Exhibit
A
to
Appendix
BSpecificatiöns
and
Test
Procedures
1.
Installation
and
Measurement
Location
1.1
Gas
and
Mercury
Monitors
Following
the
procedures
in
Section
8.1.1
of
Performance
Specification
2
in
Appendix
B
to
40
CFR
60,
incorporated
by reference
in
Section
225.140,
install the
pollutant
concentration
monitor
or
monitoring
system
at
a
location
where
the
pollutant
concentration
and
emission
rate
measurements
are
directly
representative
of
the
total
emissions
from
the
affected
unit. Select
a
representative
measurement
point
or
path
for
the
monitor
probe(s)
(or
for
the
path
from
the
transmitter
to
the
receiver)
such
that
the
CO
2
Q
2
,
concentration
monitoring
system,
mercury
concentration
monitoring
system,
or
sorbent
trap
monitoring
system
will
pass
the
relative
accuracy
test
(see
Section
6
of
this
Exhibit).
It
is
recommended
that
monitor
measurements
be
made
at locations
where
the
exhaust
gas
temperature
is
above
the
dew-point
temperature.
If
the
cause
of
failure
to
meet
the
relative
accuracy
tests
is
determined
to
be
the
measurement
location,
relocate
the
monitor
probe(s).
1.1.1
Point
Monitors
Locate
the
measurement
point
(1)
within
the
centroidal
area
of
the
stack
or
duct
cross
section,
or
no
less
than
1.0
meter
from
the
stack
or
duct
wall.
1.2
Flow
Monitors
Install
the
flow
monitor
in
a
location
that
provides
representative
volumetric
flow
over
all
operatjpg
conditions.
Such
a
location
is
one
that
provides
an average
velocity
of
the
flue gas
flow
over
the
stack
or
duct
cross section
and
is
representative
of
the
pollutant
concentration
monitor
location.
Where
the
moisture
content
of
the•
flue
gas
affects
volumetric
flow
measurements,
use
the
procedures
in
both
Reference
Methods
1
and
4
of
Appendix
A
to
40
CFR
60,
incorporated
by
reference
in
Section
225.140,
to
establish
a
proper
location
for
the
flow
monitor.
The
Illinois
EPA
recommends
(but
does
not
require)
performing
a
flow
profile
study
following
the
procedures
in
40
CFR
part 60,
appendix
A,
Method,
1,
Sections
11.5
or
11.4,
incorporated
by
reference
in
Section
225.140,
for
each
of
the three
operating
or
load levels
indicated
in
Section
6.5.2.1
of
this
Exhibit
to
determine
the acceptability
of
the
potential
flow
monitor
location
and
to
determine
the
number
and
location
of
flow sampling
points
required
to
obtain
a
representative
flow
value.
The
procedure
in
40
CFR
part 60, Appendix
A,
Test
Method
1,
Section
11.5,
incorporated
by
reference
in
Section
225.140,
may be
used
even
if
the
flow
measurement
location
is
greater
than
or
equal
to
2
equivalent
stack
or
duct diameters
downstream
or
greater
than
or
equal
to
1/2
duct
diameter
upstream
from
a
flow disturbance.
If
a
flow
profile
study
shows
that
cyclonic (or
swirling)
or
stratified
flow
conditions
exist
at
the
potential
flow
monitor
location
that
are
likely
to
prevent
the
monitor
from
meeting
the performance
specifications
of
this
part,
then
the
Agency
recommends
either
(1) selectjpg
1
another location where
there
is
no
cyclonic (or
swirling)
or stratified
flow
condition,
or
(2)
eliminating
the
cyclonic
(or swirling)
or stratified
flow condition
by straightening
the
flow,
e.g.Jy
installing
straightening vanes.
The Agency
also recommends
selecting
flow monitor
locations
to
minimize
the effects
of condensation,
coating, erosion,
or other conditions
that
could
adversely
affect
flow
monitor
performance.
1.2.1
Acceptability
of Monitor
Location
The installation of a flow
monitor is acceptable
if either
(1)
the location
satisfies the
minimum
sjjpg
criteria
of
Method 1 in Appendix
A to
40 CFR 60,
incorporated
by
reference
in Section
225.140
(i.e.,
the location is
greater
than
or
equal
to eight stack or duct
diameters
downstream
and two
diameters
upstream
from a
flow
disturbance;
or, if
necessary,
two
stack or duct
diameters downstream
and
one-
half stack or duct diameter
upstream
from
a flow
disturbance),
or
(2)
the results
of a flow
profile
study,
if
performed,
are
acceptable
(i.e.. there are
no cyclonic
(or
swirling)
or
stratified
flow
conditions),
and the
flow
monitor also satisfies
the performance
specifications
of this
part. If
the
flow
monitor is
installed
in
a location
that
does not
satisfy these physical
criteria,
but
nevertheless
the
monitor achieves
the performance
specifications of
this
part,
then
the location
is
acceptable,
notwithstanding the
requirements
of this
Section.
1.2.2
Alternative Monitoring
Location
Whenever
the owner or
operator
successfullydemonstrates
that
modifications
to the
exhaust
duct
or
stack
(such
as installation
of straightening
vanes, modifications
of ductwork,
and
the
like)
are
necessary
for the flow
monitor to meet
the
performance
specifications,
the Agency
may
approve
an
interim
alternative
flow monitoring methodology
and
an
extension
to the required
certification
date
for
the
flow monitor.
‘Where
no location
exists
that
satisfies
the physical
siting criteria
in Section
1.2.1, where
the
results
of
flow profile
studies
performed
at
two
or
more alternative
flow monitor locations
are
unacceptable,
or
where
installation
of
a flow monitor
in either the stack
or the
ducts
is
demonstrated
to
be
technically
infeasible, the
owner or operator
may
petition
the Agency for
an alternative
method
for
monitoring
flow.
2. Equipment
Specifications
2.1 Instrument
Span
and Range
In
implementing
Sections 2.1.1
through 2.1.2
of this Exhibit,
set
the
measurement
range
for
each
parameter
(COQ
2
,
or
flow rate)
high
enough
to prevent
full-scale exceedances
from
occurring,
yet
low
enough to
ensure
good measurement
accuracy
and to maintain
a high
signal-to-noise
ratio.
To
meet
these
objectives,
select
the
range such that the
majority
of the
readings
obtained
during
typical
unit
operation
are kept, to the
extent practicable,
between
20.0
and 80.0 percent
of the
full-scale
range
of
the
instrument.
2
2.1.1
CO
2
and
02
Monitors
For
an
02
monitor
(including
02
monitors
used
to
measure
CO
2
emissions
or
percentage
moisture),
select
a
span
value
between
15.0
and
25.0
percent
02.
For
a
CO
2
monitor
installed
on
a
boiler,
select
a
span
value
between
140
and
20.0
percent
CO
2
.
For
a
CO, monitor
installed
on
a
combustion
turbine,
an
alternative
span value
between
6.0
and
14.0
percent
CO
may
be
used.
An
alternative
cQ2
span value
below
6.0
percent
may be
used
if
an
appropriate
technical
justification
is
included
in
the
hardcopy
monitoring
plan.
An
alternative
02
span value
below
15.0
percent
02
may
be
used
if
an
appropriate
technical
justification
is
included
in
the
monitoring
plan (e.g.,
02
concentrations
above
a
certain
level
create
an
unsafe
operating
condition).
Select
the
full-scale
range
of
the
instrument
to
be
consistent
with
Section
2.1
of
this
Exhibit
and
to
be
greater
than
or
equal
to
the
span
value.
Select
the
calibration
gas
concentrations
for
the
daily
calibration
error
tests
and
linearity
checks
in
accordance
with
Section
5.1
of
this
Exhibit,
as
percentages
of
the
span
value.
For
02
monitors
with
span
values
>=21.0
percent
02,
purified
instrument
air
containing
20.9
percenL02
may
be
used
as
the
high-level
calibration
material.
If
a
dual-range
or
autoranging
diluent
analyzer
is
installed,
the
analyzer
may
be
represented
in
the
monitoring
plan
as
a
single
component,
using
a
special
component
type
code
specified
by
the
USEPA
to
satisfy
the
requirements
of
40
CFR
75.53(e)(1)(iv)(D),
incorporated
by
reference
in
Section
225.140.
2.1.2
Flow
Monitors
Select
the
full-scale
range
of
the
flow
monitor
so
that
it
is
consistent
with
Section
2.1
of
this
Exhibit
and
can
accurately
measure
all
potential
volumetric
flow
rates
at
the
flow
monitor
installation
site.
2.1.2.1
Maximum
Potential
Velocity
and
Flow
Rate
For
this
purpose,
determine
the
span
value
of
the
flow
monitor
using
the
following
procedure.
Calculate
the
maximum
potential
velocity
(MPV)
using
Equation
A-3a
or
A-3b or
determine
the
MPV
(wet
basis)
from
velocity
traverse
testing
using
Reference
Method
2
(or
its
allowable
alternatives)
in
appendix
A
to
40
CFR
60, incorporated
by
reference
in
Section
225.140.
If
using
test
values,
use
the
highest
average
velocity
(determined
from the
Method
2
traverses)
measured
at
or
near
the
maximum
unit
operating
load
(or.
for
units that
do
not
produce
electrical
or
thermal
output,
at
the
normal
process
operating
conditions
corresponding
to
the
maximum
stack
gas
flow
rate).
Express
the
MPV
in
units
of
wet
standard
feet
per
minute
(fpm).
For
the
purpose
of
providing
substitute
data
during
periods
of
missing
flow
rate
data
in
accordance
with
Sec
75.31
and
75.33
of
40
CFR
Part
75
and
as
required
elsewhere
in
this
part, calculate
the
maximum
potential
stack
gas
flow
rate
(MPF)
in
units
of
standard
cubic
feet
per
hour
(scth),
as
the
product
of
the MPV
(in
units
of
wet,
standard
fpm) times
60,
times
the
cross-sectional
area
of
the
stack
or
duct
(in
fl
2
)
at
the flow
monitor
location.
3
(FdHY
209
‘V
100
MPV
I
II
II
I
(Equation
A-3a)
A
J
2
O.
9
—%O
2
d).lOO—%H
2
O)
or
MPV
= I
(FH
1
Y
II
100
1
ii
100
I____________________
I
(Equation
A-3b)
A
)%CO
2d
)L100—%H
2
0)
Where:
MPV maximum potential
velocity
(fpm,
standard
wet
basis).
= dry-basis F factor
(dscf7mmBtu)
from Table 1, Section
3.3.5 of
Appenfix
F ,
40
CFR
Part
75.
= carbon-based F
factor
(scf C0
2
/mmBtu)
from Table
1,
Section
3.3.5 of
Appenfix
F
, 40
CFR
Part 75.
Hf = maximum
heat
input (mmBtu!minute)
for
all
units,
combined, exhausting
to the
stack
or
duct
where
the
flow monitor
is
located.
A
inside cross
sectional area
(fl
2)
of the flue
at
the flow monitor location.
°2d
= maximum
oxygen concentration,
percent
dry basis, under normal
operating
conditions.
%CO
2d
= minimum
carbon dioxide
concentration,
percent
dry
basis,
under
normal
operating
conditions.
%H
20
= maximum percent
flue gas moisture
content under
normal
operating
conditions.
2.1.2.2
Span
Values
and Range
Determine
the span
and range of the flow
monitor
as follows.
Convert
the
MPV,
as
determined
in
Section
2.1
.2.1
of this Exhibit, to
the same
measurement
units
of flow rate
that are used
for
dfly
calibration
error tests (e.g., scfh,
kscth, kacfrn,
or differential
pressure(inches
of
water)Nex.
determine
the “calibration
span
value” by
multiplying
the
MPV
(có
étejiT’1ent
dailj
calibration error
units)
by a factor no less
than 1.00
and
no
greater
than 1.25, and
rounding
up
the
result
to
at
least two
significant figures.
For calibration
span values in
inches of water,
retain
at
least
two
decimal
places. Select
appropriate
reference
signals for the
daily calibration
error
tests
as
percentages
of the calibration
span
value,
as
specified
in Section
2.2.2.1 of
this
Exhibit.
Finally
calculate
the “flow rate span
value”
(in
scth)
as
the
product
of the
MPF,
as determined
in
Section
2.1.2.1 of this
Exhibit, times the
same factor
(between
1.00 and
1.25)
that was
used
to
calculate
the
calibration
span value. Round
off the flow rate
span
value
to
the nearest
1000 scth.
Select
the
full
4
scale
range
of
the
flow
monitor
so
that
it
is
greater
than
or
equal
to
the
span
value
and
is
consistent
with
Section
2
1
of
this
Exhibit
Include
in
the
morntonng
plan
for
the
unit
calculations
of
the
MPV
MPF,
calibration
span
value,
flow
rate
span
value,
and
full-scale
range
(expressed
both
in
seth
and,
if
different.
in
the
measurement
units
of
calibration).
2.1.2.3
Adjustment
of
Span
and
Range
For
each
affected
unit
or
common
stack,
the
owner
or
operator
must
make
a
periodic
evaluation
of
the
MPV,
span,
and
range
values
for
each
flow
rate
monitor
(at
a
minimum,
an
annual
evaluation
is
required)
and
must
make
any
necessary
span
and
range
adjustments
with
corresponding
monitoring
plan
updates,
as
described
in
paragraphs
(a)
through
(c)
of
this
Section
2.1.2.3.
Span
and
range
adjustments
may
be
required,
for
example,
as
a
result
of
changes
in
the
fuel
supply,
changes
in
the
stack
or
ductwork
configuration,
changes
in
the
manner
of
operation
of
the
unit,
or
installation
or
removal
of
emission
controls.
In
implementing
the
provisions
in
paragraphs
(a)
and
(b)
of
this
Section
2.1.2.3,
note
that
flow
rate
data
recorded
during
short-term,
non-representative
operating
conditions
(e.g..
a
trial
bum
of
a
different
type
of
fuel)
must
be
excluded
from
consideration.
The
owner.
or
operator
must
keep
the
results
of
the
most
recent
span
and.
range
evaluation
on-site,
in
a
format
suitable
for
inspection.
Make
each
required
span
or
range
adjustment
no
later
than
45
days
after
the
end
of
the
quarter
in
which
the
need
to
adjust
the
span
or
range
is
identified.
(a)
If
the
fuel
supply,
stack
or
ductwork
configuration,
operating
parameters,
or
other
conditions
change
such
that
the
maximum
potential
flow
rate
changes
significantly,
adjust
the
span
and
range
to
assure
the
continued
accuracy
of
the
flow
monitor.
A
“significant”
change
in
the
MPV
means
that
the
guidelines
of
Section
2.1
of
this
Exhibit
can
no
longer
be
met,
as
determined
by
either
a
periodic
evaluation
by
the
owner
or
operator
or
from
the
results
of
an
audit
by
the
Agency.
The
owner
or
operator
should
evaluate
whether
any
planned
changes
in
operation
of
theunit
may
affect
the
flow
of
the
unit
or
stack
and
should
plan
any
necessary
span
and
range
changes
needed
to
account
for
these
changes,
so
that
they
are
made
in
as
timely
a
manner
as
practicable
to
coordinate
with
the
operational
changes.
Calculate
the
adjusted
calibration
span
and
flow
rate
span
values
using
the
procedures
in
Section
2.1.2.2
of
this
Exhibit.
(b)
Whenever
the
full-scale
range
is
exceeded
during
a
quarter,
provided
that
the
exceedance
is
not
caused
by
a
monitor
out-of-control
period,
report
200.0
percent
of
the
current
full-scale
range
as
the
hourly
flow
rate
for
each
hour
of
the
full-scale
exceedance.
If
the
range
is
exceeded,
make
appropriate
adjustments
to
the
flow
rate
span,
and
range
to
prevent
future
full-scale
exceedances.
Calculate
the
new
calibration
span
value
by
converting
the
new
flow
rate
span
value
from
units
of
seth
to
units
of
daily
calibration.
A
calibration
error
test
must
be
performed
and
passed
to
validate
data
on
the
new
range.
(c)
Whenever
changes
are
made
to
the
MPV,
full-scale
range,
or
span
value
of
the
flow
monitor,
as
described
in
paragraphs
(a)
and
(b)
of
this
Section,
record
and
report
(as
applicable)
the
new
full
scale
range
setting,
calculations
of
the
flow
rate
span
value,
calibration
span
value,
and
MPV
in
an
updated
monitoring
plan
for
the
unit.
The
monitoring
plan
update
must
be
made
in
the
quarter
in
5
which
the
changes become effective. Record and report the adjusted calibration span
and
reference
values
as
parts
of
the records for the
calibration
error test required by
Exhibit
B
to this Appendix.
Whenever
the
calibration span value is
adjusted,
use
reference values for
the
calibration
error
test
that
meet the requirements of
Section 2.2.2.1
of this Exhibit, based on the most recent
adjusted
calibration span value. Perform a
calibration
error test according to Section 2.1 .1 of Exhibit
B to
this
Appendix whenever
making
a
change
to
the flow monitor span or range, unless the
range
change
also triggers a
recertification under Section 1.4
of
this
Appendix.
2.1.3 Mercury Mpnitors
Determine the appropriate span and range
value(s)
for each mercury
pollutant
concentration
monitor,
so that all
expected
mercury concentrations can be determined accurately.
2.1.3.1 Maximum Potential Concentration
The maximum
potential
concentration depends upon the type of coal combusted in
the unit.
For
the
initial MPC
determination, there are three options:
(1)
Use
one of the
following default values:
9 fig/scm for bituminous coal; 10 pjg/scm
for sub-
bituminous coal; 16
iig/scm
for
lignite,
and
1
jig/scm
for waste
coal, i.e., anthracite
cuim
or
bituminous gob. If
different coals are blended, use the highest
MPC for any fuel in the blend;
or
(2)
You may
base
the MPC on the results of site-specific emission
testing using
the
one
of
the
mercury reference
methods in Section 1.6 of this Appendix, if
the
unit
does not
have
add-on
mercury
emission
controls or a flue gas desulfurization system, or if you test upstream
of these
control
devices.
A
minimum
of 3 test runs are required, at the normal operating load. Use the
highest
total
mercury
concentration obtained
in
any
of the tests as the
MPC;
or
(3)
You may
base
the MPC on 720 or more hours of historical CEMS data or data
from
a
sorbent
trap
monitoring
system,
if the
unit does not have add-on mercury
emission controls
or a
flue
gas
desulfurization
system
(or
if the CEMS or sorbent trap system is located upstream
of these
control
devices)
and if
the mercury CEMS or sorbent
trap
system has been tested for relative
accuracy
against one
of the
mercury
reference methods in Section
1.6 of this Appendix and has
met
a relative
accuracy
specification of 20.0%
or
less.
2.1.3.2 Maximum ExpectedConcentration
For units
with FGD
systems that significantly reduce
mercury
emissions
(including
fluidized
bed
units that
use limestone
injection) and for units
equipped
with
add-on mercury emission
controls
(e.g.,
carbon
injection),
determine
the maximum expected mercury
concentration
(MEC)
during
normal,
stable
operation of the unit and emission controls. To calculate the MEC,
substitute
the
MPC
value from
Section
2.1.3.1
of
this Exhibit into Equation
A-2 in Section 2.1.1.2 of
Appendix
A to
40
6
CFR
75,
incoorated
by
reference
in
Section
225.140.
For
units
with
add-on
mercury
emission
controls,
base
the
percent
removal
efficiency on
design
engineering
calculations.
For
units
with
FGD
systems,
use
the
best available
estimate
of
the
mercury
removal
efficiency
of
the
FGD
system.
2.1.3.3
Span
and
Range
Value(s)
(a)
For each
mercury
monitor,
determine
a
high
span
value,
by
rounding
the
MPC
value
from
Section
2.1
.3.1
of
this
Exhibit
upward
to
the
next highest
multiple
of
10
jig/scm.
(b)
For
an affected
unit equipped
with
an
FGD
system
or
a
unit
with
add-on
mercury
emission
controls,
if
the
MEC value
from
Section
2.1.3.2
of
this
Exhibit
is
less
than
20
percent
of
the
high
span
value from
paragraph
(a)
of
this
Section,
and
if
the
high
span
value
is
20
jig/scm
or
greater,
define
a
second,
low
span value
of
10
jig/scm.
(c)
If
only
a
high
span
value
is
required,
set
the
full-scale
range
of
the
mercury
analyzer
to
be
greater
than
or
equal
to
the
span
value.
(d)
If
two span values
arecqiiired,
you
may either:
(1)
Use
two separate
(high
and
low)
measurement
scales,
setting
the
range
of
each
scale
to
be
greater
than
or
equal to
the
high or
low
span
value,
as
appropriate
or
(2)
Quality-assure
two segments
of
a
single measurement
scale.
2.1.3.4
Adjustment
of
Span
and Range
For
each affected
unit
or
common
stack,
the
owner
or
operator
must
make
a periodic
evaluation
of
the
MPC,
MEC,
span,
and
range values
for
each
mercury
monitor
(at
a
minimum,
an
annual
evaluation
is
required)
and must
make
any
necessary
span
and
range
adjustments,
with
corresponding
monitoring
plan
updates.
Span
and
range
adjustments
may be
required,
for
example,
as
a
result
of
changes
in the
fuel
supply,
changes
in
the
manner
of
operation
of
the
unit,
or
installation
or
removal
of
emission
controls.
In
implementing
the
provisions
in
paragraphs
(a)
and
(b)
of
this
Section,
data
recorded
during
short-term,
non-representative
process
operating
conditions
(e.g.,
a trial bum
of
a
different
type
of
fuel)
must
be
excluded
from
consideration.
The
owner
or
operator
must keep
the
results
of
the
most
recentpan
and
range
evaluation
on-site,
in
a
format
suitable
for
inspection
Make
each required
span
r
L
110
later
trian
45
days
after
the
end
of
the quarter
in
which
he
ttie
span
or
range
is
identified
except
that
up
to
90
days
after the
end
of
that
quarter
may
be
taken
to
implement
a
span
adjustment
if
the
calibration
gas
concentrations
currently
being
used
for
calibration
error
tests,
system
integrity
checks,
and
lineariti
checks
are
unsuitable
for use
with
the
new
span
value
and
new
calibration
materials
must
be
ordered.
(a)
The
guidelines
of
Section
2.1
of
this
Exhibit
do
not
apply
to
mercury
monitoring
systems.
7
(b)
Whenever
a fu11sca1e range
exceedanceoccursduring
a quarter and
is not’caused
by a
monitor
out-of-control
period,
proceed
as follows:
(1) For monitors
with
a single
measurement
scale, report that
the system
was
out of
range
and
invalid
data
was
obtained
until the
readings come back
on-scale
and, if
appropriate,
make
adjustments
to
the
MPC,
span, and range
to
prevent
future
full-scale
exceedances;
or
(2)
For units with two
separate measurement
scales,
if the low range
is exceeded,
no
further
action
is
required, provided
that
the
high.range
is available and
is not out-of-control
or
out-of-service
for
any
reason.
However,
if the high range
is
not able
to provide
quality
assured
data at the time
of
the
low
range exceedance
or
at
any time
during
the continuation
of the
exceedance,
report
that
the
system
was
out-of-control
until the readings
return
to the
low range
or until the high
range is able
to provide
quality
assured
data
(unless
the
reason that the high-scale
range
is
not
able to
provide
quality
assured
data
is because
the
high-scale
range
has been exceeded;
if the
high-scale range
is
exceeded
follow
the procedures in
paragraph
(b)(l)
of this
Section).
(c)
Whenever changes
are
made
to
the
MPC, MEC,
full-scale range,
or span
value of. the
mercury
monitor, record
and report
(as
applicable)
the
new
full-scale
range setting,
the new
MPC
or
MEC
and calculations
of the adjusted
span value
in an updated monitoring
plan.
The
monitoring
plan
update
must
be made
in
the
quarter in which
the
changes
become
effective.
In addition,
record
and
report
the
adjusted
span as
part
of the records
for
the
daily
calibration
error test and
linearity
check
specified
by
Exhibit B
to
this
Appendix.
Whenever
the
span
value is
adjusted,
use
calibration
gas
concentrations
that meet
the
requirements
of Section 5.1
of this Exhibit,
based on
the
adjusted
span
value.
When
a
span
adjustment is
so significant that
the
calibration
gas concentrations
currently
being
used
for
calibration error tests,
system
integrity
checks
and linearity
checks are
unsuitable
for
use with
the new span value,
then
a
diagnostic
linearity or
3-level
system integrity
check
using
the
new
calibration gas concentratiOns
must
be performed
and passed.
Use the
data
validation
procedures
in Section
1
.4(b)(3)
of this Appendix,
beginning
with
the hour in which
the
span
is
changed.
2.2
Design
for
Quality
Control
Testing
2.2.1
Pollutant Concentration
and
CO
2or
02
Monitors
(a)
Design
and
equip
each
pollutant
concentration
and
CO
2 or
02
monitor
with
a
calibration
gas
injection
port that
allows
a check of the entire
measurement
system
when
calibration
gases
are
introduced.
For
extractive
and dilution
type
monitors,
all
ucnitwig
cümponents
exposed
to
the
sample gas, (e.g.,
sample
lines, filters,
scrubbers,
conditioners,
and
as much
of
the
probe as
practicable) are
included
in
the measurement
system.
For in
situ type
monitors,
the
calibration
must
check against
the
injected
gas
for the performance
of all
active electronic and
optical
components
(e.g.
transmitter,
receiver, analyzer).
(b)
Design
and
equip
each
pollutant concentration
or
CO
2
or
02
monitor to
allow
daily
8
determinations
of
calibration
error
(positive
or
negative)
at
the
zero-
and
mid-or
high-level
concentrations
specified
in
Section
5.2
of
this
Exhibit.
2.2.2
Flow
Monitors
Design
all
flow
monitors
to
meet
the
applicable
performance
specifications.
2.2.2.1
Calibration
Error
Test
Design
and
equip
each
flow
monitor
to
allow
for
a
daily
calibration
error
test
consisting
of
at
least
two
reference
values:
Zero
to
20
percent
of
span
or
an
equivalent
reference
value
(e.g..
pressure
pulse
or
electronic
signal)
and
50
to
70 percent
of
span.
Flow
monitor
response,
both
before
and
after
any
adjustment,
must
be
capable
of
being
recorded
by
the
data
acquisition
and
handling
system.
Design
each
flow
monitor
to
allow
a
daily
calibration
error
test
of
the
entire
flow
monitoring
system,
from
and
including
the
probe
tip
(or
equivalent)
through
and
including
the
data
acquisition
and
handling
system,
or
the
flow
monitoring
system
from
and
including
the
transducer
through
and
including
the
data acquisition
and
handling system.
2.2.2.2
Interference
Check
(a)
Design
and
equip
each
flow
monitor
with
a
means
to
ensure
that
the
moisture
expected
to
occur
at
the monitoring
location
does
not
interfere
with
the
proper
functioning
of
the
flow
monitoring
system.
Design
and
equip
each
flow
monitor
with
a
means
to
detect,
on
at
least
a
daily
basis,
pluggage
of
each
sample
line and
sensing
port,
and
malfunction
of
each
resistance
temperature
detector
(RTD),
transceiver
or
equivalent.
(b)
Design
and
equip
each
differential
pressure
flow
monitor
to
provide
an automatic,
periodic
back
purging
(simultaneously
on
both
sides
of
the
probe)
or
equivalent
method
of
sufficient
force
and
frequency
to
keep
the
probe
and lines
sufficiently
free
of
obstructions
on
at
least
a
daily
basis
to
prevent
velocity
sensing
interference,
and
a
means
for
detecting
leaks
in
the
system
on
at
least
a
quarterly
basis
(manual
check
is
acceptable).
(c)
Design
and equip
each
thermal
flow
monitor
with
a
means
to
ensure
on
at
least
a
daily
basis
that
the
probe remains
sufficiently
clean
to
prevent
velocity
sensing
interference.
(d)
Design
anu
uip
each
ultrason
‘çw
monitor
with
a
mean.
LO
ensute
ona
least
a
dail
lc
that
the
transceiv.
‘
1
ean
(e.g.,
backn’
:
system
to
prevent
veii
sensinc
interference.
2.2.3
Mercury
Monitors.
Design
and
equip
each
mercury
monitor
to permit
the
introduction
of
known
concentrations
of
elemental
mercury
and
HgCl2
separately,
at
a
point
immediately
preceding
the
sample
extraction
9
filtration
system,
suchthat
the
entire
measurement
system
be
checkedlf
the mercury
monitor
does
not
have a
converter,
the
HgCl2
injection
capability
is
not
required.
3. Performance
Specifications
3.1 Calibration
Error
(a)
The
calibration
error
performance
specifications in this
Section
apply only
to
7-day
calibration
error
tests
under
Sections
6.3.1
and
6.3.2
of
this
Exhibit
and
to the
offline
calibration
demonstration
described
in
Section
2.1.1.2
of
Exhibit
B to this
Appendix.
The calibration
error
limits
for
daily
operation
of the
continuous
monitoring
systems
required
under
this
part are
found
in
Section
2.1.4(a)
of Exhibit
B
to
this Appendix.
(b)
The
calibration
error
of
a mercury
concentration
monitor
must
not deviate
from
the
reference
value
of
either
the
zero or
upscale
calibration
gas
by
more
than
5.0
percent
of
the span
value,
as
calculated
using
Equation
A-5 of
this
Exhibit.
Alternatively,
if the
span
value
is 10
ig/scrn,
the
calibration
error
test
results
are also
acceptable
if the absolute
value
of the
difference
between
the
monitor
response
value
and
the
reference
value,
R-A
in Equation
A-5
of this
Exhibit,
is
<=
1.0
LIg/scm.
CE
=
x
100
(Equation
A-5)
where,
CE =
Calibration
error
as a percentage
of
the
span
of
the
instrument.
R
=
Reference
value
of
zero
or
upscale
(high-level
or mid-level,
as
applicable)
calibration
gas
introduced
into
the
monitoring
system.
A
Actual
monitoring
system
response
to the
calibration
gas.
S
Span of
the
instrument,
as specified
in
Section
2 of this
Exhibit.
3.2 Linearity
Check
ror
2
CO
olzQ2
monitors
(including
02
:io,;
ased
to measure
CO
2
emissions
or
percent
moisture):
La)
The
error
in linearity
for
each calibration
gas
concentration
(low-,
mid-,
and
high-levels)
must
not
exceed
or
deviate
from the
reference
value
by
more
than
5.0
percent
as
calculated
using
Equation
A-4
of this
Exhibit;
or
10
(b)
The
absolute
value
of
the
difference
between
the
average
of
the
monitor
response
values
and
the
average
of
the
reference
values,
R-A
in
Equation
A-4
of
this
Exhibit,
must
be
less
than
or
equal
to
0.5
percent
CO
or
02,
whichever
is
less
restrictive.
