limits
based
on
these
tests.
These
requirements
could
result
in
the
need
to
conduct
more
than
one
performance
test.

(
e)
You
may
not
conduct
performance
tests
during
periods
of
startup,
shutdown,
or
malfunction.

(
f)
You
must
conduct
three
separate
test
runs
for
each
performance
test
required
in
this
section,
as
specified
in
§
63.7(
e)(
3).
Each
test
run
must
last
at
least
1
hour.

(
g)
To
determine
compliance
with
the
emission
limits,

you
must
use
the
F­
Factor
methodology
and
equations
in
sections
12.2
and
12.3
of
EPA
Method
19
of
appendix
A
of
this
part
to
convert
the
measured
particulate
matter
concentrations,
the
measured
hydrogen
chloride
concentrations,
the
measured
total
selected
metals
concentrations,
and
the
measured
mercury
concentrations
that
result
from
the
initial
performance
test
to
pounds
per
million
Btu
heat
input
emission
rates
using
F­
factors.

§
63.7521
What
fuel
analyses
and
procedures
must
I
use?

(
a)
You
must
conduct
fuel
analyses
according
to
the
procedures
in
paragraphs
(
b)
through
(
e)
of
this
section
and
Table
6
of
this
subpart,
as
applicable.
(
b)
You
must
develop
and
submit
a
site­
specific
fuel
analysis
plan
to
the
Administrator
for
review
and
approval
according
to
the
following
procedures
and
requirements
in
paragraphs
(
b)(
1)
and
(
2)
of
this
section.

(
1)
You
must
submit
the
fuel
analysis
plan
no
later
than
180
days
before
the
date
that
you
intend
to
demonstrate
compliance.

(
2)
You
must
include
the
information
contained
in
paragraphs
(
b)(
2)(
i)
through
(
vi)
of
this
section
in
your
fuel
analysis
plan.

(
i)
The
identification
of
all
fuel
types
anticipated
to
be
burned
in
each
boiler
or
process
heater.

(
ii)
For
each
fuel
type,
the
notification
of
whether
you
or
a
fuel
supplier
will
be
conducting
the
fuel
analysis.

(
iii)
For
each
fuel
type,
a
detailed
description
of
the
sample
location
and
specific
procedures
to
be
used
for
collecting
and
preparing
the
composite
samples
if
your
procedures
are
different
from
paragraphs
(
c)
or
(
d)
of
this
section.
Samples
should
be
collected
at
a
location
that
most
accurately
represents
the
fuel
type,
where
possible,

at
a
point
prior
to
mixing
with
other
dissimilar
fuel
types.

(
iv)
For
each
fuel
type,
the
analytical
methods,
with
the
expected
minimum
detection
levels,
to
be
used
for
the
measurement
of
selected
total
metals,
chlorine,
or
mercury.

(
v)
If
you
request
to
use
an
alternative
analytical
method
other
than
those
required
by
Table
6
of
this
subpart,
you
must
also
include
a
detailed
description
of
the
methods
and
procedures
that
will
be
used.

(
vi)
If
you
will
be
using
fuel
analysis
from
a
fuel
supplier
in
lieu
of
site­
specific
sampling
and
analysis,

the
fuel
supplier
must
use
the
analytical
methods
required
by
Table
6
of
this
subpart.

(
c)
At
a
minimum,
you
must
obtain
three
composite
fuel
samples
for
each
fuel
type
according
to
the
procedures
in
paragraphs
(
c)(
1)
or
(
2)
of
this
section.

(
1)
If
sampling
from
a
belt
(
or
screw)
feeder,

collect
fuel
samples
according
to
paragraphs
(
c)(
1)(
i)
and
(
ii)
of
this
section.

(
i)
Stop
the
belt
and
withdraw
a
6­
inch
wide
sample
from
the
full
cross­
section
of
the
stopped
belt
to
obtain
a
minimum
two
pounds
of
sample.
Collect
all
the
material
(
fines
and
coarse)
in
the
full
cross­
section.
Transfer
the
sample
to
a
clean
plastic
bag.

(
ii)
Each
composite
sample
will
consist
of
a
minimum
of
three
samples
collected
at
approximately
equal
intervals
during
the
testing
period.

(
2)
If
sampling
from
a
fuel
pile
or
truck,
collect
fuel
samples
according
to
paragraphs
(
c)(
2)(
i)
through
(
iii)
of
this
section.

(
i)
For
each
composite
sample,
select
a
minimum
of
five
sampling
locations
uniformly
spaced
over
the
surface
of
the
pile.

(
ii)
At
each
sampling
site,
dig
into
the
pile
to
a
depth
of
18
inches.
Insert
a
clean
flat
square
shovel
into
the
hole
and
withdraw
a
sample,
making
sure
that
large
pieces
do
not
fall
off
during
sampling.

(
iii)
Transfer
all
samples
to
a
clean
plastic
bag
for
further
processing.

(
d)
Prepare
each
composite
sample
according
to
the
procedures
in
paragraphs
(
d)(
1)
through
(
7)
of
this
section.

(
1)
Throughly
mix
and
pour
the
entire
composite
sample
over
a
clean
plastic
sheet.

(
2)
Break
sample
pieces
larger
than
three
inches
into
smaller
sizes.

(
3)
Make
a
pie
shape
with
the
entire
composite
sample
and
subdivide
it
into
four
equal
parts.

(
4)
Separate
one
of
the
quarter
samples
as
the
first
subset.

(
5)
If
this
subset
is
too
large
for
grinding,
repeat
the
procedure
in
paragraph(
d)(
3)
of
this
section
with
the
quarter
sample
and
obtain
a
one­
quarter
subset
from
this
sample.

(
6)
Grind
the
sample
in
a
mill.

(
7)
Use
the
procedure
in
paragraph
(
d)(
3)
of
this
section
to
obtain
a
one­
quarter
sub­
sample
for
analysis.

If
the
quarter
sample
is
too
large,
subdivide
it
further
using
the
same
procedure.

(
e)
Determine
the
concentration
of
pollutants
in
the
fuel
(
mercury,
chlorine,
and/
or
total
selected
metals)
in
units
of
pounds
per
million
Btu
of
each
composite
sample
for
each
fuel
type
according
to
the
procedures
in
Table
6
of
this
subpart.

§
63.7522
Can
I
use
emission
averaging
to
comply
with
this
subpart?

(
a)
As
an
alternative
to
meeting
the
requirements
of
§
63.7500,
if
you
have
more
than
one
existing
large
solid
fuel
boiler
located
at
your
facility,
you
may
demonstrate
compliance
by
emission
averaging
according
to
the
procedures
in
this
section
in
a
State
that
does
not
choose
to
exclude
emission
averaging.

(
b)
For
purposes
of
emission
averaging,
if
you
change
after
the
effective
date
any
existing
large
solid
fuel
boiler
such
that
its
applicable
subcategory
also
changes
and
the
change
does
not
meet
the
definition
of
reconstruction
as
defined
in
subpart
A
of
this
part,
you
may
choose
to
meet
the
applicable
emission
limits
in
this
subpart
for
the
original
subcategory.

(
c)
For
purposes
of
emission
averaging,
if
you
replace
after
the
effective
date
any
existing
large
solid
fuel
boiler
with
a
new
gaseous
fuel
boiler,
and
document
that
the
existing
large
solid
fuel
boiler
is
permanently
shutdown,
you
may
choose
to
include
in
the
emission
averaging
the
new
gaseous
fuel
boiler
heat
input
up
to
the
maximum
rated
heat
input
capacity
of
the
replaced
large
solid
fuel
boiler.
The
new
gaseous
fuel
boiler
must
meet
each
emission
limit
and
work
practice
standard
in
Table
1
of
this
subpart
that
applies.
(
d)
For
each
existing
large
solid
fuel
boiler
in
the
averaging
group,
the
emission
rate
achieved
during
the
initial
compliance
test
for
the
HAP
being
averaged
must
not
exceed
the
emission
level
that
was
being
achieved
on
the
effective
date
of
the
standard
or
the
control
technology
employed
during
the
initial
compliance
test
must
not
be
less
effective
for
the
HAP
being
averaged
than
the
control
technology
employed
on
the
effective
date
of
the
standard.

(
e)
You
may
average
particulate
matter
or
total
selected
metals
emissions,
hydrogen
chloride
emissions,
and
mercury
emissions
from
existing
large
solid
fuel
boilers
to
demonstrate
compliance
with
the
limit
in
Table
1
of
this
subpart
if
you
satisfy
the
requirements
in
paragraphs
(
f)

and
(
g)
of
this
section.

(
f)
The
weighted
average
emissions
from
the
existing
large
solid
fuel
boilers
participating
in
the
emissions
averaging
option
must
be
in
compliance
with
the
limits
in
Table
1
at
all
times
following
the
compliance
date
specified
in
§
63.7495.

(
1)
Owners
or
operators
must
use
equation
1
of
this
section
to
demonstrate
that
the
particulate
matter
or
total
selected
metals,
hydrogen
chloride,
and
mercury
emissions
from
all
existing
large
solid
fuel
boilers
participating
in
the
emissions
averaging
option
do
not
exceed
the
emission
limits
in
Table
1
of
this
subpart.

Where:

AveWeighted
=
Emissions
Er
=
Emiss
metals,
hydrogen
chloride,
or
mercury,
in
units
of
pounds
per
million
Btu
of
heat
input.
Hm
=
Maximum
rated
heat
input
capacity
of
boiler,
i,
in
units
of
million
Btu
per
hour.
n
=
Number
of
large
solid
fuel
boilers
participating
in
the
emissions
averaging
option.

(
2)
If
you
are
not
capable
of
monitoring
heat
input,

you
can
use
equation
2
as
an
alternative
to
using
equation
1
of
this
section
to
demonstrate
that
the
particulate
matter
or
total
selected
metals,
hydrogen
chloride,
and
mercury
emissions
from
all
existing
large
solid
fuel
boilers
participating
in
the
emissions
averaging
option
do
not
exceed
the
emission
limits
in
Table
1
of
this
subpart.
AveWeightedEmissions
Er
Hm
Hm
i
n
i
n
=
×
÷
=
=


(
)
1
1
AveWeightedEmissions
Er
Sm
Cf
Sm
Cf
i
n
i
n
=
×
×
÷
×
=
=


(
)
1
1
(
Eq.
2)

Where:

AveWeighted
=
Average
weighted
emission
level
for
Emissions
PM
or
total
selected
metals,
HCl,
or
mercury,
in
units
of
pounds
per
million
Btu
of
heat
input.
Er
=
Emission
rate
(
as
calculated
according
to
Table
5
of
this
subpart)
or
fuel
analysis
(
as
calculated
by
the
applicable
equation
in
§
63.7530)
for
boiler,
i,
for
particulate
matter
or
total
selected
metals,
hydrogen
chloride,
or
mercury,
in
units
of
pounds
per
million
Btu
of
heat
input.
Sm
=
Maximum
steam
generation
by
boiler,
i,
in
units
of
pounds.
Cf
=
Conversion
factor,
calculated
from
the
most
recent
compliance
test,
in
units
of
million
Btu
of
heat
input
per
pounds
of
steam
generated.

(
g)
For
each
calendar
month,
owners
or
operators
must
ensure
that
the
heat
capacity
for
existing
large
solid
fuel
boilers
participating
in
the
emissions
averaging
option
does
not
result
in
an
exceedance
of
the
average
weighted
emission
limit
following
the
compliance
date
specified
in
§
63.7495.

(
1)
For
each
calendar
month,
owners
or
operators
must
use
equation
3
of
this
section
to
calculate
the
average
weighted
emission
limit
using
the
actual
heat
capacity
for
each
existing
large
solid
fuel
boilers
participating
in
the
emissions
averaging
option.

(
Eq.
3)

Where:

AveWeighted
=
Averag
Emissions
partic
Er
=
Emiss
boiler,
i,
for
particulate
matter
or
total
selected
metals,
hydrogen
chloride,
or
mercury,
in
units
of
pounds
per
million
Btu
of
heat
input.
Hb
=
The
average
heat
input
for
each
calendar
month
of
boiler,
i,
in
units
of
million
Btu
n
=
Number
of
large
solid
fuel
boilers
participating
in
the
emissions
averaging
option.

(
2)
If
you
are
not
capable
of
monitoring
heat
input,

you
can
use
equation
4
as
an
alternative
to
using
equation
3
of
this
section
to
demonstrate
that
the
actual
steam
generation
from
the
large
solid
fuel
boilers
participating
in
the
emissions
averaging
option
for
the
calendar
month
does
not
result
in
an
exceedance
of
the
average
weighted
emission
limit.
AveWeightedEmissions
Er
Hb
Hb
i
n
i
n
=
×
÷
=
=


(
)
1
1
(
Eq.
4)

Where:

AveWeighted
=
Average
weighted
emission
level
for
Emissions
Er
=
boiler,
i,
for
particulate
matter
or
total
selected
metals,
hydrogen
chloride,
or
mercury,
in
units
of
pounds
per
million
Btu
of
heat
input.
Sa
=
Actual
steam
generation
for
each
calender
month
by
boiler,
i,
in
units
of
pounds.
Cf
=
Conversion
factor,
as
calculated
during
the
most
recent
compliance
test,
in
units
of
million
Btu
of
heat
input
per
pounds
of
steam
generated.

(
h)
You
must
develop
and
submit
an
implementation
plan
for
emission
averaging
to
the
applicable
regulatory
authority
for
review
and
approval
according
to
the
following
procedures
and
requirements
in
paragraphs
(
h)(
1)

through
(
4):

(
1)
You
must
submit
the
implementation
plan
no
later
than
6
months
before
the
date
that
the
facility
intends
to
demonstrate
compliance
using
the
emission
averaging
option.
AveWeightedEmissions
Er
Sa
Cf
Sa
Cf
i
n
i
n
=
×
×
÷
×
=
=


(
)
1
1
(
2)
You
must
include
the
information
contained
in
paragraphs
(
2)(
i)
through
(
vii)
in
your
implementation
plan
for
all
emission
sources
included
in
an
emissions
average:

(
i)
The
identification
of
all
existing
large
solid
fuel
boilers
in
the
averaging
group,
including
for
each
either
the
applicable
HAP
emission
level
or
the
control
technology
installed
on
the
effective
date
of
the
standard;

(
ii)
The
process
parameter
(
heat
input
or
steam
generated)
that
will
be
monitored
for
each
averaging
group
of
large
solid
fuel
boilers;

(
iii)
The
specific
control
technology
or
pollution
prevention
measure
to
be
used
for
each
emission
source
in
the
averaging
group
and
the
date
of
its
installation
or
application.
If
the
pollution
prevention
measure
reduces
or
eliminates
emissions
from
multiple
sources,
the
owner
or
operator
must
identify
each
source.
If
the
pollution
prevention
measures
is
the
replacement
of
an
existing
large
solid
fuel
boiler,
the
owner
or
operator
must
document
that
this
boiler
has
been
permanently
shutdown
or
dismantled;

(
iv)
The
test
plan
for
the
measurement
of
particulate
matter
(
or
selected
total
metals),
hydrogen
chloride,
or
mercury
emissions
in
accordance
with
the
requirements
in
§
63.7520;

(
v)
The
operating
parameters
to
be
monitored
for
each
control
system
or
device
and
a
description
of
how
the
operating
limits
will
be
determined;

(
vi)
If
you
request
to
monitor
an
alternative
operating
parameter
pursuant
to
§
63.7525,
you
must
also
include:

(
A)
A
description
of
the
parameter(
s)
to
be
monitored
and
an
explanation
of
the
criteria
used
to
select
the
parameter(
s);
and
(
B)
A
description
of
the
methods
and
procedures
that
will
be
used
to
demonstrate
that
the
parameter
indicates
proper
operation
of
the
control
device;
the
frequency
and
content
of
monitoring,
reporting,
and
recordkeeping
requirements;
and
a
demonstration,
to
the
satisfaction
of
the
applicable
regulatory
authority,
that
the
proposed
monitoring
frequency
is
sufficient
to
represent
control
device
operating
conditions;
and
(
vii)
A
demonstration
that
compliance
with
each
of
the
applicable
emission
limit(
s)
will
be
achieved
under
representative
operating
conditions.

(
3)
Upon
receipt,
the
regulatory
authority
shall
review
and
approve
or
disapprove
the
plan
according
to
the
following
criteria:

(
i)
Whether
the
content
of
the
plan
includes
all
of
the
information
specified
in
paragraph
(
f)(
2)
of
this
section;
and
(
ii)
Whether
the
plan
presents
sufficient
information
to
determine
that
compliance
will
be
achieved
and
maintained.

(
4)
The
applicable
regulatory
authority
shall
not
approve
an
emission
averaging
implementation
plan
containing
any
of
the
following
provisions:

(
i)
Any
averaging
between
emissions
of
differing
pollutants
or
between
differing
sources;
or
(
ii)
The
inclusion
of
any
emission
source
other
than
an
existing
large
solid
fuel
boiler,
except
for
a
new
gaseous
fuel
boiler
that
replaces
an
existing
large
solid
fuel
boiler.

