source must notify agency, more than 30 days prior, of date upon which
demonstration of continuous monitoring system performance is to com-
mence.
1 Performance tests shall be conducted within 60 days after achieving the
maximum production rate at which the affected facility will be operated, but
not later than 180 days after initial startup of such facility.
11-174
-------
TABLE # 6
QUARTERLY REPORTING REQUIREMENTS1 (NSPS)
I. Excess Emissions
A. Description of Excess Emission
1. Magnitude
2. Conversion factors used
3. Date and time of commencement and completion
B. Explanation of Excess Emission
1. Occurrances during start-ups, shutdowns, and malfunctions
2. Nature and cause of malfunction
3. Corrective and preventative action taken
C. To be submitted in Units Same as Standard
II. Continuous Monitoring Systems
A. Date and Time when System was Inoperative (except for zero and span
checks)
B. Nature of System Repairs or Adjustments
III. Lack of Occurrances During A Quarter
A. Absence of Excess Emissions during Quarter
B. Absence of Adjustments, Repairs, or Inoperativeness of Continuous
Monitoring System
"Each owner or operator required to install a continuous monitoring system
shall submit a written report . . . for every calendar quarter"
"All quarterly reports shall be postmarked by the 30th day following the
end of each calendar quarter ..."
11-175
-------
SUSPART
D
TABLE #7
DEFINITION OF EXCESS EMISSIONS (NSPS)
POLLUTANT EXCESS EMISSION
NO
x
NO
x
opacity any six-minute period during which the average opa-
city of emissions exceed 20% opacity, except that one
six-minute average per hour of up to 27% opacity need
not be reported.
S02 any three-hour period during which the average
emissions of S02 (arithmetric average of three con-
tiguous one-hour periods) exceed the standard.
any three-hour period during which the average
emissions of NOX (arithmetric average of three con-
tiguous one-hour periods) exceed the standard.
any three-hour period during which the average nitro-
gen oxides emissions (arithmetric average of three
contiguous one-hour periods) exceed the standard.
H S02 all three-hour periods (or the arithmetric average of
three consecutive one-hour periods) during which the
integrated average sulfur dioxide emissions exceed the
applicable standards.
J Opacity all one-hour periods which contain two or more six-
minute periods during which the average opacity
exceeds 30 percent.
CO all hourly periods during which the average CO con-
centration exceeds the standard.
S02 any three-hour period during which the average con-
centration of S02 emissions from any fuel gas com-
bustion device exceeds the standard.
S02 any twelve-hour period during which the average con-
centration of S02 emissions from any Glaus sulfur
recovery plant exceed the standard.
P Opacity any six-minute period during which the average opacity
exceeds the standard.
S02 any six-hour period during which the average emissions
of S02 (arithmetric mean of six contiguous one-hour
periods) exceed the standard.
Q Opacity any six-minute period during which the average opacity
exceeds the standard.
S02 any two-hour period during which the average emissions
of S02 (arithmetric mean of two contiguous one-hour
periods) exceed the standard.
11-176
-------
SUBPART
R
TABLE #7
DEFINITION OF EXCESS EMISSIONS (NSPS)
POLLUTANT EXCESS EMISSION
AA
Opacity
S02
Opacity
Opacity
BB
Recovery TRS
Furnace
Opacity
Lime Kiln TRS
Digester TRS
system,
brown stock
washer system,
multiple-effect
evaporator system,
black liquor oxidation
system, or condensate
stripper.
any six-minute period during which the average opacity
exceeds the standard.
any two-hour period during which the average emissions
of S02 (arithmetric mean of two contiguous one-hour
periods) exceed the standard.
all six-minute periods in which the average opacity is
15 percent or greater.
all six-minute periods during which the average opa-
city is 3 percent or greater.
any twelve-hour period during which the TRS emissions
exceed the standard.
any six-minute period during which the average opacity
exceeds the standard.
any twelve-hour period during which the TRS emissions
exceed the standard.
any twelve-hour period during which the TRS emissions
exceed the standard.
HH
Opacity
all six-minute periods during which the average opa-
city is greater than the standard.
11-177
-------
TABLE #8
SPANNING AND ZEROING (NSPS)
I.- Explanation of Zero and Span Checks
A. Extractive gas monitors
1. Span gas composition
a. S02 ~ sulfur dioxide/nitrogen or air-gas mixture
b. NO - nitric oxide/oxygen-free nitrogen mixture
c. N02 ~ nitrogen dioxide/air mixture
2. Zero gases
a. Ambient air
or b. A gas certified by the manufacturer to contain less than
1 ppm of the pollutant gas
3. Analysis of span and zero gases
a. Span and zero gases certified by their manufacturer to be
traceable to National Bureau of Standards reference gases
shall be used whenever these gases are available.