(c)
For
the
linearity
check
and
the
3-level
system
integrity
check
of
a
mercury
monitor,
which
are
required,
respectively,
under
Section
1
.4(c)(1
)(B)
and
(c)(
1
)(E)
of
this
Appendix,
the
measurement
error
must
not
exceed
10.0
percent
of
the
reference
value
at
any
of
the
three
gas
levels.
To
calculate
the
measurement
error
at
each
level,
take
the
absolute
value
of
the
difference
between
the
reference
value
and
mean
CEM
response,
divide
the
result
by
the
reference
value,
and
then
multiply
by
100.
Alternatively,
the results
at
any
gas
level
are
acceptable
if
the
absolute
value
of
the
difference
between
the
average
monitor
response
and
the
average
reference
value,
i.e.,
R
—
Aj
in
Equation
A-4
of
this
Exhibit,
does
not
exceed
0.8
Igi’m
3
.
The
principal
and
alternative
performance
specifications
in
this
Section
also
apply
to
the
single-level
system
integrity
check
described
in
Section
2.6
of
Exhibit
B
to
this
Appendix.
LE
R-AI
=
x
100
(Equation
A-4)
where,
LE
=
Percentage
Linearity
error,
based
upon
the
reference
value.
R
=
Reference
value
of
Low-,
mid-,
or
high-level
calibration
gas
introduced
into
the
monitoring
system.
A
=
Average
of
the monitoring
system
responses.
3.3
Relative
Accuracy
3.3.1
Relative
Accuracy
for
CO
2
and
02
Monitors
The relative
accuracy
for
C0
and
0
monitors
must
not
exceed
10.0
percent.
The
relative
accuracy
test
results
are
also
acceptable
if
the
difference
between
-the
mean
value
of
the
C0
or
02 monitor
measurements
and
the
corresponding
reference
method
measurement
mean
value,
calculated
using
equation
A-7
of
this Exhibit,
does
not
exceed
+-
1.0
percent
CO
2
or
02,
d
=
d.
(Equation
A-7’)
where,
11
n
= Number
of data
points
d1
=
The difference
between
a referencemethod
value
and
the
corresponding
continuous
emission
monitoring
system
value
(RM—CEM)ata.given..pointintimei
3.3.2
Relative
Accuracy
for Flow
Monitors
(a)
The
relative accuracy
of
flow monitors
must not
exceed
10.0 percent
at any
load
(or
operating)
level
at
which
a
RATA
is
performed
(i.e.,
the low,
mid, or
high
level,
as
defined
in
Section
6.5.2.1
of
this
Exhibit).
(b)
For
affected units
where
the average
of the
flow
reference
method
measurements
of
gas
velocity
at a particular
load
(or
operating)
level
of the
relative
accuracy
test audit
is less
than or
eciual
to
10.0
fp
s, the
difference
between
the mean
value of the
flow
monitor
velocity
measurements
and
the
reference
method
mean
value
in
fps
at that level
must not
exceed
+-
2.0
fps, wherever
the
10.0.
percent
relative accuracy
specification
is
not
achieved.
3.3.3 Relative
Accuracy
for
Moisture
Monitoring
Systems
The
relative accuracy
of
a moisture
monitoring
system
must not
exceed
10.0
percent.
The
relative
accuracy
test
results
are
also acceptable
if the
difference
between
the
mean value
of
the
reference
method measurements
(in percent
H
2
0)
and
the corresponding
mean value
of
the
moisture
monitoring
system
measurements
(in
percent
0),2
H
calculated
using
Equation
A-7
of
this
Exhibit
does
not exceed
+-
1.5
percent
HO.
3.3.4 Relative
Accuracy
for Mercury
Monitoring
Systems
The
relative
accuracy
of
a mercury
concentration
monitoring
system or
a sorbent
trap
monitoring
system must
not
exceed
20.0 percent.
Alternatively,
for affected
units
where
the
average
of the
reference
method
measurements
of mercury
concentration
during
the relative
accuracy
test
audit
is
less than
5.0
jig/scm,
the
test
results
are acceptable
if the difference
between
the
mean
value
of
the
monitor
measurements
and the reference
method
mean value
does
not
exceed
1.0
jig/scm,
in
cases
where
the
relative accuracy
specification
of
20.0 percent
is
not achieved.
3.4 Bias
3.4.1 Flow
Monitors
Flow
monitors
must
not be biased
low
as
determined
by
the
test
procedure
in
Section
7.4
of this
Exhibit.
The bias
specification
applies
to all flow
monitors
including
those
measuring
an
average
gas
velocity
of 10.0
fps
or less.
12
3.4.2
Mercury
Monitoring
Systems
Mercury
concentration
monitoring-systems
and
sorbent
trap
monitoring
systems
must
not
be
biased
low
as
determined
by
the
test
procedure
in
Section
7.4
of
this
Exhibit.
3.5
Cycle
Time
The
cycle
time
for
mercury
concentration
monitors,
oxygen
monitors
used
to
determine
percent
moisture,
and
any
other
monitoring
component
of
a continuous
emission
monitoring
system
that
is
required
to
perform
a cycle
time
test
must
not
exceed
15
minutes.
4. Data
Acquisition
and
Handling
Systems
Automated
data
acquisition
and
handling
systems
must
read
and
record
the
full
range
of
pollutant
concentrations
and
volumetric
flow
from
zero
through
span
and
provide
a
continuous,
permanent
record
of
all
measurements
and
required information
as
an
ASCII
flat
file
capable
of
transmission
both
by
direct
computer-to-computer
electronic
transfer
via modem
and
EPA-provided
software
and
by
an
IBM-compatible
personal
computer
diskette.
These
systems
also
must
have
the
capability
of
- interpreting
and
converting
the
individual
output
signals
from
a
flow
monitor,
a
CO,
monitor,
an
02
monitor,
a
moisture
monitoring
system,
a
mercury
concentration
monitoring
system,
and
a
sorbent
trap
monitoring
system,
to
produce
a
continuous
readout
of
pollutant
emission
rates
or
-pollutant
-
mass
emissions
(as
applicable)
in
the
appropriate
units
(e.g.,
lb/hr.
lb/MMBtu, ounces/hr.
tons/br).
These
systems
also
must
have-
-the
capability
of
interpreting
and
converting
the
individual
output
signals
from
a flow
monitor
to produce
a
continuous
readout
of pollutant
mass
emission
rates
in the
units
of the
standard.
Where
CO
2
emissions
are
measured
with
a continuous
emission
monitoring
system,
the
data
acquisition
and
handling
system
must
also
produce a readout
of
CO
2
mass
emissions
in tons.
Data
acquisition and
handling
systems
must
also
compute
and
record
monitor
calibration
error;
any
bias
adjustments
to
mercury
pollutant
concentration
data,
flow
rate
data,
or
mercury
emission
rate
data.
5. Calibration
Gas
5.1
Reference
Gases
-
-
-
For
the
purposes
of
this
Appendix,
calibration
gases
include
the
following:
5.1.1
Standard
Reference
Materials
(SRM)
These
calibration
gases
may
be
obtained
from
the
National
Institute
of
Standards
and
Technology
(NIST)
at the
following
address:
Quince
Orchard
and
Cloppers
Road,
Gaithersburg,
MD
20899-
13
0001
5.1.2
SRM-Eguivalent
Compressed
Gas
Primary
Reference
Material
(PRM)
Contact
the
Gas
Metrology
Team,
Analytical
Chemistry
Division,
Chemical
Science
and
Technology
Laboratory
of
NIST,.at
the
address
in.
Section
5.l.l,for
a list
of
vendors
and
cylinder
gases.
5.1.3
NIST
Traceable
Reference Materials
Contact
the
Gas
Metrology
Team,
Analytical
Chemistry
Division,
Chemical
Science
and
Technology
Laboratory
of
NIST,
at the
address
in
Section
5.1.1,
for
a list
of
vendors
and
cylinder
gases
that
meet
the
definition
for a
NIST
Traceable
Reference
Material
(NTRM)
provided
in
40
CFR
72.2,
incorporated
by
reference
in Section
225.140.
5.1.4
EPA
Protocol
Gases
(a)
An
EPA
Protocol
Gas
is
a
calibration
gas mixture
prepared
and
analyzed
according
to
Section
2
of
the
“EPA
Traceability
Protocol
for Assay
and
Certification
of
Gaseous
Calibration
Standards,”
September
1997,
EPA-600/R-97/121
or
such
revised
procedure
as approved
by
the
Administrator
(EPA
Traceability
Protocol).
(b)
An EPA
Protocol
Gas
must
have
a
specialty
gas
producer-certified
uncertainty
(95-percent
confidence
interval)
that
must
not
be
greater
than
2.0 percent
of the
certified
concentration
(tag
value)
of the
gas
mixture.
The
uncertainty
must
be
calculated
using
the
statistical
procedures
(or
equivalent statistical
techniques)
that
are
listed
in Section
2.1.8
of the
EPA
Traceability
Protocol.
(c)
A
copy
of EPA-600/R-97/121
is
available
from
the
National
Technical
Information
Service,
5285
Port
Royal
Road,
Springfield.
VA,
703-605-6585
or
http://www.ntis.gov,
and
from
http://www.epa.
gov/ttnlemc/news.html or
http://
www.epa.gov/appcdwww/tsb/index.html.
5.1.5
Research
Gas
Mixtures
Research gas
mixtures
must
be
vendor-certified
to
be
within
2.0
percent
of
the
concentration
specified
on
the cylinder
label
(tag
value),
using
the
uncertainty
calculation
procedure
in
Section
2.1.8
of the
“EPA
Traceability
Protocol
for
Assay
and
Certification
of
Gaseous
Calibration
Standards,” September
1997,
EPA-600/R-97/121.
Inquiries
about
the
RGM
program
should
be
directed to: National
Institute
of
Standards
and
Technology,
Analytical
Chemistry
Division,
Chemical Science
and
Technology Laboratory,
B-324
Chemistry,
Gaithersburg,
MD
20899.
5.1.6
Zero
Air
Material
14
Zéroafr-rnaterialis
ipóratedb/refeTence
iii
Sëctioft225.T40.
5.1.7
N1ST/EPA-Approved
Certified
Reference
Materials
Existing
certified
reference
materials
(CRMs) that
are
still
within
their
certification
period
may
be
used
as
calibration
gas.
5.1.8
Gas Manufacturer’s
Intermediate
Standards
Gas
manufacturer’s
intermediate
standards
is
defined
in
40
CFR 72.2,
incorporated
by
reference
in
Section
225.140.
5.1.9
Mercury
Standards
For
7-day
calibration
error
tests
of
mercury
concentration
monitors
and
for
daily
calibration
error
tests
of
mercury
monitors,
either
NIST-traceable
elemental
mercury
standards
(as
defined
in
Section
225.130)
or
a
NIST-traceable
source
of
oxidized
mercury
(as
defined
in
Section
225.130)
may
be
used.
For linearity
checks,
NIST-traceable
elemental
mercury
standards
must
be
used.
For
3-
level
and single-point
system
integrity
checks
under
Section
1
.4(c)(1)(E)
of
this
Appendix,
Sections
6.2(g)
and 6.3.1
of
this Exhibit,
and
Sections
2.1.1,
2.2.1
and
2.6
of
Exhibit
B
to
this
Appendix,
a
NIST
traceable
source
of
oxidized
mercury
must
be
used.
Alternatively,
other
NIST-traceable
standards
may be
used-for
the
required
checks,
subject
to
the
approval
of
the
Agency.
Notwithstanding
these
requirements,
mercury
calibration
standards
that
are
not
NIST-traceable
may
be
used
for
the
tests
described
in
this
Section
until
December
31, 2009.
However,
on
and
after
January
1,
2010,
only
NIST-traceable
calibration
standards
must
be
used
for
these
tests.
5.2
Concentrations
Four
concentration
levels
are
required
as
follows.
5.2.1
Zero-level
Concentration
0.0
to
20.0
percent
of
span,
including
span
for
high-scale
or
both
low-
and
high-scale
for
CO,
and
02
monitors,
as
appropriate.
5.2.2
Low-level
Concentration
20.0 to
30.0 percent
of
span, including
span
for
high-scale
or
both-low--
and high-scale
for
CQ
2
and
Q
monitors,
as
appropriate.
5.2.3
Mid-level
Concentration
50.0 to
60.0
percent
of
span,
including span
for
high-scale
or
both
low-
and
high-scale
for
CO
2
and
15
Q2
monitors,:
asappropri’ate
5.2.4High-level
Concentration
80.0 to
100.0
percent
of span,
including
span
for
high-scale
orboth
low-and
high-scale
for
CO
2
and
Q2
monitors,
as
appropriate.
6.
Certification
Tests
and
Procedures
6.1 General
Requirements
6.1.1
Pretest
Preparation
Install
the
components
of the
continuous
emission
monitoring
system
(i.e.,
pollutant
concentration
monitors,
CO,
or
02
monitor,
and
flow
monitor)
as specified
in Sections
1, 2, and
3
of
this
Exhibit,
and
prepare
each
system
component
and
the combined
system
for
operation
in
accordance
with
the
manufacturer’s
written
instructions.
Operate
the
unit(s)
during
each
period
when
measurements
are
made.
Units
may
be tested
on
non-consecutive days.
To
the extent
practicable,
test
the
DABS
software
prior
to
testing
the
monitoring
hardware.
6.1.2
Requirements
for
Air
Emission
Testing
Bodies
(a)
On and
after
January
1, 2009,
any
Air Emission
Testing
Body
(AETB)
conducting
relative
accuracy
test
audits
of
CEMS
and
sorbent
trap
monitoring
systems
under
Part
225,
Subpart
B,
must
conform
to the
requirements
of
ASTM
D7036-04
(incorporated
by
reference
under
Section
225.140).
This
Section
is
not
applicable
to
daily
operation,
daily
calibration
error
checks,
daily
flow
interference
checks,
quarterly
linearity
checks
or
routine
maintenance
of CEMS.
(b’)
The AETB
must
provide
to
the affected
source(s)
certification
that the
AETB
operates
in
conformance
with,
and
that
data
submitted
to the
Agency
has
been
collected
in accordance
with,
the
requirements
of
ASTM
D7036-04
(incorporated
by
reference
under
Section:225.i4O).
This
certification
may
be
provided
in
the
form
of:
(1)
A
certificate
of
accreditation
of relevant
scope
issued
by
a recognized,
national
accreditation
body:
or
(2)
A
letter
of
certification
signed
by
a
member
of
the senior
management
staff
of the AETB.
(c)
The AETB
must
either
provide
a
Qualified
Individual
on-site
to
conduct
or
must
oversee
all
relative
accuracy
testing
carried
out
by
the AETB
as
required
in ASTM
D7036-04
(incorporated
by
reference
under
Section
225.140).
The
Qualified
Individual
must provide
the affected
source(s)
with
copies
of the
qualification credentials
relevant
to the
scope
of the
testing
conducted.
16
6.2
Li±
Check
the
linearity
of
each
CO,.
Hg,
and
02
monitor
while
the
unit,
or
group
of
units
for
a
common
stack,
is
combustingfuel.
atconditions
of
typical
stack
temperature
and
pressure;
it
is
not
necessary
for
the
unit
to
be
generating
electricity
during
this
test.
For
units
with
two
measurement
ranges
(high
and
low)
for
a
particular
parameter,
perform
a
linearity check
on
both
the
low
scale
and
the
high
scale.
For
on-going
quality
assurance
of
the
CEMS,
perform
linearity
checks,
using
the
procedures
in
this
Section,
on
the
range(s)
and
at
the
frequency
specified in
Section
2.2.1
of
Exhibit
B
to
this
Appendix.
Challenge
each
monitor
with
calibration
gas,
as
defined
in
Section
5.1
of
this
Exhibit,
at
the
lowmid-,
and high-range
concentrations
specified
in
Section
5.2
of
this
Exhibit.
Introduce
the
calibration
gas
at
the gas
injection
port,
as
specified
in
Section
2.2.1
of
this Exhibit.
Operate
each
monitor
at
its
normal
operating
temperature
and
conditions.
For
extractive
and
dilution
type
monitors,
pass
the calibration
gas
through
all
filters,
scrubbers,
conditioners,
and
other
monitor
components
used
during
normal
sampling
and
through
as
much
of
the
sampling
probe
as
is
practical.
For
in-situ
type
monitors,
perform
calibration
checking
all
active
electronic
and
optical
components..
including
the
transmitter,
receiver,
and
analyzer.
Challenge
the
monitor
three
times
with
each
reference
gas
(see
example
data
sheet
in
Figure
1).
Do
not
use
the
same
gas
twice
in
succession.
To
the
extent
practicable,
the
duration
of
each
linearity
test,
from
the
hour
of
the
first
injection
to
the
hour
of
the last
injection,
must
not
exceed
24
unit
operating
hours.
Record
the
monitor
response
from
the
data acquisition
and
handling
system.
For
each
concentration,
use
the
average
of
the
responses
to
determine
the
error
in
linearity
using Equation
A-4
in
this
Exhibit.
Linearity
checks
are
acceptable
for
monitor
or
monitoring
system
certification,
recertification,
or
quality
assurance
if
none
of
the
test
results
exceed
the
applicable
perfonnance
specifications
in
Section
3.2
of
this
Exhibit
The
status
of
emission
data
from
a
CEMS
prior
to
and
during
a
linearity
test
period
must
be
determined
as
follows:
(a)
For
the initial
certification
of
a
CEMS,
data
from the
monitoring
system
are
considered
invalid
until
all certification
tests,
including
the
linearity
test,
have
been
successfully
completed,
unless
the
conditional
data validation
procedures
in
Section
1
.4(b)(3) of
this
Appendix
are
used.
When
the
procedures
in
Section
1
.4(b)(3)
of
this
Appendix
are
followed,
the
words
“initial
certification”
apply
instead
of
“recertification,”
and
complete
all
of
the
initial
certification
tests
by
January
1,
2009,
rather
than
within
the
time
periods
specified
in
Section
1
.4(b)(3)(D)
of
this
Appendix
for
the
individual
tests.
(b)
For
tue
ruuL
assurance
linearity
checks
required
by
Section
2.2.1
of
Exhibit
B
to
this
Appendix,
use
the
data validation
proc:
cection
2.2.3
of
Exhibit
B
to
this
Appendix.
(c)
When
a
linearity
test
is
required
as
a
diagnostic
test
or
for
recertification,
use
the
data
validation
procedures
in
Section
1.4
(b)(3)
of
this
Appendix.
(d)
For linearity
tests of
non-redundant
backup
monitoring
systems,
use
the
data
validation
procedures
in
Section
1
.4(d)(2)(C)
of
this
Appendix.
17
(e)
theexpiratiorrofagraceperkod
use
the
data
validation
procedures
in Sections 2.2.3
and 2.2.4,
respectively, of
Exhibit
B
to this
Appendix.
(f)
For all other
linearity
checks, use
the data validation
procedures
in Section 2.2.3
of Exhibit
B to
this Appendix.
(g)
For
mercury monitors,
follow the
guidelines in Section
2.2.3 of
this
Exhibit
in
addition
to
the
applicable
procedures
in Section 6.2 when
performing
the system
integrity
checks
described
in
Section
1.4(c)(1)(E)
and in
Sections 2.1.1,
2.2.1, and 2.6
of Exhibit B to this
Appendix.
(h)
For
mercury concentration
monitors,
if moisture
is added to the
calibration
gas
during
the
recuired
linearity
checks
or system integrity
checks,
the
moisture content
of the calibration
gas
must
be accounted
for. Under these
circumstances,
the dry basis
concentration
of the calibration
gas
must
be
used to
calculate the linearity
error
or measurement
error
(as applicable).
6.3 7-Day
Calibration
Error
Test
6.3.1 Gas
Monitor 7-day Calibration
Error Test
Measure the
calibration error of each
mercury
concentration monitor,
and
each
CO
2 or
0,
monitor
while the
unit is combusting
fuel
(but
not
necessarily
generating
electricity)
once each
day
for
7
consecutive
operating
days
according to the
following procedures.
For mercury
monitors,
you
may
perform this test using
either elemental mercury
standards
or a NIST-traceable
source
of
oxidized
mercury.
Also
for
mercury
monitors, if
moisture is
added to the calibration
gas,
the added
moisture
must be
accounted for
and the
dry-basis
concentration
of the calibration
gas
must
be
.used
to
calculate
the
calibration
error.
(In
the
event
that unit
outages occur
after the
commencement
of
the
test,
the
7
consecutive
unit
operating
days need
not
be 7 consecutive calendar
days.)
Units
using
dual
span monitors
must
perform
the
calibration error
test
on both high-
and low-scales
of
the
pollutant
concentration
monitor.
The calibration
error test
procedures
in
this
Section and
in
Section
6.3.2
of
this
Exhibit
must also be used
to perform the
daily assessments and
additional
calibration
error
tests
required
under
Sections 2.1.1
and
2.1.3
of Exhibit
B
to
this
Appendix. Do not
make
manual
or
automatic
adjustments to the monitor
settings
until after taking measurements
at both
zero
and
high
concentration
levels
for that
day during the
7-day
test. If automatic
adjustments
are
made
following
both
injections,
conduct the
calibration error
test such
that
the magnitude of
the
adjustments
can
be
determined and
recorded.
Record and
report test results
for cach
day
using
the
unadjusted
concentration
measured
in
the calibration
error
test prior to making
any manual
or
automatic
adjustments
(i.e.,
resetting the
calibration). The calibration
error
tests should
be approximately
24
hours
apart,
(unless
the
7-
day
test
is performed
over
non-consecutive
days).
Perform
calibration
error tests at
both the zero-level
concentration
and high-level
concentration,
as specified
in
Section
5.2
of this
Exhibit. Alternatively,
a
mid-level
concentration
gas
(50.0
to
60.0
percent
of
the
span
value)
may be used
in
lieu of the high-level
gas,
provided
that
the mid-level
gas
is
more
representative
of the actual
stack gas concentrations.
Use only
calibration
gas, as specified
in
Section
18
5.1
of
this
Ehib’iL
Jñtroducethe’
calibration
gas
at
the’gasiniection
port,’
as
specffiediriSecón22J
of
this
Exhibit.
Operate
each
monitor
in
its
normal
sampling
mode.
For
extractive
and
dilution
type
monitors,
pass
the
calibration
gas
through
all
filters,
scrubbërs,
conditioners,
and•
other
monitor
components
used
during
normal
sampling
and
through
as:much.
of
the
sampling
probe
as
is
practical.
For
in-situ
type
monitors,
perform
calibration,
checking
all
active
electronic
and
optical
components,
including
the transmitter,
receiver,
and
analyzer.
Challenge
thern
pollutant
concentration
monitors
and
cQ
or
02
monitors
once
with
each
calibration
gas. Record
the
monitor
response
from
the
data
acquisition
and handling
system.
Using
Equation
A-5
of
this
Exhibit,
determine
the
calibration
error
at
each
concentration
once
each
day
(at
approximately
24-hour
intervals)
for
7
consecutive
days
according
to
the procedures
given
in
this
Section.
The
results
of
a
7-day
calibration
error
test
are
acceptable
for monitor
or
monitoring
system
certification,
recertification
or
diagnostic
testing
if
none
of
these
daily
calibration
error
test
results
exceed
the
applicable
performance
specifications
in
Section
3.1
of
this Exhibit.
The
status
of
emission
data
from
a
gas
monitor
prior
to
and
during
a
7-
day
calibration
error
test
period
must
be
determined
as
follows:
(a)
For
initial
certification,
data
from
the
monitor
are
considered
invalid
until
all
certification
tests.
including
the
7-day
calibration
error
test,
have
been
successfully
completed,
unless
the
conditional
data
validation
procedures
in
Section
1
.4(b)(3)
of
this
Appendix
are
used.
When
the
procedures
in
Section
1.4(b)(3)
of
this
Appendix
are
followed,
the
words
“initial
certification”
apply
instead
of
“recertification,”
and complete
all
of
the
initial
certification
tests
by
January
1,
2009,
rather
than
within
the
time
periods
specified
in
Section
1
.4(b)(3)(D)
of
this
Appendix
for
the
individual
tests.
(b)
When
a
7-day
calibration
error
test
is
required
as
a
diagnostic
test
or
for
recertification,
use
the
data validation
procedures
in
Section
1
.4(b)(3)
of
this
Appendix.
6.3.2
Flow
Monitor
7-day
Calibration
Error
Test
Flow
monitnr
installed
on
peaking
units
(as
defined
in
40
CFR
72.2,
incorporated
by
reference
in
Section
225
140)
are
excivpteu
1Iou
‘
1
ay
calibration
error
test
requirements
of
this
part
In
all
other
cases,
perform
the
7-day
calibration
erir
test
of
a
flow
monitor,
when
required
for
certification,
recertification
or
diagnostic
testing,
according
io
:e
foHowing
procedures.
Introduce
the reference
signal
corresponding
to
the
values
specified
in
Section
2.2.2.1
of
this
Exhibit
to
the
probe
tip
(or
equivalent),
or
to
the
transducer.
During
the
7-day
certification
test
period,
conduct
the
calibration
error
test
while
the
unit
is
operating
once
each
unit
operating
day
(as
close
to
24-hour
intervals
as
practicable).
In
the
event
that
unit outages
occur
after
the
commencement
of
the
test,
the
7
consecutive
operating
days
need
not
be 7
consecutive
calendar
days.
Record
the
flow
monitor
responses
by
means
of
the
data
acquisition
and
handling
system.
Calculate
the
calibration
error
using
Equation
A-6
of
this Exhibit.
Do
not
perform
any
corrective
maintenance,
repair,
or
replacement
upon
the
flow
monitor
during
the
7-day
test
period
other
than
that
required
in
the
quality
assurance/quality
control
plan
required
by
Exhibit
B
to
this
Appendix.
Do
not
make
adjustments
between
the
zero
and
high
reference
level
measurements
on
any
day
during
the
7-day
test.
If
the
flow
monitor
operates
within
the
calibration
error
performance
specification
(i.e.,
less
than
or
equal
to
3.0
percent
error
each
day
and
requiring
no
corrective
maintenance,
repair,
or
replacement
during
the
7-
19
day
testperiod),
alLmaintenance•aetivjtiés
and
the magnitude
of any
adjustments.
Record
output
readings
from the
data
acquisition
and
handling
system
bef6re
and
after
all
adjustments.
Record
and
report
all
calibration
error test
results
using
the
unadjusted
flow
rate
measured
in the calibration
error test
prior
to resetting
the
calibration.
Record
all adjustments
made
during
the
7-day period
at the time
the
adjustment
is made,
and
report
them
in the certification
or recertification
ap.plication
The. status
of emissions
data
from
a flow
monitor
prior
to and
during
a 7-day
calibration
error test
period
must be
determined
as
follows:
(a)
For
initial
certification,
data
from
the
monitor
are considered
invalid
until
all
certification
tests,
including
the
7-day
calibration
error test,
have been
successfully
completed,
unless
the
conditional
data
validation
procedures
in
Section
l.4(b)(3)
ofthis
Appendix
are
used.
When
the
procedures
in
Section
1
.4(b)(3)
of
this Appendix
are followed,
the
words
?initial
certification’
apply
instead
of
“recertification,”
and
complete
all of the
initial
certification
tests
by
January 1,
2009,
rather
than
within the
time
periods
specified
in Section
1
.4(b)(3)(D)
of
this Appendix
for
the
individual
tests.
(b) When
a 7-day
calibration
error
test is
required as
a diagnostic
test or
for
recertification,
use the
data validation
procedures
in Section
1
.4(b)(3).
CE
=
x
100
(Equation
A-6)
S
where:
CE
= Calibration
error
as a
percentage
of span.
R =
Low or
high level
reference
value
specified
in
Section
2.2.2.1
of
this Exhibit.
A = Actual
flow
monitor
response
to
the reference
value.
S
= Flow
monitor
calibration
span
value
as
determined
under
Section
2.1.2.2 of this
Exhibit.
6.3.3
For
gas
or
flow
monitors
installed
on peaking
units,
the
exemption
from performing
the
7-day
calibration
error test
applies
as long as
the unit continues
to meet the
definition
of
a
peaking
unit
in
40
CFR
72.2, incorporated
by
reference
in
Section
225.140.
However,
if at
the end
of a
particular
calendar
year
or ozone season,
it is
determined
that
peaking
unit
status has
been lost,
the
owner
or
operator
must
perform
a diagnostic
7-day calibration
error test
of each monitor
installed
on
the
unit,
by
no
later
than December
31 of
the
following
calendar
year.
6.4 Cycle
Time
Test
20
Perform
cycle
time
tests
for
each
pollutant
concentration
monitor
and
continuous
emission
monitoring
system
while
the
unit
is
operating,
according
to
the
following
procedures.
Use
a zero-
level
and
a
high-level
calibration
gas’
(asdefined.
in.
Section
5.2
of
this
Exhibit)
alternately.
For
mercury
monitors,
the
calibration
gas
used
for
this
test
may
either
be
the elemental
or
oxidized
form
of mercury.
To
determine
the
downscale
cycle
time,
measure
the
concentration
of
the
flue
gas
emissions
until
the
response
stabilizes.
Record
the
stable
emissions
value.
Inject
a
zero-level
concentration
calibration
gas
into
the
probe
tip
(or
injection
port
leading
to
the
calibration
cell,
for
in
situ
systems
with
no
probe).
Record
the
time
of
the
zero
gas
injection,
using
the
data
acquisition
and
handling
system
(DAHS).
Next,
allow
the monitor
to
measure
the
concentration
of the
zero
gas
until
the
response
stabilizes.
Record
the
stable
ending
calibration’
gas
reading.
Determine
the
downscale
cycle
time
as the
time
it
takes
for
95.0
percent
of the
step
change
to
be
achieved
between
the
stable
stack
emissions
value
and
the
stable
ending
zero
gas
reading.
Then
repeat
the
procedure,
starting
with
stable stack
emissions
and
injecting
the
high-level
gas,
to
determine
the
upscale
cycle
time.
which
is
the
time
it
takes
for
95.0
percent
of
the
step
change
to
be
achieved
between
the
stable
stack
emissions
value
and
the
stable
ending
high-level
gas
reading.
Use the
following
criteria
to
assess
when
a
stable
reading
of
stack
emissions
or
calibration
gas
concentration
has
been
attained.