§
63.7525
What
are
my
monitoring,
installation,
operation,

and
maintenance
requirements?

(
a)
If
you
have
an
applicable
work
practice
standard
for
carbon
monoxide
and
your
boiler
or
process
heater
has
a
heat
input
capacity
of
100
million
Btu
per
hour
or
greater,
you
must
install,
operate,
and
maintain
a
continuous
emission
monitoring
system
for
carbon
monoxide
according
to
the
procedures
in
paragraphs
(
a)(
1)
through
(
5)
of
this
section
by
the
compliance
date
specified
in
§
63.7495.

(
1)
Each
continuous
emissions
monitoring
system
must
be
installed,
operated,
and
maintained
according
to
Performance
Specification
(
PS)
4A
of
40
CFR
part
60,

appendix
B,
and
according
to
the
site­
specific
monitoring
plan
developed
according
to
§
63.7505(
d).

(
2)
You
must
conduct
a
performance
evaluation
of
each
continuous
emission
monitoring
system
according
to
the
requirements
in
§
63.8
and
according
to
PS
4A
of
40
CFR
part
60,
appendix
B.

(
3)
Each
continuous
emission
monitoring
system
must
complete
a
minimum
of
one
cycle
of
operation
(
sampling,

analyzing,
and
data
recording)
for
each
successive
15­

minute
period.

(
4)
Continuous
emissions
monitoring
system
data
must
be
reduced
as
specified
in
§
63.8(
g)(
2).

(
5)
For
purposes
of
calculating
data
averages,
you
must
not
use
data
recorded
during
periods
of
monitoring
malfunctions,
associated
repairs,
out­
of­
control
periods,
required
quality
assurance
or
control
activities,
or
when
your
boiler
or
process
heater
is
operating
at
less
than
50
percent
of
its
rated
capacity.
You
must
use
all
the
data
collected
during
all
other
periods
in
assessing
compliance.

Any
period
for
which
the
monitoring
system
is
out
of
control
and
data
are
not
available
for
required
calculations
constitutes
a
deviation
from
the
monitoring
requirements.

(
b)
If
you
have
an
applicable
opacity
operating
limit,
you
must
install,
operate,
certify
and
maintain
each
continuous
opacity
monitoring
system
according
to
the
procedures
in
paragraphs
(
b)(
1)
through
(
7)
of
this
section
by
the
compliance
date
specified
in
§
63.7495.

(
1)
Each
continuous
opacity
monitoring
system
must
be
installed,
operated,
and
maintained
according
to
PS
1
of
40
CFR
part
60,
appendix
B.

(
2)
You
must
conduct
a
performance
evaluation
of
each
continuous
opacity
monitoring
system
according
to
the
requirements
in
§
63.8
and
according
to
PS
1
of
40
CFR
part
60,
appendix
B.

(
3)
As
specified
in
§
63.8(
c)(
4)(
i),
each
continuous
opacity
monitoring
system
must
complete
a
minimum
of
one
cycle
of
sampling
and
analyzing
for
each
successive
10­

second
period
and
one
cycle
of
data
recording
for
each
successive
6­
minute
period.

(
4)
Continuous
opacity
monitoring
system
data
must
be
reduced
as
specified
in
§
63.8(
g)(
2).

(
5)
You
must
include
in
your
site­
specific
monitoring
plan
procedures
and
acceptance
criteria
for
operating
and
maintaining
each
continuous
opacity
monitoring
system
(
COMS)
according
to
the
requirements
in
§
63.8(
d).
At
a
minimum,
the
monitoring
plan
must
include
a
daily
calibration
drift
assessment,
a
quarterly
performance
audit,
and
an
annual
zero
alignment
audit
of
each
COMS.

(
6)
You
must
operate
and
maintain
each
COMS
according
to
the
requirements
in
the
monitoring
plan
and
the
requirements
of
§
63.8(
e).
Identify
periods
the
COMS
is
out­
of­
control
including
any
periods
that
the
COMS
fails
to
pass
a
daily
calibration
drift
assessment,
a
quarterly
performance
audit,
or
an
annual
zero
alignment
audit.

(
7)
You
must
determine
and
record
all
the
6­
minute
averages
(
and
1­
hour
block
averages
as
applicable)

collected
for
periods
during
which
the
COMS
is
not
out­

ofcontrol
(
c)
If
you
have
an
operating
limit
that
requires
the
use
of
a
continuous
monitoring
system,
you
must
install,

operate,
and
maintain
each
continuous
parameter
monitoring
system
according
to
the
procedures
in
paragraphs
(
c)(
1)

through
(
5)
of
this
section
by
the
compliance
date
specified
in
§
63.7495.

(
1)
The
continuous
parameter
monitoring
system
must
complete
a
minimum
of
one
cycle
of
operation
for
each
successive
15­
minute
period.
You
must
have
a
minimum
of
four
successive
cycles
of
operation
to
have
a
valid
hour
of
data.

(
2)
Except
for,
monitoring
malfunctions,
associated
repairs
and
required
quality
assurance
or
control
activities
(
including,
as
applicable,
calibration
checks
and
required
zero
and
span
adjustments),
you
must
conduct
all
monitoring
in
continuous
operation
at
all
times
that
the
unit
is
operating.
A
monitoring
malfunction
is
any
sudden,
infrequent,
not
reasonably
preventable
failure
of
the
monitoring
to
provide
valid
data.
Monitoring
failures
that
are
caused
in
part
by
poor
maintenance
or
careless
operation
are
not
malfunctions.

(
3)
For
purposes
of
calculating
data
averages,
you
must
not
use
data
recorded
during
monitoring
malfunctions,

associated
repairs,
out­
of­
control
periods,
or
required
quality
assurance
or
control
activities.
You
must
use
all
the
data
collected
during
all
other
periods
in
assessing
compliance.
Any
period
for
which
the
monitoring
system
is
out­
of­
control
and
data
are
not
available
for
required
calculations
constitutes
a
deviation
from
the
monitoring
requirements.

(
4)
Determine
the
3­
hour
block
average
of
all
recorded
readings,
except
as
provided
in
paragraph
(
c)(
3)

of
this
section.

(
5)
Record
the
results
of
each
inspection,

calibration,
and
validation
check.

(
d)
If
you
have
an
operating
limit
that
requires
the
use
of
a
flow
measurement
device,
you
must
meet
the
requirements
in
paragraphs
(
c)
and
(
d)(
1)
through
(
4)
of
this
section.

(
1)
Locate
the
flow
sensor
and
other
necessary
equipment
in
a
position
that
provides
a
representative
flow.

(
2)
Use
a
flow
sensor
with
a
measurement
sensitivity
of
2
percent
of
the
flow
rate.
(
3)
Reduce
swirling
flow
or
abnormal
velocity
distributions
due
to
upstream
and
downstream
disturbances.

(
4)
Conduct
a
flow
sensor
calibration
check
at
least
semiannually.

(
e)
If
you
have
an
operating
limit
that
requires
the
use
of
a
pressure
measurement
device,
you
must
meet
the
requirements
in
paragraphs
(
c)
and
(
e)(
1)
through
(
6)
of
this
section.

(
1)
Locate
the
pressure
sensor(
s)
in
a
position
that
provides
a
representative
measurement
of
the
pressure.

(
2)
Minimize
or
eliminate
pulsating
pressure,

vibration,
and
internal
and
external
corrosion.

(
3)
Use
a
gauge
with
a
minimum
tolerance
of
1.27
centimeters
of
water
or
a
transducer
with
a
minimum
tolerance
of
1
percent
of
the
pressure
range.

(
4)
Check
pressure
tap
pluggage
daily.

(
5)
Using
a
manometer,
check
gauge
calibration
quarterly
and
transducer
calibration
monthly.

(
6)
Conduct
calibration
checks
any
time
the
sensor
exceeds
the
manufacturer's
specified
maximum
operating
pressure
range
or
install
a
new
pressure
sensor.

(
f)
If
you
have
an
operating
limit
that
requires
the
use
of
a
pH
measurement
device,
you
must
meet
the
requirements
in
paragraphs
(
c)
and
(
f)(
1)
through
(
3)
of
this
section.

(
1)
Locate
the
pH
sensor
in
a
position
that
provides
a
representative
measurement
of
scrubber
effluent
pH.

(
2)
Ensure
the
sample
is
properly
mixed
and
representative
of
the
fluid
to
be
measured.

(
3)
Check
the
pH
meter's
calibration
on
at
least
two
points
every
8
hours
of
process
operation.

(
g)
If
you
have
an
operating
limit
that
requires
the
use
of
equipment
to
monitor
voltage
and
secondary
current
(
or
total
power
input)
of
an
electrostatic
precipitator
(
ESP),
you
must
use
voltage
and
secondary
current
monitoring
equipment
to
measure
voltage
and
secondary
current
to
the
ESP.

(
h)
If
you
have
an
operating
limit
that
requires
the
use
of
equipment
to
monitor
sorbent
injection
rate
(
e.
g.,

weigh
belt,
weigh
hopper,
or
hopper
flow
measurement
device),
you
must
meet
the
requirements
in
paragraphs
(
c)

and
(
h)(
1)
through
(
3).

(
1)
Locate
the
device
in
a
position(
s)
that
provides
a
representative
measurement
of
the
total
sorbent
injection
rate.

(
2)
Install
and
calibrate
the
device
in
accordance
with
manufacturer's
procedures
and
specifications.

(
3)
At
least
annually,
calibrate
the
device
in
accordance
with
the
manufacturer's
procedures
and
specifications.

(
i)
If
you
elect
to
use
a
fabric
filter
bag
leak
detection
system
to
comply
with
the
requirements
of
this
subpart,
you
must
install,
calibrate,
maintain,
and
continuously
operate
a
bag
leak
detection
system
as
specified
in
paragraphs
(
i)(
1)
through
(
8)
of
this
section.

(
1)
You
must
install
and
operate
a
bag
leak
detection
system
for
each
exhaust
stack
of
the
fabric
filter.

(
2)
Each
bag
leak
detection
system
must
be
installed,

operated,
calibrated,
and
maintained
in
a
manner
consistent
with
the
manufacturer's
written
specifications
and
recommendations
and
in
accordance
with
the
guidance
provided
in
EPA­
454/
R­
98­
015,
September
1997.

(
3)
The
bag
leak
detection
system
must
be
certified
by
the
manufacturer
to
be
capable
of
detecting
particulate
matter
emissions
at
concentrations
of
10
milligrams
per
actual
cubic
meter
or
less.
(
4)
The
bag
leak
detection
system
sensor
must
provide
output
of
relative
or
absolute
particulate
matter
loadings.

(
5)
The
bag
leak
detection
system
must
be
equipped
with
a
device
to
continuously
record
the
output
signal
from
the
sensor.

(
6)
The
bag
leak
detection
system
must
be
equipped
with
an
alarm
system
that
will
sound
automatically
when
an
increase
in
relative
particulate
matter
emissions
over
a
preset
level
is
detected.
The
alarm
must
be
located
where
it
is
easily
heard
by
plant
operating
personnel.

(
7)
For
positive
pressure
fabric
filter
systems
that
do
not
duct
all
compartments
of
cells
to
a
common
stack,
a
bag
leak
detection
system
must
be
installed
in
each
baghouse
compartment
or
cell.

(
8)
Where
multiple
bag
leak
detectors
are
required,

the
system's
instrumentation
and
alarm
may
be
shared
among
detectors.

§
63.7530
How
do
I
demonstrate
initial
compliance
with
the
emission
limits
and
work
practice
standards?

(
a)
You
must
demonstrate
initial
compliance
with
each
emission
limit
and
work
practice
standard
that
applies
to
you
by
either
conducting
initial
performance
tests
and
establishing
operating
limits,
as
applicable,
according
to
§
63.7520,
paragraph
(
c)
of
this
section,
and
Tables
5
and
7
of
this
subpart
OR
conducting
initial
fuel
analyses
to
determine
emission
rates
and
establishing
operating
limits,

as
applicable,
according
to
§
63.7521,
paragraph
(
d)
of
this
section,
and
Tables
6
and
7
of
this
subpart.

(
b)
New
or
reconstructed
boilers
or
process
heaters
in
one
of
the
liquid
fuel
subcategories
that
burn
only
fossil
fuels
and
other
gases
and
do
not
burn
any
residual
oil
must
demonstrate
compliance
according
to
§
63.7506(
a).

(
c)
If
you
demonstrate
compliance
through
performance
testing,
you
must
establish
each
site­
specific
operating
limit
in
Tables
2
through
4
of
this
subpart
that
applies
to
you
according
to
the
requirements
in
§
63.7520,
Table
7
of
this
subpart,
and
paragraph
(
c)
(
4)
of
this
section,
as
applicable.
You
must
also
conduct
fuel
analyses
according
to
§
63.7521
and
establish
maximum
fuel
pollutant
input
operating
limits
according
to
paragraphs
(
c)(
1)
through
(
3)

of
this
section,
as
applicable.

(
1)
You
must
establish
a
chlorine
fuel
input
operating
limit
based
on
the
maximum
chlorine
fuel
input
(
Clinput)
established
during
the
initial
performance
testing
according
to
the
procedures
in
paragraphs
(
c)(
1)(
i)

through
(
iii)
of
this
section.

(
i)
You
must
determine
the
fuel
type
or
fuel
mixture
that
you
could
burn
in
your
boiler
or
process
heater
that
has
the
highest
content
of
chlorine.

(
ii)
During
the
performance
testing
for
hydrogen
chloride,
you
must
determine
the
fraction
of
the
total
heat
input
for
each
fuel
type
burned
(
Qi)
based
on
the
fuel
mixture
that
has
the
highest
content
of
chlorine,
and
the
average
chlorine
concentration
of
each
fuel
type
burned
(
Ci
).

(
iii)
You
must
establish
a
maximum
chlorine
input
level
using
Equation
1
of
this
section.

Where:

Clinput
=
Maximum
amount
of
chlorine
entering
the
boiler
or
process
heater
through
fuels
burned
in
units
of
pounds
per
million
Btu.
This
is
your
operating
limit
for
chlorine
fuel
input.

Ci
=
Arithmetic
average
concentration
of
chlorine
in
fuel
type,
i,
analyzed
according
to
§
63.7521,
in
units
of
[
]
C
CQ
input
i
n
i
i
1
1
=
=

(
)(
)
pounds
per
million
Btu
Qi
=
Fraction
of
total
heat
input
from
fuel
type,
i,
based
on
the
fuel
mixture
that
has
the
highest
content
of
chlorine.
If
you
do
not
burn
multiple
fuel
types
during
the
performance
testing,
it
is
not
necessary
to
determine
the
value
of
this
term.
Insert
a
value
of
"
1"
for
.
Qi
n
=
Number
of
different
fuel
types
burned
in
your
boiler
or
process
heater
for
the
mixture
that
has
the
highest
content
of
chlorine.

(
2)
If
you
choose
to
comply
with
the
alternative
total
selected
metals
emission
limit
instead
of
the
particulate
matter
emission
limit,
you
must
establish
a
total
selected
metals
fuel
input
operating
limit
based
on
the
maximum
total
selected
metals
fuel
input
(
Metalsinput)

established
during
the
initial
performance
testing
according
to
the
procedures
in
paragraphs
(
c)(
2)(
i)
through
(
iii)
of
this
section.

(
i)
You
must
determine
the
fuel
type
or
fuel
mixture
that
you
could
burn
in
your
boiler
or
process
heater
that
has
the
highest
content
of
total
selected
metals.

(
ii)
During
the
performance
testing
for
total
selected
metals,
you
must
determine
the
fraction
of
total
heat
input
from
each
fuel
burned
(
Qi)
based
on
the
fuel
mixture
that
has
the
highest
content
of
total
selected
metals,
and
the
average
total
selected
metals
concentration
of
each
fuel
type
burned
(
Mi).

(
ii)
You
must
establish
a
baseline
total
selected
metals
input
level
using
Equation
2
of
this
section.

Where:

Metalsinput
=
Maximum
amount
of
total
selected
metals
entering
the
boiler
or
process
heater
through
fuels
burned
in
units
of
pounds
per
million
Btu.
This
is
your
operating
limit
for
total
selected
metals
fuel
input.

Mi
=
Arithmetic
average
concentration
of
total
selected
metals
in
fuel
type,
i,
analyzed
according
to
§
63.7521,
in
units
of
pound
per
million
Btu
Qi
=
Fraction
of
total
heat
input
from
based
fuel
type,
i,
based
on
the
fuel
mixture
that
has
the
highest
content
of
total
selected
metals.
If
you
do
not
burn
multiple
fuel
types
during
the
performance
test,
it
is
not
necessary
to
determine
the
value
of
this
term.
Insert
a
value
of
"
1"
for
Qi.
n
=
Number
of
different
fuel
types
burned
in
your
boiler
or
process
heater
for
the
mixture
that
has
the
highest
content
of
total
selected
metals.