b. Span and zero gases should be reanalyzed every six months
after date of manufacture with Reference Method 6 for
S02 and 7 for NOX
c. Span and zero gases shall be analyzed two weeks prior to
performance specification tests
B. Non-extractive gas monitors
1. Span check - certified gas cell or test cell
2. Zero check - mechanically produced or calculated from upscale
measurements
C. Transmissometers
1. Span check is a neutral density filter that is certified within
+3 percent opacity
2. Zero check is a simulated zero.
D. Span values are specified in each subpart
1. Span check is 90 percent of span.
II. Adjustment of Span and Zero
A. Adjust the zero and span whenever the zero or calibration drift
exceeds the limits of applicable performance specification in
Appendix B
1. For opacity, clean optional surfaces before adjusting zero or
span drift
2. For opacity systems using automatic zero adjustments, the opti-
cal surfaces shall be cleaned when the cumulative automatic zero
compensation exceeds four percent opacity
III. How to Span and Zero
A. Extractive gas monitors
1. Introduce the zero and span gas into the monitoring system as
near the probe as practical
B. Non-extractive gas monitors
1. Use a certified gas cell or test cell to check span
2. The zero check is performed by computing the zero value from
upscale measurements or by mechanically producing a zero
C. Transmissometers
1. Span check with a neutral density filter
2. Zero check by simulating a zero opacity
11-178
-------
SUBPART
D Fossil Fuel Fired Steam
Generators
liquid fossil fuel
solid fossil fuel
gaseous fuel
mixutures of fossil fuels
Da Electric Utility Steam
Generators
gaseous fuel
liquid fossil fuel
solid fossil fuel
*FGD Inlet
*FGD Outlet
G Nirtic Acid Plants
H Sulfurlc Acid Plants
J Petroleum Refineries
Catalytic Cracker
Glaus Recovery Plant
Fuel Gas Combustion
TABLE it9
SPAN SPECIFICATIONS (NSPS)
POLLUTANT
opacity
S02
NO
x
opacity
S02
NO
x
NO
x
opacity
S02
NOX
Opacity
NOX
NOX
NOX
SO 2
S02
N02
S02
opacity
CO
S02
H2S
TRS
S02
H2S
SPAN
80, 90, or 100% opacity
1000 ppm
500 ppm
80, 90, or 100% opacity
1500 ppm
1000 ppm
500 ppm
80, 90, or 100% opacity
lOOOy + ISOOz1
500 (x + Y) + lOOOz
60%-80%
500 ppm
500 ppm
1000 ppm
125% of max. estimated
potential emissions
50% of max. estimated
hourly potential emissions
500 ppm
1000 ppm
60, 70, or 80% opacity
1000 ppm
500 ppm
20 ppm
600 ppm
100 ppm
300 ppm
*Span values for S02 are specified for FGD inlet and outlet and apply to
liquid and solid fossil fuels.
11-179
-------
SUBPART
P Primary Copper Smelters
TABLE #9
SPAN SPECIFICATIONS
POLLUTANT
opacity
S02
SPAN
80 to 100% opacity
0.20% by volume
Q Primary Zinc Smelters
opacity
S02
80 to 100% opacity
0.20% by volume
R Primary Lead Smelters
opacity
S02
80 to 100% opacity
0.20% by volume
Z Ferroalloy Production
Facilities
opacity
not specified
AA Steel Plants
BB Kraft Pulp Mills
Recovery Furnace
Kime Kiln, recovery furnace
digester system, brown stock
washer system, multiple effect TRS
evaporator system, black liquor
oxidation system, or condensate
stripper system
opacity
opacity
02
HH Lime Manufacturing Plant
opacity
not specified
70% opacity
20%
30 ppm
(except that for any
cross recovery furnace
the span shall be 500 ppm)
40% opacity
x = fraction of total heat input from gas
y = fraction of total heat input from liquid fossil fuel
z = fraction of total heat input from solid fossil fuel
Span value shall be rounded off to the nearest 500 ppm.
11-180
-------
TABLE #10
NOTIFICATION REQUIREMENTS1
Requirements
I. Date of Commencement of Construction
II. Anticipated Date of Initial Start-Up
III. Actual Date of Initial Start-Up
IV. Any physical or operational change to a
facility which may increase the emission
rate of any air pollutant to which a
standard applies
A. The precise nature of the change
B. Present and proposed emission control
systems
C. Productive capacity before and after
the change
D. Expected completion date of change
V. Date upon which demonstration of continuous
monitoring system performance commences
Time Deadline
Less than 30 days after
such date
Less than 60 or more than
30 days prior to date
Within 15 days after date
Postmarked 60 days or as
soon as practical before
the change is commenced
More than 30 days prior
1 "Any owner or operator subject to the provisions of this part will furnish
the Adminstrator written notification..."