A
stable
value
is equivalent
to
a reading
with
a
change
of
less
than
2.0
percent
of
the
span
value’
for
2
minutes,
or
a
reading
with
a change
of
less
than
6.0
percent
from
the
measured
average
concentration
over
6 minutes.
Alternatively,
the
reading
is considered
stable
if it
changes
by
no
more
than
0.5
ppm,
0.5
g/m
3
(for
mercury) for
two
minutes.
(Owners
or
operators
of systems
which
do
not
record
data
in
1-minute
or
3-minute
intervals
may.
petition
the
Agency
for
alternative
stabilization
criteria). For
monitors
or
monitoring
systems that
perform
a
series
of
operations
(such
as purge, sample,
and
analyze),
time
.the injections
of
the
calibration
gases
so
they
will
produce
the
longest
possible
cycle
time.
Refer
to
Figures
6a
and
6b
in
this
Exhibit
for
example
calculations
of
upscale
and
downscale
cycle
times.
Report
the
slower
of
the
two
cycle
times
(upscale
or
downscale)
as
the
cycle
time
for
the
analyzer.
On
and
after
January
1,
2009,
record
the
cycle
time
for
each
component
analyzer
separately.
For
time-shared
systems,
perform
the
cycle
time
tests
at
each
probe
locations
that
will
be
polled
within
the
same
15-minute
period
during
monitoring
system
operations.
To
determine
the
cycle
time
for
time-shared
systems,
at
each
monitoring
location,
report
the
sum
of
the
cycle
time
observed
at that
monitoring
location
plus
the
sum
of
the
time
required
for
all
purge
cycles
(as
determined
by the
continuous
emission
monitoring
system
manufacturer)
at
each
of
the
probe
locations
of
the
time-shared
systems.
For
monitors
with
dual
ranges,
report
the
test
results
for
each
range
separately.
Cycle
time
test
results
are
acceptable
for
monitor
or
monitoring
system
certification,
recertification
or
diagnostic
testing
if
none
of
the
cycle
times
exceed
15
minutes.
The
status
of
emissions
data
from
a
monitor
prior
to
and
during
a
cycle
time
test
period
must
be
determined
as
follows:
(a)
For
initial
certification,
data
from
the
monitor
are
considered
invalid
until
all
certification
tests,
including
the
cycle
time
test,
have
been
successfully
completed,
unless
the
conditional
data
validation procedures
in Section
1
.4(b)(3) of
this
Appendix
are
used.
When
the
procedures
in
Section
1 .4(b)(3) of this
Appendix
are
followed,
the
words
“initial
.certification”
apply
instead
of
“recertification,”
and
complete
all of
the
initial
certification
tests
by
January
1,
2009,
rather
than
21
within’the’tinie
periods’speci’ffedin Section
.4(b4E•3)(DYofthisAppendix’fortheindividüai.
tests.
(b)
When a cycle time test is required as a diagnostic test or
for rcertificatiön,
use the
data
validation
procedures in Section
1
.4(b)(3.)
of this Appendix.
6.5 Relative Accuracy and
Bias Tests
(General Procedures)
Perform
the required relative accuracy test
audits
(RATAs)
as follows for each flow
monitor,
each
Q2
or CO
2 diluent monitor used to calculate heat input, each
mercury concentration
monitoring
system, each sorbent
trap
monitoring system,
and each moisture monitoring system:
(a) Except as
otherwise provided
in
this paragraph,
perform
each RATA while the
unit
(or
units,
if
more than one unit exhausts into the flue) is combusting the fuel that
is a normal primary
or
backup
fuel for that unit
(for
some
units, more than one type
of fuel may be considered normal,
e.g.,
a
unit
that combusts
gas or oil on
a seasonal
basis).
For units that co-fire fuels
as
the
predominant
mode
of
operation, perform the RATAs while co-firing. For mercury
monitoring
systems,
perform the
RATAs while the unit is combusting coal. When relative accuracy test audits are
performed
on
CEMS
installed on
bypass
stacks/ducts,
use
the
fuel
normally combusted
by
the
unit (or
units,
if
more
than one unit exhausts into the
flue)
when emissions
exhaust through the bypass
stack/ducts.
(b)
Perform each RATA at the load
(or
operating)
level(s)
specified
in Section 6.5.1 or
6.5.2
of this
Exhibit or in Section 2.3.1.3 of Exhibit B to this Appendix, as applicable.
(c)
For monitoring
systems with
dual ranges,
perform
the relative
accuracy
test on
the
range
normally used
for measuring emissions. For
units with add-on mercury
controls
that
operate
continuously
rather than
seasonally,
or for units
that
need a dual, range to record high
concentration
“spikes”
during startup conditions, the low range is considered
normal. However, for
some
dual
span
units
(e.g., for units that use
fuel
switching or for which
the emission controls
are
operated
seasonally),
provided
that
both monitor ranges
are connected
to
a common
probe
and
sample
interface,
either
of the two measurement ranges may
be considered normal; in such
cases,
perform
the
RATA on the range that is in use at the time of the
scheduled test. If the low
and
high
measurement
ranges are connected to separate sample
probes
and interfaces, RATA
testing
on
both
ranges is
required.
(d)
Record monitor or monitoring
system output
from the data acquisition and
handling
system.
(e)
Complete
each single-load relative accuracy test
audit within
a
period
of 168
consecutive
unit
operating
hours, as
defined
in
40 CFR 72.2, incorporated
by reference in
Section 225. 140
(or,
for
CEMS
installed on
common stacks or bypass
stacks, 168 consecutive stack
operating
hours,
as
defined
in 40 CFR
72.2, incorporated
by
reference
in Section
225.140). Notwithstanding
this
requirement, up to
336 consecutive unit or stack
operating hours
may be taken to
complete
the
RATA of a
mercury monitoring
system,
when ASTM 6784-02
(incorporated
by
reference
under
Section
225.140)
or
Method
29
in appendix A-8 to
40 CFR 60, incorporated
by reference
in
Section
22
225
l40isused
asth&
referet
cenetho
For-2-1eve}and34eveiflow
moniforRATAs,
comD}ete
afi
of
the
RATAs
at
all
levels,
to
the
extent
practicable,
within
a
period
of
168
consecutive
unit
(or
stack)
operating
hours
however,
if
this
is
not
possible,
up
to
720 consecutive
unit
(or
stack)
operating
hoursmay.be
taken4o:comp1etearnu1tip1e-load
flow
RATA..
(f)
The status
of
emission
data
from
the
CEMS
prior,
to
and
during
the
RATA
test
period
must
be
determined
as
follows:
(1)
For
the
initial
certification
of
a
CEMS,
data
from the
monitoring
system
are
considered
invalid
until
all certification
tests,
including
the
RATA,
have
been
successfully
completed,
unless
the
conditional
data
validation
procedures
in
Section
1
.4(b)(3)
of
this
Appendix
are
used.
When
the
procedures
in
Section
1
.4(b)(3)
of
this
Appendix
are
followed,
the
words
“initial
certification”
apply
instead
of
“recertification,”
and
complete
all
of
the
initial
certification
tests
by
January
1,
2009,
rather
than
within
the
time periods
specified
in
Section
1
.4(b)(3)(D)
of
this
Appendix
for
the
individual
tests.
(2)
For the
routine
quality
assurance
RATAs
required
by
Section
2.3.1
of
Exhibit
B
to
this
Appendix,
use
the
data validation
procedures
in
Section
2.3.2
of
Exhibit
B
to
this
Appendix.
(3)
For
recertification
RATAs,
use
the
data
validation
procedures
in
Section
1
.4(b)(3).
(4)
For quality
assurance
RATAs
of
non-redundant
backup
monitoring
systems,
use
the
data
validation
procedures
in
Sections
1.4(d)(2)(D)
and
(E)
of
this
Appendix.
(5)
For RATAs
performed
during
and
after
the
expiration
of
a
grace
period,
use
the
data
validation
procedures
in
Sections
2.3.2
and
2.3.3,
respectively,
of
Exhibit
B
to
this.
Appendix.
(6)
For all
other
RATAs,
use
the
data
validation
procedures
in
Section
2.3.2
of
Exhibit
B
to
this
Appendix.
(g)
For
each
flow monitor,
each
CQ2
or
02
diluent
monitor
used
to
determine
heat
input,
each
moisture
monitoring
system,
each
mercury
concentration
monitoring
system,
and
each
sorbent
trap
monitoring
system,
calculate
the
relative
accuracy,
in
accordance
with
Section
7.3
of
this
Exhibit,
as
applicable.
6.5.1
Gas and
Mercury
Monitoring
System
RATAs
(Special
Considerations)
(a)
Perform
the
required
relative
accuracy
test
audits
for
each
CO
2
or
0, diluent
monitor
used
to
determine heat
input, each
mercury
concentration
monitoring
system,
and
each
sorbent
trap
monitoring
system
at
the normal
load
level
or
normal
operating
level
for
the
unit
(or
combined
units,
if
common
stack),
as
defined
in
Section
6.5.2.1
of
this Exhibit.
If
two load
levels
or
operating
levels
have
been
designated
as
normal,
the
RATAs
may
be
done
at
either
load
level.
23
(b)
For
the initialcertiflthtionfa
:gasor meru.ry”nioni.tring..system:.•and
:
forrectjflóations
in,,
which,
in
addition to
a RATA,
one
or more
other
tests
are required
(i.e.,
a
linearity
test,
cycle
time
test, or
7-day
calibration
error
test), the
Agency recommends
that
the RATA
not
be
commenced
until
the
other
required
tests.of
the:
CEMShave
been.
passed
6.5.2
Flow
Monitor RATAs;(Special
Considerations)
(a) Except
as
otherwise
provided
in paragraph
(b)
or
(e)
of
this Section,
perform
relative
accuracy
test audits
for the
initial
certification
of each
flow
monitor
at three
different
exhaust
gas
velocities
(low,
mid,
and
high),
corresponding
to three
different
load levels
or
operating
levels
within
the
range
of operation,
as
de±ine&
iii
Section
6.5.2.1 of
this’ Exhibit
For a
common
stack/duct,
the
three
different
exhaust
gas
velocities
may
be
obtained
from
frequently
used
unit/load
or
operating
level
combinations
for
the
units exhausting
to the
common
stack.
Select the
three
exhaust
gas
velocities
such
that
the audit
points at
adjacent
load
or
operating
levels
(i.e.,
low
and
mid or
mid and
high),
in
megawatts
(or
in
thousands
of
lb/hr
of
steam
production
or in fl/sec.
as
applicable),
are
separated
by
no less
than 25.0 percent
of the
range of
operation,
as defined
in Section
6.5.2.1
of
this
Exhibit.
(b)
For flow
monitors
on bypass
stacks/ducts
and
peaking units,
the flow
monitor
relative
accuracy
test
audits
for
initial
certification
and
recertification
must
be single-load
tests,
performed
at the
normal
load, as
defined in
Section
6.5.2.1(d)
of
this Exhibit.
(c)
Flow
monitor
recertification
RATAs
must
be done
at
three load
level(s)
(or
three
operating
levels),
unless
otherwise
specified
in
paragraph
(b)
or
(e)
of
this
Section
or
unless
otherwise
specified
or approved
by
the
Agency.
(d)
The semiannual
and annual
quality
assurance
flow monitor
RATAs
required
under
Exhibit
B to
this Appendix
must be done
at the
load level(s)
(or
operating
levels)
specified
in Section
2.3.1.3
of
Exhibit
B to
this
Appendix.
(e)
For
flow
monitors
installed on
units that
do
not
produce
electrical
or thermal
output,
the
flow
RATAs
for
initial certification
or
recertification
may
be done
at
fewer
than three
operating
levels,
if:
(1)
The
owner
or
operator provides
a
technical
justification
in the
hardcopy
portion
of the
monitoring
plan for
the
unit
required
under 40
CFR
75.53(e)(2),
incorporated
by
reference
in
Section
225.140,
demonstrating
that the
unit operates
at only
one level or
two levels
during
normal
operation
(excluding
unit
startup
and
shutdown).
Appropriate
documentation
and
data must
be
provided
to
support
the claim
of
single-level
or
two-level
operation;
and
(2)
The
justification
provided
in
paragraph
(e)(1)
of this
Section
is deemed
to be
acceptable
by
the
permitting
authority.
6.5.2.1
Range
of Operation
and
Normal
Load
(or
Operating)
Level(s)
24
(a
Theowneror”operator
must
dëtermine
the:
‘ge
of•
operation”
as
follows
for
each
unit
(or
combination
of
units,
for
common
stack
configurations):
(1)
For
affected
units
that
produce electrical:
output
(in
megawatts)
or:
thermal
output
(in
klb/hr
of
steam
production
or
mmBtulhr),
the
lower
boundary
of
the
range
of
operation
of
a
unit
must
be
the
minimum
safe,
stable
loads
for
any
of
the units
discharging
through
the
stack.
Alternatively,
for
a
group
of
frequently-operated
units
that
serve
a
common
stack,
the
sum
of
the
minimum
safe,
stable
loads
for
the individual
units
may
be
used
as
the
lower
boundary
of
the
range
of
operation.
The
upper
boundary
of
the
range
of
operation
of
a
unit
must
be
the
maximum
sustainable
load.
The
“maximum
sustainable
load”
is
the
higher
of
either:
the
nameplate
or
rated
capacity
of
the
unit,
less
any physical
or
regulatory
limitations
or
other
deratings;
or
the highest
sustainable
load,
based
on
at
least
four
quarters
of
representative
historical
operating
data.
For
common
stacks,
the
maximum
sustainable
load
is
the
sum
of
all
of
the maximum
sustainable
loads
of
the
individual
units
discharging
through
the
stack,
unless
this
load
is
unattainable
in
practice,
in
which
case
use
the
highest
sustainable
combined
load
for
the
units
that
discharge
through
the
stack.
Based
on
at
least
four
quarters
of
representative
historical
operating
data.
The
load
values
for
the
unit(s)
must
be
expressed
either
in
units
of
megawatts
of
thousands
of
lb/hr
of
steam
load
or
mmBtu!hr
of
thermal
output;
or
(2)
For affected
units
that
do not
produce
electrical
or
thermal
output,
the
lower
boundary
of
the
range
of
operation
must
be
the
minimum
expected
flue
gas
velocity
(in
ft/sec)
during
normal,
stable
operation
of
the unit.
The
upper
boundary
of
the
range
of
operation
must
be the
maximum
potential
flue
gas velocity
(in
fi/sec)
as
defined
in
Section
2.1.2.1
of
this
Exhibit.
The
minimum
expected
and
maximum
potential
velocities
may
be derived
from
the
results
of
reference
method
testing
or
by
using
Equation
A-3a
or
A-3b
(as
applicable)
in
Section
2.1.2.1
of
this
Exhibit.
If
Equation
A-3a
or
A-3b
is
used
to
determine
the
minimum
expected
velocity,
replace
the
.word
“maximum”
with
the
word
“minimum”
in
the
definitions
of
“MPV,”
“Hf,”
“
°2d
,“
and
%H
20
,“
arid
replace
the
word
“minimum”
with
the
word
“maximum”
in
the
definition
of
“CO
1
.”
Alternatively,
0.0
ft/sec
may
be
used
as
the
lower
boundary
of
the
range
of
operation.
b)
The operating
levels
for
relative
accuracy
test
audits
will,
except
for
peaking
units,
be
defined
as
follows:
the
“low”
operating
level
will
be
the
first 30.0
percent
of
the
range
of
operation;
the
“mid”
operating
level
will
be
the middle
portion
(>30.0
percent,
but
<=60.0
percent)
of
the
range
of
operation;
and the
“high”
operating
level
will
be the
upper
end
(>60.0 percent)
of
the
range
of
operation.
For example,
if
the
upper
and
lower
boundaries
of
the
range
of
operation
are
100
and
1100
megawatts,
respectively,
then
the
low,
mid,
and
high
operating
levels
would
be
100
to
400
megawatts,
400
to
700 megawatts,
and
700
to
1100
megawatts,
respectively.
(c)
Units
that
do not
produce
electrical
or
thermal
output are
exempted
from
the
requirements
of
this
paragraph,
(c). The
owner
or
operator
must
identify,
for
each
affected
unit
or
common
stack,
the
“normal”
load
level
or levels
(low,
mid
or
high),
based
on
the
operating
history
of
the
unit(s).
To
identify
the
normal
load
level(s), the
owner
or
operator
must,
at
a
minimum,
determine
the
relative
number
of
operating
hours
at
each
of
the
three
load
levels,
low,
mid
and
high
over
the
past
four
25
representative
.operating’guarteis
The
owner:oroperatormust
determine.,
tothenearest’0Jpercent,
the
percentage of
the time that each
load level
(low,
mid,
high)
has been used
during
that
time
period.
A summary
of th data used
for this determination
and
the calculated results
must
be kept
on-
site
in
a
format suitable for
inspection.
For
new
units
or
newly-affected
units,
the data
analysis
in
this
paragraph
may
be based
on fewer
than four
quarters
of data
if
fewer
than four
representative
quarters
of
historical
load
data are
available.
Or,
if no historical
load
data
are available,
the
owner
or
operator
may
designate
the
normal
load
based
on the
expected
or
projected
manner
of
operating
the
unit. However,
in either
case, once four quarters
of
representative
data become
available,
the
historical
load
analysis must be
repeated.
(d)
Determination
of normal load
(or
operating
level)
(1)
Based
on
the analysis of the
historical
load data described
in paragraph
(c)
of
this
Section.
the
owner
or
operator
must, for
units that produce
electrical
or thermal output,
designate
the
most
frequently
used load level as the
normal
load
level for the unit
(or
combination
of units,
for
common
stacks).
The
owner or operator
may also designate
the second
most frequently
used load
level
as
an
additional
normal load level
for the
unit or
stack. If the manner
of operation
of
the unit
changes
significantly,
such
that
the
designated
normal
load(s) or the
two most
frequently used
load
levels
change, the
owner
or
operator
must repeat
the historical
load analysis and
must
redesignate
the
normal
lodis)
and
the
two
most frequently
used load levels,
as appropriate.
A
minimum
of
two
representative
quarters
of historical
load data are required
to document
that a
change
in
the
maimer
of
unit operation
has occurred.
Update
the
electronic
monitoring
plan whenever
the
normal
load
level(s)
and the
two most frequently-used
load levels
are redesignated.
(2)
For
units that do not
produce
electrical
or thermal output,
the
normal
operating
level(s)
must
be
determined
using
sound
engineering
judgment,
based
on knowledge
of the unit
and
operajpg
experience
with the industrial
process.
(e)
The owner or
operator
must report
the
upper
and
lower boundaries
of the range
of
operation
for
each unit
(or
combination
of units,
for common
stacks),
in units
of megawatts
or
thousands
of lb/hr
or
mmBtu/hr of steam
production
or ft/sec
(as
applicable),
in the
electronic monitoring
plan
required
under Section
1.10
of
this Appendix.
6.5.2.2 Multi-Load
(or
Multi-Level)
Flow
RATA
Results
For
each
multi-load
(or
multi-level)
flow RATA,
calculate
the
flow monitor
relative
accuracy
at each
operating
level. If a flow
monitor relative accuracy
test is
failed or
aborted
due to a
problem
with
the
monitor on any
level
of a 2-level
(or 3-level)
relative
accuracy
test audit, the
RATA
must
be
repeated at that
load
(or operating)
level. However,
the entire 2-level
(or 3-level)
relative
accuracy
test
audit
does not
have
to be repeated
unless
the
flow monitor polynomial
coefficients
or
K-factor(s)
are
changed,
in
which
case
a 3- level RATA is required
(or,
a 2-level RATA,
for
units
demonstrated
to
operate at only
two levels, under
Section
6.5.2(e)
of this
Exhibit).
26
6.5.3
Calculations
Using
the
data from
the
relative
accuracy
test
audits,
calculate
relative
accuracy
and
bias
in
accordanc:e
with theprocedures
an&equations::specifiád
iii
Section
7
of
this.
Exhibit.:.:
6;5.4
Reference
MethodMeasurement
Location
Select
a
location
for
reference
method
measurements
that
is
(1)
accessible;
(2)
in
the
same
proximity
as
the
monitor
or
monitoring
system
location;
and
(3)
meets
the
requirements
of
Performance
Specification
3
in
appendix
B
of
40
CFR
60,
incorporated
by
reference
in
Section
225.140,
for
CO
1
or
02
monitors,
or
Method
I
(or
1A)
in
appendix
A
of
40
CFR
60,
incorporated
by
reference
in
Section
225.
14,
for
volumetric
flow,
except
as
otherwise
indicated
in
this
Section
or
as
approved
by
the
Agency.
6.5.5
Reference
Method
Traverse
Point
Selection
Select
traverse
points
that
ensure
acquisition
of
representative
samples
of
pollutant
and
diluent
concentrations,
moisture
content,
temperature,
and
flue
gas
flow
rate
over
the
flue
cross
Section.
To
achieve
this,
the
reference
method
traverse
points
must
meet
the
requirements
of
Section
8.1.3
of
Performance
Specification
2
(“PS No.
2”)
in
appendix
B
to
40
CFR
60,
incorporated
by
reference
in
Section
225.140
(for
moisture
monitoring
system
RATAs),
Performance
Specification
3 in
appendix
B
to
40
CFR
60,
incorporated
by
reference
in
Section
225.140
(for
02
and
CO
2
monitor
RATAs),
Method
1
(or
1A)
(for
volumetric
flow
rate
monitor
RATAs),
Method
3
(for
molecular
weight),
and
Method 4
(for
moisture
determination) in
appendix
A
to
40
CFR
60,
incorporated
by
reference
in
Section 225.140. The
following
alternative
reference
method
traverse
point
locations
are
permitted
for
moisture
and
gas
monitor
RATAs:
(a)
For
moisture
determinations
where
the
moisture
data
are
used
only
to
determine
stack
g
molecular
weight,
a
single
reference
method
point,
located
at least
1.0
meter
from
the
stack
wall,
may
be
used. For
moisture
monitoring
system
RATAs
and
for
gas
monitor
RATAs
in
which
moisture
data
are
used
to
correct
pollutant
or
diluent
concentrations
from
a
dry
basis
to
a
wet
basis
(or
vice-versa),
single-point
moisture
sampling
may
only be
used
if
the
12-point
stratification
test
described
in
Section 6.5.5.1
of
this
Exhibit
is performed
prior
to
the
RATA
for
at
least
one
pollutant
or
diluent
gas,
and
if
the
test
is
passed
according
to
the
acceptance
criteria
in
Section
6.5.5.3(b)
of
this
Exhibit.
(b)
For
gas
monitoring
system
RATAs,
the
owner
or
operator
may
use
any
of
the
following
options:
(1)
At
any
location (including
locations
where
stratification
is
expected),
use
a
minimum
of
six
traverse points
along
a
diameter,
in
the
direction
of
any
expected
stratification.
The
points must
be
located
in
accordance
with
Method
1 in
appendix
A
to
40
CFR
60,
incorporated
by
reference
in
Section
225.140.
27
(2).
At
lëations:
whereSection 8.E3.cf PSNy.2
short
reference’method
measurement
line
(with
three points
located
at 0.4, 1.2, and 2.0 meters
from the stack
wall),
the
owner
or
operator
may use an
alternative
3-point
measurement line, locating
the three
points
at 4:4,
14.6,
and 29.6 percent ofthe way across thestack,. in accordance. with
Method 1 in
appendix, A to 40
• CFR 60, incorporated by reference in Section 225.140.
(3)
At locations where stratification is likely to occur (e.g., following
a wet scrubber
or
when
dissimilar
gas streams are combined), the short measurement line
from Section 8.1.3 of
PS
No. 2
(or
the alternative
line
described in paragraph
(b)(2)
of this
Section)
may
be
used in
lieu
of
the
prescribed “long” measurement line in Section 8.1.3 of
PS No. 2, provided
that the
12-point
stratification
test described in
Section
6.5.5.1 of this Exhibit is performed
and passed one
time
at
the
location
(according
to the acceptance criteria
of
Section
6.5.5.3(a) of this
Exhibit)
and
provided
that
either the
12-point
stratification test or the
alternative
(abbreviated)
stratification test
in
Section
6.5.5.2 of this Exhibit is performed and passed prior to each
subsequent RATA at
the
location
(according
to
the acceptance criteria of Section
6.5.5.3(a)
of
this Exhibit).
(4)
A single
reference method measurement
point,
located no less than 1.0
meter from the
stack
wall
and
situated
along one of the measurement lines
used for the stratification
test,
may
be
used
at
any
sampling
location if the 12-point stratification test described in
Section 6.5.5.1 of
this
Exhibit
is
performed and passed prior to each RATA at the location (according
to the acceptance
criteria
of
Section
6.5.5.3(b)
of this
Exhibit).
(c)
For mercury
monitoring systems, use
the same
basic
approach for traverse
point
selection
that
is
used for the other
gas monitoring system RATAs,
except
that
the stratification
test
provisions
in
Sections 8.1.3
through 8.1.3.5 of
Method
30A
must
apply, rather
than the
provisions of
Sections
6.5.5.1
through 6.5.5.3 of this Exhibit.
6.5.5.1 Stratification
Test
(a)
With the
unit(s)
operating
under
steady-state
conditions at the
normal load level
(or normal
operating
level),
as defined in Section 6.5.2:1 of this Exhibit, use
a traversing
gas sampling
probe
to
measure
diluent
(CQ
or
O)
concentrations at a minimum of twelve
(12) points, located
according
to
Method
1 in
appendix A to 40 CFR 60,
incorporated by reference in
Section 225.140.
(b) Use
Method3A in appendix A to 40
CFR 60,
incorporated
by reference
in
Section
225.140,
to
make
the
measurements. Data from the reference method
analyzers must
be quality
assured
by
performing
analyzer
calibration error and system
bias
checks
before the series
of
measurements
and
by
conducting
system bias and calibration drift checks
after the measurements,
in
accordance
with
the
procedures
of Method 3A.
(c)
Measure
for a
minimum of 2 minutes at
each traverse point. To
the extent practicable,
complete
the
traverse within
a 2-hour period.
28
(d)
If
the
load
has
remained
constant
(+-3
.0
percent) during
the•
traverse
and
if
the
reference
method
analyzers
have
passed
all
of
the
required
quality
assurance
checks,
proceed
with
the
data
analysis.
(e)
Calculate
the
average
CO
2
(or
02)
concentrations
at
each
of
the.
individual
traverse
points.
Then,
calculate
the arithmeticaverage
CO
2
(or
02)
concentrations
for
a1ltraverse
points.
6.5.5.2
Alternative
(Abbreviated)
Stratification
Test
(a)
With
the
unit(s)
operating
under
steady-state
conditions
at
the
normal
load
level
(or
normal
operating
level),
as
defined
in
Section
6.5.2.1
of
this
Exhibit,
use
a traversing
gas
sampling
probe
to
measure
the diluent
(CO
2
or
02)
concentrations
at
three
points.
The
points
must
be
located
according
to
the
specifications
for
the
long
measurement
line
in
Section
8.1.3
of
PS
No.
2
(i.e..
locate
the
points
16.7
percent,
50.0 percent,
and 83.3
percent
of
the
way
across
the
stack).
Alternatively,
the
concentration
measurements
may
be
made
at
six
traverse
points
along
a
diameter.
The
six
points
must
be
located
in
accordance
with
Method
1
in
appendix
A
to
40
CFR
60,
incorporated
by
reference
in
Section
225.140;
(b)
Use
Method
3A
in
appendix
A
to
40
CFR
60,
incorporated
by
reference
in
Section
225.140,
to
make
the
measurements.
Data
from
the
reference
method
analyzers
must
be
quality
assured
by
performing
analyzer
calibration
error
and
system
bias
checks
before
the
series
of
measurements
and
by
conducting
system
bias
and
calibration
drift
checks
after
the
measurements,
in
accordance
with
the
procedures
of
Method
3A.
(c)
Measure
for
a
minimum
of
2
minutes
at
each
traverse
point.
To
the
extent
practicable,
complete
the
traverse
withina
1-hour
period.
(d)
If
the
load
has remained
constant (+-3.0
percent)
during
the
traverse
and
if
the
reference
method
analyzers
have passed
all
of
the
required
quality
assurance
checks,
proceed
with
the
data
analysis.
(e)
Calculate
tne
average
CO
2
(or
0)
concentrations
at
each
of
the
individual
traverse
points.
T1,
calculate
the anti
CC
‘‘-
for
all
trp”;
-—ntg
6.5.5.3
Stratification
Test
Results
and
Acceptance
Criteria
(a)
For
each
diluent
gas, the
short
reference
method
measurement
line
described
in
Section
8.1.3
of
PS
No. 2
may
be
used
in
lieu
of
the
long
measurement
line prescribed
in
Section
8.1.3
of
PS
No. 2
if
the
results
of
a
stratification
test,
conducted
in
accordance
with
Section
6.5.5.1
or
6.5.5.2
of
this
Exhibit
(as
appropriate:
see Section
6.5.5(b)(3)
of
this
Exhibit), show
that
the concentration
at
each
individual
traverse
point
differs
by
no
more
than
+-10.0
percent
from
the arithmetic
average
concentration
for
all
traverse
points.
The results
are
also
acceptable
if
the
concentration
at
each
individual
traverse
point
differs
by
no
more
than
+-Sppm
or
+-0.5
percent
CQ
2
(or
0)
from
the
arithmetic
average
concentration
for
all
traverse
points.
29
(b)
For
each
diluent
gas,
a single
reference
method
measurement
point,
located
at least
1.0
meter
from
the stack
wall
and
situated
along
One
of the
measurement
lines
used
for
the
stratification
test,
may
be
used
for
that diluent
gas
if the
results
of
a
stratification
test.
conducted
in
accordance
with
Section
6.5.5.1
of this
Exhibit,
show
that
the concentration
at
each
individual
traverse
point
differs
by no
more
than
+-5.0
percent
from thearithmetic
average
concentration
for
all traverse
points.
The
results
are
also
acceptable
if
the
concentration
at
each
individual
traverse
point
differs
by
no
more
than
+-3
ppm
or
+-0.3
percent
CO2
(or
O)
from
the
arithmetic
average
concentration
for
all
traverse
points.
(c)
The owner
or
operator
must
keep
the results
of
all stratification
tests
on-site,
in a
format
suitable
for
inspection,
as
part
of
the supplementary
RATA
records
required
under
Section
1.1
3(a)(7)
of
this
Appendix.