(
3)
You
must
establish
a
mercury
fuel
input
operating
[
]
Metals
M
Q
input
i
n
i
i
=

=

1
(
)(
)
limit
based
on
the
maximum
mercury
fuel
input
(
Mercury
input)
established
during
the
initial
performance
testing
using
the
procedures
in
paragraphs
(
c)(
3)(
i)
through
(
iii)

of
this
section.

(
i)
You
must
determine
the
fuel
type
or
fuel
mixture
that
you
could
burn
in
your
boiler
or
process
heater
that
has
the
highest
content
of
mercury.

(
ii)
During
the
compliance
demonstration
for
mercury,

you
must
determine
the
fraction
of
total
heat
input
for
each
fuel
burned
(
Qi)
based
on
the
fuel
mixture
that
has
the
highest
content
of
mercury,
and
the
average
mercury
concentration
of
each
fuel
type
burned
(
HGi)
.

(
iii)
You
must
establish
a
maximum
mercury
input
level
using
Equation
3
of
this
section.

Where:

Mercuryinput
=
Maximum
amount
of
mercury
entering
the
boiler
or
process
heater
through
fuels
burned
in
units
of
pounds
per
million
Btu.
This
is
your
operating
limit
for
mercury
fuel
input.
[
]
Mercury
HG
Q
input
i
n
i
i
=
=

1
(
)(
)
HGi
=
Arithmetic
average
concentration
of
mercury
in
fuel
type,
i,
analyzed
according
to
§
63.7521,
in
units
of
pound
per
million
Btu
.

Qi
=
Fraction
of
total
heat
input
from
fuel
type,
i,
based
on
the
fuel
mixture
that
has
the
highest
mercury
content.
If
you
do
not
burn
multiple
fuel
types
during
the
performance
test,
it
is
not
necessary
to
determine
the
value
of
this
term.
Insert
a
value
of
"
1"
for
Qi.
n
=
Number
of
different
fuel
types
burned
in
your
boiler
or
process
heater
for
the
mixture
that
has
the
highest
content
of
mercury.

(
4)
You
must
establish
parameter
operating
limits
according
to
paragraphs
(
c)(
4)(
i)
through
(
iv)
of
this
section.

(
i)
For
a
wet
scrubber,
you
must
establish
the
minimum
scrubber
effluent
pH,
liquid
flowrate,
and
pressure
drop
as
defined
in
§
63.7575,
as
your
operating
limits
during
the
three­
run
performance
test.
If
you
use
a
wet
scrubber
and
you
conduct
separate
performance
tests
for
particulate
matter,
hydrogen
chloride,
and
mercury
emissions,
you
must
establish
one
set
of
minimum
scrubber
effluent
pH,
liquid
flow
rate,
and
pressure
drop
operating
limits.
The
minimum
scrubber
effluent
pH
operating
limit
must
be
established
during
the
hydrogen
chloride
performance
test.
If
you
conduct
multiple
performance
tests,
you
must
set
the
minimum
liquid
flowrate
and
pressure
drop
operating
limits
at
the
highest
minimum
values
established
during
the
performance
tests.

(
ii)
For
an
electrostatic
precipitator,
you
must
establish
the
minimum
voltage
and
secondary
current
(
or
total
power
input),
as
defined
in
§
63.7575,
as
your
operating
limits
during
the
three­
run
performance
test.

(
iii)
For
a
dry
scrubber,
you
must
establish
the
minimum
sorbent
injection
rate,
as
defined
in
§
63.7575,
as
your
operating
limit
during
the
three­
run
performance
test.

(
iv)
The
operating
limit
for
boilers
or
process
heaters
with
fabric
filters
that
choose
to
demonstrate
continuous
compliance
through
bag
leak
detection
systems
is
that
a
bag
leak
detection
system
be
installed
according
to
the
requirements
in
§
63.7525
and
that
each
fabric
filter
must
be
operated
such
that
the
bag
leak
detection
system
alarm
does
not
sound
more
than
5
percent
of
the
operating
time
during
a
6­
month
period.

(
d)
If
you
elect
to
demonstrate
compliance
with
an
applicable
emission
limit
through
fuel
analysis,
you
must
conduct
fuel
analyses
according
to
§
63.7521
and
follow
the
procedures
in
paragraphs
(
d)(
1)
through
(
5)
of
the
section.

(
1)
If
you
burn
more
than
one
fuel
type,
you
must
determine
the
fuel
mixture
you
could
burn
in
your
boiler
or
process
heater
that
would
result
in
the
highest
emission
rates
of
the
pollutants
that
you
elect
to
demonstrate
compliance
through
fuel
analysis.
The
emission
rates
calculated
according
to
paragraphs
(
3)
through
(
5)
of
this
section
are
your
operating
limits.

(
2)
You
must
determine
the
90th
percentile
confidence
level
fuel
pollutant
concentration
of
the
composite
samples
analyzed
for
each
fuel
type
using
the
one­
sided
z­
statistic
test
described
in
Equation
1
of
this
section.

P90
=
mean
+
(
SD
*
t)
(
Eq.
4)

where:

P90
=
90th
percentile
confidence
level
pollutant
concentration,
in
pounds
per
million
Btu.
mean
=
Arithmetic
average
of
the
fuel
pollutant
concentration
in
the
fuel
samples
analyzed
according
to
§
63.7521,
in
units
of
pounds
per
million
Btu.
SD
=
Standard
deviation
of
the
pollutant
concentration
in
the
fuel
samples
analyzed
according
to
§
63.7521,
in
units
of
pounds
per
million
Btu.
t
=
t
distribution
critical
value
for
90th
percentile
(
0.1)
probability
for
the
appropriate
degrees
of
freedom
(
number
of
samples
minus
one)
as
obtained
from
at
Distribution
Critical
Value
Table.
(
3)
To
demonstrate
compliance
with
the
applicable
emission
limit
for
hydrogen
chloride,
the
hydrogen
chloride
emission
rate
that
you
calculate
for
your
boiler
or
process
heater
using
Equation
5
of
this
section
must
be
less
than
the
applicable
emission
limit
for
hydrogen
chloride.

Where:

HCl
=
Hydrogen
chloride
emission
rate
from
the
boiler
or
process
heater
in
units
of
pounds
per
million
Btu.
This
is
your
operating
limit.

Ci90
=
90th
percentile
confidence
level
concentration
of
chlorine
in
fuel
type,
i,
in
units
of
pounds
per
million
Btu
as
calculated
according
to
Equation
4
of
this
section
Qi
=
Fraction
of
total
heat
input
from
fuel
type,

i,
based
on
the
fuel
mixture
that
has
the
highest
content
of
chlorine.
If
you
do
not
burn
multiple
fuel
types,
it
is
not
necessary
to
determine
the
value
of
this
term.
Insert
a
value
of
"
1"
for
Qi
n
=
Number
of
different
fuel
types
burned
in
your
boiler
or
process
heater
for
the
mixture
that
has
the
highest
content
of
chlorine
.
1.028=
Molecular
weight
ratio
of
hydrogen
chloride
to
chlorine.

(
4)
To
demonstrate
compliance
with
the
applicable
[
]
HCl
C
Q
i
i
i
n
=
=

(
)(
)(.
)
90
1
1028
emission
limit
for
total
selected
metals,
the
total
selected
metals
emission
rate
that
you
calculate
for
your
boiler
or
process
heater
using
Equation
5
of
this
section
must
be
less
than
the
applicable
emission
limit
for
total
selected
metals.

Where:

Metals
=
Total
selected
metals
emission
rate
from
the
boiler
or
process
heater
in
units
of
pounds
per
million
Btu.
This
is
your
operating
limit.

Mi90
=
90th
percentile
confidence
level
concentration
of
total
selected
metals
in
fuel,
i,
in
units
of
pound
per
million
Btu
as
calculated
according
to
Equation
4
of
this
section
Qi
=
Fraction
of
total
heat
input
from
fuel
type,
i,
based
on
the
fuel
mixture
that
has
the
highest
content
of
total
selected
metals.
If
you
do
not
burn
multiple
fuel
types,
it
is
not
necessary
to
determine
the
value
of
this
term.
Insert
a
value
of
"
1"
for
Q
i.
n
=
Number
of
different
fuel
types
burned
in
your
boiler
or
process
heater
for
the
mixture
that
has
the
highest
content
of
total
selected
metals.

(
5)
To
demonstrate
compliance
with
the
applicable
emission
limit
for
mercury,
the
mercury
emission
rate
that
[
]
Metals
M
Q
i
i
i
n
=
=

(
)(
)
90
1
you
calculate
for
your
boiler
or
process
heater
using
Equation
7
of
this
section
must
be
less
than
the
applicable
emission
limit
for
mercury.

Where:

Mercury
=
Mercury
emission
rate
from
the
boiler
or
process
heater
in
units
of
pounds
per
million
Btu.
This
is
your
operating
limit.

HGi90
=
90th
percentile
confidence
level
concentration
of
mercury
in
fuel,
i,
in
units
of
pound
per
million
Btu
as
calculated
according
to
Equation
4
of
this
section.
Qi
=
Fraction
of
total
heat
input
from
fuel
type,
i,
based
on
the
fuel
mixture
that
has
the
highest
mercury
content.
If
you
do
not
burn
multiple
fuel
types
,
it
is
not
necessary
to
determine
the
value
of
this
term.
Insert
a
value
of
"
1"
for
Qi.
n
=
Number
of
different
fuel
types
burned
in
your
boiler
or
process
heater
for
the
mixture
that
has
the
highest
mercury
content.

(
e)
You
must
submit
the
Notification
of
Compliance
Status
containing
the
results
of
the
initial
compliance
demonstration
according
to
the
requirements
in
§
63.7545(
e).

Continuous
Compliance
Requirements
§
63.7535
How
do
I
monitor
and
collect
data
to
demonstrate
[
]
Mercury
HG
Q
i
i
i
n
=
=

(
)()
90
1
continuous
compliance?

(
a)
You
must
monitor
and
collect
data
according
to
this
section
and
the
site­
specific
monitoring
plan
required
by
§
63.7505(
d).

(
b)
Except
for
monitor
malfunctions,
associated
repairs,
and
required
quality
assurance
or
control
activities
(
including,
as
applicable,
calibration
checks
and
required
zero
and
span
adjustments),
you
must
monitor
continuously
(
or
collect
data
at
all
required
intervals)
at
all
times
that
the
affected
source
is
operating.

(
c)
You
may
not
use
data
recorded
during
monitoring
malfunctions,
associated
repairs,
or
required
quality
assurance
or
control
activities,
in
data
averages
and
calculations
used
to
report
emission
or
operating
levels.

You
must
use
all
the
data
collected
during
all
other
periods
in
assessing
the
operation
of
the
control
device
and
associated
control
system.
Boilers
and
process
heaters
that
have
an
applicable
carbon
monoxide
work
practice
standard
and
are
required
to
install
and
operate
a
continuous
emission
monitoring
system,
may
not
use
data
recorded
during
periods
when
the
boiler
or
process
heater
is
operating
at
less
than
50
percent
of
its
rated
capacity.
§
63.7540
How
do
I
demonstrate
continuous
compliance
with
the
emission
limits
and
work
practice
standards?

(
a)
You
must
demonstrate
continuous
compliance
with
each
emission
limit,
operating
limit,
and
work
practice
standard
in
Tables
1
through
4
of
this
subpart
that
applies
to
you
according
to
the
methods
specified
in
Table
8
of
this
subpart
and
paragraphs
(
a)(
1)
through
(
11)
of
this
section.

(
1)
Following
the
date
on
which
the
initial
performance
test
is
completed
or
is
required
to
be
completed
under
§
63.7
and
§
63.7510,
whichever
date
comes
first,
you
must
not
operate
above
any
of
the
applicable
maximum
operating
limits
or
below
any
of
the
applicable
minimum
operating
limits
listed
in
Tables
2
through
4
of
this
subpart
at
all
times
except
during
periods
of
startup,

shutdown
and
malfunction.
Operating
limits
do
not
apply
during
performance
tests.
Operation
above
the
established
maximum
or
below
the
established
minimum
operating
limits
shall
constitute
a
deviation
of
established
operating
limits.

(
2)
You
must
keep
records
of
the
type
and
amount
of
all
fuels
burned
in
each
boiler
or
process
heater
during
the
reporting
period
to
demonstrate
that
all
fuel
types
and
mixtures
of
fuels
burned
would
either
result
in
lower
emissions
of
total
selected
metals,
hydrogen
chloride,
and
mercury,
than
the
applicable
emission
limit
for
each
pollutant
(
if
you
demonstrate
compliance
through
fuel
analysis),
or
result
in
lower
fuel
input
of
total
selected
metals,
chlorine,
and
mercury
than
the
maximum
values
calculated
during
the
last
performance
tests
(
if
you
demonstrate
compliance
through
performance
testing).

(
3)
If
you
demonstrate
compliance
with
an
applicable
hydrogen
chloride
emission
limit
through
fuel
analysis
and
you
plan
to
burn
a
new
type
of
fuel,
you
must
recalculate
the
hydrogen
chloride
emission
rate
using
Equation
5
of
§
63.7530
according
to
paragraphs
(
a)(
3)(
i)
through
(
iii)
of
this
section.

(
i)
You
must
determine
the
chlorine
concentration
for
any
new
fuel
type
in
units
of
pounds
per
million
Btu,
based
on
supplier
data
or
your
own
fuel
analysis,
according
to
the
provisions
in
your
site­
specific
fuel
analysis
plan
developed
according
to
§
63.7521(
b).

(
ii)
You
must
determine
the
new
mixture
of
fuels
that
will
have
the
highest
content
of
chlorine.
(
iii)
Recalculate
the
hydrogen
chloride
emission
rate
from
your
boiler
or
process
heater
under
these
new
conditions
(
HCl)
using
Equation
5
of
§
63.7530.
The
recalculated
hydrogen
chloride
emission
rate
must
be
less
than
the
applicable
emission
limit.

(
4)
If
you
demonstrate
compliance
with
an
applicable
hydrogen
chloride
emission
limit
through
performance
testing
and
you
plan
to
burn
a
new
type
of
fuel
type
or
a
new
mixture
of
fuels,
you
must
recalculate
the
maximum
chlorine
input
using
Equation
1
of
§
63.7530.
If
the
results
of
recalculating
the
maximum
chlorine
input
using
Equation
1
of
§
63.7530
are
higher
than
the
maximum
chlorine
input
level
established
during
the
previous
performance
test,
then
you
must
conduct
a
new
performance
test
within
60
days
of
burning
the
new
fuel
type
or
fuel
mixture
according
to
the
procedures
in
§
63.7520
to
demonstrate
that
the
chlorine
emissions
do
not
exceed
the
emission
limit.

You
must
also
establish
new
operating
limits
based
on
this
performance
test
according
to
the
procedures
in
§
63.7530(
c).

(
5)
If
you
demonstrate
compliance
with
an
applicable
total
selected
metals
emission
limit
through
fuel
analysis
and
you
plan
to
burn
a
new
type
of
fuel,
you
must
recalculate
the
total
selected
metals
emission
rate
using
Equation
6
of
§
63.7530
according
to
the
procedures
specified
in
paragraphs
(
a)(
5)(
i)
through
(
iii)
of
this
section.

(
i)
You
must
determine
the
total
selected
metals
concentration
for
any
new
fuel
type
in
units
of
pounds
per
million
Btu,
based
on
supplier
data
or
your
own
fuel
analysis,
according
to
the
provisions
in
your
site­
specific
fuel
analysis
plan
developed
according
to
§
63.7521(
b).

(
ii)
You
must
determine
the
new
mixture
of
fuels
that
will
have
the
highest
content
of
total
selected
metals
.

(
iii)
Recalculate
the
total
selected
metals
emission
rate
from
your
boiler
or
process
heater
under
these
new
conditions
(
Metals)
using
Equation
6
of
§
63.7530.
The
recalculated
total
selected
metals
emission
rate
must
be
less
than
the
applicable
emission
limit.

(
6)
If
you
demonstrate
compliance
with
an
applicable
total
selected
metals
emission
limit
through
performance
testing
and
you
plan
to
burn
a
new
type
of
fuel
type
or
a
new
mixture
of
fuels,
you
must
recalculate
the
maximum
total
selected
metals
input
using
Equation
2
of
§
63.7530.
If
the
results
of
recalculating
the
maximum
total
selected
metals
input
using
Equation
2
of
§
63.7530
are
higher
than
the
maximum
total
selected
metals
input
level
established
during
the
previous
performance
test,
then
you
must
conduct
a
new
performance
test
within
60
days
of
burning
the
new
fuel
type
or
fuel
mixture
according
to
the
procedures
in
§
63.7520
to
demonstrate
that
the
total
selected
metals
emissions
do
not
exceed
the
emission
limit.
You
must
also
establish
new
operating
limits
based
on
this
performance
test
according
to
the
procedures
in
§
63.7530(
c).