11-181
-------
TABLE #11
SUBPART Da EMISSION LIMITATIONS
AND REQUIRED PERCENT REDUCTIONS
Fuel
Coal
Pollutant
SO 2
Liquid Fossil
Fuel
NOX
Particulate Matter
SO 2
Gas
NOX
Particulate Matter
SO 2
NOX
Particulate Matter
Coal-derived NOX
gaseous fuel
Emission Limitation
520ng/J (1.201b/106Btu)
210ng/J (0.501b/106Btu)
13ng/J (0.03lb/106Btu)
340ng/J (0.801b/106Btu)
130ng/J (0.301b/106Btu)
13ng/J (0.03lb/106Btu)
340ng/J (0.80lb/106Btu)
86ng/J (0.201b/106Btu)
13ng/J (0.03lb/106Btu)
210ng/J (0.501b/106Btu)
Required
Percent Reduction
90%
(70% if emissions
are less than
260ng/J)
65%*
99%*
90%
(if emissions are
below 86ng/J, there
is no reduction
requirement)
30%*
70%*
90%
(if emissions are
below 86ng/J, there
is no reduction
requirement)
25%*
25%*
* Compliance with the emission limitation constitutes compliance with the
percent reduction requirements.
11-182
-------
Table #11, continued
Fuel
Pollutant
Lignite mined in NOX
N. Dakota, S. Dakota,
or Montana and is com-
busted in a slag type
furnace
Other Lignite
NO,
Subbituminous Coal NOX
Bituminous Coal NOX
Anthracite Coal NO,,
Emission Limitation
340ng/J (0.81b/106Btu)
Required
Percent Reduction
65%*
260ng/J (0.61b/106Btu)
210ng/J (0.51b/106Btu)
260ng/J (0.61b/106Btu)
260ng/J (0.6lb/106Btu)
65%*
65%*
65%*
65%*
* Compliance with the emission limitation constitutes compliance with the
percent reduction requirements.
11-183
-------
TABLE #12
PERFORMANCE SPECIFICATIONS
TRANSMISSOMETERS
Calibration Error
Zero Drift (24-hour)
Calibration Drift (24-hour)
Response Time
Operational Test Period
NOV and S02
Accuracy
Calibration Error
Zero Drift (2-hour)
Zero Drift (24-hour)
Calibration Drift (2-hour)
Calibration Drift (24-hour)
Response Time
Operational Period
02 and C02
Zero Drift (2-hour)
Zero Drift (24-hour)
Calibration Drift (2-hour)
Calibration Drift (24-hour)
Operational Period
Response Time
<3 percent opacity
<2 percent opacity
<2 percent opacity
10 seconds maximum
168 hours
£20 percent of the mean value
of the reference method test
data
£5 percent of (50 percent, 90
percent) calibration gas mix-
ture value
2 percent of span
2 percent of span
2 percent of span
2.5 percent of span
15 minutes maximum
168 hours minimum
£0.4 percent Q£ or C02
^O-J percent 02 or C02
£0.4 percent 02 or C02
£0.5 percent 02 or C02
168 hours minimum
10 minutes
11-184
-------
TABLE #13
WHEN TO RUN THE MONTIOR PERFORMANCE TEST
Initial
Facility
Start-up
I
Max.
Production
Rate Reached
Performance
Test and Submit
Report for
Compliance
Monitor
Performance
Test
t
30
Days
i
60
Days
Monitor Performance
Test Report
11-185
-------
TABLE #14
REQUIREMENTS FOR SIP REVISIONS
I. Submit SIP revisions by October 6, 1976
II. Contain monitoring requirements for the following sources (as a minimum)
A. Fossil Fuel-Fired Steam Generators
B. Sulfuric Acid Plants
C. Nitric Acid Plants
D. Petroleum Refineries
(see Table #15)
III. Require that sources evaluate the performance of their monitoring system
IV. Require the sources to maintain a file of all pertinent continuous moni-
toring data
A. Emission measurements
B. Monitoring system evaluation data
C. Adjustments and maintenance performed on the monitoring system
V. Require the source to submit periodic (such period not to exceed 3
months) reports containing the following information
A. Number and magnitude of excess emissions
B. Nature and cause of excess emissions
C. Statement concerning absence of excess emissions and/or monitor in-
operativeness
VI. Require that monitoring begin within 18 months of EPA approval of the
SIP revision (or within 18 months of EPA promulgation)
11-186
-------
TABLE #15
EXISTING SOURCES REQUIRED TO CONTINUOUSLY MONITOR EMISSIONS
Source
Fossil-Fuel Fired
Steam Generators
Pollutant
SO 2
NO,
Opacity
Nitric Acid Plants
Sulfuric Acid Plants
Petroleum Refineries
NOX
SO 2
Opacity
Comments
1. >250 x 106 Btu/hr
2. Source that has control equip-
ment for S02
1. MOOO x 106 Btu/hr
2. Located in a designated non-
attainment area for N0£
3. Exempt if source is 30% or
more below the emission
standard
1. >250 x 106 Btu/hr
2. Exempt if burning gas
3. Exempt if burning oil, or a
mixture of oil and gas are the
only fuels used and the source
is able to comply with the
applicable particulate matter
and opacity standards without
installation of control equip-
ment
1. >300 ton/day
2. Located in a designated non-
attainment area for N02
1. >300 tons/day
1. >20,000 barrels/day
11-187
-------
SECTION III
VENDORS OF CONTINUOUS MONITORING EQUIPMENT
III-l
-------
Acurex Autodata
485 Clyde Avenue
Mountain View, CA 94042
Allis Chalmers Corporation
Box 512
Milwaukee, WI 53201
Analytical Instrument
Development, Inc.