6.5.6
Sampling
Strategy
(a)
Conduct
the
reference
method
tests
so
they will
yield
results
representative
of
the
pollutant
concentration, emission
rate,
moisture,
temperature,
and
flue
gas
flow rate
from
the
unit and
can
be
correlated
with
the pollutant
concentration
monitor,
2
CO
or
02
monitor,
flow
monitor,
and
mercury
CEMS
measurements.
The minimum
acceptable
time
for
a gas
monitoring
system
RATA
run
or
for
a
moisture
monitoring
system
RATA
run
is 21
minutes.
For
each
run
of
a gas monitoring
system
RATA,
all
necessary
pollutant
concentration
measurements,
diluent
concentration
measurements,
and
moisture
measurements
(if
applicable)
must,
to
the extent
practicable,
be
made
within
a
60-
minute
period.
For
flow
monitor
RATAs,
the
minimum
time
per
run must
be
5 minutes.
Flow
rate
reference
method
measurements
may
be
made
either
sequentially
from port
to
port
or
simultaneously
at
two
or more
sample
ports.
The
velocity
measurement
probe
may be
moved
from
traverse
point
to
traverse
point
either
manually
orautomatically.
If,
during
a flow
RATA,
significant
pulsations
in
the
reference
method
readings
are
observed,
be
sure
to
allow
enough
measurement
time
at each
traverse
point
to
obtain
an
accurate
average
reading
when
a
manual
readout
method
is
used
(e.g.,
a
“sight-
weighted”
average
from
a
manometer).
Also,
allow
sufficient
measurement
time to
ensure
that
stable
temperature
readings
are
obtained
at
each
traverse
point,
particularly
at the
first
rnasurement
point
t,
.
-
ii
po-to-on
minimum
of
one
set
of
auxiliary
measur.ments
for
stack
gas molecular
weight
determination
(i.e.,
diluent
gas
data
and
moisture
data)
is
required
for
every
clock
hour
of
a flow
RATA
or
for every
three
test
runs
(whichever
is
less
restrictive).
Alternatively,
moisture
measurements
for
molecular
weight
determination may
be performed
before
and
after
a
series
of
flow RATA
runs
at
a particular
load
level
(low,
mid,
or
high),
provided
that
the
time
interval
between
the two
moisture
measurements
does
not
exceed
three
hours.
If this
option
is selected,
the
results
of
the two
moisture
determinations
must
be
averaged
arithmetically
and
applied
to
all RATA
runs
in
the series.
Successive
flow
RATA
runs
may
be
performed
without
waiting
in-between
runs. If
an
02
-diluent
monitor
is
used
as
a
CO7
continuous
emission
monitoring
system,
perform
a 2
CO
system
RATA
(i.e.,
measure
CO,.
rather
thanQ2,
with
the
reference
method).
For
moisture
monitoring
systems,
an
appropriate
coefficient,
“K”
factor
or
other
suitable
mathematical
algorithm
may
be
developed
prior
to the
RATA,
to
adjust
30
themonitorng’svstemreadingswithrespect
to
thereference
rnethbd
ifsucfräcoeffiiient
K-factor
or
algorithm
is
developed,
it
must
be
applied
to
the
CEMS
readings
during
the
RATA
and
(if
the
RATA
is
passed),
to
the
subsequent
CEMS
data,
by
means
of
the
automated
data
acquisition
and
handling.
coefficient,
K
factor
or
algorithm,
as
specified
in
Section
l.13(a)(5)(F)
of
this
Appendix.
Whenever
the
coefficient,
K
factor
or
algorithm
is
changed,
a
RATA
of
the
moisture
monitoring
system
is
required.
For
the
RATA
of
a
mercury
CEMS
using
the
Ontario
Hydro
Method,
or
for
the
RATA
of
a
sorbent
trap
system
(irrespective
of
the
reference
method
used),
the
time
per
run
must
be
long
enough
to
collect
a
sufficient
mass
of
mercury
to
analyze.
For
the
RATA
of
a
sorbent
trap
monitoring
system,
the
type
of
sorbent
material
used
by
the
traps
must
be
the
same
as
for
daily
operation
of
the
monitoring
system;
however,
the
size
of
the
traps
used
for
the
RATA
may
be
smaller
than
the
traps
used
for
daily
operation
of
the
system.
Spike
the
third
section
of
each
sorbent
trap
with
elemental
mercury,
as
described
in
Section
7.1.2
of
Exhibit
D
to
this
Appendix.
Install
a
new
pair
of
sorbent
traps
prior
to
each
test
run.
For
each
run,
the
sorbent
trap
data
must
be
validated
according
to
the
quality
assurance
-
criteria
in
Section
8
of
Exhibit
D
to
this
Appendix.
(b)
To
properly
correlate
individual
mercury
CEMS
data
(in
lbIMMBtu)
and
volumetric
flow
rate
data
with
the
reference
method
data,
annotate
the
beginning
and
end
of
each
reference
method
test
run
(including
the
exact
time
of
day)
on
the
individual
chart
recorder(s)
or
other
permanent
recording
device(s).
6.5.7
Correlation
of
Reference
Method
and
Continuous
Emission
Monitoring
System
Confirm
that
the.
monitor
or.
monitoring
system.
and
reference
method
test
results
are
on
consistent
moisture,
pressure,
temperature,
and
diluent
concentration
basis
(e.g.,
since
the
flow
monitor
measures
flow
rate
on
a
wet
basis,
Method
2
test
results
must
also
be
on
a
wet
basis).
Compare
flow-
monitor
and
reference
method
results
on
a
scfh
basis.
Also,
consider
the
response
times
of
the
pollutant
concentration
monitor,
the
continuous
emission
monitoring
system,
and
the
flow
monitoring
system
to
ensure
comparison
of
simultaneous
measurements.
relative
accuracy
test
audit
run,
compare
the
measurements
obtained
from
the
monitor
or
continuourn
monitoring
system
(in
ppm.
percent
CO,
lb/mmBtu,
or
other
units)
against
the
corresponding
reference
metno
the
paired
data
in
a
table
such
as
the
one
shown
in
Figure
2.
6.5.8
Number
of
Reference
Method
Tests
Perform
a
minimum
of
nine
sets
of
paired
monitor
(or
monitoring
system)
and
reference
method
test
data
for
every
required
(i.e.,
certification,
recertification,
diagnostic,
semiannual,
or
annual)
relative
accuracy
test
audit.
For
2-level
and
3-level
relative
accuracy
test
audits
of
flow
monitors,
perform
a
minimum
of
nine
sets
at
each
of
the
operating
levels.
6.5.9
Reference
Methods
31
The following
methods are
from
appendix
A to 40
CFR 60, incorporated
by reference
in
Section
225.140,
or have been
published.
by
ASTM, and
are the reference
methods for
perfO.ing
relative
accuracy
test audits
under.
this
part: Method
1 or 1A in.
appendix A-i to
40 CFR
60
for
siting;
Method 2 in
appendices
A-i
and A-2 to
40 CFR 60 or its. allowable
alternatives
in
appendix
A to 40
CFR 60
(except
for
Methods
2B and 2E in
appendix
A-i
to 40 CFR
60)
for stack
gas
velocity
and
volumetric
flow rate;
Methods 3, 3A or
3B in
appendix
A-2
to 40
CFR
60 for
02
and
C0
2;
Method
4
in
appendix A-3 to 40
CFR 60 for
moisture; and
for mercury, either
ASTM
D6784-02
(the
Ontario
Hydro
Method)
(incorporated
by reference
under Section
225.140),
Method
29 in
appendix
A-8
to
40
CFR
60,
Method
30A,
or
Method
30B.
7.
Calculations
7.1 Linearity
Check
Analyze
the linearity
data for pollutant
concentration
monitors as follows.
Calculate
the
Percentage
error
in linearity
based upon the reference
value
at
the low-level,
mid-level,
and
high-level
concentrations
specified
in Section
6.2 of
this
Exhibit. Perform
this calculation
once
during
the
certification test.
Use the following
equation
to
calculate the error
in linearity
for
each
reference
value.
jR-At
LE
=
x
100
(EquatiOn
A-4)
R
where,
LE=Percentage Linearity
error, based
upon the reference
value.
R=Reference
value
of Low-, mid-,
or
high-level
calibration
gas
introduced
into the monitoring
system.
A=Average
of
the monitoring system
responses.
7
‘ ‘Ziiiration
Error
i Pollutant
Concentration
and Diluent
Monitors
aci
relerence value,
calculate
the
percentage
calibration
error
based upon instrument
span
for
daily
calibration error
tests
using
the
following
equation:
CE=
xlOO
(EquationA-5)
32
where
CE
Calibration
error
as
a percentage
of
the
span
of
the
instrument.
R
=
Reference
value
of
zero
or
upscale
(high-level
or
mid-level,
as
applicable)
calibration
gas
introduced
into
the
monitoring
system.
A
=
Actual
monitoring
system
response
to
the
calibration
gas.
S
Span
of
the
instrument,
as
specified
in
Section
2
of
this
Exhibit.
7.2.2
Flow
Monitor
Calibration
Error
For
each
reference
value,
calculate
the
percentage
calibration
error
based
upon
span
using
the
following
equation:
R-AI
CE
=
x
100
(Equation
A-6)
where,
CE
=
Calibration
error
as
a
percentage
of
span.
R
=
Low
or
high level
reference
value
specified
in
Section
2.2.2.1
of
this
Exhibit.
A
=
Actual flow
monitor
response
to
the
reference
value.
5
Flow
monitor
calibration
span
value
as
determined
under
Section
2.1.2.2
of
this
Exhibit.
7.3
Relative
Accuracy
for
O
Monitors,
Mercury
Monitoring
Systems,
and
Flow
Monitors
Analyze
the
relative
accuracy
test
audit
data
from
the
reference
method
tests
for
CO
2
or
02
monitors
used
only
for
heat input
rate
determination,
mercury
monitoring
systems
used
to
determine
mercury
mass emissions
under
Sections
1.14
through
1.18
of
Appendix
B,
and
flow
monitors
using
the
following
procedures.
Summarize
the
results
on
a
data
sheet.
An
example
is
shown
in
Figure
2.
Calculate
the
mean
of
the
monitor
or
monitoring
system
measurement
values.
Calculate
the
mean
of
the
reference
method
values.
Using
data
from
the
automated
data
acquisition
and
handling
system,
calculate
the
arithmetic
differences
between
the
reference
method
and
monitor
measurement
data
sets. Then calculate
the
arithmetic
mean
of
the
difference,
the
standard
deviation,
the
confidence
coefficient,
and
the
monitor
or
monitoring
system
relative
accuracy
using
the
following
procedures
and
equations.
33
7.3.1
Arithmetic
Mean
Calculate the
arithmetic
mean
of the
differences, d, of a
data set as follows.
d
=
d,
(Equation
A-7)
where,
n = Number
of data points.
d1
= The difference
between a reference
method value
and the corresponding
continuous
emission
monitoring
system value
(RM
1
—CEM1
)
at a given
point
in time
i.
7.3.2 Standard
Deviation
Calculate the
standard deviation,
Sd,
of a data set as follows:
4
L=
The difference
between
a
reference
method
value
and the
corresponding
continuous
emission
monitoring system
value
(RM
1
—CEM) at a
given
point
in
time i.
7.3.3 Confidence
Coefficient
Calculate
the
confidence coefficient
(one-tailed),
cc, of a
data
set
as
follows:
Sd
(Equation
A-8)
where,
n
= Number
of data points.
34
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i
I
J3j
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W
W
4
01
H
W
I
01
I
C
—
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I
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:
I
CD.
CD
I
II
b
H
l-t
I
IHIH
fZ
CD
C
I
CD
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11
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I.
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00
OHHHHHHH
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CD
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CD
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101
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concentration monitoring
systems, and sorbent trap monitoring systems, using
the
procedures
outlined
in Sections 7.4.1 through 7.4.4 of this Exhibit. For multiple-load flow
RATAs,
perform
a
bias test.at each lOad leveldesignated as normal under
SectiOn 6.5.2.1 of this. Exhibit;
7.4.1
Arithmetic Mean
Calculate
the arithmetic mean
of
the difference, “d”,
of the data set
using
Equation
A-7
of
this
Exhibit. To calculate bias
for a
flow monitor, “d” is,
for each paired data point,
the
difference
between the flow rate values
(in
scfh)
obtained from the
reference method and the
monitor.
To
calculate
bias for a
mercury
monitoring
system
when using the Ontario
Hydro
Method or
Method
29
im appendix A-8 to 40 CFR
60,
incorporated by reference
in Section 225.140, “d”
is, for
each
data
point, the difference between
the average mercury concentration value
(in
jig/rn
3)
from
the
paired
Ontario Hydro or Method 29 in appendix A-8 to 40
CFR 60 sampling trains and the
concentration
measured
by
the monitoring system. For sorbent trap
monitoring systems, use the
average
mercury
concentration measured
by the paired traps in the calculation of
“d”.
7.4.2 Standard Deviation
Calculate
the standard
deviation,
Sd,
of the
data set using Equation A-8.
7.4.3 Confidence
Coefficient
Calculate the confidence coefficient, cc, of the data set using
Equation
A-9.
7.4.4 Bias Test
If, for the relative accuracy
test audit data set being
tested, the mean difference,
d, is
less
than
or
equal to the
absolute value of the confidence coefficient,
cc(, the monitor or monitoring
system
has
passed the bias test. If the
mean
difference, d,
is greater than the absolute
value of the
confidence
coefficient,
jcc(.
the monitor or monitoring system has failed to meet
the bias test
requirement.
7.5
Reference Flow-to-Load
Ratio
or Gross Heat
Rate
(a)
Except as provided in Section 7.6 of
this Exhibit,
the owner or operator
must determine
R
reference
value
of
the ratio of flow rate to unit load,
each time that a passing
flow
RATA
is
performed at a load
level
designated
as normal in
Section 6.5.2.1 of this Exhibit.
The
owner
or
operator must
report
the
current
value of
Rrej
in
the electronic quarterly
report
required
under
40
CFR
75.64, incorporated by
reference
in Section 225.140, and
must also report
the
completion
date
of
the associated RATA. If two
load
levels have
been designated
as normal under Section
6.5.2.1
of
this
Exhibit,
the owner or
operator must determine a
separate R value for
each of the
normal
load
36
levels.
The
referenccflowto-ioad
ratio
must’becaiulated
as
follows:
Rref
=—-xi0
(Equation
A-13)
avg
where,
Rrej
=
Reference
value
of
the
flow-to-load
ratio,
from
the
most
recent
normal-load
flow
RATA,
scfh/megawatts,
scfhJl000
lb/hr
of
steam,
or
scfh/
(mmBtu/hr
of
steam
output).
Qrei
Average
stack
gas volumetric
flow
rate
measured
by
the
reference
method
during
the
normal-
load
RATA,
scth.
Lava
=
Average
unit load
during
the
normal-load
flow
RATA,
megawatts,
1000
lb/hr
of
steam,
or
mBtuJhr
of
thermal
output.
(b)
In
Equation
A-13,
for
a
common
stack,
determine
Lavg
by
summing,
for
each
RATA
run,
the
operating
loads
of
all
units
discharging
through
the
common
stack,
and
then
taking
the
arithmetic
average
of
the
summed
loads.
For
a
unit
that
discharges
its
emissions
through
multiple
stacks,
either
determine
a
single
value
of
for
the
unit
or
a separate
value
of
Qrej
for
each
stack.
In
the
former
case, calculate
Qr
by
summing,
for
each
RATA
run,
the
volumetric
flow
rates
through
the
individual
stacks
and
then taking
the
arithmetic
average
of
the
summed
RATA
run
flow
rates.
In
the
latter
case, calculate
the value
of
Qrej
for
each
stack
by
taking
the
arithmetic
average,
for
all
RATA
runs,
of
the
flow rates
through
the
stack.
For
a
unit
with
a
multiple
stack
discharge
configuration
consisting
of
a
main
stack
and
a
bypass
stack
(e.g.,
a
unit
with
a
wet
S_Q
2
scrubber),
determine
Qrej
separately
for
each stack
at
the
time
of
the
normal
load
flow
RATA.
Round
off the
value
of
Rref
-
two decimal
places.
(c)
In
addition
to
determining
Rrej
or
as
an
alternative
to
determine
Rref
a
reference
value
of
the
gross
heat rate
(GHR)
may
be
determined.
In
order
to
use this
option,
quality
assured
diluent
gas
(CO
2
or
02)
must
be
available
for
each
hour
of
the
most
recent
normal-load
flow
RATA.
The
reference
value
of
the
GHR
must
be
determined
as
follows:
(Heatlnput)oyg
(GHR)rej
=
xl000
(Equation
A-13a)
avg
where,
37
(GHR)ref
= Reference value
of
the
gross heat, rate at the time of the most recent.
normaL-load,
flow
RATA,
Btu!kwh, Btu/lb steam
load, or Btu heat input/mmBtu steam output.
(HeatInput)vg
= Average
hourly
heat input during the normal-load flow
RATA, as
determined
using
the
applicable
equation
in Exhibit
C
to
this Appendix, mmBtuJhr. For multiple stack
configurations,
if
the reference GHR value is determined
separately
for each stack, use the hourly
heat
input
measured
at each stack.
If
the reference GHR is determined
at the unit level, sum the
hourly
heat
inputs measured at the individual stacks.
Average unit load during the
normal-load flow RATA, megawatts, 1000
lb/hr of
steam,
or
mmBtu/hr thermal output.
(d)
In the calculation of
(Heatlnput)avg,
use
Qrej’
the average
volumetric flow rate
measured
by
the
reference method during the RATA, and
use the average diluent gas concentration
measured
‘during
the flow RATA (i.e., the arithmetic average of the diluent
gas concentrations for all
clock
hours
in
which a RATA run was performed).
7.6
Flow-to-Load
Test Exemptions
(a)
For
complex
stack configurations
(e.g.,
when
the effluent from a unit is divided
and
discharges
through
multiple stacks in such a manner that
the flow rate in the individual stacks
cannot
be
correlated
with unit
load),
the owner or operator may
petition the USEPA under
40
CFR
75.66,
incorporated
by
reference
in Section 225.140,.for an
exemption from the.requirements
of
Section 7.7
to
Appendix A to
40
CFR Part 75 and Section 2.2.5 of Exhibit B
to
Appendix
B. The
petition must
include
sufficient
information
and
data to demonstrate that a flow-to-load
or gross
heat rate
evaluation is
infeasible for the complex stack configuration.
(b)
Units that do
not produce electrical output
(in
megawatts) or thermal output
(in klb of
steam
per
hour)
are
exempted from the flow-to-load ratio test requirements
of Section 7.5 of this
Exhibit
and
Section 2.2.5 of
Exhibit B to Appendix
B.
Figures for Exhibit
A to Appendix B
Figure l.--Linearity
Error Determination
Day
Date
and
Reference
Monitor
Difference
Percent
of
time
value
value
reference
value
Low-level:
38
Mid-level:
High-level:
Figure
2.--Relative
Accuracy
Determination
(Pollutant
Concentration
Monitors)
S02
(ppm
[FNcJ)
C02
(Pollutant)
(ppm
[FNc])
Date
Date
Run
and
RM
[FNa]
M
[FNb)
Diff
and
RM
[FNa)
M
[FNb]
Diff
No.
time
time
1.
2
3
4
5
S
7
8
9
10
11
39
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C
Reference
method
data
NOX
system
(lb/rnmBtu)
Run
No.
Date
and
time
NOX(
)
[ENa]
02/C02%
RM
M
Difference
1
2
3
4
5
6
7
8
9
10
11
12
Arithmetic
Mean
Difference
(Eq.
A-7).
Confidence
Coefficient
(Eq.
A-9)
.
Relative
Accuracy
(Eq.
A-b)
[FNa]
Specify
units:
ppm,
lb/dscf,
mg/dscm.
Figure
5--Cycle
Time
Date
of
test
Component/system
ID#:
Analyzer type
Serial
Number
High
level gas
concentration:
ppm!%
(circle
one)
Zero
level
gas
concentration:
ppml%
(circle
one)
Analyzer
span
setting:
ppml%
(circle
one)
41
Upscale:
Stable starting monitor value:
ppml% (circle
one)
Stable
ending
monitor reading:
ppml% (circle
one)
Elapsed time:
seconds
Downscale:
Stable starting monitor value:
ppml%
(circle one)
Stable ending monitor
value:
ppml%
(circle
one)
Elapsed
time:
seconds
Component cycle time=
seconds
System cycle
time=:
seconds
A.
To determine the upscale cycle time (Figure
6a),
measure
the flue gas emissions
until
the
response stabilizes. Record the stabilized value
(see
Section 6.4
of this Exhibit for
the
stability
criteria).
B.
Ihject a high-level
calibration
gas into the port leading to the calibration
cell or thimble
(Point
B).
Allow the analyzer to
stabilize.
Record
the stabilized
value.
C.
Determine the step change. The step change is equal
to
the
difference between
the
final
stable
calibration gas value
(Point
D)
and the stabilized stack emissions value
(Point
A).
D. Take 95%
of the step change value and add the result to the
stabilized stack
emissions
value
(Point
A).
Determine
the time at which
95% of the step change occurred
(Point C).
E. Calculate
the upscale cycle time by subtracting the time at which
the calibration
gas was
injected
(Point
B)
from the time at
which
95% of the step change occurred
(Point
C).
In this
example,
upscale
cycle
time
= (11-5)
= 6
minutes.
F. To
determine the
downscale
cycle
time (Figure 6b) repeat the procedures
above, except
that
a zero
gas is
injected when
the
flue gas emissions have stabilized,
and
95% of the
step
change
in
concentration is
subtracted from
the
stabilized
stack emissions value.
G.
Compare
the upscale and downscale cycle time values. The
longer of these two
times is
the
cycle
time for
the analyzer.
42
Exhibit
B
to
Appendix
B--Quality
Assurance
and
Quality
Control
Procedures
1.
Quality
Assurance/Quality
Control
Program
Develop
and
implement
a
quality
assurance/quality
control
(OAIQC)
program
for
the
continuous
emission
monitoring
systems,
and
their
components.
At
a
minimum,
include
in
each
QA/OC
program
a
written
plan
that
describes
in
detail
(or
that
refers
to
separate
documents
containing)
complete,
step-by-step
procedures
and
operations
for
each
of
the
following
activities.
Upon
request
from
regulatory
authorities,
the
source
must
make
all
procedures,
maintenance
records,
and
ancillary
supporting
documentation
from
the
manufacturer
(e.g..
software
coefficients
and
troubleshooting
diagrams)
available
for
review
during
an
audit.
Electronic
storage
of
the
information
in
the
QA/OC
plan
is
permissible,
providedthat
the
information
can
be
made
available
in
hardcopy
upon
request
during
an
audit.
1.1
Requirements
for
All
Monitoring
Systems
1.1.1
Preventive
Maintenance
Keep
a
written
record
of
proc1r’
m--cr
vstem
inpp
ow-kg
condition
and
a
schedule
for
those
procedures.
This
must,
at
a
minimum,
inciuue
u
cedures
specified
by
the
manufacturers
of
the
equipment
and,
if
applicable,
additional
or
alternate
procedures
developed
for
the
equipment.
1.1.2
Recordkeeping
and
Reporting
Keep
a
written
record
describing
procedures
that
will
be
used
to
implement
the
recordkeeping
and
reporting
requirements
in
subparts
E
and
G
of
40
CFR
75,
incorporated
by
reference
in
Section
225.140,
and
Sections
1.10
through
1.13
of
Appendix
B,
as
applicable.
1.1.3
Maintenance
Records
Keep
a
record
of
all
testing,
maintenance,
or
repair
activities
performed
on
any
monitoring
system
or
43
component
in a location
and fàrmat
suitable
for
inspectiom
A
maintenance
log
may
be
used•
fOr
this
purpose. The
following records should
be
maintained:
date, time,
and
description
of any
testing,
adjustment,
repair,
replacement,
or preventive maintenance
action
performed on any
monitojpg
system
and records of
any
corrective actions associated
with
a monitor’s outage
period.
Additionally,
any adjustment that
recharacterizes
a system’s
ability
to record and report
emissions
data
must
be
recorded
(e.g.,
changing
of flowmonitor
or
moisture
monitoring
system
polynomial
coefficients,
K
factors or mathematical
algorithms,
changing
of temperature and pressure
coefficients
and
dilution
ratio settings),
and a written
explanation of the procedures
used
to make the adjustment(s)
must
be
kept.
1.1.4
0
The
requirements in
Section 6.1.2
of Exhibit A
to this Appendix must
be met by
any Air
Emissions
Testing
Body
(AETB)
performing
the semiannual/annual
RATAs
described in Section
2.3
of
this
Exhibit
and the
mercury emission
tests
described
in Sections
1.15(c)
and 1.1
5(d)(4)
of
Appendix
B.
1.2 Specific
Requirements
for Continuous
Emissions
Monitoring
Systems
1.2.1 Calibration
Error
Test and Linearity
Check Procedures
Keep
a
written record
of the procedures
used for daily calibration
error
tests and
linearity
checks
(e.g.,
how. gases
are to be
injected,
adjustments of flow
rates
and
pressure,
introduction
of
reference
values,
length
of time for injection
of calibration gases,
steps for obtaining
calibration
error
or error
in
linearity,
determination
of interferences, and
when calibration
adjustments
should
be
made).
Identify any calibration
error test and linearity
check procedures
specific
to the
continuous
emission
monitoring system
that vary
from the
procedures
in Exhibit A
to this Appendix.
1.2.2 Calibration
and Linearity
Adjustments
how each
wnhinuous ernssion
rn’iuLoring
system will
be
adjusted
to
provide
cerect
responses to calibration
gases,
reference values, and/or
indications
of
interference
both
initially
and after repairs
or corrective action.
Identify
equations,
conversion factors
and
other
factors
affecting
calibration of
each continuous
emission monitoring
system.
1.2.3
Relative Accuracy
Test Audit
Procedures
Keep a
written
record
of procedures
and details peculiar
to the installed
continuous
emission
monitoring
systems
that are to be
used for relative
accuracy test
audits, such
as sampling
and
analysis
methods.
1.2.4
Parametric
Monitoring
for
Units With Add-on
Emission
Controls
The
owner
or
operator
shall keep
a
written
(or
electronic)
record including
a list of
operating
44
parameters
for
the
addLon
mercury
emission
controls,
as
applicable,
and
the
range
of
each
operating
parameter
that
indicates
the
add-on
emission
controls
are
operating
properly.
The
owner
or.
operator
shall
keep
a
written
(or
electronic)
record
of
the
parametric
monitoring
data
during
each
mercury
missing
data
period.
1.3
Requirements
for
Sorbent
Trap
Monitoring
Systems
1.3.1
Sorbent
Trap
Identification
and
Tracking
Include
procedures
for
inscribing
or
otherwise
permanently
marking
a
unique
identification
number
on
each
sorbent
trap,
for
tracking
purposes.
Keep
records
of
the
ID
of
the
monitoring
system
in
which
each
sorbent
trap
is
used,
and
the
dates
and
hours
of
each
mercury
collection
period.
1.3.2
Monitoring
System
Integrity
and
Data
Quality
Explain
the
procedures
used
to
perform
the
leak
checks
when
sorbent
traps
are
placed
in
service
and
removed
from
service.
Also
explain
the
other
QA
procedures
used
to
ensure
system
integrity
and
data
quality,
including,
but
not
limited
to,
gas
flow
meter
calibrations,
verification
of
moisture
removal,
and
ensuring
air-tight
pump
operation.
In
addition,
the
QA
plan
must
include
the
data
acceptance
and
quality
control
criteria
in
Section
8
of
Exhibit
D
to
this
Appendix.
All
reference
meters
used
to
calibrate
the
gas
flow
meters
(e.g.,
wet
test
meters)
must
be
periodically
recalibrated.
Annual,
or
more
frequent,
recalibration
is
recommended.
If
a
NIST-traceable
calibration
device
is
used
as
a
reference
flow
meter,
the
QA
plan
must
include
a
protocol
for
ongoing
maintenance
and
periodic
recalibration
to
maintain
the
accuracy
and
NIST-traceability
of
the
calibrator.
1.3.3
Mercury
Analysis
Explain
tn
jjp
of
custod
‘mployed
in
packing,
transporting,
and
anai,
—
sorbent
traps
(see
Sections
7
2
‘
“hit
D
to
th
1
\ppendix)
Keepre”
analyses
must
be
performed
in
acco
1
*he
uescnbed
in
Section
i
to
this
Appendix.
1.3.4
Laboratory
Certification
The
QA
Plan
must
include
documentation
that
the
laboratory
performing
the
analyses
on
the
carbon
sorbent
traps
is
certified
by
the
International
Organization
for
Standardization
(ISO)
to
have
a
proficiency
that
meets
the
requirements
of
ISO
17025.
Alternatively,
if
the
laboratory
performs
the
spike
recovery
study
described
in
Section
10.3
of
Exhibit
D
to
this
Appendix
and
repeats
that
procedure
annually,
ISO
certification
is
not
required.
1.3.5
Data
Collection
Period
45
State,
and
provide
the
rationale
‘for, th&mirthnum
ácceptabl’
data collection
‘period
(e.g.,
one
day,
one week,
etc.)
for the size of sorbent
trap selected
for the
monitoring.
Include
in
the
discussion
such
factors as
the mercury concentration
in the
stack gas, the capacity
of the
sorbent
trap,
and
the
minimum
mass of mercury
requited
forthe
analysis’..
1.3.6 Relative’
Accuracy
Test
Audit Procedures
Keep records
of the procedures
and details peculiar
to the sorbent
trap monitoring
systems
that
are to
be followed
for relative accuracy
test audits, such
as sampling
and analysis methods.
2. Frequency
of Testing
A summary
chart showing
each
quality assurance
test
and
the frequency at
which
each
test
is
required
is located at the end of
this Exhibit
in Figure 1.
2.1 Daily
Assessments
Perform
the following
daily
assessments
to quality-assure
the hourly
data
recorded
by
the
monitoring
systems during
each period
of unit operation, or,
for
a
bypass
stack or duct,
each
period
in
which emissions pass
through the bypass
stack or duct.
These requirements
are effective
as
of
the
date
when the monitor
or continuous emission
monitoring
system
completes
certification
testing.
2.1.1 Calibration
Error Test
Except
as provided in
Section
2.1.1.2
of this
Exhibit,
perform
the
daily
calibration
error
test
of
each
gas monitoring system
(including
moisture
monitoring
systems
consisting
of wet-
and
dry-basis
02
analyzers)
according to
the procedures in Section
6.3.1
of Exhibit A
to
this
Appendix,
and
perform
the daily
calibration
error
test of each flow
monitoring
system according
to the
procedure
in
Section
6.3.2
of
Exhibit
A to
\nDendix.