(
7)
If
you
demonstrate
compliance
with
an
applicable
mercury
emission
limit
through
fuel
analysis
and
you
plan
to
burn
a
new
type
of
fuel,
you
must
recalculate
the
mercury
emission
rate
using
Equation
7
of
§
63.7530
according
to
the
procedures
specified
in
paragraphs
(
a)(
7)(
i)
through
(
iii)
of
this
section.

(
i)
You
must
determine
the
mercury
concentration
for
any
new
fuel
type
in
units
of
pounds
per
million
Btu,
based
on
supplier
data
or
your
own
fuel
analysis,
according
to
the
provisions
in
your
site­
specific
fuel
analysis
plan
developed
according
to
§
63.7521(
b).

(
ii)
You
must
determine
the
new
mixture
of
fuels
that
will
have
the
highest
content
of
mercury.

(
iii)
Recalculate
the
mercury
emission
rate
from
your
boiler
or
process
heater
under
these
new
conditions
(
Mercury)
using
Equation
7
of
§
63.7530.
The
recalculated
mercury
emission
rate
must
be
less
than
the
applicable
emission
limit.

(
8)
If
you
demonstrate
compliance
with
an
applicable
mercury
emission
limit
through
performance
testing
and
you
plan
to
burn
a
new
type
of
fuel
type
or
a
new
mixture
of
fuels,
you
must
recalculate
the
maximum
mercury
input
using
Equation
3
of
§
63.7530.
If
the
results
of
recalculating
the
maximum
mercury
input
using
Equation
3
of
§
63.7530
are
higher
than
the
maximum
mercury
input
level
established
during
the
previous
performance
test,
then
you
must
conduct
a
new
performance
test
within
60
days
of
burning
the
new
fuel
type
or
fuel
mixture
according
to
the
procedures
in
§
63.7520
to
demonstrate
that
the
mercury
emissions
do
not
exceed
the
emission
limit.
You
must
also
establish
new
operating
limits
based
on
this
performance
test
according
to
the
procedures
in
§
63.7530(
c).

(
9)
If
your
unit
is
controlled
with
a
fabric
filter,

and
you
demonstrate
continuous
compliance
using
a
bag
leak
detection
system,
you
must
operate
each
fabric
filter
system
such
that
the
bag
leak
detection
system
does
not
sound
more
than
5
percent
of
the
operating
time
during
a
6­

month
period.
You
must
also
keep
records
of
the
date,

time,
and
duration
of
each
alarm
and
the
time
corrective
action
was
initiated
and
completed,
and
a
brief
description
of
the
cause
of
the
alarm,
and
the
corrective
action
taken.

You
must
also
record
the
percent
of
the
operating
time
during
each
6­
month
period
that
the
alarm
sounds.
In
calculating
this
operating
time
percentage,
if
inspection
of
the
fabric
filter
demonstrates
that
no
corrective
action
is
required,
no
alarm
time
is
counted.
If
corrective
action
is
required,
each
alarm
shall
be
counted
as
a
minimum
of
1
hour.
If
you
take
longer
than
1
hour
to
initiate
corrective
action,
the
alarm
time
shall
be
counted
as
the
actual
amount
of
time
taken
to
initiate
corrective
action.

(
10)
If
you
have
an
applicable
work
practice
standard
for
carbon
monoxide
and
you
are
required
to
install
a
continuous
emission
monitoring
system
according
to
§
63.7525(
a),
then
you
must
meet
the
requirements
in
paragraphs
(
a)(
10)(
i)
through
(
iii)
of
this
section.
(
i)
You
must
continuously
monitor
carbon
monoxide
according
to
§
63.7525(
a)
and
§
63.7535.

(
ii)
Maintain
a
carbon
monoxide
emission
level
below
your
applicable
carbon
monoxide
work
practice
standard
in
Table
1
of
this
subpart
at
all
times
except
during
periods
of
startup,
shutdown,
malfunction,
and
when
your
boiler
or
process
heater
is
operating
at
less
than
50
percent
of
rated
capacity.

(
iii)
Keep
records
of
carbon
monoxide
levels
according
to
§
63.7555(
b).

(
b)
You
must
report
each
instance
in
which
you
did
not
meet
each
emission
limit,
operating
limit,
and
work
practice
standard
in
Tables
1
through
4
of
this
subpart
that
apply
to
you.
You
must
also
report
each
instance
during
a
startup,
shutdown,
or
malfunction
when
you
did
not
meet
each
applicable
emission
limit,
operating
limit,
and
work
practice
standard.
These
instances
are
deviations
from
the
emission
limits
and
work
practice
standards
in
this
subpart.
These
deviations
must
be
reported
according
to
the
requirements
in
§
63.7550.

(
c)
During
periods
of
startup,
shutdown,
and
malfunction,
you
must
operate
in
accordance
with
the
startup,
shutdown,
and
malfunction
plan
as
required
in
§
63.7505(
e).

(
d)
Consistent
with
§
§
63.6(
e)
and
63.7(
e)(
1),

deviations
that
occur
during
a
period
of
startup,
shutdown,

or
malfunction
are
not
violations
if
you
demonstrate
to
the
Administrator's
satisfaction
that
you
were
operating
in
accordance
with
your
startup,
shutdown,
and
malfunction
plan.
The
Administrator
will
determine
whether
deviations
that
occur
during
a
period
of
startup,
shutdown,
or
malfunction
are
violations,
according
to
the
provisions
in
§
63.6(
e).

§
63.7541
How
do
I
demonstrate
continuous
compliance
under
the
emission
averaging
provision?

(
a)
Following
the
compliance
date,
the
owner
or
operator
must
demonstrate
compliance
with
this
standard
on
a
continuous
basis
by
meeting
the
requirements
of
paragraphs
(
a)(
1)
through
(
4)
of
this
section.

(
1)
For
each
calendar
month,
demonstrate
compliance
with
the
average
weighted
emissions
limit
for
the
existing
large
solid
fuel
boilers
participating
in
the
emissions
averaging
option
as
determined
in
Section
63.7522,

paragraphs
(
f)
and
(
g);
(
2)
For
each
existing
solid
fuel
boiler
participating
in
the
emissions
averaging
option
that
is
equipped
with
a
dry
control
system,
maintain
opacity
at
or
below
the
applicable
limit;

(
3)
For
each
existing
solid
fuel
boiler
participating
in
the
emissions
averaging
option
that
is
equipped
with
a
wet
scrubber,
maintain
the
3­
hour
average
parameter
values
at
or
below
the
operating
limits
established
during
the
most
recent
performance
test;
and
(
4)
For
each
existing
solid
fuel
boiler
participating
in
the
emissions
averaging
option
that
has
an
approved
alternative
operating
plan,
maintain
the
3­
hour
average
parameter
values
at
or
below
the
operating
limits
established
in
the
most
recent
performance
test.

(
b)
Any
instance
where
the
owner
or
operator
fails
to
comply
with
the
continuous
monitoring
requirements
in
paragraphs
(
a)(
1)
through
(
4)
of
this
section,
except
during
periods
of
startup,
shutdown,
and
malfunction,
is
a
deviation.

Notification,
Reports,
and
Records
§
63.7545
What
notifications
must
I
submit
and
when?

(
a)
You
must
submit
all
of
the
notifications
in
§
§
63.6(
h)(
4)
and
(
5),
63.7(
b)
and
(
c),
63.8
(
e),
63.8(
f)(
4)

and
(
6),
and
63.9
(
b)
through
(
h)
that
apply
to
you
by
the
dates
specified.

(
b)
As
specified
in
§
63.9(
b)(
2),
if
you
start
up
your
affected
source
before
[
INSERT
THE
DATE
OF
PUBLICATION
OF
THE
FINAL
RULE
IN
THE
FEDERAL
REGISTER],
you
must
submit
an
Initial
Notification
not
later
than
120
calendar
days
after
[
INSERT
THE
DATE
THE
FINAL
RULE
IS
PUBLISHED
IN
THE
FEDERAL
REGISTER].
The
Initial
Notification
must
include
the
information
required
in
paragraphs
(
b)(
1)
and
(
2)
of
this
section,
as
applicable.

(
1)
If
your
affected
source
has
an
annual
capacity
factor
of
greater
than
10
percent,
your
Initial
Notification
must
include
the
information
required
by
§
63.9(
b)(
2).

(
2)
If
your
affected
source
has
a
federally
enforceable
permit
that
limits
the
annual
capacity
factor
to
less
than
or
equal
to
10
percent
such
that
the
unit
is
in
one
of
the
limited
use
subcategories
(
the
limited
use
solid
fuel
subcategory,
the
limited
use
liquid
fuel
subcategory,
or
the
limited
use
gaseous
fuel
subcategory),

your
Initial
Notification
must
include
the
information
required
by
§
63.9(
b)(
2)
and
also
a
signed
statement
indicating
your
affected
source
has
a
federally
enforceable
permit
that
limits
the
annual
capacity
factor
to
less
than
or
equal
to
10
percent.

(
c)
As
specified
in
§
63.9(
b)(
3),
if
you
start
up
your
new
or
reconstructed
affected
source
on
or
after
[
INSERT
THE
DATE
THE
FINAL
RULE
IS
PUBLISHED
IN
THE
FEDERAL
REGISTER],
you
must
submit
an
Initial
Notification
not
later
than
120
calendar
days
after
you
become
subject
to
this
subpart.
The
Initial
Notification
must
include
the
information
required
in
paragraphs
(
c)(
1)
and
(
2)
of
this
section,
as
applicable.

(
1)
If
your
affected
source
has
an
annual
capacity
factor
of
greater
than
10
percent,
your
Initial
Notification
must
include
the
information
required
by
§
63.9(
b).

(
2)
If
your
affected
source
has
a
federally
enforceable
permit
that
limits
the
annual
capacity
factor
to
less
than
or
equal
to
10
percent
such
that
the
unit
is
in
one
of
the
limited
use
subcategories,
your
Initial
Notification
must
include
the
information
required
by
§
63.9(
b)
and
a
signed
statement
indicating
your
affected
source
has
a
federally
enforceable
permit
that
limits
the
annual
capacity
factor
to
less
than
or
equal
to
10
percent.

(
d)
If
you
are
required
to
conduct
a
performance
test
you
must
submit
a
notification
of
intent
to
conduct
a
performance
test
at
least
30
calendar
days
before
the
performance
test
is
scheduled
to
begin
as
required
in
§
63.7(
b)(
1).

(
e)
If
you
are
required
to
conduct
an
initial
compliance
demonstration
as
specified
in
§
63.7530(
a),
you
must
submit
a
Notification
of
Compliance
Status
according
to
§
63.9(
h)(
2)(
ii).

(
1)
For
each
initial
compliance
demonstration,
you
must
submit
the
Notification
of
Compliance
Status,

including
all
performance
test
results
and
fuel
analyses,

before
the
close
of
business
on
the
60th
calendar
day
following
the
completion
of
the
performance
test
and/
or
other
initial
compliance
demonstrations
according
to
§
63.10(
d)(
2).
The
Notification
of
Compliance
Status
report
must
contain
all
the
information
specified
in
paragraphs
(
e)(
l)(
i)
through
(
ix),
as
applicable.

(
i)
A
description
of
the
affected
source(
s)
including
identification
of
which
subcategory
the
source
is
in,
the
capacity
of
the
source,
a
description
of
the
add­
on
controls
used
on
the
source
description
of
the
fuel(
s)

burned,
and
justification
for
the
fuel(
s)
burned
during
the
performance
test.

(
ii)
Summary
of
the
results
of
all
performance
tests,

fuel
analyses,
and
calculations
conducted
to
demonstrate
initial
compliance
including
all
established
operating
limits.

(
iii)
Identification
of
whether
you
are
complying
with
the
particulate
matter
emission
limit
or
the
alternative
total
selected
metals
emission
limit.

(
iv)
Identification
of
whether
you
plan
to
demonstrate
compliance
with
each
applicable
emission
limit
through
performance
testing
or
fuel
analysis.

(
v)
Identification
of
whether
you
plan
to
demonstrate
compliance
by
emissions
averaging.

(
vi)
A
signed
certification
that
you
have
met
all
applicable
emission
limits
and
work
practice
standards.

(
vii)
A
summary
of
the
carbon
monoxide
emissions
monitoring
data
and
the
maximum
carbon
monoxide
emission
levels
recorded
during
the
performance
test
to
show
that
you
have
met
any
applicable
work
practice
standard
in
Table
1
of
this
subpart.

(
viii)
If
your
new
or
reconstructed
boiler
or
process
heater
is
in
one
of
the
liquid
fuel
subcategories
and
burns
only
liquid
fossil
fuels
other
than
residual
oil
either
alone
or
in
combination
with
gaseous
fuels,
you
must
submit
a
signed
statement
certifying
this
in
your
Notification
of
Compliance
Status
report.

(
ix)
If
you
had
a
deviation
from
any
emission
limit
or
work
practice
standard,
you
must
also
submit
a
description
of
the
deviation,
the
duration
of
the
deviation,
and
the
corrective
action
taken
in
the
Notification
of
Compliance
Status
report.

§
63.7550
What
reports
must
I
submit
and
when?

(
a)
You
must
submit
each
report
in
Table
9
of
this
subpart
that
applies
to
you.

(
b)
Unless
the
Administrator
has
approved
a
different
schedule
for
submission
of
reports
under
§
63.10(
a),
you
must
submit
each
report
by
the
date
in
Table
9
of
this
subpart
and
according
to
the
requirements
in
paragraphs
(
b)(
1)
through
(
5)
of
this
section.

(
1)
The
first
compliance
report
must
cover
the
period
beginning
on
the
compliance
date
that
is
specified
for
your
affected
source
in
§
63.7495
and
ending
on
June
30
or
December
31,
whichever
date
is
the
first
date
that
occurs
at
least
180
days
after
the
compliance
date
that
is
specified
for
your
source
in
§
63.7495.

(
2)
The
first
compliance
report
must
be
postmarked
or
delivered
no
later
than
July
31
or
January
31,
whichever
date
is
the
first
date
following
the
end
of
the
first
calendar
half
after
the
compliance
date
that
is
specified
for
your
source
in
§
63.7495.

(
3)
Each
subsequent
compliance
report
must
cover
the
semiannual
reporting
period
from
January
1
through
June
30
or
the
semiannual
reporting
period
from
July
1
through
December
31.

(
4)
Each
subsequent
compliance
report
must
be
postmarked
or
delivered
no
later
than
July
31
or
January
31,
whichever
date
is
the
first
date
following
the
end
of
the
semiannual
reporting
period.

(
5)
For
each
affected
source
that
is
subject
to
permitting
regulations
pursuant
to
40
CFR
part
70
or
40
CFR
part
71,
and
if
the
permitting
authority
has
established
dates
for
submitting
semiannual
reports
pursuant
to
§
§
70.6(
3)(
iii)(
A)
or
71.6(
3)(
iii)(
A),
you
may
submit
the
first
and
subsequent
compliance
reports
according
to
the
dates
the
permitting
authority
has
established
instead
of
according
to
the
dates
in
paragraphs
(
b)(
1)
through
(
4)
of
this
section.

(
c)
The
compliance
report
must
contain
the
information
required
in
paragraphs
(
c)(
1)
through
(
11)
of
this
section.

(
1)
Company
name
and
address.

(
2)
Statement
by
a
responsible
official
with
that
official's
name,
title,
and
signature,
certifying
the
truth,
accuracy,
and
completeness
of
the
content
of
the
report.

(
3)
Date
of
report
and
beginning
and
ending
dates
of
the
reporting
period.

(
4)
The
total
fuel
use
by
each
affected
source
subject
to
an
emission
limit,
for
each
calendar
month
within
the
semiannual
reporting
period,
including,
but
not
limited
to,
a
description
of
the
fuel
and
the
total
fuel
usage
amount
with
units
of
measure.