Rt. 41 and Newark Road
Avondale, PA 19311
Asarco, Inc.
3422 South 700 West
Salt Lake City, UT 84119
B G I, Inc.
58 Guinan Street
Waltham, MA 02154
Bachrach Instrument Co.
2300 Leghorn Street
Mountain View, CA 94043
Bambeck Co.
1000 Quail St., Suite 290
Newport Beach, CA 92660
Bausch & Lomb Anal. Sys.
Division
820 Linden Avenue
Rochester, NY 14625
Bendix Corp. EPID Div.
Box 831
Lewisburg, WV 24901
Bio Marine Industries, Inc.
45 Great Valley Center
Malvern, PA 19355
CEA Instruments, Inc.
15 Charles Street
Westwood, NJ 07675
Chemetrics, Inc.
Mill Run Drive
Warrenton, NJ 22186
Chemtrix, Inc.
163 SW Freeman Avenue
Hillsboro, OR 97123
Andersen Samplers, Inc.
4215-C Wendell Dr. SW
Atlanta, GA 30336
Astro Ecology/Astro
Resource
801 Link Road
League City, TX 77058
Babcock & Wilcox Co.
Bailey Meter Co.
29801 Euclid Avenue
Wickliffe, OH 44092
Bahnson Div. Envirotech
Corporation
Box 10458 Salem Station
Winston-Salem, NC 27108
Baseline Industries, Inc.
Box 649
Lyons, CO 80540
Beckman Inst. PID
2500 Harbor Blvd.
Fullerton, CA 92634
Berkeley Controls
2700 Dupont Dr.
Irvine, CA 92715
Brinkman Instruments, Inc.
Cantiague Road
Westbury, NY 11590
Calibrated Instruments, Inc.
731 Saw Mill River Road
Ardsley, NY 10502
Chemical Sensor Develop.
Co.
5606 Calle de Arboles
Torrance, CA 90505
Clean Air Engineering, Inc.
835 Sterling Avenue
Palatine, IL 60067
•111-2
-------
Cleveland Controls, Inc.
5755 Granger Rd., Suite 850
Cleveland, OH 44109
Columbia Scientific Inds.
Box 9908
Austin, TX 78766
Control Instruments Corp.
18 Passaic Avenue
Fairfield, NJ 07006
Datatest, Inc.
1117 Cedar Avenue
Croydon, PA 19020
Delta Scientific Div.
250 Marcus Blvd.
Hauppauge, NY 11787
Dynamatrion, Inc.
168 Enterprise Drive
Ann Arbor, MI 48103
Dynatech R/D Co.
99 Erie St.
Cambridge, MA 02139 .
Ecologic Instrument
132 Wilbur Place
Bohemia, NY 11716
Energetics Science, Inc.
85 Executive Blvd.
Elmsford, NY 10523
Environmental Data Corp.
608 Fig Avenue
Monrovia, CA 91016
Esterline Angus Div. Esterline
Box 24000
Indianapolis, IN 46224
Foxboro/ICT Inc.
414 Pendleton Way
Oakland, CA 94621
Gil Enterprises, Inc.
Box 3356
Cherry Hill, NJ 08034
Gow Mac Instrument Co.
Box 32
Bound Brook, NJ 08805
Climet Instruments Div. WEHR
1320 W. Colton Ave., Box 151
Redlands, CA 92373
Contraves-Goerz Corp.
610 Epsilon Dr.
Pittsburgh, PA 15238
Dasibi Environmental Corp.
616 E. Colorado St.
Glendale, CA 91205
Delta F Corporation
One Walnut Hill Park
Woburn, MA 01801
Dupont Instrument Products
Concord Plaza
Wilmington, DE 19898
Dynasciences Env. Prods. Div.
Township Line Road
Blue Bell, PA 19422
Dynatron Inc.
Box 745
Wallingford, CT 06492
Electronics Corp. of Amer.
1 Memorial Drive
Cambridge, MA 02142
Enmet Corp.
2308 S. Industrial
Ann Arbor, MI 48104
Environmental Techtronics Corp.