When two measurement
ranges
(jpw and hih are
guired
for
particular
‘oient
calibration
error
te
acnrae
to
validate
the
data
r—
‘at cange, according
to the
2.1.5
of this
Exhibit.
For units with
add-on emission
controls
and
dual-span or auto-ranging
monitors,
and
other
units
that
use the
maximum expected
concentration
to
determine
calibration
gas values, perform
the
daiiy
calibration error tests
on each
scale that
has
been used
since the previous
calibration
error
test.
For
example, if the
pollutant
concentration
has not exceeded
the low-scale
value
(based
on
the
maximum
expected
concentration)
since the previous
calibration
error test,
the calibration
error
test
mayjç
performed
on the
low-scale
only. If, however,
the
concentration
has
exceeded
the
low-scale
span
value
for
one hour or
longer
since
the
previous
calibration
error
test,
perform
the
calibration
error
test
on
both the low-
and
high-scales.
2.1.1.1 On-line
Daily
Calibration
Error Tests.
46
Except
as’
provided ifi”Section2:L
I”;2’ofthfs
E*hibftalT”dáilycalibration
error
tests
must
be”
performed
while
the
unit
is
in
operation
at
normal,
stable
conditions
(i.e.
“on-line
11
).
2.1.1.2
Off-line
Daily
Calibration
Error
Tests.
Daily
calibrations
may
be
performed’
while
theunit
isnot
operating
(i.e.,
“off-line”)
and
may
be
used
to
validate
data
for
a
monitoring
system
that
meets
the
following
conditions:
(1)
An
initial
demonstration
test
of
the
monitoring
system
is
successfully
completed
and
the
results
are
reportedjn
the
quarterly report
required
under
40
CFR
75.64,
incorporated
by
reference
in
Section
225.140.
The
initial
demonstration
test,
hereafter
called
the
“off-line
calibration
demonstration”,
consists
of
an
off-line
calibration
error
test
followed
by
an
on-line
calibration
error
test.
Both
the
off-line
and
on-line
portions
of
the
off-line
calibration
demonstration
must
meet
the
calibration
error
performance
specification
in
Section
3.1
of
Exhibit
A
to
Appendix
B.
Upon
completion
of
the
off-line
portion
of
the
demonstration,
the
zero
and
upscale
monitor
responses
may
be
adjusted,
but
only
toward
the
true
values
of
the
calibration
gases
or
reference
signals
used
to
perform
the
test
and
only
in
accordance
with
the
routine
calibration
adjustment
procedures
specified
in
the
quality
control
program
required
under
Section
1
of
this
Exhibit.
Once
these
adjustments
are
made,
no further
adjustments
may
be
made
to
the
monitoring
system
until
after
completion
of
the
on-line
portion
of
the
off-line
calibration
demonstration.
Within
26
clock
hours
of
the
completion
hour
of
the
off-line
portion
of
the
demonstration,
the
monitoring
system
must
successfully
complete
the
first attempted
calibration
error
test, i.e.,
the
on-line
portion
of
the
demonstration.
(2)
For
each
monitoring
system
that has
passed
the
off-line
calibration
demonstration,
off-line
calibration
error
tests
may
be
used
on
a
limited
basis
to
validate
data,
in
accordance
with
paragraph
(2)
in
Section
2.1.5.1
of
this
Exhibit.
2.1.2
Daily
Flow
Interference
Check
Perform
the
daily
flow
monitor
interference
checks
specified
in
Section
2.2.2.2
of
Exhibit
A
to
this
Appendix
while
the
unit
is
in
operation
at
normal,
stable
conditions.
2.1.3
Addition
CJi’,ration
Error
Tests
and
Calibration
Adjustments
(a)
In
addition
to
the
daily
calibration
error
tests
required
under
Section
2.1.1
of
this
Exhibit,
a
calibration
error
test
of
a
monitor
must
be
performed
in
accordance
with
Section
2.1.1
of
this
Exhibit,
as
follows:
whenever
a
daily
calibration
error
test
is
failed
whenever
a
monitoring
system
is
returned
to
service
following
repair
or
corrective
maintenance
that
could
affect
the
monitor’s
ability
to
accurately
measure
and
record
emissions
data
or
after
making
certain
calibration
adjustments,
as
described
in
this
Section.
Except
in
the case
of
the
routine
calibration
adjustments
described
in
this
Section,
data
from the
monitor
are
considered
invalid
until
the
required
additional
calibration
error
test
has
been
successfully
completed.
-
47
(b)
Routine
calibrtitrn
àdj
tnients’of’anionitor
are permitted
‘after any
successfül’calibrati’dn
error
test. These
,routine
adjustments
must
be made
so
as to
bring
the
monitor readings
as
close
as
practicable
to the kiibwn
tag
values of
the calibration
gases or to the
actual
value of
the
flow
monitor
reference.
signals.
An’
additiona’icalibration
error test is required
following
routine
calibration
adjustments
where
the monitor’s
calibration
has been physically
adjusted
(e.g.,
by
turning
a
potentiometer)..
toverify
that.
the
adiustments.have’
:been’
made’
properly.
An additional
calibration
error
test
is
not required,
however,
if
the routine
calibration
adjustments
are made
by
means
of
a
mathematical
algorithm
programmed
into
the
data
acquisition
and handling
system. It
is
recommended
that routine
calibration
adjustments
be
made,
at
a minimum,
whenever
the
daily
calibration
error
exceeds
the limits
of the
applicable
performance
specification in
Exhibit
A to
this
Appendix
for the pollutant
concentration
monitor,
2
CO or
02
monitor,
or flow
monitor.
(c)
Additional
(non-routine)
calibration
adjustments
of a
monitor
are
permitted
prior
to
(but
not
during)
linearity
checks
and RATAs
and at other
times, provided
that
an appropriate
technical
justification
is included in
the quality
control
program
required
under Section 1 of this
Exhibit.
The
allowable
non-routine
adjustments
are
as follows.
The owner or operator
may physically
adjust
the
calibration
of a monitor
(e.g.,
by means
of a potentiometer),
provided
that
the
post-adjustment
zero
and
upscale
responses
of the monitor
are within
the performance
specifications
of
the
instrument
given
in Section
3 1 of Exhibit
A to this Appendix
An additional
calibration
error
test
is
required
following
such
adjustments
to
verify
that the
monitor
is operating
within the
performance
specifications
at both
the zero
and upscale
calibration
levels.
2.1.4
Data Validation
(a)
An out-of-control
period
occurs
when the
calibration
error
of a
CO
2
or
02
monitor
(including
02
monitors used to
measure
CO2
emissions or
percent
moisture)
exceeds
1.0
percent
CO
2
or
0,.
when the calibration
error
of a flow
monitor or
a
moisture
sensor exceeds
6.0 percent
of the
span
value,
which
is
twice
the
applicable
specification
of Exhibit
A to this Appendix.
Notwithstanding,
a
differential pressure-type
flow
monitor for which
the calibration
error
exceeds
6.0
percent of
the
span
value will not be considered
out-of-control
if
— Al,
the
absolute
value
of the
difference
between the monitor
response and
the reference
value in Equation
A-6
of
Exhibit
A to
this
Appendix, is
<
0.02 inches
of water.
For
a mercury
monitor,
an out-of-control
period
occurs
when
the
calibration error
exceeds
5.0%
of the
span
value. Notwithstanding,
the
mercury
monitor
will
not
be
considered
out-of-control if
IR — Al
in
Equation
A-6
does not exceed
1.0 jig/scm.
The
out-of-
control period
begins
upon
failure
of the calibration
error
test
and ends
upon
completion
of
a
successful
calibration error test.
Note,
that
if a failed
calibration,
corrective
action,
and
successful
calibration
error test
occur
within the
same
hour, emission
data
for
that hour recorded
by
the
monitor
after
the successful
calibration
error test
may be
used for reporting
purposes,
provided’
that
two
or
more
valid
readings
are
obtained
as required
by
Section 1.2 of
this
Appendix.
Emission
data
must
not
be reported
from an
out-of-control
monitor.
(b)
An
out-of-control
period
also occurs
whenever
interference
of a flow
monitor
is
identified.
The
48
out-of-control
period
begins
with
the hour
ofcompletion
of
the failed
interference
check
and
ends
with
the
hour
of
completion
of an
interference
check
that is
passed.
2.1.5
OualityAssurance.ofData
With
ReecttoDaily
Assessments
When
a
monitoring
system
passes
a daily
assessment
(i.e.,
daily
calibration
error
test
or
daily
flow
interference
check),
data from
that
monitoring
system
are prospectively
validated
for
26
clock
hours
(i.e.,
24 hours
plus
a 2-hour
grace
period)
beginning
with
the hour
in
which
the test
is
passed,
unless
another
assessment
(i.e.
a daily
calibration
error test,
an
interference
check
of
a flow
monitor,
a
qjiarterly
linearity
check,
a quarterly
leak
check,
or
a relative
accuracy
test
audit)
is
failed
within
the
26-hour
period.
2.1.5.1
Data
Invalidation
with
Respect
to
Daily Assessments.
The
following
specific
rules
apply
to the
invalidation
of
data
with respect
to daily
assessments:
(1)
Data
from a
monitoring
system
are invalid,
beginning
with
the
first
hour
following
the
expiration
of a
26-hour
data
validation
period
or beginning
with
the
first hour
following
the
expiration
of
an
8-
hour
start-up
grace
period
(as
provided
under
Section
2.1.5.2
of this
Exhibit),
if the
required
subsequent
daily
assessment
has
not
been conducted.
(2)
For
a
monitor
that
has passed
the
off-line
calibration
demonstration,
a
combination
of
on-line
and
off-line
calibration
error
tests
may
be used
to
validate
data
from
the monitor,
as
follows.
For
a
particular
unit
(or
stack) operating
hour,
data from
a
monitor
may
be validated
using
a
successful
off-line
calibration
error
test
if:
(a)
An
on-line
calibration
error
test
has been
passed
within
the
previous
26 unit
(or
stack)
operating
hours;
and
(b)
the
26 clock
hour data
validation
window
for
the
off-line
calibration
error
test has
not expired.
If
either
of
these conditions
is
not met,
then
the
data
from
the
monitor
are
invalid
with
respect
to
the
daily
calibration
error
test
requirement.
Data
from
the
monitor
must
remain
invalid
until
the
appropriate
on-line
or off-line
calibration
error
test
is
successfully
completed
so that
both
conditions
(a)
and
(b)
are met
—
(3)
For
units with
two measurement
ranges
(low
and
high)
for
a
particular
parameter,
when
separate
analyzers
are used
for the
low
and high
ranges,
a
failed
or expired
calibration
on
one
of
the
ranges
does not
affect
the
quality-assured
data
status
on
the other
range.
For
a dual-range
analyzer
(i.e.. a
single
analyzer
with two
measurement
scales),
a
failed
calibration
error
test
on either
the
low
or
jjg
scale
results
in
an out-of-control
period
for
the
monitor.
Data
from
the
monitor
remain
invalid
until
corrective
actions
are
taken
and “hands-off’
calibration
error
tests
have
been
passed
on
both
ranges.
However,
if the
most
recent
calibration
error
test on
the
high
scale
was
passed
but has
expired,
while
the low
scale
is
up-to-date
on
its calibration
error
test
requirements
(or
vice-versa),
the
expired
calibration
error
test
does
not
affect
the
quality-assured
status of
the data
recorded
on the
other
scale.
2.1.5.2
Daily
Assessment
Start-Up
Grace
Period.
49
For
the iurpose’
ofquaiity
assuringdatãwith’respectto
a
daii’sassessment
(i.e;
adaiiycaiibratiàn
error
test or a
flow interference
check),
a start-up
grace
period
may
apply
when a
unit begins
to
operate
after
a period
of
non-operation.
The start-up
grace
period
for
a daily
calibiation
error
test
is
independent
of
the. start-up
graceperiod
fora
dailyflow
interference;check.
To
qualify
for
a start-up
grace
period for
a daily
assessment,
there
are
two
requirements:
(1) The
unit must
have resumed
operation
after
being in outage
for 1
or more
hours
(i.e.,
the
unit
must
be in a
start-up condition)
as
evidenced
by a change
in unit
operating time
from
zero
in
one
clock
hour to
an
operating
time
greater
than
zero
in the
next clock
hour.
(2)
For the
monitoring
system
to
be used to
validate
data
during
the
grace period,
the
previous
daily
assessment
of the
same
kind must
have
been
passed on-line
within
26
clock
hours prior
to
the
last
hour
in which
the
unit operated
before the
outage.
In
addition,
the
monitoring
system
must
be
in-
control
with respect
to
quarterly
and
semi-annual
or annual
assessments.
If both
of
the
above
conditions
are
met, then
a start-up grace
period
of
up
to
8 clock
hours
applies,
beginning
with
the
first hour
of
unit
operation
following
the outage.
During the
start-up
grace
period,
data
generated
by
the
monitoring
system are
considered
quality-assured.
For each
monitoring
system,
a start-up
grace
period
for a calibration
error
test
or
flow
interference
check
ends
when
either:
(1)
a
daily assessment
of
the same
kind
(i.e.,
calibration
error
test
or
flow
interference
check)
is perfonned
or
(2)
8
clock
hours have
elapsed
(starting
with the first
hour
of
unit
operation
following
the outage),
whichever
occurs
first.
2.1.6 Data
Recording
Record
and tabulate
all calibration
error
test data
according
to
month,
day,
clock-hour,
and
magnitude
in
either ppm,
percent
volume,
or scth. Program
monitors
that
automatically
adjust
data
to the
corrected
calibration
values
(e.g.,
microprocessor
control)
to record
either:
(1)
The
unadjusted
concentration
or
flow
rate measured
in
the
calibration
error
test
prior
to resetting
the
calibration,
or
(2)
the magnitude
of
any
adjustment.
Record the
following
applicable
flow
monitor
interference
check
data:
(1)
Sample
line/sensing
port
pluggage,
and
(2) malfunction
of each RTD,
transceiver,
or
equivalent.
2.2
Ouarterly
Assessments
For each
primary
and redundant
backup
monitor
or
monitoring
system,
perform
the
following
quarterly
assessments.
This requirement
is applies
as of
the calendar
quarter
following
the
calendar
quarter
in
which
the monitor
or
continuous
emission monitoring
system
is provisionally
certified.
2.2.1
Linearity
Check
Unless
a
particular
monitor
(or
monitoring
range)
is exempted
under
this
paragraph
or under
Section
6.2 of
Exhibit
A to
this Appendix,
perform
a
linearity
check, in
accordance
with the
procedures
in
50
Sectfän
6.2’ôf’Exhibit
A’
to”thi
Appendix
for each
primary
and
redunthnt
backup,
mercu,
pollutant
concentration
monitor
and
each
primary
and
redundant
backup
CO
2
or
02
monitor
(including
02
monitors
used
to
measure
C0
2
’
emissions’
or
to
continuously
monitor
moisture)
at
least
once
‘during
eaelr
OA
operating
quarter,
as
defined
in’
40
CFR
72.2,
incorporated
by
reference
in
Section
225.140.
For.
mercury monitors,
perform
the
linearity
checks
using
elemental
mercury
standards.
Alternatively,
you’.
may
perform
3-level
system”
intety
checks
at
the
same
three
calibration
gas levels
(i.e.,
low,
mid,
and
high),
using
a
NIST-traceable
source
of
oxidized
mercury.
If
you
choose
this
option,
the
performance
specification
in
Section
3.2(c)
of
Exhibit
A
to
this
part
must
be
met
at
each
gas
level.
For
units
using
both a
low
and
high
span
value,
a
linearity
check
is
reqire4.ypjhe
range(s)
used.
to
record
and.
report
emission
data
during
the
QA
operating
quarter.
Conduct
the
linearity
checks
no
less
than
30
days
apart,
to
the
extent
practicable.
The
data
validation
procedures
in
Section
2.2.3(e) of
this
Exhibit
must
be
followed.
2.2.2
Leak
Check
For
differential
pressure
flow
monitors,
perform
a
leak
check
of
all
sample
lines
(a
manual
check
is
acceptable)
at
least
once
during
each
QA
operating
quarter.
For
this
test,
the
unit
does
not
have
to
be
in
operation.
Conduct
the
leak
checks
no
less
than
30
days
apart,
to
the
extent
practicable.
If
a
leak
check
is
failed,
follow
the
applicable
data
validation
procedures
in
Section
2.2.3(g)
of
this
Exhibit.
2.2.3
Data
Validation
(a)
A
linearity
check
must
not
be
commenced
if
the
monitoring
system
is
operating
out-of-control
with’respect
to
any
of
the
daily
or
semiannual
quality
assurance
assessments
required
by
Sections
2.1
and
2.3
of
this
Exhibit
or
with
respect
to
the
additional
calibration
error
test
requirements
in
Section
2.1.3
of
this”Exhibit.
(b)
Each
required
linearity
check
must
be
done
according
to
paragraph
(b)(1’),
(b)(2)
or
(b)(3)
of
this
Section:
(1)
The
linearity
check
may
be
done
“cold,”
i.e.,
with
no
correctivem’aintenancè,
-repair,’
calibration
adjustments,
re-linearization
or
reprogramming
of
the
monitor
prior
to
the
test.
(2)
The linearity
check
may
be
done
after
performing
only
the
routine
or
non-routine
calibration
adjustments
described
in
Section
2.1.3
of
this
Exhibit
at
the
various
calibration
gas
levels
(zero,
low,
mid
or
high),
but no
other
corrective
maintenance,
repair,
re-linearization
or
reprogramming
of
the
monitor.
Trial
gas
injection
runs
may
be
performed
after
the
calibration
adjustments
and
additional
adjustments
within
the
allowable
limits
in
Section
2.1.3
of
this
Exhibit
may be
made
prior
to
the
linearity
check,
as
necessary,
to
optimize
the
performance
of
the
monitor.
The
trial
gas
injections
need
not
be
reported,
provided
that
they
meet
the
specification
for
trial
gas
injections in
Section
1
.4(b)(3)(G)(v)
of
this
Appendix.
However,
if,
for
any
trial
injection,
the specification
in
Section
1
.4(b)(3)(G)(v)
is
not
met,
the
trial
injection
must
be counted
as
an
aborted
linearity
check.
51
(3)
The”liiiearity checkmay
be’
dOne ‘a’ftr’repair’
correctivemaintenance
or’reprogrammingof
the
monitor.
In this case, the monitor must
be considered
out-of-control from
the hour
in
which
the
repair, corrective maintenance
or
reprogramming
is commenced until
the
linearity
check
has
been
passed.
Alternatively,
the data validatiom
procedures,
and :•associated
timelines
in
Sections
1
.4(b)(3)(B)
through
(I)
of this Appendix may be followed upon
completion of the
necessary
repair,
correctivemaintenance,
or:reprogramming.:Jf
thepioceduresimSection
1
.4(b)(3)
are
used,
the
words
“quality
assurance” apply instead of
the
word “recertification”.
(c) Once
a
linearity check
has
been commenced,
the test must
be
done
hands-off.
That
is,
no
adjustments
of the monitor are permitted during the linearity
test period, other
than
the
routine
calibration
4justments
following daily
calibration error tests, as described
in Section
2.1.3
of this
Exhibit. If a routine daily calibration error test is performed
and passed just prior to
a
linearity
test
(or during a linearity test
period)
and a mathematical
correction factor
is
automatically
applied
by
the
DAHS,
the correction factor must
be applied to all subsequent
data
recorded by
the
monitor,
including the linearity test data.
(d)
If
a
daily
calibration error
test
is failed
during
a linearity test period, prior
to completing
the
test,
the
linearity test must be repeated. Data from the monitor are
invalidated prospectively
from
the
hour
of
the failed calibration error test until the hour of completion of
a subsequent successful
calibration
error test. The
linearity test
must
not be
commenced until the monitor
has successfully
completed
a
calibration error
test.
(e)
An
out-of-control period occurs when a linearity
test is failed
(i.e.,
when
the error in
linearity
at
any of
the three concentrations in the quarterly linearity
check
(or
any
of the six
concentrations,
when
both ranges
of
a single analyzer with a dual
range are
tested)
exceeds
the
applicable
specification
in Section 3.2 of Exhibit Ato this Appendix)
or
when
alinearity
test is aborted
due
to
a
problem with the monitor or
monitoring
system.
The
out-of-control
period
begins
with the
hour
of
the
failed
or
aborted linearity check and ends
with the hour of completion
of a satisfactory
linearity
check
following
corrective action and/or monitor repair, unless
the
option
in
paragraph
(b)(3) of this
Section
to use the data
validation
procedures
and associated timelines
in
Section
1
.4(b)(3)(B)
through (I) of
this Appendix has been selected, in which
case the beginning
and end
of the
out-of-
control
period must be determined in accordance with
Sections
l.4(b)(3)(G)(i)
and
(ii).
For
a
dual-
range analyzer,
“hands-off’ linearity checks must
be
passed
on both
measurement
scales
to
end
the
out-of-control
period.
(f)
No more
than four successive calendar quarters must elapse
after the
quarter
in which
a
linearity
check of a
monitor or monitoring
system (or
range of a
monitor or monitoring
system) was
last
performed
without a
subseguent
linearity test
having
been
conducted. If
a linearity test
has
not
been
completed by
the end of the fourth calendar
quarter
since the
last
linearity test,
then the
linearity
test
must be
completed within a 168 unit operating hour or
stack operating
hour “grace
period”
(as
provided
in Section 2.2.4
of
this
Exhibit)
following
the end
of the fourth successive
elapsed
calendar
quarter,
or
data from the
CEMS
(or range)
will
become
invalid.
52
(g)
An
out-of-control
period
alsO
occurs
‘when aflOw
monitor
sample
line
leak
is
detectedThe
out-
of-control
period
begins
with
the
hour
of
the
failed
leak
check
and
ends
with,
the
hour
of
a
satisfactory
leak
check
following
corrective
action.
(h)
For
each
monitoring
‘system,
report
the
results
of
all
completed’
and
partial
linearity’
tests
that
affect
data
validation’
(i.e.,
all
completed,
passed
linearity
checks;
all
completed,
failed
linearity
checks; and
all
linearity
checks
aborted
due
to
a
problem
with
the
monitor,
including
trial
gas
injections
counted
as
failed
test
attempts
under
paragraph
(b)(2)
of
this
Section
or
under
Section
1
.4(b)(3)(G)(vi) of
Appendix
B),
in
the
quarterly
report
required
under
40
CFR
75.64,
incorporated
yreference in
Section
225
J40.
Noj
empts
which
are
aborted
or
invalidated
‘due
to
problems
with
the
reference
calibration
gases
or
due
to
operational
problems
with
the
affected
unit(s)
need
not
be
reported. Such
partial
tests
do
not
affect
the
validation
status
of
emission
data
recorded
by
the
monitor.
A
record
of
all
linearity
tests,
trial
gas
injections
and
test
attempts
(whether
reported
or
not)
must
be
kept
on-site
as
part
of
the
official
test
log
for
each
monitoring
system.
2.2.4
Linearity
and
Leak
Check
Grace
Period
(a)
When a required
linearity
test
or
flow
monitor
leak
check
has
not
been
completed
by
the
end
of
the
OA
operating
quarter
in
which
it
is
due
or
if,
due
to
infrequent
operation
of
a unit
or
infrequent
use
of
a
required
high
range
of
a monitor
or
monitoring
system,
four successive
calendar
quarters
have
elapsed after
the
quarter
in
which
a
linearity
check
of
a
monitor
or
monitoring
system
(or
range)
was
last
performed
without
a
subsequent
linearity
test
having
been
done,
the
owner
or
operator
has
a
grace
period
of
168
consecutive
unit
operating
hours,
as
defined
in
40
CFR
72.2.
incorporated
by
reference
in
Section
225.140
(or,
for
monitors
installed
on
common
stacks
orbypass
stacks,
168
consecutive
stack
operating
hours,
as
defined
in
40
CFR
72.2)
in
which
to
perform
a
linearity test
or
leak
check
of
that
monitor
or
monitoring
system
(or
range).
The
grace
period
begins
with
the
first
unit
or
stack
operating
hour
following
the
calendar
quarter
in
which
the
linearity
test
was
due.
Data
validation
during
a
linearity
or
leak
check
grace
period
must
be
done
in
accordance
with
the
applicable
provisions
in
Section 2.2.3
of
this
Exhibit.
(b)
If,
at
the
end
of
the
168
unit
(or
stack)
operating
hour
grace
period,
the
required
linearity
test
or
leak
check
has
not
been
completed,
data
from
the
monitoring
system
(or
range)
will
be
invalid,
beginning
with
the
first
unit
operating
hour
following
the
expiration
of
the
grace
period. Data
from
the
monitoring
system
(or
range)
remain
invalid
until
the
hour
of
completion’
of
a
subsequent
successful
hands-off
linearity
test
or
leak
check
of
the
monitor
or
monitoring
system
(or
range).
Note
that
when
a
linearity
test
or
a
leak
check
is conducted
within
a
grace
period
for
the
purpose
of
satisfying
the
linearity
test
or
leak
check requirement
from
a previous
OA
operating
quarter,
the
results
of
that
linearity
test
or
leak
check
may
only
be
used
to
meet
the
linearity
check
or
leak
check
requirement
of
the
previous quarter,
not
the
quarter in
which
the
missed
linearity test
or
leak
check
is
completed.
2.2.5
Flow-to-Load
Ratio
or
Gross
Heat
Rate
Evaluation
53
(a) Applicability’
and’
underSection
7.8 to
Appendix
A to
40
CFR Part 75 , the owner or operator must, for each flow
rate
monitoring
system
installed
on each unit, common stack or multiple stack, evaluate
the flow-to-load
ratio
quarterly,
i.e. for each
QA
operating
quarter (asdefinedin;40CFR72.2,
incorporated
byreference
in Section
225.140).
At the end of each
QA
operating quarter,
the owner or operator
must
use
EquationB-1
tocalculatethe.flow-to-ioad:ratio,foreveryhour
during the quarter in
which:
the
unit
(or
combination of units, for a common
stack)
operated within
+-l0.0
percent
of
the
average
load during the
most recent normal-load flow
RATA; and a quality assured hourly average
flow
rate
was obtained with a certified flow rate monitor. Alternatively,
for the reasons stated in
paragraphs
(c)(i)
through
(c)(6):
of this Section the owner or
operatormay:
exclude
from
the
data
analysis
certain
hours
within
+-
10.0 percent of
Lavg
and
may
calculate
Rh
values
for only the
remaining
hours.
0
Rh
=--io-
(Equation
B-i)
where,
Rh
= Hourly
value
of the flow-to-load ratio, seth/megawatts,
scfhli 000 lb/hr
of steam,
or
scfhl(mmBtu/hr
thermal
output).
Qh
= Hourly
stack gas volumetric flow rate, as measured by the
flow rate monitor, scth.
Lh
Hourly unit load,
megawatts, 1000 lb/hr
of
steam,
or mmBtu/hr thermal output;
must
be
within
+
10.0
percent of
Lavg
during the most recent normal-load flow
RATA.
(1)
In
Equation
B-i, the
owner
or
operator
may use either bias-adjusted flow
rates or
unadjusted
flow rates,
provided
that
all of the ratios are calculated the
same way. For a common
stack,
Lh
will
be the
sum of the
hourly operating loads of all units that
discharge through the stack.
For
a unit
that
discharges
its
emissions
through
multiple stacks or that
monitors its emissions
in
multiple
breechings,
Qh
will be either the
combined höürly
vOlumetric flow rate for
all of the stacks
or ducts
(if
the test
is done on a
unit
basis)
or the hourly flow rate
through each stack
individually
(‘if
the
test
is
performed
separately for each
stack)
For a unit with
a multiple
stack
discharge
configuration
consisting
of a main
stack
and
a
bypass stack, each of which
has a certified flow monitor
(e.g.,
a
unit
with a wet
SQ
2
scrubber),
calculate the hourly flow-to-load ratios
separately for each
stack.
Round
off each
value of
Rh
to two decimal places.
(2)
Alternatively,
the owner or
operator may
calculate the hourly
gross
heat rates
(G1{R)
in
lieu
of
54
the’
hourly
flow-to-kad’ratios.
The’houri’
GHR’
must
‘be
‘determined’
only
for
those
hours
in
which
quality
assured
flow
rate
data and
diluent
gas
(QQ
2
or
02)
concentration
data are
both,
available
from
a
certified
monitor
or
monitoring system
or
reference
method.
If
this
option
is
selected,
calculate
each’
hourly
GHR
value
as
follows:
(Heatlnput),
(GHR)h
=
x
1000
(Equation
B-la)
where,
(GHR)h
=
Hourly
value
of
the
gross
heat
rate,
Btulkwh,
Btu/lb
steam
load,
or
1000
mmBtu
heat
input/mmBtu
thermal
output.
(Heatlnput)h
=
Hourly
heat
input,
as
determined
from
the
quality
assured
flow
rate
and
diluent
data,
using
the
applicable
equation
in
Exhibit
C
to
this
Appendix,
mmBtu/hr.
L,,
=
Hourly
unit
load,
megawatts,
1000
lb/hr
of
steam,
or
mmBtulhr
thermal
output
must
be
within
+
10.0
percent
of
Lavg
during
the
most
recent
normal-load
flow
RATA.
(3)
In
Equation
B-la,
the
owner
or
operator
may
either
use
bias-adjusted
flow
rates
or
unadjusted
flow
rates
in
the
calculation
of
(Heatlnput)h,
provided
that
all
of
the
heat
input
values
are
determined
in
the
same
manner.
(4)
The
owner
or
operator
must
evaluate
the
calculated
hourly
flow-to-load
ratios
(or
gross
heat
rates)
as
follows.
A
separate
data
analysis
must
be
performed
for
each
primary
and
each
redundant
backup
flow
rate
monitor
used
to
record
and
report
data
during
the
quarter.
Each
analysis
must
be
based
on
a
minimum
of
168
acceptable
recorded
hourly
average
flow
rates
(i.e.,
at
loads
within
+-
10
percent
of
La).
When
two
RATA
load
levels
are
designated
as
normal,
the
analysis
must
be
performed
at
the
higher
load
level,
unless
there
are
fewer
than
168
acceptable
data
points
available
at
that
load
level,
in
which
case
the
analysis
must
be
performed
at
the
lower
load
level.
If,
for
a
particular
flow
monitor,
fewer
than
168
acceptable
hourly
flow-to-load
ratios
(or
GHR
values)
are
available
at
any
of
the
load
levels
designated
as
normal,
a
flow-to-load
(or
GHR)
evaluation
is
not
required
for
that monitor
for
that
calendar
quarter.