(
5)
A
summary
of
the
results
of
the
annual
performance
tests
and
documentation
of
any
operating
limits
that
were
reestablished
during
this
test,
if
applicable.
(
6)
A
signed
statement
indicating
that
you
burned
no
new
types
of
fuel.
Or,
if
you
did
burn
a
new
type
of
fuel,

you
must
submit
the
calculation
of
chlorine
input,
using
Equation
1
of
§
63.7530,
that
demonstrates
that
your
source
is
still
within
its
maximum
chlorine
input
level
established
during
the
previous
performance
testing
(
for
sources
that
demonstrate
compliance
through
performance
testing)
or
you
must
submit
the
calculation
of
hydrogen
chloride
emission
rate
using
Equation
5
of
§
63.7530
that
demonstrates
that
your
source
is
still
meeting
the
emission
limit
for
hydrogen
chloride
emissions
(
for
boilers
or
process
heaters
that
demonstrate
compliance
through
fuel
analysis).
If
you
burned
a
new
type
of
fuel,
you
must
submit
the
calculation
of
total
selected
metals
input,

using
Equation
2
of
§
63.7530,
that
demonstrates
that
your
source
is
still
within
its
maximum
total
selected
metals
input
level
established
during
the
previous
performance
testing
(
for
sources
that
demonstrate
compliance
through
performance
testing)
or
you
must
submit
the
calculation
of
total
selected
metals
emission
rate
using
Equation
6
of
§
63.7530
that
demonstrates
that
your
source
is
still
meeting
the
emission
limit
for
total
selected
metals
emissions
(
for
boilers
or
process
heaters
that
demonstrate
compliance
through
fuel
analysis).
If
you
burned
a
new
type
of
fuel,
you
must
submit
the
calculation
of
mercury
input,
using
Equation
3
of
§
63.7530,
that
demonstrates
that
your
source
is
still
within
its
maximum
mercury
input
level
established
during
the
previous
performance
testing
(
for
sources
that
demonstrate
compliance
through
performance
testing)
or
you
must
submit
the
calculation
of
mercury
emission
rate
using
Equation
7
of
§
63.7530
that
demonstrates
that
your
source
is
still
meeting
the
emission
limit
for
mercury
emissions
(
for
boilers
or
process
heaters
that
demonstrate
compliance
through
fuel
analysis).

(
7)
If
you
wish
to
burn
a
new
type
of
fuel
and
you
can
not
demonstrate
compliance
with
the
maximum
chlorine
input
operating
limit
using
Equation
1
of
§
63.7530,
the
maximum
total
selected
metals
input
operating
limit
using
Equation
2
of
§
63.7530,
or
the
maximum
mercury
input
operating
limit
using
Equation
3
of
§
63.7530,
you
must
include
in
the
compliance
report
a
statement
indicating
the
intent
to
conduct
a
new
performance
test
within
60
days
of
starting
to
burn
the
new
fuel.

(
8)
The
hours
of
operation
for
each
boiler
and
process
heater
that
is
subject
to
an
emission
limit
for
each
calendar
month
within
the
semiannual
reporting
period.
This
requirement
applies
only
to
limited
use
boilers
and
process
heaters.

(
9)
If
you
had
a
startup,
shutdown,
or
malfunction
during
the
reporting
period
and
you
took
actions
consistent
with
your
startup,
shutdown,
and
malfunction
plan,
the
compliance
report
must
include
the
information
in
§
63.10(
d)(
5)(
i).

(
10)
If
there
are
no
deviations
from
any
emission
limits
or
operating
limits
in
this
subpart
that
apply
to
you
and
there
are
no
deviations
from
the
requirements
for
work
practice
standards
in
this
subpart,
a
statement
that
there
were
no
deviations
from
the
emission
limits,

operating
limits,
or
work
practice
standards
during
the
reporting
period.

(
11)
If
there
were
no
periods
during
which
the
continuous
monitoring
systems,
including
continuous
emissions
monitoring
systems,
continuous
opacity
monitoring
systems,
and
operating
parameter
monitoring
systems,
were
out­
of­
control
as
specified
in
§
63.8(
c)(
7),
a
statement
that
there
were
no
periods
during
which
the
continuous
monitoring
systems
were
out­
of­
control
during
the
reporting
period.

(
d)
For
each
deviation
from
an
emission
limit
or
operating
limit
in
this
subpart
and
for
each
deviation
from
the
requirements
for
work
practice
standards
in
this
subpart
that
occurs
at
an
affected
source
where
you
are
not
using
a
continuous
monitoring
systems
to
comply
with
that
emission
limit,
operating
limit,
or
work
practice
standard,

the
compliance
report
must
contain
the
information
in
paragraphs
(
c)(
1)
through
(
10)
of
this
section
and
the
information
required
in
paragraphs
(
d)(
1)
and
(
4)
of
this
section.
This
includes
periods
of
startup,
shutdown,
and
malfunction.

(
1)
The
total
operating
time
of
each
affected
source
during
the
reporting
period.

(
2)
A
description
of
the
deviation
and
which
emission
limit,
operating
limit,
or
work
practice
standard
from
which
you
deviated.

(
3)
Information
on
the
number,
duration,
and
cause
of
deviations
(
including
unknown
cause),
as
applicable,
and
the
corrective
action
taken.

(
4)
A
copy
of
the
test
report
if
the
annual
performance
test
showed
a
deviation
from
the
emission
limit
for
particulate
matter
or
the
alternative
total
selected
metals
limit,
a
deviation
from
the
hydrogen
chloride
emission
limit,
or
a
deviation
from
the
mercury
emission
limit.

(
e)
For
each
deviation
from
an
emission
limitation
and
operating
limit
or
work
practice
standard
in
this
subpart
occurring
at
an
affected
source
where
you
are
using
a
continuous
monitoring
system
to
comply
with
that
emission
limit,
operating
limit,
or
work
practice
standard,
you
must
include
the
information
in
paragraphs
(
c)(
1)
through
(
10)

of
this
section
and
the
information
required
in
paragraphs
(
e)(
1)
through
(
12)
of
this
section.
This
includes
periods
of
startup,
shutdown,
and
malfunction
and
any
deviations
from
your
site­
specific
monitoring
plan
as
required
in
§
63.7505(
d).

(
1)
The
date
and
time
that
each
malfunction
started
and
stopped
and
description
of
the
nature
of
the
deviation
(
i.
e.,
what
you
deviated
from).

(
2)
The
date
and
time
that
each
continuous
monitoring
system
was
inoperative,
except
for
zero
(
low­
level)
and
high­
level
checks.
(
3)
The
date,
time,
and
duration
that
each
continuous
monitoring
system
was
out­
of­
control,
including
the
information
in
§
63.8(
c)(
8).

(
4)
The
date
and
time
that
each
deviation
started
and
stopped,
and
whether
each
deviation
occurred
during
a
period
of
startup,
shutdown,
or
malfunction
or
during
another
period.

(
5)
A
summary
of
the
total
duration
of
the
deviation
during
the
reporting
period
and
the
total
duration
as
a
percent
of
the
total
source
operating
time
during
that
reporting
period.

(
6)
A
breakdown
of
the
total
duration
of
the
deviations
during
the
reporting
period
into
those
that
are
due
to
startup,
shutdown,
control
equipment
problems,

process
problems,
other
known
causes,
and
other
unknown
causes.

(
7)
A
summary
of
the
total
duration
of
continuous
monitoring
systems
downtime
during
the
reporting
period
and
the
total
duration
of
continuous
monitoring
system
downtime
as
a
percent
of
the
total
source
operating
time
during
that
reporting
period.

(
8)
An
identification
of
each
parameter
that
was
monitored
at
the
affected
source
for
which
there
was
a
deviation,
including
opacity,
carbon
monoxide,
and
operating
parameters
for
wet
scrubbers
and
other
control
devices.

(
9)
A
brief
description
of
the
source
for
which
there
was
a
deviation.

(
10)
A
brief
description
of
each
continuous
monitoring
system
for
which
there
was
a
deviation.

(
11)
The
date
of
the
latest
continuous
monitoring
system
certification
or
audit
for
the
system
for
which
there
was
a
deviation.

(
12)
A
description
of
any
changes
in
continuous
monitoring
systems,
processes,
or
controls
since
the
last
reporting
period
for
the
source
for
which
there
was
a
deviation.

(
f)
Each
affected
source
that
has
obtained
a
title
V
operating
permit
pursuant
to
40
CFR
part
70
or
40
CFR
part
71
must
report
all
deviations
as
defined
in
this
subpart
in
the
semiannual
monitoring
report
required
by
§
§
70.6(
3)(
iii)(
A)
or
71.6(
3)(
iii)(
A).
If
an
affected
source
submits
a
compliance
report
pursuant
to
Table
9
of
this
subpart
along
with,
or
as
part
of,
the
semiannual
monitoring
report
required
by
§
§
70.6(
3)(
iii)(
A)
or
71.6(
3)(
iii)(
A),
and
the
compliance
report
includes
all
required
information
concerning
deviations
from
any
emission
limit
operating
limit,
or
work
practice
requirement
in
this
subpart,
submission
of
the
compliance
report
satisfies
any
obligation
to
report
the
same
deviations
in
the
semiannual
monitoring
report.
However,

submission
of
a
compliance
report
does
not
otherwise
affect
any
obligation
the
affected
source
may
have
to
report
deviations
from
permit
requirements
to
the
permit
authority.

(
g)
If
you
operate
a
new
gaseous
fuel
unit
that
is
subject
to
the
work
practice
standard
specified
in
Table
1
of
this
subpart
and
you
intend
to
use
a
fuel
other
than
natural
gas
or
equivalent
to
fire
the
affected
unit,
you
must
submit
a
notification
of
alternative
fuel
use
within
48
hours
of
the
declaration
of
a
period
of
natural
gas
curtailment
or
supply
interruption,
as
defined
in
§
63.7575.

The
notification
must
include
the
information
specified
in
paragraphs
(
g)(
1)
through
(
5)
of
this
section.

(
1)
Company
name
and
address.
(
2)
Identification
of
the
affected
unit.

(
3)
Reason
you
are
unable
to
use
natural
gas
or
equivalent
fuel,
including
the
date
when
the
natural
gas
curtailment
was
declared
or
the
natural
gas
supply
interruption
began.

(
4)
Type
of
alternative
fuel
that
you
intend
to
use.

(
5)
Dates
when
the
alternative
fuel
use
is
expected
to
begin
and
end.

§
63.7555
What
records
must
I
keep?

(
a)
You
must
keep
records
according
to
paragraphs
(
a)(
1)
through
(
3)
of
this
section.

(
1)
A
copy
of
each
notification
and
report
that
you
submitted
to
comply
with
this
subpart,
including
all
documentation
supporting
any
Initial
Notification
or
Notification
of
Compliance
Status
or
semiannual
compliance
report
that
you
submitted,
according
to
the
requirements
in
§
63.10(
b)(
2)(
xiv).

(
2)
The
records
in
§
63.6(
e)(
3)(
iii)
through
(
v)

related
to
startup,
shutdown,
and
malfunction.

(
3)
Records
of
performance
tests,
fuel
analyses,
or
other
compliance
demonstrations,
performance
evaluations,

and
opacity
observations
as
required
in
§
63.10(
b)(
2)(
viii).
(
b)
For
each
continuous
emissions
monitoring
system,

continuous
parameter
monitoring
system,
and
continuous
opacity
monitoring
system,
you
must
keep
records
according
to
paragraphs
(
b)(
1)
through
(
5)
of
this
section.

(
1)
Records
described
in
§
63.10(
b)(
2)(
vi)
through
(
xi).

(
2)
Monitoring
data
for
continuous
opacity
monitoring
system
during
a
performance
evaluation
as
required
in
§
63.6(
h)(
7)(
i)
and
(
ii).

(
3)
Previous
(
i.
e.,
superseded)
versions
of
the
performance
evaluation
plan
as
required
in
§
63.8(
d)(
3).

(
4)
Request
for
alternatives
to
relative
accuracy
test
for
continuous
emissions
monitoring
system
as
required
in
§
63.8(
f)(
6)(
i).

(
5)
Records
of
the
date
and
time
that
each
deviation
started
and
stopped,
and
whether
the
deviation
occurred
during
a
period
of
startup,
shutdown,
or
malfunction
or
during
another
period.

(
c)
You
must
keep
the
records
required
in
Table
8
of
this
subpart
including
records
of
all
monitoring
data
and
calculated
averages
for
applicable
operating
limits
such
as
opacity,
pressure
drop,
carbon
monoxide,
and
pH
to
show
continuous
compliance
with
each
emission
limit,
operating
limit,
and
work
practice
standard
that
applies
to
you.

(
d)
For
each
boiler
or
process
heater
subject
to
an
emission
limit,
you
must
also
keep
the
records
in
paragraphs
(
d)(
1)
through
(
5)
of
this
section.

(
1)
You
must
keep
records
of
monthly
fuel
use
by
each
boiler
or
process
heater,
including
the
type(
s)
of
fuel
and
amount(
s)
used.

(
2)
You
must
keep
records
of
monthly
hours
of
operation
by
each
boiler
or
process
heater.
This
requirement
applies
only
to
limited­
use
boilers
and
process
heaters.

(
3)
A
copy
of
all
calculations
and
supporting
documentation
of
maximum
chlorine
fuel
input,
using
Equation
1
of
§
63.7530,
that
were
done
to
demonstrate
continuous
compliance
with
the
hydrogen
chloride
emission
limit,
for
sources
that
demonstrate
compliance
through
performance
testing.
For
sources
that
demonstrate
compliance
through
fuel
analysis,
a
copy
of
all
calculations
and
supporting
documentation
of
hydrogen
chloride
emission
rates,
using
Equation
5
of
§
63.7530,
that
were
done
to
demonstrate
compliance
with
the
hydrogen
chloride
emission
limit.
Supporting
documentation
should
include
results
of
any
fuel
analyses
and
basis
for
the
estimates
of
maximum
chlorine
fuel
input
or
hydrogen
chloride
emission
rates.
You
can
use
the
results
from
one
fuel
analysis
for
multiple
boilers
and
process
heaters
provided
they
are
all
burning
the
same
fuel
type.
However,

you
must
calculate
chlorine
fuel
input,
or
hydrogen
chloride
emission
rate,
for
each
boiler
and
process
heater.

(
4)
A
copy
of
all
calculations
and
supporting
documentation
of
maximum
total
selected
metals
fuel
input,

using
Equation
2
of
§
63.7530,
that
were
done
to
demonstrate
continuous
compliance
with
the
total
selected
metals
emission
limit
for
sources
that
demonstrate
compliance
through
performance
testing.
For
sources
that
demonstrate
compliance
through
fuel
analysis,
a
copy
of
all
calculations
and
supporting
documentation
of
total
selected
metals
emission
rates,
using
Equation
6
of
§
63.7530,
that
were
done
to
demonstrate
compliance
with
the
total
selected
metals
emission
limit.
Supporting
documentation
should
include
results
of
any
fuel
analyses
and
basis
for
the
estimates
of
maximum
total
selected
metals
fuel
input
or
total
selected
metals
emission
rates.
You
can
use
the
results
from
one
fuel
analysis
for
multiple
boilers
and
process
heaters
provided
they
are
all
burning
the
same
fuel
type.
However,
you
must
calculate
total
selected
metals
fuel
input,
or
total
selected
metals
emission
rates,
for
each
boiler
and
process
heater.

(
5)
A
copy
of
all
calculations
and
supporting
documentation
of
maximum
mercury
fuel
input,
using
Equation
3
of
§
63.7530,
that
were
done
to
demonstrate
continuous
compliance
with
the
mercury
emission
limit
for
sources
that
demonstrate
compliance
through
performance
testing.
For
sources
that
demonstrate
compliance
through
fuel
analysis,

a
copy
of
all
calculations
and
supporting
documentation
of
mercury
emission
rates,
using
Equation
7
of
§
63.7530,
that
were
done
to
demonstrate
compliance
with
the
mercury
emission
limit.
Supporting
documentation
should
include
results
of
any
fuel
analyses
and
basis
for
the
estimates
of
maximum
mercury
fuel
input
or
mercury
emission
rates.
You
can
use
the
results
from
one
fuel
analysis
for
multiple
boilers
and
process
heaters
provided
they
are
all
burning
the
same
fuel
type.
However,
you
must
calculate
mercury
fuel
input,
or
mercury
emission
rates,
for
each
boiler
and
process
heater.
(
e)
If
your
boiler
or
process
heater
is
subject
to
an
emission
limit
or
work
practice
standard
in
Table
1
of
this
subpart
and
has
a
federally
enforceable
permit
that
limits
the
annual
capacity
factor
to
less
than
or
equal
to
10
percent
such
that
the
unit
is
in
one
of
the
limited
use
subcategories,
you
must
keep
the
records
in
paragraphs
(
e)(
1)
and
(
2)
of
this
section.

(
1)
A
copy
of
the
federally
enforceable
permit
that
limits
the
annual
capacity
factor
of
the
source
to
less
than
or
equal
to
10
percent.

(
2)
Fuel
use
records
for
the
days
the
boiler
or
process
heater
was
operating.

§
63.7560
In
what
form,
and
how
long
must
I
keep
my
records?

(
a)
Your
records
must
be
in
a
form
suitable
and
readily
available
for
expeditious
review,
according
to
§
63.10(
b)(
1).

(
b)
As
specified
in
§
63.10(
b)(
1),
you
must
keep
each
record
for
5
years
following
the
date
of
each
occurrence,

measurement,
maintenance,
corrective
action,
report,
or
record.