101 James Way
Southampton, PA 18966
Fischer & Porter Co.
125E County Line Road
Warminster, PA 18974
G C A Precision Scientific
3737 W. Cortland St.
Chicago, IL 60647
General Monitors, Inc.
3019 Enterprise St.
Costa Mesa, CA 92626
III-3
-------
Gubelin Inds., Inc.
45 Kensico Dr., Box 307
Mt. Kisco, NY 10549
High Voltage Eng. Corp. Ind.
Corp.
South Bedford Street
Burlington, MA 01803
Horiba Instruments, Inc.
1021 Duryea Avenue
Irvine, CA 92714
Hydrolab Corp.
Box 9406
Austin, TX 78766
ITT Barton
Box 1882
City of Industry, CA 91749
Instruments SA, Inc.
173 Essex Avenue
Metuchen, NJ 08840
InterScan Corp.
9614 Cozycroft Avenue
Chatsworth, CA 91311
K V B Equipment Corp.
17332 Irvine Blvd.
Tustin, CA 92680
Lamotte Chemical Prods. Co.
Box 329
Chestertown, MD 21620
Leco Corp.
3000 Lakeview Avenue
St. Joseph, MI 49085
Lockwood & Mclorie, Inc.
Box 113
Horsham, PA 19044
M D A Scientific, Inc.
Bob Busse Highway
Park Ridge, IL 60068
Mast Development Co.
2212 East 12th St.
Davenport, IA 52803
H N U Systems, Inc.
30 Ossipee Road
Newton Upper Falls, MA 02164
Honeywell, Inc.
1100 Virginia Drive
Ft. Washington, PA 19034
Houston Atlas, Inc.
9441 Baythorne Street
Houston, TX 77041
I R T Corp.
7650 Convoy Court
San Diego, CA 92111
Infrared Industries, Inc.
Box 989
Santa Barbara, CA 93102
International Sensor Tech.
3201 South Halladay St.
Santa Ana, CA 91311
Jacoby Tarbox Corp.
808 Nepperhan Avenue
Yonkers, NY 10703
Kernco Instruments Co., Inc.
420 Kenazo Avenue
El Paso, TX 79927
Lear Siegler, Inc.
74 Inverness Drive East
Englewood, CO 80110
Leeds & Northrup
Sumneytown Pike
North Wales, PA 19454
Lumicor Safety Products Corp.
5364 NW 167th St.
Miami, FL 33014
Martek Instruments, Inc.
17302 Daimler, Box 16487
Irvine, CA 92713
Meloy Labs, Inc.
6715 Electronic Drive
Springfield, VA 22151
III-4
-------
Meteorology Research, Inc.
Box 637
Altadena, CA 91001
Mine Safety Applicances Co.
600 Penn Center Blvd.
Pittsburgh, PA 15235
Monitor Labs, Inc.
10180 Scripps Ranch Blvd.
San Diego, CA 92131
Napp, Inc.
8825 N. Lamar
Austin, TX 78753
Oceanography Intl. Corp.
Box 2980
College Station, TX 77840
Overhoff & Associates
P. 0. Box 8091
Cincinnati, OH 45208
Particle Measuring Systems,
Inc.
1855 S. 57th Court
Boulder, CO 80301
Phoenix Precision Instru.
Route 208
Gardner, NY 12525
Photomation, Inc.
270 Polaris Avenue
Mt. View, CA 94043
Princeton Aqua Science
789 Jersey Avenue
New Brunswick, NJ 08902
Pullman Kellogg Div. of Pullman
1300 Three Greenway Plaza E
Houston, TX 77046
Rexnord, Inc. Instrument PDTS
30 Great Valley Parkway
Malvern, PA 19355
Science Spectrum
Box 3003
Santa Barbara, CA 93105
Milton Roy Co. Hays Republic
4333 S. Ohio St.
Michigan City, IN 46360
Modern Controls, Inc.
340 Snelling Avenue S.
Minneapolis, MN 55406
Montedoro Whitney Corp.
Box 1401
San Luis Obispo, CA 93406
National Draeger, Inc.
401 Parkway View Drive
Pittsburgh, PA 15203
Orion Research, Inc.
380 Putnam Avenue
Cambridge, MA 02139
PCI Ozone Corp.
One Fairfield Crescent
West Caldwell, NJ 07006
Perkin Elmer Corp.
411 Clyde Avenue
Mountain View, CA 94043
Photobell Co., Inc.
162 5th Avenue
New York, NY 10010
Preferred Instru. Div.
Preferred Utilities Mfg. Corp.
11 South St.
Danbury, CT 06810
Process Analyzers, Inc.
1101 State Road
Princeton, NJ 08540
Research Appliance Co.
Moose Lodge Rd. , P.O. Box 2
Cambridge, MD 21613
Schneider Instrument Co.