(5)
For each
flow’
monitor,
use Equation
B-2
in
this
Exhibit
to
calculate
Eh,
the
absolute
percentage
difference
between
each
hourly
Rh
value
and
Rrej
the reference
value
of
the
flow-to-load
ratio,
as
determined
in
accordance
with
Section
7.7
to
Appendix
A
to
40
CFR
Part
75.
Note
that
Rrej
must
always
be
based
upon
the
most
recent
normal-load
RATA,
even
if
that
RATA
was
performed
in
the
55
caiendar”q’uarter
be ing
evaluated.:
R
ref
-R;
t
x100
(EguationcB2.
Rrej
where:
Eh
= Absolute percentage difference between the
hourly average
flow-to-load ratio
and
the
reference valueof the fiow-to-1oad ratio at norn al load.
Rh
= The hourly average flow-to-load ratio, for each flow rate recorded at a load level
within
+-10.O
percent of
Rref
= The
reference
value of the
flow-to-load ratio from the most recent normal-load
flow
RATA,
determined in accordance with Section 7.7 to Appendix A to 40 CFR Part 75.
(6)
Equation B-2 must be used in a consistent manner.
That is,
use
Rref
and
Rh
if the
flow-to-load
ratio
is being
evaluated, and use
(GHR)ref
and
(GHR)
h if the gross heat rate is being
evaluated.
Finally, calculate
E. the arithmetic average of all of the hourly
Eh
values. The owner
or
operator
must
report the results of each quarterly flow-to-load
(or
gross heat rate) evaluation, as
determined
from
Equation B-2, in the electronic
quarterly
report
required under
40 CFR 75.64.
(b)
Acceptable
results. The results of a quarterly flow-to-load
(or
gross heat
rate)
evaluation
are
acceptable,
and
no
further action is required, if the calculated
value
of Ef is less than
or equal
to:
(1)
15
0
percent if
for the most recent normal-load flow RATA is
>=60
megawatts
(or
>=500
klb/hr of
steam)
and
if
unadjusted flow rates were used in th& calculations or
(2)
10 0
percent if
Lavg
for
the most recent normal-load flow RATA is
>=60
megawatts
(or
>=500
klb/hr
of steam)
and
if
bias-adjusted
flow rates were used in the calculations; or
(3)
20.0 percent,
if
Lavg
for
the
most
recent
normal-load flow RATA is <60 megawatts (or <500 klb/hr of
steam)
and if
unadjusted
flow
rates were used in
the
calculations;
or
(4)
15.0
percent,
if
Layg
for the most recent
normal-load
flow
RATA
is
<60
megawatts (or <500
klb/hr of
steam)
and if
bias-adjusted
flow rates were
used
in
the
calculations.
If Ef is above
these limits, the owner or operator
must
either:
implement
Option
1
in
Section
2.2.5.1 of this
Exhibit:
or perform a RATA in accordance with
Option
2 in Section
2.2.5.2
of
this
Exhibit:
or
re-examine the hourly data used for the
flow-to-load
or GHR analysis
and
recalculate
Ef.
after
excluding all
non-representative hourly flow rates. If
Ef is above these limits,
the
owner
56
or
operator
must
either:
implëment’Option
1
in
Section
2;2.51’OfthiExhibit;perfo
a
RATA
in
accordance
with
Option
2
in
Section 2.2.5.2
of
this
Exhibit;
or
(if
applicable)
re-examine
the
hourly
data
used
for
the
flow-to-load
or
GHR
analysis
and
recalculate
E.
after
excluding
all
non
representative
hourly,
flow
rates,
as
‘provided
in
paraaph
(c)
ofthis
Section.
(c)
Recalculation
of
E.
If
the
owner
or
operator
did
not
exclude
any
hours
within
+-
10
percent
of
Lavg
from the
original
data
analysis
and
chooses
to
recalculate
E.
the
flow
rates
for
the
following
hours
are
considered
non-representative
and
may
be
excluded
from
the
data
analysis:
(1)
Any
hour
in
which
the
type
of
fuel
combusted
was
different
from
the
fuel
burned
during
the
most
recent
normal-load
RATA.
For
purposes
of
this
determination,
the
type
of
fuel
is
different
if
the
fuel
is
in
a different
state
of
matter
(i.e.,
solid,
liquid,
or
gas)
than
is
the
fuel
burned
during
the
RATA
or
if
the
fuel
is
a
different
classification
of
coal
(e.g.,
bituminous
versus
sub-bituminous).
Also,
for
units
that
co-fire
different
types
of
fuels,
if
the
reference
RATA
was
done
while
co-firing,
then
hours
in
which a
single
fuel
was
combusted
may
be
excluded
from the
data
analysis
as
different
fuel
hours
(and
vice-versa
for
co-fired
hours,
if
the
reference
RATA
was
done
while
combusting
only
one
type
of
fuel);
(2)
For
a
unit
that
is
equipped
with
an
SO
2
scrubber
and
which
always
discharges
its
flue
gases
to
the
atmosphere
through
a
single stack,
any
hour
in
which
the
SO
2
scrubber
was
bypassed;
(3)
Any hour
in
which
“ramping”
occurred,
i.e.,
the
hourly
load
differed
by
more
than
+-15.0
percent
from
the
load
during
the
preceding
hour
or
the
subsequent
hour;
(4)
For
a
unit
with
a multiple
stack
discharge
configuration
consisting
of
a
main
stack
and
a
bypass
stack,
any
hour
in which the
flue
gases
were
discharged
through
both
stacks;
(5)
If
a
normal-load
flow
RATA
was
performed
and
passed
during
the
quarter
being
analyzed,
any
hour
prior
to
completion
of
that
RATA;
and
(6)
If
a
problem
with
the
accuracy
of the
flow
monitor
was discovered
during
the
quarter
and
was
corrected
(as
evidenced
by
passing
the
abbreviated
flow-to-load
test
in
Section
2.2.5.3
of
this
Exhiht.
ai
L
:
to
completion
of
the
abbreviated flow-to-load
test.
(7)
After
identifying
and
excluding
au
-representative
hr:rly
data
in
accordance
with
paragraphs
(c)(1)
through
(6)
of
this
Section,
the
owner
J:.
,
rvz
fl,
remaining
dacond
time.
At
least
168 representative
hourly
ratios
or
GHR
values
must
be
avaiiaue
tc
pertiin
the
analysis;
otherwise,
the
flow-to-load
(or
GHR)
analysis
is
not
required
for
that
monitor
for
that
calendar
quarter.
(8)
If,
after re-analyzing
the
data,
E
meets the
applicable
limit
in
paraaph
(bX1),
(b)(2),
b)(3),
or
57
(b)(4)
of thi
Sëctiön
no
further action
i
required:If,
hbwever
is still
above
the
apliëabIV
limit
data from
the monitor will
be declared out-of-control,
begiing with the first unit
operating
hour
following the
quarter
in which
E
exceeded the
applicable
limit.
Alternatively,
if
a
probationary
calibration
error test is performed and
passed according to Section 1
.4(b)(3)(B)
of this
Appendix,
dataVfrom
the
rnonitormay
be
declared
condjtjOnallyvaijd
following the
quarter
in
which
exceeded the
applicable
limit. The
owner
or
operator must then either implement
Option
1 in
Section 2.2.5.1
of
this Exhibit
or
Option
2 in Section 2.2.5.2
of
this
Exhibit.
2.2.5.1
Option
1
Within
14
unit
operating
days of the end
of the calendar quarter for which
the
value is
above
the
applicable limit, investigate and troubleshoot
the applicable flow
monitor(s).
Evaluate
the
results
of
each investigation as
follows:
(a)
If the investigation fails to uncover a problem
with
the
flow monitor, a RATA
must be
performed
in accordance with
Option
2
in
Section 2.2.5.2 of this Exhibit.
(b)
If a problem
with
the flow
monitor is identified through the investigation
(including
the
need
to
re-linearize
the monitor by changing
the polynomial coefficients or
K
factor(s)),
data
from
the
monitor are considered invalid back to
the first unit operating hour after the
end of the
calendar
quarter for which
was above the applicable
limit. If the option to use conditional
data
validation
was
selected
under
Section
2.2.5(c)(8)
of this Exhibit, all conditionally
valid data will
be
invalidated,
back to the first
unit operating
hour after the end of the calendar
quarter
for which Ef
was
above
the
applicable
limit. Corrective actions
must be
taken.
All corrective actions
(e.g., non-routine
maintenance, repairs,
major
component replacements, re-linearization
of the monitor,
etc.) must
be
documented in
the operation and
maintenance records for the monitor.
The owner or
operator
then
must
either complete the abbreviated flow-to-load test
in Section 2.2.5.3 of this
Exhibit,
or, if
the
corrective action
taken has required
relinearization of the flow monitor,
must perform
a
3-load
RATA. The
conditional data validation
procedures in Section 1
.4(b)(3)of
this
Appendix
may
be
applied to
the
3-load
RATA.
V
2.2.5.2Option2
Perform a
single-1oaçi
a’__‘cmated
iormal under
Section
6.5.2.1 of
Exhibit
A
to
this Apoep
di
xc.ai
now morr
for which E is outside of the applicable limit.
If the
RATA
is
passed
hands-off, in accordance with Section 2.3.2(c)
of
this Exhibit,
no further action
is
required
and
the
out-of-control
period
for the monitor ends at the date and
hour of completion
of a
successful
RATA,
unless
the
option to use conditional
data validation was selected under
Section
2.2.5(c)(8)
of
this
Exhibit.
In
that case, all
conditionally
valid data from
the
monitor are considered
to
be
quality
58
assured,
lack tothe
fitt
tmitoperatinghôur
1Toing
thea
thddfthe
calendar
quarter
fo
which
the
value
was
above
the
applicable
limit.
If
the
RATA
is
failed,
all
data
from
the
monitor
will
be
jyalidated,back.to
the
first
unit
operating
hourfollowing:
the.
endof
the
calendar
quarter
for
which
theEf
value
was
above
the
applicable
limit.
Data.
from
the
monitor
remain
invalid
until
the
required
RATA
has
been
passed
Alternatively,
following
a
failed
RATA
and
corrective
actions,
the
conditional
data
validation
procedures
of
Section
1
.4(b)(3)
of
this
Appendix
may
be
used
until
the
RATA
has been
passed.
If
the
corrective
actions
taken
following
the
failed
RATA
included
adjustment
of
the polynomial
coefficients
or
K-factor(s)
of
the
flow
monitor,
a
3-level
RATA
is
required,.
except
as.
otherwiçpçcified
inSection
21.3.
of
his
Exhibit
2.2.5.3
Abbreviated
Flow-to-Load
Test
(a)
The following
abbreviated
flow-to-load
test
may
be
performed
after
any
documented
repair,
component
replacement,
or
other
corrective
maintenance
to
a
flow
monitor
(except
for
changes
affecting
the linearity
of
the
flow
monitor,
such
as
adjusting
the
flow
monitor
coefficients
or
K
factor(s)) to
demonstrate
that
the
repair,
replacement,
or
other
maintenance
has
not
significantly
affected
the
monitor’s
ability
to
accurately
measure
the
stack
gas
volumetric
flow
rate.
Data
from
the
monitoring
system
are considered
invalid
from
the
hour
of
commencement
of
the
repair,
replacement,
or
maintenance
until
either the
hour
in
which
the
abbreviated
flow-to-load
test
is
passed,
or
the
hour in
which
a
probationary
calibration
error
test
is
passed
following
completion
of
the
repair,
replacement,
or
maintenance
and
any
associated
adjustments
to
the
monitor
If
the
latter
option
is
selected,
the
abbreviated
flow-to-load
test
must
be
completed
within
168
unit
operatjng
hours
of
the probationary
calibration
error
test
(or,
for
peaking
units,
within
30
unit
operating
days,
if
that
is
less restrictive).
Data
from
the
monitor
are
considered
to
be
conditionally
valid
(as
defined
in
40
CFR
72.2, incorporated
by
reference
in
Section
225.140),
beginning
with
the
hour
of
the
probationary
calibration
error test.
(b)
Operate
the
unit(s)
in
such
a
way
as
to
reproduce,
as
closely
as
prti,
the
exact
conditions
at
the
time
of
the
most
recent
normal-load
flow
P
‘
T.
iieve
this,
it
is
recommended
that
the
load be
held
constant
to
within
+-
I
ent
of
the
average
load
during
the
RATA
and
that
the
diluent
gas
(CQ
r0,
oncentration
be
maintained
within
+-0.5
percent
CQ2
or
02
of
the
aveg
diluent
concentration
during
the
RATA.
For
common
stacks,
to
the
extent
practicable,
use
the
same
combination
of
units
and load
levels
that
were
used
during
the
RATA.
When
the
process
parameters
have
been set, record
a
minimum
of
six
and
a
maximum
of
12
consecutive
hourly
average
flow
rates,
using
the
flow
monitor(s)
for
which
was
outside
the
applicable
limit.
For
peaking
units,
a
minimum
of
three
and
a
maximum
of
12.
consecutive
hourly
average
flow
rates
are
required.
Also
record
the
corresponding
hourly
load values
and,
if
applicable,
the
hourly
diluent
gas
concentrations.
Calculate
the
flow-to-load
ratio
(or
GHR)
for
each
hour
in
the
test
hour
period,
using
Equation
B-i
or
B-la.
Determine
Eh
for
each
hourly
flow-
to-load
ratio
(or
GRR).
using
Equation
B-2
of
this
Exhibit
and
then calculate
the
arithmetic
average
of
the
Eh
values.
59
(c)
The results of the abbreviated
flow-to-load test will
be
considered
acceptable,
and
no
further
action
is
required
if the
value of
Eh
does not exceed the
applicable limit
specified
in
Section2.2.5
of
this
Exhibit
All
éonditionally
valid
data
recorded”by’the
flow
monitor will ‘b
considered
quality
assured, beginning with
the hour of the probationary calibration
error test that
preceded
the
abbreviated flow-to-load
test
(if
applicable). However,
if
is outside the
applicable
limit,
all
conditionally valid data recorded by the flow
monitor
(if
applicable) will be
considered
invalid
back
to the hour of the probationary calibration error
test
that
preceded the abbreviated
flow-to-load
test,
in1-load RATAiqpjred
in accordance with Section 2.2.5.2
of this Exhibit.
If
the
flow
monitor must be re-linearized, however, a 3-load
RATA is required.
2.3 Semiannual and Annual Assessments
For
each
primary and redundant backup monitoring
system, perform relative accuracy
assessments
either semiannually or
annually,
as specified in Section 2.3.1.1
or
2.3.1.2
of this Exhibit
for
the
type
of test
and
the performance
achieved.
This requirement applies as of the, calendar
quarter
following
the calendar quarter in which the monitoring system
is provisionally certified.
A
summary
chart
showing the frequency with which a relative accuracy test
audit must be performed,
depending
on
the accuracy
achieved,
is
located
at the end of this Exhibit in Figure 2.
2.3.1
Relative Accuracy Test Audit
(RATA)
2.3.1.1
Standard RATA Frequencies
(a)
Except
for mercury monitoring systems, and
as otherwise specified in
Section
2.3.1.2
of this
Exhibit, perform relative accuracy test audits semiannually, i.e.,
once every
two
successive
QA
operating
quarters
(as
defined
in 40 CFR 72.2, incorporated by reference
in Section
225.140)
for
each
primary
and redundant backup flow monitor,
2
CO
or
02
diluent monitor
used to
determjneheat
input,
moisture monitoring
system.
F cach mary and redundant
backup
mercury
concentration
monitoring
system and
each
sorbent trap monitoring sy:tm.
1AI
must
be
performed
annually,
i.e., once
every four successive
QA
operating quarters (as defined
in 40 CFR 72.2).
A
calendar
quarter
that does not qualify as a
QA
operating
quarter
must be excluded in
determining
the
deadline
for
the next
RATA.
No
more
than eight successive calendar
quarters
must elapse
after the
quarter
in
which a RATA
was last
performed
without a subsequent
RATA having
been
conducted. If
a
RATA
has not been
completed by the end
of the
eighth
calendar quarter
since the quarter
of the last
RATA,
then the RATA
must
be completed
within a 720 unit
(or
stack)
operating
hour grace
period
(as
provided in Section
2.3.3 of this
Exhibit) following the end of the
eighth
successive
elapsed
calendar
quarter, or data
from the
CEMS will become invalid.
(b)
The relative
accuracy
test audit
frequency of a CEMS may
be reduced, as
specified in
Section
2.3.1.2 of
this Exhibit, for primary or redundant
backup
monitoring systems
which
qualify
for less
frequent
testing.
Perform all
required RATAs in accordance
with the applicable
procedures
and
60
provisions
in
Sëctions
65
though6.522
uf
:EthibitA:.to.
this Appendix
ànd
Sections
2:3
I.3’and
2.3.1.4
of
this Exhibit.
2.3.1.2
Reduced
RATAFrequencies
Relative
accuracytest
auditsofprimary
and:redundantbackup
CO
2
or
O
diluent
monitors
used
to
determine
heat
input,
moisture
monitoring
systems,
flow
monitors
may
be
performed
annually
(i.e.,
once
every
four
successive
OA
operating
quarters,
rather
than
once
every
two
successive
QA
operating
quarters)
if
any
of
the
following
conditions
are
met
for
the
specific
monitoring
system
involved:
(a)
The relative
accuracy
during
the
audit
of
a
CO
2
or
02
diluent
monitor
used
to
determine
heat
input
is
<=r75
percent;
(b)
The relative
accuracy
during
the
audit
of
a
flow
monitor
is
<=7.5
percent
at
each
operating
level
tested;
(c)
For low
flow
(<=10.0
fbs), as
measured
by the
reference
method
during
the
RATA
stacks/ducts,
when
the flow
monitor
fails
to
achieve
a
relative
accuracy
<7.5
percent
during
the
audit,
but
the
monitor
mean
value,
calculated
using
Equation
A-7
in
Exhibit
A
to
this
Appendix
and
converted
back
to
an
equivalent
velocity
in
standard
feet
per
second
(fps),
is
within
+-
1.5
fps
of
the
reference
method
mean
value,
converted
to
an
equivalent
velocity
in
fps;
(d)
For
a
Q2
or
Q2
monitor,
when
the
mean
difference
between
the
reference
method
values
from
the
RATA
and
the
corresponding
monitor
values
is
within
+-
0.7
percent
CO
2
or
O;
and
(e)
When
the
relative
accuracy
of
a
continuous
moisture
monitoring
system
is
<=
7.5
percent
or
when
the
mean
difference
between
the reference
method
values
from
the
RATA
and
the
corresponding
monitoring
system
values
is
within
+-1.0
percent
H0.
2.3.1.3
RATA
Load
(or
Operating)
Levels
and
Additional
RATA
Requirements
(a) For
CO
2
oQ
2
dilut
iom
tots
u
“
determine
heat
input,
mercury
concentration
monitoring
systems,
sorb ent
trap
monitoring
systems,
moisnL
1
1onitoring
systems,
the
required
semiannual
or
annual
RATA
tests
must•
be
done
at
the
load
level
(or
op
n
g
level)
designated
as
normal
under
Section
6.5.2.1(d)
of
Exhibit
A
to
this
Appendix.
If
two
load
.
-
(or
octip1are
designated
as
normal,
the
required
RATA(s)
may
be
done
at
either
load
level
(or
operating
IL
1),
(b) For flow
monitors
installed
and
bypass
stacks,
and
for
flow
monitors
that
qualify
to
perform
only
single-level
RATAs
under
Section
6.5.2(e)
of
Exhibit
A
to
this
Appendix,
all
required
semiannual
or
annual
relative
accuracy
test
audits
must
be
single-load
(or
single-level)
audits
at
the
normal
load
(or
operating
level),
as
defined
in
Section
6.5.2.1(d)
of
Exhibit
A
to
this
Appendix.
61
(1)
An annual 2-load
(or 2-level)
flow
RATA must be done at the two most frequently
used
load
levels
(or
operating
levels),
asdeterminedunder.
Seotion&5.2.
1(d)
of
Exhi:bitA
tothis
Appendix,
or
(if applicable)
at the operating levels
determined under Section
6.5.2(e)
of Exhibit
A to this
Appendix.
Alternatively,.
a 3-load
(or•
mid, and hi
load
levels
(or
operating
levels),
as defined under Section
6.5.2.1(b)
of Exhibit A to this
Appendix,
may
be
performed in lieu of the
2-load
(or
2-level)
annual
RATA.
(2)
If
the
flow monitor is on a semiannual
RATA frequency, 2-load
(or
2-level)
flow
RATAs
and
single-load (or
single-level)
flow RATAs at the normal
load
level
(ornormal
operating
level)
may
be
performed alternately.
(3)
A single-load (or single-level) annual flow RATA
may be performed in lieu of the
2-load
(or
2-
level)
RATA
if the results of an historical load
data analysis show that in the time
period
extending
from the ending date of the last annual flow RATA
to a date that is no more than 21
days
prior
to
the
date
gf
the current
annual
flow RATA, the unit
(or
combination
of units,
for a common
stack)
has
operated at a
single load level
(or
operating
level)
(low,
mid, or
high),
for
>=85.0
percent
of
the
time.
Alternatively, a flow monitor may qualify
for a single-load (or single-level)
RATA
if
the
85.0
percent
criterion is met in the time period extending
from the beginning of the quarter
in
which
the
last
annual flow RATA
was
performed
through the end
of the calendar quarter preceding
the
quarter
of
current annual
flow
RATA.
(4)
A 3-load
(or
3-level)
RATA,
at the low-, mid-, and high-load levels
(or
operating
levels),
as
determined
under Section 6.5.2.1 of Exhibit A
to this
Appendix,
must be
performed
at
least
once
every twenty
consecutive
calendar quarters, except
for flow monitors that are
exempted
from
3-load
(or
3-level)
RATA testing under Section
65.2(b)
or
6.5.2(e)
of Exhibit A to this
Appendix.
(5)
A
3-load (or
3-level)
RATA is
required whenever
a flow monitor is re-linearized,
i.e.,
when
its
polynomial
coefficients or K
factor(s)
are changed, except
for flow monitors that are
exempted
from
3-load
(or
3-level)
RATA
testing under Section
6.5.2(b)
or
6.5.2(e)
of Exhibit A to
this
Appçjx.
For monitors
so exempted under Section
6.5.2(b),
a
single-load
flow
RATA
uired.
For
monitors so
exempted
under Section
6.5.2(e),
eith
. :ie-level RAlA
or a 2-level
RATA
is
required,
depending on
the
number
of
oper,
revels documented in the monitoring
plan
for
the
unit.
110W
audits, the audit points at
adjacent
load levels or at
adjacent
operating
levels
(e.g.,
mid
and
high)
must be separated by
no
less
than 25.0 percent of the “range
of
operation,”
as
defined in Section
6.5.2.1
of
Exhibit
A to this Appendix.
(d)
A
RATA
of a moisture monitoring
system must be performed whenever
the coefficient,
K
factor
or
mathematical
algorithm determined under
Section 6.5.6 of Exhibit A
to
this
Appendix
is
changed.
62
2.3.1.4
Number
ofRATAAttempts
The owner
or
operator
may
perform
as
many RATA
attempts
as are
necessary
to achieve
the
desired
relative
accuracy
test
audit frequencies
However,
the
data validation
procedures
in
Section
2;3
.2 of
this Exhibit
must
be
followed.
2.3.2
Data Validation
(a) A RATA
must
not
commence
if the monitoring
system
is operating
out-of-control
with
respect
to
any of the
daily
and
quarterly
gglity
assurance
ççqjred
by
Sections
2.1
and
2.2
of
this
Exhibit
or with respect
to the
additional
calibration
error
test requirements
in
Section
2.1.3
of this
Exhibit.
(b)
Each
required
RATA
must
be done
according
to paragraphs
(b)(1),
(b)(2)
or
(b)(3)
of this
Section:
(1)
The
RATA may
be done
“cold,
i.e.,
with
no
corrective
maintenance,
repair,
calibration
adjustments,
re-linearization
or
reprogramming
of
the monitoring
system
prior to
the test.
(2)
The
RATA may
be
done
after performing
only
the
routine
or non-routine
calibration
adjustments
described
in Section
2.1.3 of
this Exhibit
at the
zero and/or
upscale
calibration
gas
levels,
but no
other
corrective
maintenance,
repair,
re-linearization
or
reprogramming
of
the
monitoring
system.
Trial
RATA runs
may be
performed
after
the calibration
adjustments
and
additional
adjustments
within
the allowable
limits
in Section
2.1.3
of
this
Exhibit
may
be
made
prior
to the
RATA,
as
necessary,
to
optimize
the performance
of
the CEMS.
The
trial RATA
runs need
not
be
reported,
provided
that
they
meet
the
specification
for
trial
RATA
runs
in
Section
1.4(b)(3)(G)(v)
of
this
Appendix.
H
wever,
if, for any
trial
run,
the specification
in Section
(b)(3)(G)(v)
ofthis
Appendix
is
not
met,
the
trial
run
must be
counted
as an aborted
RATA
attempt.
(3)
The RATA
may
be done
after repair,
corrective
maintenance,
re-linearization
or reprogramming
of
the
monitoring
system.
In
this case,
the monitoring
system
will
be considered
out-of-control
from
the
hour in which
the repair,
corrective
maintenance,
re-linearization
or
reprogramming
is
commenced
until
the
RATA
has been
passed.
Alternatively,
the
data
validation
procedures
and
associated
timelines
in Sections
1.4(b)(3)(B)
through
(I)
of this
Appendix
may be
followed
upon
completion
of
the
necessary
repair, corrective
maintenance,
re-linearization
or
reprogramming.
If the
procedures
in
Section 1
.4(b)(3)
of
this
Appendix
are
used, the
words “quality
assurance”
apply
instead of
the
word “recertification.”
(c)
Once
a
RATA
is
commenced,
the test
must
be done
hands-off.
No
adjustment
of
the
monitor’s
calibration
is
permitted
during
the RATA
test period,
other
than the
routine
calibration
adjustments
following
daily
calibration
error
tests,
as described
in
Section 2.1.3
of this
Exhibit.
If a
routine
daily
calibration
error
test is performed
and
passed
just prior
to
a
RATA
(or
during
a RATA
test
period)
and a
mathematical
correction
factor
is automatically
applied by
the
DAHS,
the
correction
factor
63
mustbe
appliedto all subsequentdata recorded
byth&monitor including the RATA
test data. For
2-
level and 3-
level flow monitor audits, no linearization or reprogramming of the
monitor
is
permitted
in between load
levels..
(d)
For
single-load (or single-level)
RATAs,
if a daily calibration error test is failed during
a
RATA
test
period, prior to. completing the test,
the RATA must be repeated.
Data
from the
monitor
are
invalidated
prospectively from
the
hour of the failed calibration error test until the
hour
of
completion of a
subsequent successful calibration error test. The subsequent RATA must
not
be
commenced until
the
monitor has
successfully passed
a
calibration error test
in accordance
with
Section
2.1.3 of this Exhibit.
Notwithstanding these requirements, when ASTM
D6784-02
(incorporated
by
reference under Section
225.140) or Method 29 in
appendix A-8
to 40
CFR
60,
incorporated
by
reference
in Section
225.140, is used as the reference method for the RATA
of
a
mercury CEMS, if
a calibration error test of the CEMS is failed during
a RATA test
period,
any
test
run(s)
completed
prior to
the failed calibration error test need not be
repeated;
however, the
RATA
may not
continue until a
subsequent calibration error test of the mercury CEMS has been
passed.
For
multiple-load
(or
multiple-level)
flow RATAs, each load level (or
operating
level)
is treated
as a
separate
RATA
(i.e..
when
. a
calibration error.
test
is
failed
prior. to
completing
the RATA
at
a
particular load
level
(or
operating
level),
only the RATA at that load level
(or
operating level)
must
be
repeated;
the results of any
previously-passed
RATA(s)
at the other load level(s) (or
operating
level(s)) are
unaffected,
unless re-linearization of the monitor is required to correct the
problem
that
caused the
calibration
failure, in which case a
subsequent
3-load (or
3-level)
RATA
is
required),
except as
otherwise
provided in Section
2.3.1.3(c)(5)
of this
Exhibit.
(e)
For a
RATA
performed
using
the
option
in
paragraph
(b)(1)
or
(b)(2)
of this
Section,
if
the
RATA
is failed
(that
is, if the
relative accuracy
exceeds the applicable specification in
Section
3.3
of
Exhibit A to
this Appendix) or
if the RATA is aborted prior to completion due to a
problem
with
the
CEMS,
then
the CEMS
is out-of-control and all emission data from the CEMS are
invalidated
prospectively
from
the hour in which the RATA is failed or aborted. Data
from the
CEMS
remain
invalid
until the
hour of
completion of a
subsequent
RATA
that meets
the applicable specification
in
Section
3.3 of
ExhibitA to
this Appendix. If the option in paragraph
‘b)(3)
of this Section
to use
the
data
validation
procedures and
associated
timelines,,in Sections 1
.4(b)(3)(B)
through(b)(3)(Iof
this
Appendix
has
been selected
the
beginmng
and
end
of
the out-of-control period must
be determined
in
accordance
with
Section 1
.4(b)(3)(G)(i)
and
(ii)
of this Appendix.
Note
that
when
a
RATA
is
aborted
for a
reason other than
monitoring
system
malfunction (see
paragraph
(g)
of
this
Section),
this
does
not
trigger an
out-of-control period
for
the monitoring system.
(f)
For a
2-level
or 3-level flow
RATA, if, at any load level
(or
operating
level),
a RATA
is
failed
or
aborted
due to
a problem with
the flow monitor, the RATA
at
that load level (or operating
level)
must be
repeated
The flow
monitor is considered out-of-control and data from the
monitor
are
invalidated
from
the hour in
which the test is failed or aborted and remain invalid until the
Passing
of
a
RATA
at
the failed load
level
(or operating
level),
unless the option in paragraph
(b)(3)
of
this
Section
to
use the
data
validation
procedures
and associated timelines in Section 1
.4(b)(3)(B)
through
(b)(3)(I)
of this
Appendix has been selected,
in
which
case the
beginning and
end
of
the
out
64
of-control
j:erió&’thiist’
be•
dëterthih’ed’
iir
accordance
with
Scti’ön
i.4(b)(3RG(iT
and”(ii)’ofthi
Appendix.