(
c)
You
must
keep
each
record
on
site
for
at
least
2
years
after
the
date
of
each
occurrence,
measurement,

maintenance,
corrective
action,
report,
or
record,

according
to
§
63.10(
b)(
1).
You
can
keep
the
records
off
site
for
the
remaining
3
years.

Other
Requirements
and
Information
§
63.7565
What
parts
of
the
General
Provisions
apply
to
me?

(
a)
Table
10
of
this
subpart
shows
which
parts
of
the
General
Provisions
in
§
§
63.1
through
63.15
apply
to
you.

§
63.7570
Who
implements
and
enforces
this
subpart?

(
a)
This
subpart
can
be
implemented
and
enforced
by
U.
S.
EPA,
or
a
delegated
authority
such
as
your
State,

local,
or
tribal
agency.
If
the
Administrator
has
delegated
authority
to
your
State,
local,
or
tribal
agency,

then
that
agency
(
as
well
as
the
U.
S.
EPA)
has
the
authority
to
implement
and
enforce
this
subpart.
You
should
contact
your
EPA
Regional
Office
to
find
out
if
this
subpart
is
delegated
to
your
State,
local,
or
tribal
agency.

(
b)
In
delegating
implementation
and
enforcement
authority
of
this
subpart
to
a
State,
local,
or
tribal
agency
under
section
40
CFR
part
63,
subpart
E,
the
authorities
listed
in
paragraphs
(
b)(
1)
through
(
5)
of
this
section
are
retained
by
the
U.
S.
Administrator
and
are
not
transferred
to
the
State,
local,
or
tribal
agency,
however,

the
U.
S.
EPA
retains
oversight
of
this
regulation
and
can
take
enforcement
actions,
as
appropriate.

(
1)
Approval
of
alternatives
to
the
non­
opacity
emission
limits
and
work
practice
standards
in
§
63.7500(
a)

through
(
c)
under
§
63.6(
g).

(
2)
Approval
of
alternative
opacity
emission
limits
in
§
63.7500(
a)
under
§
63.6(
h)(
9).

(
3)
Approval
of
major
alternatives
to
test
methods
in
Table
5
of
this
subpart
under
§
63.7(
e)(
2)(
ii)
and
(
f)
and
as
defined
in
§
63.90.

(
4)
Approval
of
major
alternatives
to
monitoring
under
§
63.8(
f)
and
as
defined
in
§
63.90.

(
5)
Approval
of
major
alternatives
to
recordkeeping
and
reporting
under
§
63.10(
f)
and
as
defined
in
§
63.90.

§
63.7575
What
definitions
apply
to
this
subpart?

Terms
used
in
this
subpart
are
defined
in
the
Clean
Air
Act,
in
§
63.2
of
subpart
A
of
this
part,
(
the
General
Provisions),
and
in
this
section
as
follows:

Annual
capacity
factor
means
the
ratio
between
the
actual
heat
input
to
a
boiler
or
process
heater
from
the
fuels
burned
during
a
calendar
year
and
the
potential
heat
input
to
the
boiler
or
process
heater
had
it
been
operated
for
8,760
hours
during
a
calendar
year
at
the
maximum
steady
state
design
heat
input
capacity.

Bag
leak
detection
system
means
an
instrument
that
is
capable
of
monitoring
particulate
matter
loadings
in
the
exhaust
of
a
fabric
filter
(
i.
e.,
baghouse)
in
order
to
detect
bag
failures.
A
bag
leak
detection
system
includes,

but
is
not
limited
to,
an
instrument
that
operates
on
electrodynamic,
triboelectric,
light
scattering,
light
transmittance,
or
other
principle
to
monitor
relative
particulate
matter
loadings.

Biomass
fuel
means
unadulterated
wood
as
defined
in
this
subpart,
wood
residue,
and
wood
products
(
e.
g.,
trees,

tree
stumps,
tree
limbs,
bark,
lumber,
sawdust,
sanderdust,

chips,
scraps,
slabs,
millings,
and
shavings);
animal
litter;
vegetative
agricultural
and
silvicultural
materials,
such
as
logging
residues
(
slash),
nut
and
grain
hulls
and
chaff
(
e.
g.,
almond,
walnut,
peanut,
rice,
and
wheat),
bagasse,
orchard
prunings,
corn
stalks,
coffee
bean
hulls
and
grounds.

Blast
furnace
gas
fuel­
fired
boiler
or
process
heater
means
an
industrial/
commercial/
institutional
boiler
or
process
heater
that
receives
90
percent
or
more
of
its
total
heat
input
(
based
on
an
annual
average)
from
blast
furnace
gas.

Boiler
means
an
enclosed
device
using
controlled
flame
combustion
and
having
the
primary
purpose
of
recovering
thermal
energy
in
the
form
of
steam
or
hot
water.
Waste
heat
boilers
are
excluded
from
this
definition.

Coal
means
all
solid
fuels
classifiable
as
anthracite,

bituminous,
sub­
bituminous,
or
lignite
by
the
American
Society
for
Testing
and
Materials
in
ASTM
D388­
77,

"
Standard
Specification
for
Classification
of
Coals
by
Rank,"
coal
refuse,
and
petroleum
coke.
Synthetic
fuels
derived
from
coal
for
the
purpose
of
creating
useful
heat,

including
but
not
limited
to,
solvent­
refined
coal,

coaloil
mixtures,
and
coal­
water
mixtures,
are
included
in
this
definition
for
the
purposes
of
this
subpart.
Coal
derived
gases
are
excluded
from
this
definition.

Coal
refuse
means
any
by­
product
of
coal
mining
or
coal
cleaning
operations
with
an
ash
content
greater
than
50
percent
(
by
weight)
and
a
heating
value
less
than
13,900
kilojoules
per
kilogram
(
6,000
Btu
per
pound)
on
a
dry
basis.

Commercial/
Institutional
boiler
means
a
boiler
used
in
commercial
establishments
or
institutional
establishments
such
as
medical
centers,
research
centers,
institutions
of
higher
education,
hotels,
and
laundries
to
provide
electricity,
steam,
and/
or
hot
water.

Construction/
demolition
material
means
waste
building
material
that
result
from
the
construction
or
demolition
operations
on
houses
and
commercial
and
industrial
buildings.

Deviation
means
any
instance
in
which
an
affected
source
subject
to
this
subpart,
or
an
owner
or
operator
of
such
a
source:

(
1)
Fails
to
meet
any
requirement
or
obligation
established
by
this
subpart,
including
but
not
limited
to
any
emission
limit,
operating
limit,
or
work
practice
standard;

(
2)
Fails
to
meet
any
term
or
condition
that
is
adopted
to
implement
an
applicable
requirement
in
this
subpart
and
that
is
included
in
the
operating
permit
for
any
affected
source
required
to
obtain
such
a
permit;
or
(
3)
Fails
to
meet
any
emission
limit,
operating
limit,
or
work
practice
standard
in
this
subpart
during
startup,
shutdown,
or
malfunction,
regardless
or
whether
or
not
such
failure
is
permitted
by
this
subpart.

Distillate
oil
means
fuel
oils,
including
recycled
oils,
that
comply
with
the
specifications
for
fuel
oil
numbers
1
and
2,
as
defined
by
the
American
Society
for
Testing
and
Materials
in
ASTM
D396­
02a,
"
Standard
Specifications
for
Fuel
Oils."

Dry
scrubber
means
an
add­
on
air
pollution
control
system
that
injects
dry
alkaline
sorbent
(
dry
injection)
or
sprays
an
alkaline
sorbent
(
spray
dryer)
to
react
with
and
neutralize
acid
gas
in
the
exhaust
stream
forming
a
dry
powder
material.
Sorbent
injection
systems
in
fluidized
bed
boilers
and
process
heaters
are
included
in
this
definition.

Electric
utility
steam
generating
unit
means
a
fossil
fuel­
fired
combustion
unit
of
more
than
25
megawatts
that
serves
a
generator
that
produces
electricity
for
sale.
A
unit
that
cogenerates
steam
and
electricity
and
supplies
more
than
one­
third
of
its
potential
electric
output
capacity
and
more
than
25
megawatts
electrical
output
to
any
utility
power
distribution
system
for
sale
is
considered
an
electric
utility
steam
generating
unit.

Electrostatic
precipitator
means
an
add­
on
air
pollution
control
device
used
to
capture
particulate
matter
by
charging
the
particles
using
an
electrostatic
field,

collecting
the
particles
using
a
grounded
collecting
surface,
and
transporting
the
particles
into
a
hopper.

Fabric
filter
means
an
add­
on
air
pollution
control
device
used
to
capture
particulate
matter
by
filtering
gas
streams
through
filter
media,
also
known
as
a
baghouse.

Federally
enforceable
means
all
limitations
and
conditions
that
are
enforceable
by
the
Administrator,

including
the
requirements
of
40
CFR
part
60
and
61,

requirements
within
any
applicable
State
Implementation
Plan,
and
any
permit
requirements
established
under
§
52.21
or
under
§
§
51.18
and
51.24.

Firetube
boiler
means
a
boiler
in
which
hot
gases
of
combustion
pass
through
the
tubes
and
water
contacts
the
outside
surfaces
of
the
tubes.

Fuel
type
means
each
category
of
fuels
that
share
a
common
name
or
classification.
Examples
include,
but
are
not
limited
to:
bituminous
coal,
subbituminous
coal,

lignite,
anthracite,
biomass,
construction/
demolition
material,
salt
water
laden
wood,
creosote
treated
wood,

tires,
residual
oil.
Individual
fuel
types
received
from
different
suppliers
are
not
considered
new
fuel
types
except
for
construction/
demolition
material.

Fossil
fuel
means
natural
gas,
petroleum,
coal,
and
any
form
of
solid,
liquid,
or
gaseous
fuel
derived
from
such
materials.

Gaseous
fuel
includes,
but
is
not
limited
to,
natural
gas,
process
gas,
landfill
gas,
coal
derived
gas,
refinery
gas,
and
biogas.
Blast
furnace
gas
is
exempted
from
this
definition.

Heat
input
means
heat
derived
from
combustion
of
fuel
in
a
boiler
or
process
heater
and
does
not
include
the
heat
input
from
preheated
combustion
air,
recirculated
flue
gases,
or
exhaust
gases
from
other
sources
such
as
gas
turbines,
internal
combustion
engines,
kilns,
etc.

Hot
water
heater
means
a
closed
vessel
with
a
capacity
of
no
more
than
120
U.
S.
gallons
in
which
water
is
heated
by
combustion
of
gaseous
or
liquid
fuel
and
is
withdrawn
for
use
external
to
the
vessel
at
pressures
not
exceeding
160
psig,
including
the
apparatus
by
which
the
heat
is
generated
and
all
controls
and
devices
necessary
to
prevent
water
temperatures
from
exceeding
210

F
(
99

C).

Industrial
boiler
means
a
boiler
used
in
manufacturing,
processing,
mining,
and
refining
or
any
other
industry
to
provide
steam,
hot
water,
and/
or
electricity.

Large
gaseous
fuel
subcategory
includes
any
watertube
boiler
or
process
heater
that
burns
gaseous
fuels
not
combined
with
any
solid
fuels,
burns
liquid
fuel
only
during
periods
of
gas
curtailment
or
gas
supply
emergencies,
has
a
rated
capacity
of
greater
than
10
MMBtu
per
hour
heat
input,
and
has
an
annual
capacity
factor
of
greater
than
10
percent.

Large
liquid
fuel
subcategory
includes
any
watertube
boiler
or
process
heater
that
does
not
burn
any
solid
fuel
and
burns
any
liquid
fuel
either
alone
or
in
combination
with
gaseous
fuels,
has
a
rated
capacity
of
greater
than
10
MMBtu
per
hour
heat
input,
and
has
an
annual
capacity
factor
of
greater
than
10
percent.
Large
gaseous
fuelfired
boilers
and
process
heaters
that
burn
liquid
fuel
during
periods
of
gas
curtailment
or
gas
supply
emergencies
are
not
included
in
this
definition.

Large
solid
fuel
subcategory
includes
any
watertube
boiler
or
process
heater
that
burns
any
amount
of
solid
fuel
either
alone
or
in
combination
with
liquid
or
gaseous
fuels,
has
a
rated
capacity
of
greater
than
10
MMBtu
per
hour
heat
input,
and
has
an
annual
capacity
factor
of
greater
than
10
percent.

Liquid
fossil
fuel
means
petroleum,
distillate
oil,

residual
oil
and
any
form
of
liquid
fuel
derived
from
such
material.

Liquid
fuel
includes,
but
is
not
limited
to,

distillate
oil,
residual
oil,
waste
oil,
and
process
liquids.

Limited
use
gaseous
fuel
subcategory
includes
any
watertube
boiler
or
process
heater
that
burns
gaseous
fuels
not
combined
with
any
liquid
or
solid
fuels,
burns
liquid
fuel
only
during
periods
of
gas
curtailment
or
gas
supply
emergencies,
has
a
rated
capacity
of
greater
than
10
MMBtu
per
hour
heat
input,
and
has
a
federally
enforceable
annual
average
capacity
factor
of
equal
to
or
less
than
10
percent.

Limited
use
liquid
fuel
subcategory
includes
any
watertube
boiler
or
process
heater
that
does
not
burn
any
solid
fuel
and
burns
any
liquid
fuel
either
alone
or
in
combination
with
gaseous
fuels,
has
a
rated
capacity
of
greater
than
10
MMBtu
per
hour
heat
input,
and
has
a
federally
enforceable
annual
average
capacity
factor
of
equal
to
or
less
than
10
percent.
Limited
use
gaseous
fuel­
fired
boilers
and
process
heaters
that
burn
liquid
fuel
during
periods
of
gas
curtailment
or
gas
supply
emergencies
are
not
included
in
this
definition.

Limited
use
solid
fuel
subcategory
includes
any
watertube
boiler
or
process
heater
that
burns
any
amount
of
solid
fuel
either
alone
or
in
combination
with
liquid
or
gaseous
fuels,
has
a
rated
capacity
of
greater
than
10
MMBtu
per
hour
heat
input,
and
has
a
federally
enforceable
annual
average
capacity
factor
of
equal
to
or
less
than
10
percent.

Minimum
pressure
drop
means
90
percent
of
the
lowest
test­
run
average
pressure
drop
measured
according
to
Table
7
of
this
subpart
during
the
most
recent
performance
test
demonstrating
compliance
with
the
applicable
emission
limit.

Minimum
scrubber
effluent
pH
means
90
percent
of
the
lowest
test­
run
average
effluent
pH
measured
at
the
outlet
of
the
wet
scrubber
according
to
Table
7
of
this
subpart
during
the
most
recent
performance
test
demonstrating
compliance
with
the
applicable
hydrogen
chloride
emission
limit.

Minimum
scrubber
flow
rate
means
90
percent
of
the
lowest
test­
run
average
flow
rate
measured
according
to
Table
7
of
this
subpart
during
the
most
recent
performance
test
demonstrating
compliance
with
the
applicable
emission
limit.

Minimum
sorbent
flow
rate
means
90
percent
of
the
lowest
test­
run
average
sorbent
(
or
activated
carbon)
flow
rate
measured
according
to
Table
7
of
this
subpart
during
the
most
recent
performance
test
demonstrating
compliance
with
the
applicable
emission
limits.

Minimum
voltage
or
amperage
means
90
percent
of
the
lowest
test­
run
average
voltage
or
amperage
to
the
electrostatic
precipitator
measured
according
to
Table
7
of
this
subpart
during
the
most
recent
performance
test
demonstrating
compliance
with
the
applicable
emission
limits.

Natural
gas
means:

(
1)
A
naturally
occurring
mixture
of
hydrocarbon
and
nonhydrocarbon
gases
found
in
geologic
formations
beneath
the
earth's
surface,
of
which
the
principal
constituent
is
methane;
or
(
2)
Liquid
petroleum
gas,
as
defined
by
the
American
Society
for
Testing
and
Materials
in
ASTM
D1835­
82,

"
Standard
Specification
for
Liquid
Petroleum
Gases."

Opacity
means
the
degree
to
which
emissions
reduce
the
transmission
of
light
and
obscure
the
view
of
an
object
in
the
background.

Particulate
matter
means
any
finely
divided
solid
or
liquid
material,
other
than
uncombined
water,
as
measured
by
the
test
methods
specified
under
this
subpart,
or
an
alternative
method.

Period
of
natural
gas
curtailment
or
supply
interruption
means
a
period
of
time
during
which
the
supply
of
natural
gas
to
an
affected
facility
is
halted
for
reasons
beyond
the
control
of
the
facility.
An
increase
in
the
cost
or
unit
price
of
natural
gas
does
not
constitute
a
period
of
natural
gas
curtailment
or
supply
interruption.