8115 Camargo Rd. - Madeira
Cincinnati, OH 45243
Scientific Resources, Inc.
3300 Commercial Avenue
Northbrook, IL 60062
II I-5
-------
Sensors, Inc.
3908 Varsity Drive
Ann Arbor, MI 48104
Sierra Instruments
Box 909 Village Square
Carmel Valley, CA 93924
Source Gas Analyzers, Inc.
7251 Garden Grove Blvd.
Garden Grove, CA 92641
T S I
Box 43394
St. Paul, MN 55164
Teledyne Analytical Insts.
Box 70
San Gabriel, CA 91776
Thermo Electron Corp. Env.
108 South St.
Hopkinton, MA 01748
Theta Sensors
17635 A Rowland St.
City of Industry, CA 91748
United McGill Corp.
Box 820
Columbus, OH 43216
Wallace & Tiernan Div. Pennwalt
25 Main St.
Belleville, NJ 07109
Wellsbach Ozone Sys. Corp.
3340 Stokley St.
Philadelphia, PA 19129
Western Research & Dev., Ltd.
1313 44th Avenue NE
Calgary, Alta. Canada T2E6L5
Xonics, Inc.
6862 Hayvenhurst Avenue
Van Nuys, CA 91406
Siemens Corp. P. E. Div.
186 Wood Avenue S.
Iselin, NJ 08830
Sierra Misco, Inc.
1825 E. Shore Highway
Berkeley, CA 94710
Systems Science & Software
Box 1620
La Jolla, CA 92038
Taylor Instrument Div. Sybron
95 Ames St.
Rochester, NY 14601
Thermco Instrument Corp.
Box 309
La Porte, IN 46350
Thermox Instruments, Inc.
6592 Hamilton Avenue
Pittsburgh, PA 15206
Tracor, Inc.
6500 Tracor Lane
Austin, TX 78721
Virtis Co.
Route 208
Gardner, NY 12525
Wallace Fisher Instrument Co.
Box 51 Ocean Grove Station
Swansea, MA 02777
Western Precipitation Division
Joy Manufacturing Company
Post Office Box 2744 Termina Annex
Los Angeles, CA 90051
Whittaker Corp.
10880 Wilshire Blvd.
Los Angeles, CA 90024
III-6
-------
SECTION IV
BIBLIOGRAPHY OF GEM RELATED ARTICLES
IV-1
-------
BIBLIOGRAPHY OF GEM RELATED ARTICLES
1. Application of Light Transmissometry and Indication Sodium Ion Measurement
To Continuous Particulate Monitoring In The Pulping Industry. NCASI
Technical Bulletin No. 79. May 1975.
2. Avetta, Edward D. In-Stack Transmissometer Evaluation and Application to
Particulate Opacity Measurement. EPA Contract No. 68-02-0660.
Owens, Illinois. NTIS PB 242402. January 1975.
3. Baladi, Emile. Manual Source Testing and Continuous Monitoring
Calibrations at the Lawrence Energy Center of Kansas Power and Light
Company. Midwest Research Institute. EPA Contract No. 68-02-0228.
EPA Report No. 73-SPP-3. May 7, 1976.
4. Beeson, H. G. Continuous Monitoring Excess Emission Report; Evaluation
and Summary. Entropy Environmentalists, Inc. EPA Contract No.
68-01-4148, Task 59. June 1979.
5. Beeson, H. G. Evaluation of Continuous Monitoring Excess Emission Reports
and Validation of Report Data. Entropy Environmentalists, Inc. EPA
Contract No. 68-01-4148, Task 45. March 1979.
6. Cheney, J. L. and J. B. Homolya. "The Development of a Sulfur Dioxide
Continuous Monitor Incorporating a Peizo-Electric Sorption Detector,"
The Science of the Total Environment, vol. 5, p. 69-77, 1976.
'7. Cline, J. R., et. al. Compilation and Analysis of State Regulations for
S02, N0y, Opacity, Continuous Monitoring and Applicable Test Methods;
Executive Summary and Volumes I, II, and III. Engineering Sciences
Inc. EPA Contract No. 68-01-4146, Task 40. EPA Report No. 340/
1-78-009 a, b, c, d. July 1978.
8. Connor, William D. "A Comparison Between In-Stack and Plume Opacity
Measurements at Oil-Fired Power Plants," presented at the Fourth
National Conference on Energy and the Environment in Cincinnati, Ohio,
October 4-7, 1976.
9. Connor, William D. Measurement of the Opacity and Mass Concentration of
Particulate Emissions by Transmissometry. Chemistry and Physics
Laboratory. EPA-650/2-74-128. November 1974.
10. Connor, W. D. and J. R. Hodkinson. Optical Proper-ties and Visual Effects of
Smoke-Stack Plumes. EPA Publication AP-3f, second printing. May 1972.