Flow
RATA(s)
that
were
previously
passed
at
the
other
load
level(s)
(or
operating
levels(s))
do
not
have
to
be
repeated
unless
the
flow
monitor
must
be
re-linearized
following
the
failed
or
aborted
test.’
if
the
flow
monitor
is.re-linearize& a subsequent
3-load
(or3-]evel)
RATA
is
reguired,
except
as
otherwise
provided
in
Section.
2.3.1
.3(c)(5)
of
this
Exhibit.
(g)
For
each
monitoring
system, report
the
results
of all
completed
and
partial
RATAs
that
affect
data
validation
(i.e.,
all
completed,
passed
RATAs all
completed,
failed
RATAs
and
all
RATAs
aborted
due
to
a
problem
with
the
CEMS,
including
trial
RATA
runs
counted
as
failed
test
attempts
pparagrapj(2)
of
this
Section
or
under
Section 1
.4(b’)(3)(G)(vi)) in
the
quarterly
report
required
under
40
CFR
75.64,
incorporated
by
reference
in
Section
225.140.
Note
that
RATA
attempts
that
are
aborted
or
invalidated
due
‘to
problems
with
the
reference
method
or
due
to
operational
problems with
the
affected
unit(s)
need
not
be
reported.
Such
runs
do
not
affect
the
validation
status
of
emission
data
recorded
by
the
CEMS.
However,
a record
of
all
RATAs,
trial
RATA runs
and
RATA
attempts
(whether
reported
or
not)
must
be
kept
on-site
as
part
of
the
official
test
log
for
each
monitoring
system.
(h)
Each
time
that
a hands-off
RATA
of
a
mercury
concentration
monitoring
system,
a
sorbent
trap
monitoring
system,
or
a
flow
monitor
is
passed, perform
a bias
test
in
accordance
with
Section
7.4.4
of Exhibit
A
to
this
Appendix.
(1)
Failure
of
the
bias
test
does
not
result
in
the
monitoring
system
being
out-of-control.
2.3.3
RATA
Grace
Period
(a)
The
owner
or operator
hasa
grace
period
of
720
consecutive
unit
operating
hours,
as
defined
in
40
CFR
72.2,
incorporated
by
reference
in
Section
225.140
(or,
for
CEMS installed
on
common
stacks
or
bypass
stacks,
720
consecutive
stack
operating
hours,
as
defined
in
40
CFR
72.2),
in
which
to
complete
the
required
RATA
for
a
particular
CEMS
whenever:
(1)
A
required
RATA
has
not
been
performed
by
the
end
of
the
OA
operating
quarter
in
which
it
is
due;or
(2)
A
required 3-load
flow
RATA
has
not
been
performed
by
the
end
of
the
calendar
quarter
in
which
it
is
due.
f)
The
grace
period
will
begin with
the
first
unit
(or
stack)
operating
hour
following
the
calendar
quarter
in
which the
required
RATA
was
due.
Data
validation
during
a
RATA
grace
period
must
be
done
in
accordance
with
the
applicable
provisions
in Section
2.3.2
of
this
Exhibit.
(c)
If,
at
the
end
of
the
720
unit
(or
stack)
operating
hour
grace
period,
the
RATA
has
not
been
completed,
data
from
the
monitoring
system
will
be
invalid,
beginning
with
the
first
unit
operating
hour following the
expiration
of
the
grace
period.
Data
from
the
CEMS
remain
invalid
until
the
hour
65
of
completion
of a subsequent
handsoff
RATA. The
deadlinefbithe
next test will
be
either
two
OA
operating quarters
(if
a semiannual RATA
frequency
is
obtained)
or four
QA
operating
quarters
(if
an annual RATA
frequency
is
obtained)
after
the
quarter
in
which the
RATA
is
completed,
not•
to
exceed eight
calendar
quarters.
(d)
When
a
RATA
is done during
a grace
period
in order
to satisfy a RATA
requirement
from
a
previous quarter,
the
deadline
for the next
RATA
must
be
determined as follows:
(1) If the
grace period RATA
qualifies
for
a reduced,
(i.e.,
annual),
RATA
frequency
the
deadline
for
the
next RATA will be
set at three
OA
operating
quarters
after the
quarter in
which
the
grace
period test
is completed.
(2) If the
grace period RATA
qualifies
for
the
standard,
(i.e.,
semiannual),
RATA
frequency
the
deadline for the
next RATA will
be set at two
QA
operating
quarters
after
the quarter
in
which
the
grace period
test is completed.
(3)
Notwithstanding
these
requirements, no
more than
eight
successive
calendar
quarters
must
elapse
after
the quarter in which
the grace period
test
is completed,
without a
subsequent
RATA
having
been
conducted.
2.4 Recertification,
quality Assurance,
and
RATA Frequency
(Special
Considerations)
(a)
When a
significant change is
made to a
monitoring
system
such
that
recertification
of the
monitoring
system is required
in
accordance
with
Section
1.4(b)of
this
Appendix,
a
recertification
test
(or tests)
must be performed
to
ensure
that the
CEMS continues to
generate
valid
data.
In
all
recertifications,
a RATA
will
be one
of the required tests;
for some
recertifications,
other
tests
will
also be required.
A
recertification test
may
be used
to
satisfy
the
quality assurance
test
requirement
of this
Exhibit. For example,
if, for
a particular
change made
to a CEMS, one
of the
required
recertification tests
is a linearity check
and the linearity
check
is successful,
then,
unless
another
such recertification
event
occurs in
that
same
QA
operating
quarter,
it would
not
be
necessaryjQ
perform
an additional
linearity test
of the
CEMS in that quarter
to
meet
the quality
assurance
requirement of
Section 2.2.1 of this
Exhibit.
For this
reason.
EPA recommends
that
owners
or
operators
coordinate
component
replacements,
system upgrades,
and
other events
that
may
require
recertification,
to the extent practicable,
with the
periodic
quality
assurance
testing
required
by
this
Exhibit.
When
a quality assurance
test
is
done for
the
dual purpose
of recertification
and
routine
quality
assurance, the applicable
data validation
procedures
in Section
1 .4(b)(3) must
be
followed.
(b)
Except as provided
in Section 2.3.3
of this Exhibit,
whenever
a passing
RATA
of
a gas
monitor
is
performed,
or a passing 2-load
(or
2-level)
RATA
or apassing
3-load
(or
3-level)
RATA
of
a flow
monitor
is perfonned
(irrespective
of
whether
the
RATA
is done
to satisfy a
recertification
requirement
or to
meet the
quality assurance
requirements
of this Exhibit,
or
both),
the
RATA
frequency
(semi-annual
or
annual)
must be
established
based
upon
the
date and
time
of
completion
of
the
RATA and the relative
accuracy
percentage
obtained.
For 2-load
(or 2-level)
and
3-load
(or
3-
66
iévefl
flowRATAsusethe
highest
percentage
relative
accuracy’at
any
of
the
loads
(Or
levels)
to
determine
the
RATA
frequency.
The
results
of
a
single-load
(or
single-level)
flow
RATA
may
be
used
to
establish
the
RATA
frequency
when
the
single-load
(or
single-level)
flow
RATA
is
specifically
required
under
Section2.3..L3(b)ofthis
Exhibitor.when.
the
single-load
(orsingle-level)
RATA
is
allowed
under
Section
2.3.1.3(c)
of
this
Exhibit
for
a
unit
that
has
operated
at
one
load
level
(or
operatingr.level)for:>=85.Op.ercentofthetirne.since...theilast
annual
flow
RATA.
No
other
single-load
(or
single-level)
flow
RATA
may
be
used
to
establish
an
annual
RATA
frequency
however,
a
2-load
or
3-load
(or
a
2-level
or
3-level)
flow
RATA
maybe
performed
at
any
time
or
in
place
of
any
required
single-load
(or
single-level)
RATA,
in
order
to
establish
an
annual
RATA
frequency.
2.5
Other
Audits
Affected
units
may
be
subject
to
relative
accuracy
test
audits
at
any
time.
If
a
monitor
or
continuous
emission
monitoring
system
fails
the
relative
accuracy
test
during
the
audit,
the
monitor
or
continuous
emission
monitoring
system
will
be
considered
to
be
out-of-control
beginning
with
the
date
and
time
of
completion
of
the
audit,
and
continuing
until
a
successful
audit
test
is.
completed
following
corrective
action.
2.6
System
Integrity
Checks
for
Mercury
Monitors
For
each
mercury
concentration
monitoring
system
(except
for
a
mercury
monitor
that
does
not
have
a
converter),
perform
a
single-point
system
integrity
check
weekly,
i.e.,
at
least
once
every
168
unit
or
stack
operating
hours,
using
a
NIST-traceable
source
of
oxidized
mercury.
Perform
this
check
using
a
mid-
or
high-level
gas
concentration,
as
defined
in
Section
5.2
of
Exhibit
A
to
this
Appendix.
The
performance
specifications
in
paragraph
(3)
of
Section
3.2
of
Exhibit
A
to
this
Appendix
must
be
met,
otherwise
the
monitoring
system
is
considered
out-of-control,
from
the
hour
of
the
failed
check
until
a
subsequent
system
integrity
check
is
passed.
If
a
required
system
integrity
check
is
not
performed
and
passed
within
168
unit
or
stack
operating
hours
of
last
successful
check,
the
njjpg
system
will
also
be
considered
out
of
control,
beginning
with
the
169th
unit
or
stack
erating
hour
ar
the
last
successful
checknd
continu
...
ntil
a
subsequent
syciptt
check
is
passed
i
ic
r’
1
-
ifl-’ti
2.1.1
of
this
Exhibit
are
performed
using
a
NIST-traceable
source
of
oxidized
mercury.
[Note:
The
following
TABLE/FORM
is
too
wide
to
be
displayed
on
one
screen.
You
must
print
it
for
a
meaningful
review
of
its
contents.
The
table
has
been
divided
into
multiple
pieces
with
each
piece
containing
information
to
help
you
assemble
a
printout
ofthe-tábThè
Theinformation
for
each
piece
includes:
(1)
a
three
line
message
preceding
the
tabular
data
showing
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line
4*
and
character
4*
the
position
of
the
upper
left-hand
corner
of
the
piece
and
the
position
of
the
piece
within
the
entire
table;
and
(2)
a
numeric
scale
following
the
tabular
data
displaying
the
character
positions.]
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Exhibit
C to Appendix
B--Conversion
Procedures
1.
Applicability
Use the
procedures
in
this
Exhibit to
convert measured
data
from
a
monitor
or
continuous
emission
monitoring
system
into
the
appropriate
units of
the standard.
2.
Procedures
for Heat
Input
Use the following
procedures
to compute
heat input
rate to
an
affected
unit
(in mmBtu/hr
or
mmBtu/day):
2.1
Calculate
and
record heat
input rate
to an affected
unit
on an
hourly
basis.
The
owner
or
operator
may
choose
to use the
provisions
specified
in 40 CFR
75.16(e),
incorporated
by
reference
in
Section
225.140,
in conjunction
with the
procedures
provided in
Sections
2.4
through
2.4.2
to
apportion
heat
input
among
each
unit
using
the
common stack
or common
pipe
header.
2.2
For
an affected
unit
that has
a flow monitor
(or
approved alternate
monitoring
system
under
subpart
E of 40 CFR
75,
incorporated
by
reference
in
Section 225.140,
for
measuring
volumetric
flow
rate)
and a diluent
gas
(Q
or
C0
2)
monitor,
use
the recorded
data
from
these
monitors
and
one
of the
following
equations
to
calculate
hourly heat
input rate
(in
mmBtu/hr).
2.2.1
When
measurements
of
CO
2
concentration
are
on
a wet basis,
use
the
following
equation:
HI=Q
i%CO
21
wF
100
(EciuationF-15)
Where:
HI
Hourly
heat input
rate during
unit operation,
mmBtulhr.
= Hourly
average volumetric
flow
rate during
unit
operation,
wet
basis,
scth.
= Carbon-based
F-factor,
listed in
Section 3.3.5
of Appendix
F to
40
CFR 75
for
each
fuel,
scf/mmBtu.
72
%CO
21
Hourly
concentration
of
CO
2
during
unit
operation,
percent
CO
2
wet
basis.
2.2.2
When
measurements
of
CO
2
concentration
are
on
a
dry
basis,
use
the
following
equation:
HI
=
QhF
(100
%H
2
0)lIhCO
2d
(Equation
F-16)
L
10OF
]
100
,)
Where:
HI
=
Hourly
heat
input
rate
during
unit
operation,
mmBtu/hr.
=
Hourly
average
volumetric
flow
rate
during
unit
operation,
wet
basis,
scth.
]
Carbon-based
F-Factor,
listed
in
Section
3.3.5
of
Appendix
F
to
40
CFR
75
for
each
fuel,
scf/mmBtu.
%CO
2d
Hourly
concentration
of
CO
1
during
unit
operation,
percent
CO
2
dry
basis.
%H
2
0
=
Moisture
content
of
gas
in
the
stack,
percent.
2.2.3
When measurements
of
0,
concentration
are
on
a wet
basis,
use
the
following
equation:
HI
Q
[(2o.9/looXloo
—
%H
2
0)—
%02W1
W
(Equation
F-17)
F
20.9
Where:
HI
=
Hourly
heat
input
rate
during
unit
operation,
mmBtulhr.
=
Hourly
average
volumetric
flow
rate
during
unit
operation,
wet
basis,
scth.
73
F
= Dry
basis
F-factor,
listed in Section
3.3.5
of
Appendix
F to 40 CFR
75 for
each
fuel,
dscf7mmBtu.
%02W
= Hourly concentration
of
02
during
unit operation, percent
0,
wet
basis.
%H
20
Hourly
average
stack moisture content,
percent
by
volume.
For any operating hour where Equation F-17
results in an hourly heat input rate
that
is
<= 0.0
mmBtu/hr, 1.0 mmBtulhr
must
be recorded and
reported
as the heat
input
rate for that
hour.
2.2.4
When measurements of
0,
concentration
are on a dry basis, use the following equation:
HI
= Q
f(ioo — %H
2
0)j(20.9
— °2d
W[
(Equation F-i
8)
iOOF
JL
20.9.
J
Where:
HI
= Hourly heat input rate during unit operation, mmBtu!hr.
Q
= Hourly
average volumetric flow during
unit operation, wet basis, scfh.
F = Dry basis F-factor, listed in Section 3.3.5 of Appendix F to 40
CFR 75 for
each
fuel,
dscf/mmBtu.
%H
20
Moisture content of the stack gas, percent.
%°2d
= Hourly concentration of
0,
during unit operation, percent
02
dry basis.
2.3
Heat
Input Summation (for Heat Input Determined Using a Flow
Monitor and Diluent
Monitor)
2.3.1
Calculate
total
quarterly heat
input
for a unit or common stack
using a flow monitor
and
diluent
monitor
to calculate heat input,
using
the following equation:
74
HIq
=
HI
1
t
1
(Equation
F-18a)
hour=1
Where:
HIg
=
Total
heat
input
for
the
quarter,
mmBtu.
HI,
=
Hourly
heat
input
rate
during
unit
operation,
using
Equation
F-iS,
F-16,
F-17,
or
F-18,
mmBtu/hr.
=
Hourly
operating
time
for
the
unit
or
common
stack,
hour
or
fraction
of
an
hour
(in
eq
increments
that
can
range
from
one
hundredth
to
one
quarter
of
an
hour,
at
the
option
of
the
owner
or
operator’).
2.3.2
Calculate
total cumulative
heat
input
for
a
unit
or
common
stack
using
a
flow
monitor
and
diluent
monitor
to
calculate
heat input,
using the
following
equation:
the
—
current
quarter
HIc
=
HIq
(Equation
F-i
8b
-
q1
Where:
Hic
=
Total
heat
input
for
the
year
to
date,
mmBtu.
HIq
=
Total
heat input
for
the
quarter,
mmBtu.
2.4
Heat
Input
Rate Apportionment
for
Units
Sharing
a
Common
Stack
or
Pipe
2.4.1
Where
applicable,
the
owner
or
operator
of
an
affected
unit
that determines
heat
input
rate
at
the
unit
level
by
apportioning
the
heat input
monitored
at
a
common
stack
or
common
pipe using
megawatts
must apportion
the
heat
input
rate
using the
following
equation:
75
HI
=
HIcs[cI
Mt
1
(Equation
F21a)
Where:
HJ
= Heat input
rate for a unit, mmBtulhr.
HI
= Heat
input rate at the
common stack
or
pipe,
mmBtu/hr.
= Gross electrical
output,
MWe.
= Unit operating
time,
hour or
fraction
of an
hour
(in
equal
increments
that can
range
from
one
hundredth to one
quarter of an hour,
at the
option
of
the
owner or
operator).
Common
stack or common pipe
operating
time, hour
or fraction of an
hour
(in
equal
increments
that can range
from one
hundredth to one
quarter of an hour,
at the
option
of the
owner
or
operator).
n = Total
number of units using
the common
stack or pipe.
i
=Designation of a
particular
unit.
2.4.2
Where
applicable, the
owner
or
operator
of an
affected
unit that
determines the heat
input
rate
at
the
unit
level by apportioning
the heat input
rate
monitored
at a common
stack
or common
pipe
using
steam load must
apportion
the heat
input rate
using
the following
equation:
HI
1 =
(EquationF-21b)
ti
SFt
1
Where:
HI
1 = Heat
input
rate for a
unit, mmBtu/hr.
76
HI
3
Heat
input
rate
at
the
common
stack
or
pipe,
mmBtu/hr.
SF
Gross
steam
load,
lb/hr.
or mmBtulhr.
=
Unit
operating
time,
hour
or
fraction
of
an
hour
(in
equal
increments
that
can
range
from
one
hundredth
to
one
quarter
of
an
hour,
at
the
option
of
the
owner
or
operator).
=
Conirnon
stack
or
common
pipe
operating
time,
hour
or
fraction of
an
hour
(in
equal
increments
that
can
range
from
one
hundredth
to
one
quarter
of
an hour,
at the
option
of
the
owner
or
operator).
n
Total
number
of
units
using
the common
stack
or
pipe.
i
=
Designation
of
a particular
unit.
2.5
Heat
Input
Rate
Summation
fOr
Units
with
Multiple
Stacks
or
Pipes
The
owner
or
operator
of an
affected
unit
that
determines
the
heat
input
rate
at the
unit
level
by
summing
the
heat
input
rates
monitored
at multiple
stacks
or
multiple
pipes
must
sum
the
heat
input
rates
using
the
following
equation:
—
HIt
—
(Equation
F-2
1
c)
tUnit
Where:
HI,
111
=
Heat
input
rate
for
a
unit,
mmBtuJhr.
HI
3
=
Heat
input
rate
for
the
individual
stack,
duct,
or pipe,
mmBtu!hr.
=
Unit
operating time,
hour
or
fraction
of
the
hour
(in
equal
increments that
can
range
from
one
hundredth to
one
quarter
of
an
hour,
at
the
option
of
the
owner
or
operator).
=
Operating time
for
the
individual
stack
or
pipe,
hour
or
fraction
of
the
hour
(in
equal
increments
that
can
range
from
one
hundredth
to one
quarter
of
an
hour,
at
the
option
of
the
owner
or
operator).
s
=
Designation for
a
particular
stack,
duct,
or
pipe.
77
3.
Procedure
for
Converting
Volumetric
Flow
to
STP
Use
the
following
equation
to
convert
volumetric
flow
at
actual
temperature
and
pressure
to
standard
temperature and
pressure.
= FActual
(TSfd
ITStack
XStack
“1S,d)
(Equation
F-22)
Where:
=Flue
gas
volumetric
flow
rate
at
standard
temperature
and pressure,
scth.
FAct,a!
=Flue
gas
volumetric
flow
rate
at actual
temperature
and pressure,
acfh.
T
=Standard temperature=528
degreesR.
TStack
=Flue
gas
temperature
at flow
monitor
location,
degreesR,
where
degreesR=460+degreesF.
‘Stack
=The
absolute
flue
gas
pressure=barometric
pressure
at
the
flow
monitor
location
+
flue
gas
static
pressure,
inches
of
mercury.
‘std
=Standard pressure=29.
92
inches
of
mercury.
4.
Procedures
for
Mercury
Mass
Emissions.
4.1
Use
the
procedures
in this
Section
to calculate
the
hourly
mercury
mass
emissions
(in
ounces)
at
each
monitored
location, for
the
affected
unit
or
group
of units
that discharge
through
a
common
stack.
4.1.1
To
determine the hourly
mercury
mass
emissions
when
using
a
mercury
concentration
monitoring
system
that
measures
on
a wet
basis
and
a
flow
monitor,
use
the following
equation:
Mh
= KChQhth
(Equation
F-28)
78
Where:
=
Mercury
mass
emissions
for
the
hour,
rounded
off
to
three
decimal
places,
(ounces).
K
=
Units
conversion
constant,
9.978
x
10°
oz-scmljig-scf
Ch
Hourly
mercury
concentration,
wet
basis,
adjusted
for
bias
if
the
bias-test
procedures
in
Exhibit
A
to
this Appendix
show
that
a
bias-adjustment
factor
is
necessary,
(,ig!wscm).
Qh
=
Hourly
stack
gas
volumetric
flow
rate,
adjusted
for
bias,
where
the
bias-test
procedures
in
Exhibit
A
to
this
Appendix
shows
a
bias-adjustment
factor
is
necessary,
(scfh)
th
=
Unit
or
stack
operating
time,
as
defined
in
40
CFR 72.2,
(hr)
4.1.2
To
determine
the
hourly
mercury
mass
emissions
when
using
a
mercury
concentration
monitoring
system
that
measures
on
a
dry
basis
or a
sorbent
trap
monitoring
system
and
a
flow
monitor,
use
the
following
equation:
=
KChQ
I/h
(i
—
B
5
)
(Equation
F-29)
Where:
M,
1
=
mercury
mass
emissions
for
the
hour,
rounded
off
to
three
decimal
places,
(ounces).
K
=
Units
conversion
constant,
9.978
x
1
0’
oz-scmk<mu>>g-scf
Ch
=Hourly
mercury
concentration,
dry basis,
adjusted
for
bias
if
the
bias-test
procedures
in
Exhibit
A
to
this
Appei
1
dix
show
that
ias-adjustment
factor
is
necessary,
(tg/dscnznt
trap
systems,
a
single
value
L
13
lflWPrOjOr
‘
m..fl
tor
ne
data
collection
period),
is
applied
to
each
hour
in
the
data
collection
period,
for
a
particular
pair
of
traps.
Qh
=
Hourly
stack
gas volumetric
flow
rate,
adjusted
for
bias,
where
the bias-test
procedures
in
Exhibit
A
to
this
Appendix
shows
a
bias-adjustment
factor
is
necessary,
(seth)
Moisture
fraction
of
the
stack
gas,
expressed
as
a
decimal
(equal
to
%H
2
0
jQQ
79
th
Uiiitor
stack
operatingtirne,
asdefined
in 4c’CFW72.2,
(h)
4.1.3
For
units
that
are demonstrated
under
Section
1.15(d)
of this
Appendix
to emit
less
than
464
ounces
of
mercury
per
year,
and
for
which
the
owner
or
operator
elects
not
to
continuously
monitor
the
mercury
concentration,
calculate
the
hourly
mercury
mass
emissions
using
Equation
F-28
in
Section
4.1.1
of
this
Exhibit,
except
that
“Ch
“
will
be the
applicable
default
mercury
concentration
from
or (e)
of
this
Appendix,
expressed
in
jig/scm.
Correction
for
the
stack
gas
moisture
content
is not
required
when
this
methodology
is
used.
4.2
Use
the
following
equation
to
calculate
quarterly
and
year-to-date
mercury
mass
emissions
in
ounces:
Mtime
period
=
(Equation
F-30)
h=1
Where:
time
— period
=
Mercury
mass
emissions
for
the
given
time
period
i.e.,
quarter
or
year-to-date,
rounded
to
the
nearest
thousandth,
(ounces).
M,
Mercury
mass
emissions
for
the hour,
rounded
to
three
decimal
places,
(ounces).
n
= The
number
of
hours
in
the
given
time
period
(quarter
or year-to-date).
4.3
If
heat
input
rate
monitoring
is required,
follow
the
applicable
procedures
for
1t
apnortio1i’ 9idS1’’rnatiOn
in
Sections
2.3.
2.4
and
2.5
of
this
Fviibit
5.
Moisture
Determination
From
Wet
and
Dry
Q2
Readings
If a
correction for
the stack
gas
moisture
content
is
required
in
any
of
the emissions
or
heat
input
calculations
described
in
this
Exhibit,
and
if the
hourly
moisture
content
is determined
from
wet-
and
4y-basis
O
readings,
use
Equation
F-3
1 to
calculate
the
percent
moisture,
unless
a
“K”
factor
or
other
mathematical
algorithm is
developed
as
described
in Section
6.5.6(a)
of
Exhibit
A
to
this
ppendix:
80
%H
20
(02d_02w)XloO
(Equation
F-31)
Where:
%H
2
0=
Hourly
average
stack
gas moisture
content,
percent
H
20
°2d
=
Dry-basis
hourly
average
oxygen
concentration,
percent
02
°2w
=
Wet-basis
hourly
average
oxygen
concentration,
percent
02
Exhibit
D
to
Appendix
B--Quality
Assurance
and
Operating
Procedures
for
Sorbent
Trap
Monitoring
Systems
1.0
Scope
and
Application
This Exhibit
specifies
sampling,
and
analytical,
and
quality-assurance
criteria
and
procedures
for
the
performance-based
monitoring
of
vapor-phase
mercury
(Hg)
emissions
in
combustion
flueg
streams,
using
a
sorbent
trap
monitoring
system
(as
defined
in
Section
225.130).
The
principle
employed
is
continuous
sampling
using
in-stack
sorbent
media
coupled
with
analysis
of
the
integrated
samples.
The
performance-based
approach
of
this
Exhibit
allows
for
use
of
various
suitable
sampling
and
analytical
technologies
while
maintaining
a
specified
and
documented
level
of
data quality
through
performance
criteria.
Persons
using
this
Exhibit
should
have
a
thorough
working
knowledge
of
Methods
1,
2,
3,
4
and
5
in
appendices
A-i through
A-3
to
40
CFR
60,
incorporated
by
reference
in
Section
225.140,
as
well
as
the
determinative
technique
selected
for
analysis.
1.1
Analytes.
The
analyte
measured
by
these
procedures
and
specifications
is
total
vapor-phase
mercury
in
the
flue
gas,
which
represents
the
sum
of
elemental
mercury
(Hg°,
CAS
Number
7439-97-6)
and
oxidized
forms
of
mercury,
in
mass
concentration
units
of micrograms
per
dry
standard
cubic
meter
(ig/dscm).
1.2
Applicability.
81
These performance criteria and procedures
are applicable to monitoring
of vapor-phase
mercury
emissions under relatively low-dust
ôonditions
(i.e.,
sampling in
the stack after all
pollution
control
devices),
from coal-fired
electric- utility steam generators-whiclv are
subject to Sections
1.14
through
1.18 of Appendix B. Individual sample collection times can range
from 30 minutes
to several
days in
duration,
depending
on. themercury- concentration in-the
stack-The-monitoring-system
must
achieve
the
performance
criteria
specified
in Section
8
of this Exhibit
and the sorbent media
capture
ability
must
not
be
exceeded.
The
sampling
rate must be maintained at
a constant proportion
to
the
total
stack flow rate to ensure representativeness
of the sample collected.
Failure to achieve
certain
performance criteria
will
result in invalid mercury emissions
monitoring data.
2.0 Principle.
Known volumes
of
flue gas are extracted
from a stack or duct through
paired,
in-stack,
pre-spiked
sorbent media traps at an appropriate nominal flow rate.
Collection of mercury on the
sorbent
media
in the
stack
mitigates potential loss
of mercury during transport through
a probe/sample
line.
Paired
train
sampling is required to determine measurement
precision
and verify
acceptability
of
the
measured emissions data.
The
sorbent
traps
are recovered
from the sampling system, prepared
for analysis, as
needed,
and
analyzed by any
suitable determinative
techniciue
that can meet the
performance
criteria.
A
section
of each
sorbent trap
is
spiked
with
Hg° prior to
sampling. This section is analyzed
separately
and
the
recovery
value is used to correct the individual mercury
sample
for measurement
bias.
3.0 Clean Handling and Contamination.
To
avoid mercury
contamination
of
the
samples, special attention
should be paid to
cleanliness
during transport,
field
handling, sampling,
recovery, and laboratory analysis,
as well
as
during
preparation of
the sorbent cartridges. Collection and analysis
of blank
samples (field,
trip,
lab)
is
useful
in verifying the absence of contaminant mercury.
-
4.0 Safety.
-
-
4.1 Site hazards.
Site
hazards
must be thoroughly considered in advance
of applying these procedures/specifications
in
the field;
advance coordination with the site is critical
to understand the
conditions
and
applicable
safety
policies.
At a minimum, portions of the sampling
system will
be hot, requiring
appropriate
gloves, long
sleeves, and caution in
handling
this equipment.
4.2
Laboratory safety policies.
Laboratory
safety
policies should be in place to minimize
risk
of chemical
exposure and
to
properly
82
handle
waste
disposal.
Personne1must
wear
appropriate
laboratory
attire
according
to
a
Chemical
Hygiene
Plan
established
by
the
laboratory.
4.3
Toxicity
orcarcinogenicity;
The
toxicity
or
carcinogenicity
of
anyreagents
used
must
be
considered.
Depending
upon
the
sampling
and
analytical
technologies
selected,
this
measurement
may
involve
hazardous
materials,
operations,
and
equipment
and
this
Exhibit
does
not
address
all
of
the
safety
problems
associated
with
implementing
this
approach.
It
is
the
responsibility
of
the
user
to
establish
appropriate
safety
health
practices
and
determine
the
applicable
regulatory
limitations
prior
to
performance.
Any
chemical
should
be
regarded
as
a potential
health
hazard
and
exposure
to
these
compounds
should
be
minimized.
Chemists
should
refer
to
the
Material
Safety
Data
Sheet
(MSDS)
for
each
chemical
used.
4.4
Wastes.
Any
wastes generated
by
this
procedure
must
be
disposed
of
according
to
a hazardous
materials
management
plan
that
details
and
tracks
various
waste
streams
and
disposal
procedures.
5.0
Equipment
and
Supplies.
The
following
list
is
presented
as
an
example
of
key
equipment
and
supplies
likely
required
to
perform
vapor-phase
mercury
monitoring
using
a sorbent
trap
monitoring
system.
It
is
recognized
that
additional
equipment
and
supplies
may
be
needed.
Collection
of
paired
samples
is
required.