Process
heater
means
an
enclosed
device
using
controlled
flame,
that
is
not
a
boiler,
and
the
unit's
primary
purpose
is
to
transfer
heat
indirectly
to
a
process
material
(
liquid,
gas,
or
solid)
or
to
a
heat
transfer
material
for
use
in
a
process
unit,
instead
of
generating
steam.
Process
heaters
are
devices
in
which
the
combustion
gases
do
not
directly
come
into
contact
with
process
materials.
Process
heaters
do
not
include
units
used
for
comfort
heat
or
space
heat,
food
preparation
for
on­
site
consumption,
or
autoclaves.

Residual
oil
means
crude
oil,
and
all
fuel
oil
numbers
4,
5
and
6,
as
defined
by
the
American
Society
for
Testing
and
Materials
in
ASTM
D396­
02a,
"
Standard
Specifications
for
Fuel
Oils."

Responsible
official
means
responsible
official
as
defined
in
§
70.2.

Small
gaseous
fuel
subcategory
includes
any
firetube
boiler
that
burns
gaseous
fuels
not
combined
with
any
solid
fuels
and
burns
liquid
fuel
only
during
periods
of
gas
curtailment
or
gas
supply
emergencies,
and
any
boiler
or
process
heater
that
burns
gaseous
fuels
not
combined
with
any
solid
fuels,
burns
liquid
fuel
only
during
periods
of
gas
curtailment
or
gas
supply
emergencies,
and
has
a
rated
capacity
of
less
than
or
equal
to
10
MMBtu
per
hour
heat
input.

Small
liquid
fuel
subcategory
includes
any
firetube
boiler
that
does
not
burn
any
solid
fuel
and
burns
any
liquid
fuel
either
alone
or
in
combination
with
gaseous
fuels,
and
any
boiler
or
process
heater
that
does
not
burn
any
solid
fuel
and
burns
any
liquid
fuel
either
alone
or
in
combination
with
gaseous
fuels,
and
has
a
rated
capacity
of
less
than
or
equal
to
10
MMBtu
per
hour
heat
input.
Small
gaseous
fuel­
fired
boilers
and
process
heaters
that
burn
liquid
fuel
during
periods
of
gas
curtailment
or
gas
supply
emergencies
are
not
included
in
this
definition.

Small
solid
fuel
subcategory
includes
any
firetube
boiler
that
burns
any
amount
of
solid
fuel
either
alone
or
in
combination
with
liquid
or
gaseous
fuels,
and
any
other
boiler
or
process
heater
that
burns
any
amount
of
solid
fuel
either
alone
or
in
combination
with
liquid
or
gaseous
fuels
and
has
a
rated
capacity
of
less
than
or
equal
to
10
MMBtu
per
hour
heat
input.

Solid
fuel
includes,
but
is
not
limited
to,
coal,

wood,
biomass,
tires,
plastics,
and
other
nonfossil
solid
materials.

Temporary
boiler
means
any
gaseous
or
liquid
fuelfired
boiler
that
is
designed,
and
is
capable
of,
being
carried
or
moved
from
one
location
to
another.
A
temporary
boiler
that
remains
at
a
location
for
more
than
180
consecutive
days
is
no
longer
considered
to
be
a
temporary
boiler.
Any
temporary
boiler
that
replaces
a
temporary
boiler
at
a
location
and
is
intended
to
perform
the
same
or
similar
function
will
be
included
in
calculating
the
consecutive
time
period.

Total
selected
metals
means
the
combination
of
the
following
metallic
HAP:
arsenic,
beryllium,
cadmium,

chromium,
lead,
manganese,
nickel
and
selenium.
[
Need
to
revise
to
address
manganese
risk
offramp.]

Unadulterated
wood
means
wood
or
wood
products
that
have
not
been
painted,
pigment­
stained,
or
pressure
treated
with
compounds
such
as
chromate
copper
arsenate,

pentachlorophenol,
and
creosote.
Plywood,
particle
board,

oriented
strand
board,
and
other
types
of
wood
products
bound
by
glues
and
resins
are
included
in
this
definition.

Watertube
boiler
means
a
boiler
in
which
water
passes
through
the
tubes
and
hot
gases
of
combustion
pass
over
the
outside
surfaces
of
the
tubes.

Waste
heat
boiler
means
a
device
that
recovers
normally
unused
energy
and
converts
it
to
usable
heat.

Waste
heat
boilers
incorporating
duct
or
supplemental
burners
that
are
designed
to
supply
50
percent
or
more
of
the
total
rated
heat
input
capacity
of
the
waste
heat
boiler
are
not
considered
waste
heat
boilers,
but
are
considered
boilers.
Waste
heat
boilers
are
also
referred
to
as
heat
recovery
steam
generators.

Wet
scrubber
means
any
add­
on
air
pollution
control
device
that
mixes
an
aqueous
stream
or
slurry
with
the
exhaust
gases
from
a
boiler
or
process
heater
to
control
emissions
of
particulate
matter
and/
or
to
absorb
and
neutralize
acid
gases,
such
as
hydrogen
chloride.

Work
practice
standard
means
any
design,
equipment,

work
practice,
or
operational
standard,
or
combination
thereof,
that
is
promulgated
pursuant
to
section
112(
h)
of
the
Clean
Air
Act.
Tables
to
Subpart
DDDDD
of
Part
63
Table
1
to
Subpart
DDDDD
of
Part
63
 
Emission
Limits
and
Work
Practice
Standards
As
stated
in
§
63.7500,
you
must
comply
with
the
following
applicable
emission
limits:

If
your
boiler
or
process
heater
is
in
this
subcategory...
For
the
following
pollutants...
You
must
meet
the
following
emission
limits
and
work
practice
standards...

1.
New
or
reconstructed
large
solid
fuel­
fired
a.
Particulate
Matter
(
OR
Total
Selected
Metals)

b.
Hydrogen
Chloride
c.
Mercury
d.
Carbon
Monoxide
0.025
lb
per
MMBtu
of
heat
input
(
0.0001
lb
per
MMBtu/
hr
of
heat
input)

0.02
lb
per
MMBtu
of
heat
input
0.000003
lb
per
MMBtu
of
heat
input
400
ppm
by
volume
on
a
dry
basis
corrected
to
7
percent
oxygen
85
If
your
boiler
or
process
heater
is
in
this
subcategory...
For
the
following
pollutants...
You
must
meet
the
following
emission
limits
and
work
practice
standards...

2.
New
or
reconstructed
limited
use
solid
fuelfired
a.
Particulate
Matter
(
OR
Total
Selected
Metals)

b.
Hydrogen
Chloride
c.
Mercury
d.
Carbon
Monoxide
0.025
lb
per
MMBtu
of
heat
input
(
0.0001
lb
per
MMBtu/
hr
of
heat
input)

0.02
lb
per
MMBtu
of
heat
input
0.000003
lb
per
MMBtu
of
heat
input
400
ppm
by
volume
on
a
dry
basis
corrected
to
7
percent
oxygen
3.
New
or
reconstructed
small
solid
fuel­
fired
a.
Particulate
Matter
(
OR
Total
Selected
Metals)

b.
Hydrogen
Chloride
c.
Mercury
0.025
lb
per
MMBtu
of
heat
input
(
0.0001
lb
per
MMBtu/
hr
of
heat
input)

0.02
lb
per
MMBtu
of
heat
input
0.000003
lb
per
MMBtu
of
heat
input
4.
New
or
reconstructed
large
liquid
fuel­
fired
a.
Particulate
Matter
b.
Hydrogen
Chloride
c.
Carbon
Monoxide
0.03
lb
per
MMBtu
of
heat
input
0.0005
lb
per
MMBtu
of
heat
input
400
ppm
by
volume
on
a
dry
basis
corrected
to
3
percent
oxygen
86
If
your
boiler
or
process
heater
is
in
this
subcategory...
For
the
following
pollutants...
You
must
meet
the
following
emission
limits
and
work
practice
standards...

5.
New
or
reconstructed
limited
use
liquid
fuelfired
a.
Particulate
Matter
b.
Hydrogen
Chloride
c.
Carbon
Monoxide
0.03
lb
per
MMBtu
of
heat
input
0.0009
lb
per
MMBtu
of
heat
input
400
ppm
by
volume
on
a
dry
basis
corrected
to
3
percent
oxygen
6.
New
or
reconstructed
small
liquid
fuel­
fired
a.
Particulate
Matter
b.
Hydrogen
Chloride
0.03
lb
per
MMBtu
of
heat
input
0.0009
lb
per
MMBtu
of
heat
input
7.
New
or
reconstructed
large
gaseous
fuel­
fired
a.
Carbon
Monoxide
400
ppm
by
volume
on
a
dry
basis
corrected
to
3
percent
oxygen
8.
New
or
reconstructed
limited
use
gaseous
fuelfired
a.
Carbon
Monoxide
400
ppm
by
volume
on
a
dry
basis
corrected
to
3
percent
oxygen
87
If
your
boiler
or
process
heater
is
in
this
subcategory...
For
the
following
pollutants...
You
must
meet
the
following
emission
limits
and
work
practice
standards...

9.
Existing
large
solid
fuelfired
a.
Particulate
Matter
(
OR
Total
Selected
Metals)

b.
Hydrogen
Chloride
c.
Mercury
0.07
lb
per
MMBtu
of
heat
input
(
0.001
lb
per
MMBtu/
hr
of
heat
input)

0.09
lb
per
MMBtu
of
heat
input
0.000009
lb
per
MMBtu
of
heat
input
10.
Existing
limited
use
solid
fuelfired
a.
Particulate
Matter
(
OR
Total
Selected
Metals)
0.21
lb
per
MMBtu
of
heat
input
(
0.004
lb
per
MMBtu/
hr
of
heat
input)
88
Table
2
to
Subpart
DDDDD
of
Part
63
 
Operating
Limits
for
Boilers
and
Process
Heaters
with
Particulate
Matter
Emission
Limits
As
stated
in
§
63.7500,
you
must
comply
with
the
applicable
operating
limits:

If
you
demonstrate
compliance
with
applicable
particulate
matter
emission
limits
using...
You
must
meet
these
operating
limits...

1.
Wet
scrubber
control
a.
Maintain
the
minimum
pressure
drop
and
liquid
flow­
rate
at
or
above
the
operating
levels
established
during
the
performance
test
according
to
§
63.7530(
c)
and
Table
7
of
this
subpart
that
demonstrated
compliance
with
the
applicable
emission
limit
for
particulate
matter.

2.
Fabric
filter
control
a.
Install
and
operate
a
bag
leak
detection
system
according
to
§
63.7525
and
operate
the
fabric
filter
such
that
the
bag
leak
detection
system
alarm
does
not
sound
more
than
5
percent
of
the
operating
time
during
each
6­
month
period;
OR
b.
This
option
is
for
boilers
and
process
heaters
that
operate
dry
control
systems.
Existing
boilers
and
process
heaters
must
maintain
opacity
to
less
than
or
equal
to
20
percent
(
6­
minute
average)
except
for
one
6­
minute
period
per
hour
of
not
more
than
27
percent.
New
boilers
and
process
heaters
must
maintain
opacity
to
less
than
or
equal
to
10
percent
opacity
(
1­
hour
block
average).
89
If
you
demonstrate
compliance
with
applicable
particulate
matter
emission
limits
using...
You
must
meet
these
operating
limits...

3.
Electrostatic
precipitator
control
a.
This
option
is
for
boilers
and
process
heaters
that
operate
dry
control
systems.
Existing
boilers
and
process
heaters
must
maintain
opacity
to
less
than
or
equal
to
20
percent
(
6­
minute
average)
except
for
one
6­
minute
period
per
hour
of
not
more
than
27
percent.
New
boilers
and
process
heaters
must
maintain
opacity
to
less
than
or
equal
to
10
percent
opacity
(
1­
hour
block
average).;
OR
b.
This
option
is
only
for
boilers
and
process
heaters
that
operate
additional
wet
control
systems.
Maintain
the
minimum
voltage
and
secondary
current
or
total
power
input
of
the
electrostatic
precipitator
at
or
above
the
operating
limits
established
during
the
performance
test
according
to
§
63.7530(
c)
and
Table
7
of
this
subpart
that
demonstrated
compliance
with
the
applicable
emission
limit
for
particulate
matter.

4.
Any
other
control
type
This
option
is
for
boilers
and
process
heaters
that
operate
dry
control
systems.
Existing
boilers
and
process
heaters
must
maintain
opacity
to
less
than
or
equal
to
20
percent
(
6­
minute
average)
except
for
one
6­
minute
period
per
hour
of
not
more
than
27
percent.
New
boilers
and
process
heaters
must
maintain
opacity
to
less
than
or
equal
to
10
percent
opacity
(
1­
hour
block
average).
90
Table
3
to
Subpart
DDDDD
of
Part
63
 
Operating
Limits
for
Boilers
and
Process
Heaters
With
Mercury
Emission
Limits
and
Boilers
and
Process
Heaters
That
Choose
the
Alternative
Total
Selected
Metals
Emission
Limits
As
stated
in
§
63.7500,
you
must
comply
with
the
applicable
operating
limits:

If
you
demonstrate
compliance
with
applicable
mercury
and/
or
total
selected
metals
emission
limits
using...
You
must
meet
these
operating
limits...

1.
Wet
scrubber
control
Maintain
the
minimum
pressure
drop
and
liquid
flow­
rate
at
or
above
the
operating
levels
established
during
the
performance
test
according
to
§
63.7530(
c)
and
Table
7
of
this
subpart
that
demonstrated
compliance
with
the
applicable
emission
limits
for
mercury
and/
or
total
selected
metals.

2.
Fabric
filter
control
a.
Install
and
operate
a
bag
leak
detection
system
according
to
§
63.7525
and
operate
the
fabric
filter
such
that
the
bag
leak
detection
system
alarm
does
not
sound
more
than
5
percent
of
the
operating
time
during
a
6­
month
period;
OR
b.
This
option
is
for
boilers
and
process
heaters
that
operate
dry
control
systems.
Existing
sources
must
maintain
opacity
to
less
than
or
equal
to
20
percent
(
6­
minute
average)
except
for
one
6­
minute
period
per
hour
of
not
more
than
27
percent.
New
sources
must
maintain
opacity
to
less
than
or
equal
to
10
percent
opacity
(
1­
hour
block
average).
91
If
you
demonstrate
compliance
with
applicable
mercury
and/
or
total
selected
metals
emission
limits
using...
You
must
meet
these
operating
limits...

3.
Electrostatic
precipitator
control
a.
This
option
is
for
boilers
and
process
heaters
that
operate
dry
control
systems.
Existing
sources
must
maintain
opacity
to
less
than
or
equal
to
20
percent
(
6­
minute
average)
except
for
one
6­
minute
period
per
hour
of
not
more
than
27
percent.
New
sources
must
maintain
opacity
to
less
than
or
equal
to
10
percent
opacity
(
1­
hour
block
average).;
OR
b.
This
option
is
only
for
boilers
and
process
heaters
that
operate
additional
wet
control
systems.
Maintain
the
minimum
voltage
and
secondary
current
or
total
power
input
of
the
electrostatic
precipitator
at
or
above
the
operating
limits
established
during
the
performance
test
according
to
§
63.7530(
c)
and
Table
7
of
this
subpart
that
demonstrated
compliance
with
the
applicable
emission
limits
for
mercury
and/
or
total
selected
metals.

4.
Dry
scrubber
or
carbon
injection
control
Maintain
the
minimum
sorbent
or
carbon
injection
rate
at
or
above
the
operating
levels
established
during
the
performance
test
according
to
§
63.7530(
c)
and
Table
7
of
this
subpart
that
demonstrated
compliance
with
the
applicable
emission
limit
for
mercury.
92
If
you
demonstrate
compliance
with
applicable
mercury
and/
or
total
selected
metals
emission
limits
using...
You
must
meet
these
operating
limits...

5.
Any
other
control
type
This
option
is
only
for
boilers
and
process
heaters
that
operate
dry
control
systems.
Existing
sources
must
maintain
opacity
to
less
than
or
equal
to
20
percent
(
6­
minute
average)
except
for
one
6­
minute
period
per
hour
of
not
more
than
27
percent.
New
sources
must
maintain
opacity
to
less
than
or
equal
to
10
percent
opacity
(
1­
hour
block
average).

6.
Fuel
analysis
Maintain
the
fuel
type
or
fuel
mixture
such
that
the
mercury
and/
or
total
selected
metals
emission
rates
calculated
according
to
§
63.7530(
d)(
4)
and/
or
(
5)
is
less
than
the
applicable
emission
limits
for
mercury
and/
or
total
selected
metals.
93
Table
4
to
Subpart
DDDDD
of
Part
63
 
Operating
Limits
for
Boilers
and
Process
Heaters
with
Hydrogen
Chloride
Emission
Limits
As
stated
in
§
63.7500,
you
must
comply
with
the
following
applicable
operating
limits:

If
you
demonstrate
compliance
with
applicable
hydrogen
chloride
emission
limits
using...
You
must
meet
these
operating
limits...