11. Curtis, Foston. "A Method for Analyzing NOX Cylinder Gases, Specific Ion
Electrode Procedure," Source Evaluation Society Newsletter, February
1979. (Study done for Emission Measurement Branch, US EPA, October
1978.)
12. Decker, C. E., R. W. Murdoch, and F. K. Arey. Final Report on Analysis of
Commercial Cylinder Gases of Nitric Oxide and Sulfur Dioxide at Source
Concentrations. EPA Contract No. 68-02-2725. February 1979.
IV-2
-------
13. "Environmental Monitoring." Transcript of Science Technical Hearings, 95
Congress 1 Serial 44, September 13-15, 1977.
14. Fennelly, Paul F. Development of an Implementation Plan for a Continuous
Monitoring Program. GCA Corporation. March 1977.
15. Gregory, M. W., et. _al. "Determination of the Magnitude of S02, NO,
CC>2 Stratification in the Ducting of Fossil Fuel Fired Power Plants,"
Paper 76-35.6 presented at the 1976 APCA Meeting, Portland, Oregon.
16. Herget, W. F., et. ajl. "Infrared Gas-Filter Correlation Instrument for
In-Site Measurement of Gaseous Pollutant Concentrations," Applied
Optics, vol. 15:1222-1228, May 1976.
17. Homolya, J. B. "Current Technology for Continuous Monitoring of Gaseous
Emissions," Journal of the Air Pollution Control Association, vol. 24,
no, 8, p. 809-814, August 1975.
18. Jahnke, James A. and G. J. Aldina. Continuous Air Pollution Source
Monitoring Systems; Handbook. Northrup Services, Inc. EPA
625/6-79-005. June 1979.
19. Jaye, Frederic C. Monitoring Instrumentation for the Measurement of Sulfur
Dioxide in Stationary Source Emissions. TRW Systems Group. EPA
Project 17205, NTIS PB 220202.
20. Karels, Gale G., et. al. Use of Real-Time Continuous Monitors in Source
Testing. Paper 75-19.5 presented at APCA Annual Meeting, June 15-20,
1975. NTIS PB 230934/AS GPO.
21. Lillis, E. J. and J. J. Schueneman. "Continuous Emission Monitoring:
Objectives and Requirements," Journal of the Air Pollution Control
Association, vol. 25, no. 8, August 1975.
22. Lord III, Harry C. "In-Stack Monitoring of Gaseous Pollutants,"
Engineering Science and Technology, vol. 12, no. 3, p. 264-69, March
1978.
23. McRanie, Richard D., John M. Craig, and George 0. Layman. Evaluation of
Sample Conditioners and Continuous Stack Monitors for Measurement of
SO?, N0y, and Opacity in Flue Gas. Southern Services, Inc. February
T975.
24. McNulty, K. J., et. al. Investigation of Extractive Sampling Interface
Parameters. Walden Research Division of Abcor, Inc. EPA Contract No.
68-02-0742. EPA 650/2-74-089. October 1974.
25. Nader, John S., Frederic Jaye, and William Connor. Performance
Specifications for Stationary Source Monitoring Systems for Gases and
Visible Emissions. NERC Chemistry and Physics Laboratory. NTIS PB
209190. January 1974.
26. Osborne, Michael C. and M. R. Midgett. Survey of Continuous Source Emission
Monitors: Survey No. 1 - Nov and SO?. EPA 600/4-77-022. April 1977.
IV-3
-------
27. Osborne, Michael C. and M. Rodney Midgett. Survey of Transmissometers Used
in Conducting Visible Emissions Training Courses. EPA - 600/4-78-023.
May 1978.
28. Peeler, James W. Continuous Opacity and Particulate Emissions Monitoring in
the Federal Republic of Germany; Selected Papers From Current
Literature. Entropy Environmentalists, Inc. EPA Contract No.
29. Reisman, E., W. D. Gerber, and N. d. Potter. In-Stack Transmissometer
Measurement of Particulate Opacity and Mass Concentration. Philco-Ford
Corporation. EPA Contract No. 68-02-1229. NTIS PB 239864/AS.
November 1974.
30. Repp, Mark. Evaluation of Continuous Monitors for CO in Stationary Sources.
EPA 600/2-77-063. March 1977.
31. Rhodes, Raymond C. and H. Seymour. "Challenges of Implementing Quality
Assurance in Air Pollution Monitoring Systems," presented at APCA
Quality Assurance in Air Pollutiong Measurement Conference, March
11-14, 1979, New Orleans, Louisiana.
32. Roberson, R. L., et. al. "Continuous Emission In the Electric Utility
Industry," Paper 80-42.1 presented at APCA Annual Meeting, June 22-27,
1980, Montreal, Quebec, Canada.
33. Shigehara, R. T. "Sampling Location for Gaseous Pollutant Monitoring in
Coal-Fired Power Plants," Source Evaluation. Society Newsletter. July
1978.