Also
required
are
a
certified
stack
gas
volumetric
flow
monitor
that meets
the
requirements
of
Section
1.2
to
this
Appendix
and
an
acceptable
means
of
correcting
for
the
stack
gas
moisture
content,
i.e.,
either
by
using
data
from
a
certified
continuous
moisture
monitoring
system
or
by
using
an
approved
default
moisture
value
(see
40
CFR
75.11(b),
incorporated
by
reference
in
Section
225.140).
5.1
Sorbent
Trap
Monitoring
System.
A
typical
sorb
ent
trap
monitoring
system
is
shown
in
Figure
K-i.
The
monitoring
system
must
include the
following
components:
5.1.1
Sorbent
Traps.
The sorbent media
used
to
collect
mercury
must
be
configured
in
a
trap
with
three
distinct
and
identical
segments
or
sections,
connected
in
series,
that
are
amenable
to separate
analyses.
Section
1.
is
designated
for
primary
capture
of
gaseous
mercury.
Section
2
is
designated
as
a backup
section
for
determination
of
vapor-phase
mercury
breakthrough.
Section
3 is
designated
for
QA/OC
purposes
where
this
section
must
be
spiked
with
a
known
amount
of
gaseous
Hg°
prior
to
sampling
and
later
analyzed
to
determine
recovery
efficiency.
The
sorbent
media
may
be
any
collection
material
(e.g.,
carbon,
chemically-treated
filter,
etc.)
capable
of
quantitatively
capturing
and
recovering
for
83
subsequent
analysis;ali
gaseousforrus
of rneruryfor the
intended application:
SeiCctioir
of
th&
sorbent
media must be
based
on the
material’s
ability to achieve the
performance
criteria
contained
in
Section
8
of this
Exhibit
as
well as the
sorbent’s vapor-phase
mercury
capture
efficiency
for
the
emissions
matrix
and the
expected sampling
durationat
the
test
site. The
sorbent
media
must
be
obtained
from a source
that can demonstrate
the
quality
assurance
and control
necessary
to
ensure
consistent
reliability.
The
paired sorbent
traps are,
suported
on
a:probe
(or
probes)
and
inserted
directly
into
the
flue
gas stream.
5.1.2 Sampling
Probe
Assembly.
Each
probe
assembly
must
have a leak-free Exhibit
to the sorbent
trap(s).
Each sorbent
trap
must
be
mounted
at the entrance of or
within the
probe such that
the gas sampled
enters the
trap
directly.
Each probe/sorbent
trap assembly
must be heated
to a temperature
sufficient
to
prevent
liquid
condensation
in the sorbent trap(s).
Auxiliary
heating is required
only where
the
stack
temperature
is
too low to prevent
condensation.
Use a calibrated
thermocouple
to monitor
the stack
temperature.
A
single probe
capable
of operating
the paired
sorbent
traps may
be used. Alternatively,
individual
probe/sorbent
trap assemblies
may be used, provided
that
the
individual
sorbent
traps
are
co-located
to ensure
representative mercury
monitoring
and are sufficiently
separated
to prevent
aerodynamic
interference.
5.1.3 Moisture
Removal
Device
A
robust
moisture
removal device
or
system, suitable
for continuous
duty
(such
as a
Pëltier
cooler),
must be used
to
remove water vapor
from the gas
stream
prior
to entering
the
gas flow
meter.
5.1.4
Vacuum Pump.
Use
a leak-tight, vacuum
pump capable
of operating
within the candidate
system’s
flow
range.
5.1.5
Gas Flow
Meter
A gas
flow
meter
(such as a dry gas meter,
thermal
mass
flow meter,
or
other
suitable
measurement
device)
must
be
used to determine
the total
sample
volume on
a dry basis, in
units of
standard
cubic
meters. The
meter must be sufficiently
accurate
to measure the
total
sample
volume
to
within
2
percent
and must be
calibrated
at selected flow
rates
across
the range
of
sample
flow
rates
at
which
the
sorbent
trap
monitoring system
typically
operates. The
gas
flow
meter must
be
equipped
with
any necessary
auxiliary measurement
devices
(e.g.,
temperature sensors,
pressure
measurement
devices)
needed
to
correct
the sample
volume
to standard
conditions.
5.1.6
Sample
Flow
Rate
Meter
and
Controller.
Use a
flow rate indicator and
controller for maintaining
necessary
sampling
flow rates.
84
5.I.7’TeihperattireSensor:
Same
as
Section
6.1.1.7
of
Method
5
in
appendix
A-3
to
40
CFR
60,
incorporated
by
reference
in
Section
225.140:
5.1.8
Barometer;:
Same
as
Section
6.1.2
of
Method
5
in
appendix
A-3
to
40
CFR
60,
incorporated
by
reference
in
Section
225.140.
5.1.9
Data
Logger
(Optional).
Device
for
recording
associated
and
necessary
ancillary
information
(e.g.,
temperatures,
pressures,
flow,
time,
etc.).
5.2
Gaseous
Hg°
Sorbent
Trap
Spiking
System.
A
known
mass
of
gaseous
Hg°
must
be
spiked
onto
section
3
of
each
sorbent
trap
prior
to
sampling.
Any
approach
capable
of
quantitatively
delivering
known
masses
of
Hg°
onto
sorbent
traps
is
acceptable.
Several
technologies
or
devices
are
available
to
meet
this
objective.
Their
practicality
is
a
function
of
mercury
mass
spike
levels.
For
low
levels,
NIST-certified
or
NIST-traceable
gas
generators
or
tanks may
be
suitable,
but
will
likely
require
long
preparation
times
A
more
practical,
alternative
system,
capable
of
delivering
almost
any
mass
required,
makes
use
of
NIST-certjfied
or
NIST-traceable
mercury
salt
solutions
(e.g.,
Hg(N03)2).
With
this
system,
an
aliquot
of
known
volume
and
concentration
is
added
to
a
reaction
vessel
containing
a
reducing
agent
(e.g.,
stannous
chloride);
the
mercury
salt solution
is
reduced
to
Hg°
and
purged
onto
section
3
of
the
sorbent
trap
using
an
impinger
sparging
system.
5.3
Sample
Analysis
Equipment.
Any analytical
system
capable
of
quantitatively
recovering
and
quantifying
total
gaseous
mercury
from sorbent
media
is
acceptable
provided
that
the
analysis
can
meet
the
performance
criteria
in
Section
8
of
this
procedure.
Candidate
recovery
techniques
include
leaching, digestion,
and
thermal
desorption.
Candidate
anal’Vticäl
iechni4ues
include
ultraviolet
atomic
fluorecôii
ftJV
AF);
ultraviolet
atomic
absorption
(UV
AA),
with
and
without
gold
trapping;
and
in•
situ
X-ray
fluorescence
(XRF)
analysis.
6.0
Reagents
and
Standards.
Only NIST-certified
or
NIST-traceable
calibration
gas
standards
and
reagents
must
be
used
for
the
tests
and
procedures
required
under
this
Exhibit.
7.0
Sample
Collection
and
Transport.
85
7.1 Pre-Test Procedures.
7.1.1 Selection of SampiingSite.
Sampling siteinformation shouldbe
obtaiiiediaaccordancevwithMethod
1
in
appendix
A-i
to
40
CFR
60, incorporated by reference
in Section 225.140.
Identify
a monitoring location
representative
of source mercury emissions. Locations shown to be free of stratification through
measurement
traverses
for gases such as
SO
and
NO
may be one such approach. An estimation
of the
expected
stack
mercury
concentration jçqired to establish a target sample flow
rate, total
gas
sample
volume, and the mass of Hg° to be spiked onto section 3 of each sorbent trap.
7.1.2
Pre-sampling Spiking of Sorbent Traps.
Based on the estimated mercury
concentration
in
the
stack,
the target
sample rate and
the
target
sampling duration,
calculate the expected mass loading for section 1 of each sorbent
trap
(for
an
example calculation, see Section 11.1 of this Exhibit). The pre-sampling spike to be
added to
section
3
of each sorbent trap must be
within
+-
50
percent
of the
expected
section
1 mass loading.
Spike
section
3
of each sorbent
trap
at this level, as described
in
Section 5.2 of
this Exhibit.
For
each
sorbent trap, keep an
official record of the mass of Hg° added to section 3. This
record must
include,
at a minimum, the
ID number of the trap, the date and time of the spike, the name
of the
analyst
performing
the
procedure, the mass of Hg° added to section. 3 of the trap (rig), and the
supporting
calculations. This record must be maintained in a format suitable for inspection and audit
and
must
be made
available to the regulatory
agencies
upon
request.
7.1.3 Pre-test Leak Check
Perform a leak check
with the sorbent traps in place. Draw a vacuum in each sample train.
Adjust
the
vacuum in the
sample
train to
mercury. Using
the gas flow meter, determine leak rate.
The
leakage
rate
must
not exceed 4
percent of the target sampling rate. Once the leak check
passes this
criterion,
carefully release the
vacuum in the
sample
train then
seal the sorbent trap inlet
until the
probe
is
ready for
insertion
into the stack
or duct.
7.1.4 Determination of Flue Gas Characteristics.
Determine or
measure the
flue gas
measurement environment
characteristics
(gas
temperature,
static
pressure, gas
velocity, stack
moisture,
etc.)
in
order
to determine ancillary
requirements
such
as
probe
heating
requirements
(if
any),
initial sample
rate, proportional sampling conditions,
moisture
management, etc.
7.2 Sample Collection.
7.2.1
86
Remove
the
plug
from
the
end
of
each
sorbent
trap
and
store
each
plug
in
a
clean
sorbent
trap
storage
container.
Remove
the
stack
or
duct
port
cap
and
insert
the
probe(s).
Secure
the
probe(s)
and
ensure
that
no
leakage
occurs
between
the
duct
and
environment..
7.2.2
Record
initial
data including
the
sorbent
trap
ID,
start
time,
starting
dry
gas
meter
readings,
initial
temperatures,
set-points,
and
any
other appropriate
information.
7.2.3
Flow
Rate
Control
Set
the
initial
sample
flow
rate
at
the
target
value
from
Section
7.1
.1
of
this
Exhibit.
Record
the
initial
gas
flow meter
reading,
stack temperature
(if
needed
to
convert
to
standard
conditions),
meter
temperatures
(if
needed),
etc.
Then,
for
every
operating
hour
during
the
sampling
period,
record
the
date
and
time,
the
sample
flow
rate, the
gas
flow
meter
reading,
the
stack
temperature
(if
needçj
the
flow
meter temperatures
(if
needed),
temperatures
of
heated
equipment
such
as
the
vacuum
lines.
and the
probes
(if
heated),
and
the
sampling
system
vacuum
readings.
Also, record
the
stack
gas
flow
rate,
as
measured
by
the
certified
flow
monitor,
and
the
ratio
of
the
stack
gas
flow
rate
to
the
sample
flow
rate.
Adjust
the
sampling
flow
rate
to
maintain
proportional
sampling,
i.e.,
keep
the
ratio
of
the
stack
gas
flow
rate
to
sample
flow
rate
constant,
to
within
+-25
percent
of
the
reference
ratio
from. the
first•.
hour of
the
data
collection
period
(see
Section
11
of
this
Exhibit).
The
sample
flow
rate
through
a
sorbent
trap
monitoring
system
during
any
hour
(or
portion
of
an
hour) in
which
the
unit
is
not
operating
must
be
zero.
7.2.4
Stack
Gas
Moisture
Determination
Determine
stack
gas moisture
using
a
continuous
moisture
monitoring
system,
as
described
in
40
CFR
75.11(b).
incorporated
by
reference
in
Section
225.140.
Alternatively,
the
owner
or
operator
may
use
the
appropriate
fuel-specific
moisture
default
value
provided
in
40
CFR 75.11,
incorporated
by
reference
in
Section
225.140,
or
a
site-specific
moisture
default
value
approved
by
the
Agency.
7.2.5 Essential
Operating
Data
Obtain
and
record
any
essential
operating
data
for
the
facility
during
the
test
period,
e.g.,
the
barometric
pressure
for correcting
the
sample
volume
measured
by
a
dry
gas
meter
to
standard
conditions.
At
the
end
of
the
data
collection
period,
record
the
final
gas
flow
meter
reading
and
the
final values
of
all
other
essential
parameters.
7.2.6
Post
Test Leak
Check.
When sampling
is
completed,
turn
off
the
sample
pump,
remove
the
probe/sorbent
trap
from
the
nort
and carefully
re-plug
the
end
of
each
sorbent
trap.
Perform
a
leak
check
with
the
sorbent
traps
in
87
place,
atthemaximurn
vacuumreachedduring
the’sampiiiig•’period.
Useth’e same
genera1äpproach
described
in
Section
7.1.3
of this
Exhibit.
Record the
leakage rate
and
vacuum.
The
leakage
rate
must not
exceed 4
percent
of the
average
sampling rate
for
the
data collection
period.
Following
the
leak check,
carefully
release
the
vacuum
in
the
sample
train
7.17
Sample
Recovery.
Recover
each
sampled
sorbent
trap
by
removing
it
from the
probe, sealing
both
ends.
Wipe
any
deposited
material
from
the
outside
of
the sorbent
trap. Place
the sorbent
trap
into
an
appropriate
sample
storage
container
and store/preserve
in
appropriate
manner.
7.2.8
Sample
Preservation,
Storage,
and
Transport.
While
the
performance
criteria
of this
approach
provide
for
verification
of
appropriate
sample
handling,
it is still
important
that
the
user
consider,
determine,
and
plan for
suitable
sample
preservation,
storage,
transport,
and holding
times for
these measurements.
Therefore,
procedures
in
ASTM
D691 1-03
“Standard
Guide
for
Packaging
and
Shipping Environmental
Samples
for
Laboratory
Analysis”
(incorporated
by
reference
under
Section
225.140)
must
be
followed
for all
samples.
7.2.9 Sample
Custody.
Proper
procedures
and
documentation
for
sample
chain
of custody
are
critical
to
ensuring
data
integrity.
The chain
of custody
procedures
in ASTM
D4840-99
(reapproved
2004) “Standard
Guide
for
Sample
Chain-of-Custody
Procedures”
(incorporated
by
reference
under Section
225.140)
must
be
followed for
all
samples (including
field
samples
and
blanks).
8.0
Quality
Assurance
and
Quality
Control.
Table K-i
summarizes
the
OAJQC
performance
criteria
that
are used
to validate
the
mercury
emissions
data
from
sorbent
trap
monitoring
systems,
including
the
relative
accuracy
test
audit
(RATA)
requirement
(see
Section
1
.4(c)(7),
Section 6.5.6
of Exhibit
A
to
this
Appendix,
and
Section
2.3
of Exhibit
B to
this
Appendix).
Except
as
provided
in
Section
1.3(h)
of this
Appendix
and
as
otherwise
indicated
in Table
K-i, failure
to achieve
these
performance
criteria
will
result
in
invalidation
of
mercury
emissions
data.
Table
K-l.--Quality
Assurance/Quality
Control
Criteria
for
Sorbent Trap
Monitoring
Systems
QA/QC
test
or
Acceptance
criteria
Frequency
Consequences
if
specification
not
met
Pre-test
leak
check
<=4% of
target
sampling
rate
Prior
to
88
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sorbent1rap
monitorihg
s
ystem
typicalfr
operates.
Ybtrrnay
either
follow
theprocedures
in
SectiOn
10.3.1
of
Method
5 in
appendix
A-3
to 40
CFR
60,
incorporated
by
reference
in
Section
225.140,
or
the
procedures
in Section
16
of Method
5 in
appendix
A-3 to
40
CFR
60.
If
a
dry
gas
meter
is
being
calibrated,:use
at
least
five
revolutions
of
themeter
ateachfiow
rate.
9.2.2.2
Alternative
Initial
Calibration.
Procedures.
Alternatively,
you
may
perform
the
initial
calibration
of
the
gas
flow
meter
using
a
reference
gas
flow meter
(RGFM).
The RGFM
may
either
be:
(1)
A wet
test meter
calibrated
according
to
Section
10.3.1
of Method
5 in
appendix
A-3
to 40
CFR
60,
incorporated
by
reference
in
Section
225. 140
(2)
a gas
flow metering
device
calibrated
at
multiple
flow rates
using
the procedures
in Section
16 of Metho4
5 in appendix
A-3 to
40
CFR
60:
or
(3)
a
NIST-traceable
calibration
device
capable
of
measuring
volumetric
flow
to an
accuracy
of
1
percent.
To calibrate
the
gas flow
meter
using
the
RGFM,
proceed
as
follows:
While
the
sorbent
trap
monitoring
system
is sampling
the actual
stack
gas
or a compressed
gas
mixture
that
simulates
the
stack
gas
composition
(as
applicable),
connect
the
RGFM
to
the discharge
of the
system.
Care
should
be taken
to
minimize
the
dead
volume
between
the
sample
flow
meter
being
tested
and
the
RGFM.
Concurrently
measure
dry
gas
volume
with
the RGFM
and
the
flow
meter
being
calibrated
the for
a minimum
of 10
minutes
at
each
of three
flow
rates covering
the typical
range
of
operation
of the
sorbent
trap
monitoring
system.
For
each 10-minute
(or
longer)
data
collection
period,
record
the
total sample
volume,
in
units of
dry
standard
cubic
meters
(dscm),
measured
by the
RGFM
and
the
.gas
flow
meter
being tested.
9.2.2.3
Initial
Calibration
Factor.
Calculate
an
individual
calibration
factor
Yi
at
each
tested
flow
rate
from
Section
9.2.2.1
or
9.2.2:2
of
this Exhibit
(as
applicable),
by
taking
the ratio
of the
reference
sample
volume
to
the
sample
volume
recorded
by the
gas flow
meter.
Average
the three
Yi
values,
to
determine
Y,
the
calibration
factor
for the
flow
meter.
Each
of
the three
individual
values
of
Yi
must
be
within
+-0.02
of
Y.
Except
as
otherwise
provided
in
Sections
9.2.2.4
and
9.2.2.5
of this
Exhibit,
use
the
average
Y
value
from
the three
level
calibration
to adjust
all
subsequent
gas
volume
measurements made
with
the gas
flow
meter.
9.2.2.4
Initial
On-Site
Calibration
Check.
For
a
mass
flow
meter
that
was
initially
calibrated
using
a
compressed
gas
mixture,
an
on-site
calibration
check
must
be
performed
before
using
the
flow
meter
to
provide
data
for
this
part.
While
sampling
stack
gas, check
the
calibration
of the flow
meter
at
one
intermediate flow
rate
typical
of
normal
operation
of
the monitoring
system.
Follow
the
basic
procedures
in
Section
9.2.2.1
or
9.2.2.2
of
this Exhibit.
If the
on-site
calibration
check
shows
that
the
value
of
Yi, the
calibration
factor
at the
tested
flow
rate, differs
by
more
than
5 percent
from
the
value
of
Y obtained
in
the initial
calibration
of the
meter,
repeat
the full
3-level
calibration
of the
meter
using
stack
gas to
determine
a new
value
of
Y,
and
apply
the
new
Y value
to
all
subsequent
93
gasvohimemeastreneitsmadewith
9.2.2.5
Ongoing Quality
Assurance.
Recalibrate the
gas
flow
meter quarterly at one
intermediate
flow
rate
setting
representative
of normaLoperationofthemonitoring
system. Follow the
basic
procedures
in
Section
9.2.2.1 or 9.2.2.2
of this Exhibit. If a quarterly
recalibration shows that the
value
of
Yi,
the
calibration factor at
the tested
flow
rate,
differs from
the
current
value of Y by more
than
5
percent,
repeat
the
full
3-level calibration
of the meter to determine
a
new value
of Y, and apply
the
new
Y
value to all subsequent gas volume measurements
made with the gas flow meter.
9.3
Thermocouples
and Other
Temperature Sensors.
Use the procedures and
criteria
in Section 10.3
of Method 2 in appendix A-i
to 40
CFR
60,
incorporated
by
reference in Section 225.140,
to calibrate in-stack temperature
sensors
and
thermocouples. Dial thermometers must be calibrated
against
mercury-in-glass
thermometers.
Calibrations must
be performed
prior
to initial use and at least
quarterly thereafter.
At
each
calibration
point,
the absolute
temperature
measured
by the temperature sensor
must
agree
to
within
+-
1.5 percent of the temperature measured with the
reference sensor, otherwise the
sensor
may
not
continue
to be used.
9.4 Barometer.
Calibrate against
a mercury barometer.
Calibration must be performed
prior to initial use
and
at
least
quarterly
thereafter. At each calibration
point,
the absolute pressure measured
by
the
barometer
must
agree to
within
+-
10 mm mercury of the
pressure measured by the mercury
barometer,
otherwise
the
barometer may not continue to be used
9.5 Other Sensors and Gauges.
Calibrate
all other
sensors and
gauges according
to the
procedures
specified
by the
instrument
manufacturer(s).
9.6 Analytical
System
Calibration.
See
Section 10.1 of
this Exhibit.
10.0 Analytical Procedures.
The
analysis of the
mercury samples
may
be conducted using
any instrument or
technology
capable
of
quantifying total
mercury from the
sorbent media and meeting
the
performance
criteria
in
Section
8 of
this Exhibit.
94
10.1
Anai’yzer
System
C’alibration’
Perform
a
multipoint
calibration
of
the
analyzer
at
three
or
more•
upscale
points
over
the
desired
quantitative
range
(multiple
calibration
ranges:mustbe
calibrated,
if
necessary).
The
field
samples
analyzed
must
fall
within
a
calibrated,
quantitative
range
and
meet
the
necessary
performance
criteria;:For
samples
that
aresuitable
for
aliquotting,’.a
series
of
dilutions
may
be
needed
to
ensure
that
the samples
fall
within
a
calibrated
range.
However,
for
sorbent
media
samples
that
are
consumed
during
analysis
(e.g.,
thermal
desorption
techniques),
extra
care
must
be
taken
to
ensure
that the
analytical
system
is
appropriately
calibrated
prior
to
sample
analysis.
The
calibration
curve
range(s)
should
be
determined
based
on
the
anticipated
level
of
mercury
mass
on
the
sorbent
media.
Knowledge
of
estimated
stack
mercury
concentrations
and
total
sample
volume
may
be
required
prior
to
analysis.
The
calibration
curve
for use
with
the
various
analytical
techniques
(e.g.,
UV
AA,
UV AF,
and
XRF)
can
be
generated
by
directly
introducing
standard
solutions
into
the
analyzer
or
by
spiking
the
standards
onto
the
sorbent
media
and
then
introducing
into
the
analyzer
after
preparing
the sorbent/standard
according
to
the
particular
analytical
technique.
For
each
calibration
curve,
the
value
ofthe
square
of
the
linear
correlation
coefficient,
i.e..
r
2
,
must
be
>=
0.99,
and
the
analyzer
response
must
be
within
+-
10
percent
of
reference
value
at
each
upscale
calibration,
point.
Calibrations
must
be
performed
on
the
day
of
the
analysis,
before
analyzing
any
of
the
samples.
Following
calibration,
an
independently
prepared
standard
(not
from
same
calibration
stock
solution)
must
be
analyzed.
The
measured
value
of
the
independently
prepared
standard
must
be
within
+-
10
percent
of
the
expected
value.
10.2
Sample
Preparation.
Carefully
separate
the
three
sections
of
each
sorbent
trap.
Combine
for
analysis
all
materials
associated
with each
section,
i.e.,
any
supporting
substrate
that
the
sample
gas
passes
through
prior
to
entering
a
media
section
(e.g.,
glass
wool,
polyurethane
foam,
etc.)
must
be
analyzed
with
that
segment.
10.3
Spike
Recovery
Study.
BJzr.
afl41
yzui,
n
v
field
samples,
the
laboratory
must
demonstrate
the
ability
to
recover
and
quantify
mercury
from
the
sorbe1L.
diy
performing
the
following
spike
recovery
study
for
sorbent
media
traps
spiked
with
elemental
meic’:’.
Using
the
procedures
described
in
Sections
5.2
and 11.1
of
trim
bit,
spike
the
third
section
of
nine
sorbent
traps
with
gaseous
Hg°,
i.e.,
three
traps
at
each
of
thre
‘ifferent
mass
loadings,
representing
the
range
of
masses
anticipated
in
the
field
samples.
This
will
ye
1
da3
x
3
sample
matrix.
Prepare
and
analyze
the
third
section
of
each
spiked
trap,
using
the
techniques
that
will
be
used
to
prepare
and
analyze
the
field
samples.
The
average
recovery
for
each
spike
concentration
must
be
between
85
and
115
percent.
If
multiple
types
of
sorb
ent media
are
to
be
analyzed,
a
separate
spike
recovery
study
is
required
for
each
sorbent
material.
If
multiple
ranges
are
calibrated,
a
separate
spike
recovery
study
is
required
for
each
range.
95
10.4
Field
Sample
Analysis
Analyze.
the
sorbent t’sampiesfollowing’:thesarneprocedures::that
were
used:for;conducting
the
spike
recovery
study.
The three sections of each sorbent
trap must be analyzed separately
(i.e.,
section
1, then section2, then section
3)
Quantify
of
mercury
for
each
section
based
on analytical system response
arid the calibration curve from
Section
10.1
of this Exhibit.
Determine
the
spike
recovery from
sorbent trap section 3. The spike recovery
must be
no
less than
75
percent
and
no
greater than 125
percent.
To report the final mercury mass for each trap, add
together
the
mercury masses collected in trap sections 1 and 2.
11.0 Calculations
and
Data
Analysis.
11.1
Calculation of Pre-Sampling Spiking Level.
Determine
sorbent
trap section 3 spiking level using estimates
of the
stack
mercury
concentration,
the target
sample flow rate, and the
expected sample duration. First,
calculate the
expected
mercury
mass that will be collected in section
1 of
the
trap. The pre-sampling spike must
be within
+-
50
percent of this mass. Example calculation: For an estimated
stack
mercury concentration
of
5
ig/m
3,
a target sample rate of 0.30 L/min, and a sample duration of
5
days:
(0.30
L/min)
(1440 rnin1day
(5
days) (10 3
m
/liter) (5pg/m3)= 10.8 ig
A pre-sampling
spike of 10.8
.tg
+-
50percent is, therefore, appropriate.
11.2 Calculations for Flow-Proportional
Sampling.
For
the first hour of the data collection period, determine the reference
ratio of the
stack
gas
volumetric flow
rate to
the sample flow rate, as follows:
KQ
R
ref
ref
(Equation
K-i)
ef
Where:
Rrej
= Reference ratio of ho,
stack gas flow rate to hourly
sample flow rate
rcf
= Acrage stack gas volumetric
flow rate for first hour of collection
period
‘‘ref
= Average
sample
flow rate for first hour
of
the
collection period,
in appropriate
units
(e.g.,
liters/mm,
cc/mm,
dscmlmin)
96
K
=
Power
of
ten
multiplier,
to
keep
the
value
of
Rrej
between
1
and
100.
The,
appropriate
K
value
will
depend
on
the
selected
units
ofmeas.urefor
the
sample
flow-rate...
Then,
for
each
subsequent
hour
of
the
data
collection
period,
calculate
ratio of the
stack
gas
flow
rate
to
the
sample
flow
rate
using
the
equation K-2:
—
R,
=
(Equation
K-2)
Where:
1
R,
Ratio
of
hourly
stack
gas
flow
rate
to
hourly
sample
flow
rate
Average
stack
gas
volumetric
flow
rate
for
the
hour
F,
Average
sample
flow
rate
for
the
hour,
in
appropriate
units
(e.g.,
liters/mm,
cc/mm,
dscmJmjn)
K
=
Power
of
ten
multiplier,
to
keep
the
value
of
R,
1
between
1 and
100.
The
appropriate
K
value
will
depend
on
the
selected
units
of
measure
for
the
sample
flow
rate
and
the
range
of
expected
stack
gas
flow
rates.
Maintain
the
value
of
Rh
within
+-
25
percent
of
Rrei
throughout
the
data
collection
period.
11.3
Calculation
of
Spike
Recovery.
Calculate
the
percent
recovery
of
each
section
3
spike,
as
follows:
%R
=
x
100
(Equation
K-3)
—
Where:
%R=Percentage
recovery
of
the
pre-sampling
spike
=
Mass
of
mercury
recovered
from
section
3 of
the
sorbent
trap,
(pg)
97
Calculated
merctr
rnassoftliepresampiii
siik&frömSection
.7
:
2of
this Exhibit, (g
11.4
Calculation
of Breakthrough.
Calculate thepercent
breakthrough
to the secondsection
of
the sorbent trap, as follows:
Where:
%B
= Mi
x
100
(Equation
Where:
%B=
Percent breakthrough
= Mass of mercury
recovered from
section
2
of
the sorbent
trap,
(JIg)
M
1
Mass of
mercury
recovered
from
section
1 of
the sorbent
trap,
(pg)
11.5 Calculation
of Mercury
Concentration
Calculate the mercury
concentration for
each
sorbent
trap, using the following
equation:
C
(Eiuation K-5)
Where:
C
= Concentration of
mercury for the collection
period,
jigmldscm)
M*=
Total mass
of mercury recovered
from
sections
1 and 2 of the
sorbent trap,
jig)
= Total
volume of
dry
gas
metered during
the collection period,
(dscm).
For
the
purposes
of
this
Exhibit,
standard
temperature
and pressure are defined
as
20
C
and 760 mm
mercury,
respectively.
11.6 Calculation
of Paired Trap
Agreement
Calculate
the
relative
deviation
(RD)
between
the mercury
concentrations
measured
with
the
paired
sorbent
traps:
98
IC
-Cb
RD
a
><
(Equation
K6)
Ca+C&
Wbere:
RD
Relative
deviation between
the
mercury
concentrations
from
traps
“a”
and
“b”
(percent)
C
0
Concentration
of
mercury
for
the
collection
period,
for
sorbent
trap
“a” fligmldscm)
Cb
=
Concentration
of
mercury
for
the
collection
period,
for
sorbent
trap
“b”
(gmJdscm)
11.7
Calculation
of
Mercury
Mass
Emissions.
To
calculate
mercury
mass
emissions,
follow
the
procedures
in
Section
4.1.2
of
Exhibit
C
to
this
Appendix.
Use
the
average
of
the
two
mercury
concentrations
from
the
paired
tps
in
the
calculations,
except
as
provided
in
Section
2.2.3(h)
of
Exhibit
B
to
this
Appendix
or
in
Table
K-i.
12.0
Method
Performance.
These
monitoring
criteria
and
procedures
have
been
applied
to
coal-fired
utility
boilers
(including
units
with
post-combustion
emission
controls), having
vapor-phase
mercury
concentrations
ranging
from
0.03 ,igldscm
to
100
igJdscm.
99