34. Stanley, Jon and Peter R. Westlin. "An Alternative Method for Stack Gas
Moisture Determination," Source Evaluation Society Newsletter.
November 1978.
35. Tomaides, M. Instrumentation for Monitoring the Opacity of Particulate
Emissions Containing Condensed Water. EPA 600/2-77-005. June 1979.
36. Tretter, V. J. and Matthew Gould. "A New Concept In Compliance Monitoring,"
presented at TAPPI Environmental Conference, April 25-27, 1979,
Houston, Texas.
37. United States Environmental Protection Agency. "Standards of Performance
for New Stationary Sources," Federal Register 40;46250-70. October 6,
1975.
38. Van Acker, P. "Continuous and Semi-Continuous Measurements of Dust
Emissions In a Power Plant Burning Fuel Oil," Environmental
International, vol. 2, no. 2, p. 107. 1979.
39. West, P. W., D. L. McDermott, and K. D. Reiszner. "Development of Long-
Term Sulfur Dioxide Monitor Using Permeation Sampling," Engineering
Science and Technology, vol. 13, no. 9, September 1979.
IV-4
-------
40. Westlin, Peter R. and John W. Brown. "Methods for Collecting and Analyzing
Gas Cylinder Samples," Source Evaluation Society Newsletter, September
1978.
41. Woffinden and Ensor. Optical Method for Measuring the Mass Concentration of
Particulate Emissions. Meteorology Research, Inc. EPA Contract No.
68-02-1749. EPA 600/2-76-062. March 1976.
TV-S
-------
Availability of EPA Publications
Copies of United States EPA publications are available free of charge, as
long as supplies last, from the EPA Library in Research Triangle Park, North
Carolina. When supplies are exhausted, one may purchase publications from the
United States Government Printing Office or the National Technical Information
Service.
U. S. Environmental Protection Agency
Library (MD-35)
Research Triangle Park, N. C. 27711
commercial phone 919-541-2777
FTS phone 629- 2779
National Technical Information Service
U. S. Department of Commerce
5285 Port Royal Road
Springfield, Virginia 22151 .
phone 703-487-4600
Superintendent of Documents
Government Printing Office
Washington, D. C. 20402
IV-6
-------
TECHNICAL REPORT DATA
(Please read Instructions on the reverse before completing)
1. REPORT NO.
EPA 340/l-8l-nn8
2.
4. TITLE AND SUBTITLE
Regulations and Resource File of Continuous
Monitoring Information
7. AUTHOR(S)
William J. Pate
9. PERFORMING ORGANIZATION NAME AND ADDRESS
Kilkelly Environmental Associates, Inc.
Post Office Box 31265
Raleigh. North Carolina 27622
12. SPONSORING AGENCY NAME AND ADDRESS
U. S. Environmental Protection Agency
Office of Enforcement
Office of General Enforcement
Washington, D. C. 20460
15. SUPPLEMENTARY NOTES
3. RECIPIENT'S ACCESSION NO.
5-^cP?^eDrA,TE1981
6. PERFORMING ORGANIZATION CODE
8. PERFORMING ORGANIZATION REPORT NO.
10. PROGRAM ELEMENT NO.
11. CONTRACT/GRANT NO.
68-01-6317
"•RlfvlsW'ffeWrV0 PERI°° COVERED
14. SPONSORING AGENCY CODE
The Environmental Protection Agency has promulgated continuous emission
monitoring requirements for several NSPS source categories. The EPA has also
required states to revise their SIPs to include continuous emission monitoring
regulations.
This report is a compilation of the following continuous emission moni-
toring information: EPA regional continuous monitoring contacts; continuous
emission monitoring regulations; vendors of continuous monitoring equipment;
and a bibliography of continuous monitoring literature.
17.
a.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
Continuous Emission Monitoring
Regulations
New Source Performance Standards
18.
DISTRIBUTION STATEMENT
Release Unlimited
b. IDENTIFIERS/OPEN ENDED TERMS
Continuous Emission
Monitoring
IS^SECURITY, CLASS (This Report!
Unclassified
20. SECURITY CLASS (This page)
Unclassified
c. COS ATI Field/Group
13B
14D
21. NO. OF PAGES
22. PRICE
EPA Form 2220-1 (R«v. 4-77) PREVIOUS EDITION is OBSOLETE
-------
-------
United States
Environmental Protection
Agency
Office of Air Quality Planning and Standards
Stationary Source Compliance Division
Washington, D C 20460
Official Business
Penalty for Private Use
S300
Publication No EPA-340/1 -83-008
Postage and
Fees Paid
Environmental
Protection
Agency
EPA 335
If your address is incorrect, please change on the above label,
tear off, and return to the above address
If you do not desire to continue receiving this technical report
series, CHECK HERE D , tear off label, and return it to the
above address
-------