1.
Wet
scrubber
control
Maintain
the
minimum
scrubber
effluent
pH,
pressure
drop,
and
liquid
flow­
rate
at
or
above
the
operating
levels
established
during
the
performance
test
according
to
§
63.7530(
c)
and
Table
7
of
this
subpart
that
demonstrated
compliance
with
the
applicable
emission
limit
for
hydrogen
chloride.

2.
Dry
scrubber
control
Maintain
the
minimum
sorbent
injection
rate
at
or
above
the
operating
levels
established
during
the
performance
test
according
to
§
63.7530(
c)
and
Table
7
of
this
subpart
that
demonstrated
compliance
with
the
applicable
emission
limit
for
hydrogen
chloride.

3.
Fuel
analysis
Maintain
the
fuel
type
or
fuel
mixture
such
that
the
hydrogen
chloride
emission
rate
calculated
according
to
§
63.7530(
d)(
3)
is
less
than
the
applicable
emission
limit
for
hydrogen
chloride.
94
Table
5
to
Subpart
DDDDD
of
Part
63
 
Requirements
for
Performance
Tests
As
stated
in
§
63.7520,
you
must
comply
with
the
following
requirements
for
performance
test
for
existing,
new
or
reconstructed
affected
sources:

To
conduct
a
performance
test
for
the
following
pollutant..
You
must...
Using...

1.
Particulate
Matter
a.
Select
sampling
ports
location
and
the
number
of
traverse
points.

b.
Determine
velocity
and
volumetric
flow­
rate
of
the
stack
gas.

c.
Determine
oxygen
and
carbon
dioxide
concentrations
of
the
stack
gas.

d.
Measure
the
moisture
content
of
the
stack
gas
e.
Measure
the
particulate
matter
emission
concentration
f.
Convert
emissions
concentration
to
lb
per
MMBtu
emission
rates.
Method
1
in
appendix
A
to
part
60
of
this
chapter.

Method
2,
2F,
or
2G
in
appendix
A
to
part
60
of
this
chapter.

Method
3A
or
3B
in
appendix
A
to
part
60
of
this
chapter
or
ASME
PTC
19,
Part
10(
1981).

Method
4
in
appendix
A
to
part
60
of
this
chapter.

Method
5
or
17
(
positive
pressure
fabric
filters
must
use
Method
5D)
in
appendix
A
to
part
60
of
this
chapter.

Method
19
F­
factor
methodology
in
appendix
A
to
part
60
of
this
chapter.
95
To
conduct
a
performance
test
for
the
following
pollutant..
You
must...
Using...

2.
Total
selected
metals
a.
Select
sampling
ports
location
and
the
number
of
traverse
points.

b.
Determine
velocity
and
volumetric
flow­
rate
of
the
stack
gas.

c.
Determine
oxygen
and
carbon
dioxide
concentrations
of
the
stack
gas.

d.
Measure
the
moisture
content
of
the
stack
gas
e.
Measure
the
total
selected
metals
emission
concentration
f.
Convert
emissions
concentration
to
lb
per
MMBtu
emission
rates.
Method
1
in
appendix
A
to
part
60
of
this
chapter.

Method
2,
2F,
or
2G
in
appendix
A
to
part
60
of
this
chapter.

Method
3A
or
3B
in
appendix
A
to
part
60
of
this
chapter
or
ASME
PTC
19,
Part
10(
1981).

Method
4
in
appendix
A
to
part
60
of
this
chapter.

Method
29
in
appendix
A
to
part
60
of
this
chapter.

Method
19
F­
factor
methodology
in
appendix
A
to
part
60
of
this
chapter.
96
To
conduct
a
performance
test
for
the
following
pollutant..
You
must...
Using...

3.
Hydrogen
chloride
a.
Select
sampling
ports
location
and
the
number
of
traverse
points.

b.
Determine
velocity
and
volumetric
flow­
rate
of
the
stack
gas.

c.
Determine
oxygen
and
carbon
dioxide
concentrations
of
the
stack
gas.

d.
Measure
the
moisture
content
of
the
stack
gas
e.
Measure
the
hydrogen
chloride
emission
concentration
f.
Convert
emissions
concentration
to
lb
per
MMBtu
emission
rates.
Method
1
in
appendix
A
to
part
60
of
this
chapter.

Method
2,
2F,
or
2G
in
appendix
A
to
part
60
of
this
chapter.

Method
3A
or
3B
in
appendix
A
to
part
60
of
this
chapter
or
ASME
PTC
19,
Part
10(
1981).

Method
4
in
appendix
A
to
part
60
of
this
chapter.

Method
26
or
26A
in
appendix
A
to
part
60
of
this
chapter.

Method
19
F­
factor
methodology
in
appendix
A
to
part
60
of
this
chapter.
97
To
conduct
a
performance
test
for
the
following
pollutant..
You
must...
Using...

4.
Mercury
a.
Select
sampling
ports
location
and
the
number
of
traverse
points.

b.
Determine
velocity
and
volumetric
flow­
rate
of
the
stack
gas.

c.
Determine
oxygen
and
carbon
dioxide
concentrations
of
the
stack
gas.

d.
Measure
the
moisture
content
of
the
stack
gas
e.
Measure
the
mercury
emission
concentration
f.
Convert
emissions
concentration
to
lb
per
MMBtu
emission
rates.
Method
1
in
appendix
A
to
part
60
of
this
chapter.

Method
2,
2F,
or
2G
in
appendix
A
to
part
60
of
this
chapter.

Method
3A
or
3B
in
appendix
A
to
part
60
of
this
chapter
or
ASME
PTC
19,
Part
10(
1981).

Method
4
in
appendix
A
to
part
60
of
this
chapter.

Method
29
in
appendix
A
to
part
60
of
this
chapter
or
Method
101A
in
appendix
B
to
part
61
of
this
chapter
or
ASTM
Method
D6784­
02.

Method
19
F­
factor
methodology
in
appendix
A
to
part
60
of
this
chapter.
98
To
conduct
a
performance
test
for
the
following
pollutant..
You
must...
Using...

5.
Carbon
Monoxide
a.
Select
the
sampling
ports
location
and
the
number
of
traverse
points.

b.
Determine
velocity
and
volumetric
flow­
rate
of
the
stack
gas.

c.
Determine
oxygen
and
carbon
dioxide
concentrations
of
the
stack
gas.

d.
Measure
the
moisture
content
of
the
stack
gas.

e.
Measure
the
carbon
monoxide
emission
concentration.

f.
Convert
emissions
concentration
to
lb
per
MMBtu
emission
rates.
Method
1
in
appendix
A
to
part
60
of
this
chapter.

Method
2,
2F,
or
2G
in
appendix
A
to
part
60
of
this
chapter.

Method
3A
or
3B
in
appendix
A
to
part
60
of
this
chapter
or
ASME
PTC
19,
Part
10(
1981).

Method
4
in
appendix
A
to
part
60
of
this
chapter.

Method
10,
10A,
or
10
B
in
appendix
A
to
part
60
of
this
chapter.

Method
19
F­
factor
methodology
in
appendix
A
to
part
60
of
this
chapter.
99
Table
6
to
Subpart
DDDDD
of
Part
63
 
Requirements
for
Fuel
Analysis
Testing
As
stated
in
§
63.7520,
you
must
comply
with
the
following
requirements
for
fuel
analysis
testing
for
existing,
new
or
reconstructed
affected
sources:

To
conduct
a
fuel
analysis
for
the
following
pollutant..
You
must...
Using...
100
To
conduct
a
fuel
analysis
for
the
following
pollutant..
You
must...
Using...

1.
Mercury
a.
Collect
fuel
samples.

b.
Composite
fuel
samples.

c.
Prepare
composited
fuel
samples.

d.
Determine
heat
content
of
the
fuel
type.

e.
Determine
moisture
content
of
the
fuel
type.

f.
Measure
mercury
concentration
in
fuel
sample.

g.
Convert
concentrations
into
units
of
pounds
of
pollutant
per
MMBtu
of
heat
content.
Procedure
in
§
63.7521(
h)
or
ASTM
D2234­
00e1
(
for
coal)
or
ASTM
D6323­
98
(
for
biomass)
or
equivalent.

Procedure
in
§
63.7521(
h)
or
equivalent.

SW­
846­
3050B
(
for
solid
samples)
or
SW­
846­
3020A
(
for
liquid
samples)
or
ASTM
D2013­
01
(
for
coal)
or
ASTM
D5198­
92
(
for
biomass)
or
equivalent.

ASTM
D5865­
01ae1
(
for
coal)
or
ASTM
E
711­
87
(
for
biomass)
or
equivalent.

ASTM
D3173
or
ASTM
E
871
or
equivalent.

ASTM
D3684­
01
(
for
coal)
or
SW­
846­
7471A
(
for
solid
samples)
or
SW­
846
7470A
(
for
liquid
samples).
101
To
conduct
a
fuel
analysis
for
the
following
pollutant..
You
must...
Using...

2.
Total
selected
metals
a.
Collect
fuel
samples.

b.
Composite
fuel
samples.

c.
Prepare
composited
fuel
samples
d.
Determine
heat
content
of
the
fuel
type.

e.
Determine
moisture
content
of
the
fuel
type.

f.
Measure
total
selected
metals
concentration
in
fuel
sample.

g.
Convert
concentrations
into
units
of
pounds
of
pollutant
per
MMBtu
of
heat
content.
Procedure
in
§
63.7521(
h)
or
ASTM
D2234­
00e1
(
for
coal)
or
ASTM
D6323­
98
(
for
biomass)
or
equivalent.

Procedure
in
§
63.7521(
h)
or
equivalent.

SW­
846­
3050B
(
for
solid
samples)
or
SW­
846­
3020A
(
for
liquid
samples)
or
ASTM
D2013­
01
(
for
coal)
or
ASTM
D5198­
92
(
for
biomass)
or
equivalent.

ASTM
D5865­
01ae1
(
for
coal)
or
ASTM
E
711­
87
(
for
biomass)
or
equivalent.

ASTM
D
3173
or
ASTM
E
871
or
equivalent.

SW­
846­
6010Bor
ASTM
D3683­
94
(
for
coal)
or
ASTM
E885­
88
(
for
biomass).
102
To
conduct
a
fuel
analysis
for
the
following
pollutant..
You
must...
Using...

3.
Hydrogen
chloride
a.
Collect
fuel
samples.

b.
Composite
fuel
samples.

c.
Prepare
composited
fuel
samples
d.
Determine
heat
content
of
the
fuel
type.

e.
Determine
moisture
content
of
the
fuel
type.

f.
Measure
chlorine
concentration
in
fuel
sample.

g.
Convert
concentrations
into
units
of
pounds
of
pollutant
per
MMBtu
of
heat
content.
Procedure
in
§
63.7521(
h)
or
ASTM
D2234­
00e1
(
for
coal)
or
ASTM
D6323­
98
(
for
biomass)
or
equivalent.

Procedure
in
§
63.7521(
h)
or
equivalent.

SW­
846­
3050B
(
for
solid
samples)
or
SW­
846­
3020A
(
for
liquid
samples)
or
ASTM
D2013­
01
(
for
coal)
or
ASTM
D5198­
92
(
for
biomass)
or
equivalent.

ASTM
D5865­
01ae1
(
for
coal)
or
ASTM
E
711­
87
(
for
biomass)
or
equivalent.

ASTM
D
3173
or
ASTM
E
871
or
equivalent.

SW­
846­
9250
or
ASTM
E776­
87
(
for
biomass)
or
equivalent.
103
Table
7
to
Subpart
DDDDD
of
Part
63
 
Requirements
for
Establishing
Operating
Limits
As
stated
in
§
63.7520,
you
must
comply
with
the
following
requirements
for
establishing
operating
limits:

If
you
have
an
applicable
emission
limit
for...
And
your
operating
limits
are
based
on...
You
must...
Using...
According
to
the
following
requirements
a.
Wet
scrubber
operating
parameters
i.
Establish
a
site­
specific
minimum
pressure
drop
and
minimum
flow
rate
operating
limit
according
to
§
63.7530(
c)
(
1)
Data
from
the
pressure
drop
and
liquid
flow
rate
monitors
and
the
particulate
matter,
mercury,

or
total
selected
metals
performance
test.
(
a)
You
must
collect
pressure
drop
and
liquid
flow­
rate
data
every
15
minutes
during
the
entire
period
of
the
performance
tests;

(
b)
Determine
the
average
[
pressure
drop
and
liquid
flow­
rate
for
each
individual
test
run
in
the
three­
run
performance
test
by
computing
the
average
of
all
the
15­
minute
readings
taken
during
each
test
run.

b.
Electrostatic
i.
Establish
a
(
1)
Data
from
the
(
a)
You
must
collect
voltage
and
(
b)
Determine
the
average
voltage
1.
Particulate
matter,
mercury,
or
total
selected
metals.
c.
A
site­
specific
i.
Establish
a
(
1)
Data
from
the
(
a)
Collecting
the
opacity
(
b)
Reducing
the
opacity
monitoring
(
c)
Determine
the
average
opacity
104
If
you
have
an
applicable
emission
limit
for...
And
your
operating
limits
are
based
on...
You
must...
Using...
According
to
the
following
requirements
a.
Wet
scrubber
operating
parameters
i.
Establish
a
site­
specific
minimum
pressure
drop
and
minimum
flow
rate
operating
limit
according
to
§
63.7530(
c)
(
1)
Data
from
the
pH,

pressure
drop,

and
liquid
flow
rate
monitors
and
the
hydrogen
chloride
performance
test.
(
a)
You
must
collect
pH,
pressure
drop,
and
liquid
flow­
rate
data
every
15
minutes
during
the
entire
period
of
the
performance
tests;

(
b)
Determine
the
average
pH,

pressure
drop,
and
liquid
flowrate
for
each
individual
test
run
in
the
three­
run
performance
test
by
computing
the
average
of
all
the
15­

minute
readings
taken
during
each
test
run.

2.
Hydrogen
Chloride
b.
Dry
scrubber
i.
Establish
a
(
1)
Data
from
the
(
a)
You
must
collect
sorbent
(
b)
Determine
the
average
sorbent
105
Table
8
to
Subpart
DDDDD
of
Part
63
 
Continuous
Compliance
with
Emission
Limitations
for
Boilers
or
Process
Heaters
As
stated
in
§
63.7540,
you
must
show
continuous
compliance
with
the
emission
limitations
for
affected
sources
according
to
the
following:

If
you
must
meet
the
following
operating
limits
or
work
practice
standards...
You
must
demonstrate
continuous
compliance
by...

1.
Opacity.
a.
Collecting
the
opacity
monitoring
system
data
according
to
§
63.7525(
b)
and
§
63.7535;
and
b.
Reducing
the
opacity
monitoring
data
to
6­
minute
averages;
and
c.
Maintaining
opacity
to
less
than
or
equal
to
20
percent
(
6­
minute
average)
except
for
one
6­
minute
period
per
hour
of
not
more
than
27
percent
for
existing
sources;
OR
maintaining
opacity
to
less
than
or
equal
to
10
percent
(
1­
hour
block
average)
for
new
sources.

2.
Fabric
Filter
Bag
Leak
Detection
Operation.
a.
Installing
and
operating
a
bag
leak
detection
system
according
to
§
63.7525
and
operating
the
fabric
filter
such
that
the
requirements
in
§
63.7540(
a)(
9)
are
met.
106
If
you
must
meet
the
following
operating
limits
or
work
practice
standards...
You
must
demonstrate
continuous
compliance
by...

3.
Wet
Scrubber
Pressure
Drop
and
Liquid
Flow­
rate.
a.
Collecting
the
pressure
drop
and
liquid
flow
rate
monitoring
system
data
according
to
§
63.7525
and
§
63.7535;
and
b.
Reducing
the
data
to
3­
hour
block
averages;
and
c.
Maintaining
the
3­
hour
average
pressure
drop
and
liquid
flow­
rate
at
or
above
the
operating
limits
established
during
the
performance
test
according
to
§
63.7530
(
c).

4.
Wet
Scrubber
pH.
a.
Collecting
the
pH
monitoring
system
data
according
to
§
63.7525
and
§
63.7535;
and
b.
Reducing
the
data
to
3­
hour
block
averages;
and
c.
Maintaining
the
3­
hour
average
pH
at
or
above
the
operating
limit
established
during
the
performance
test
according
to
§
63.7530(
c).

5.
Dry
Scrubber
Sorbent
or
Carbon
Injection
Rate.
a.
Collecting
the
sorbent
or
carbon
injection
rate
monitoring
system
data
for
the
dry
scrubber
according
to
§
63.7525
and
§
63.7535;
and
b.
Reducing
the
data
to
3­
hour
block
averages;
and
c.
Maintaining
the
3­
hour
average
sorbent
or
carbon
injection
rate
at
or
above
the
operating
limit
established
during
the
performance
test
according
to
§
63.7530(
c).
107
If
you
must
meet
the
following
operating
limits
or
work
practice
standards...
You
must
demonstrate
continuous
compliance
by...

6.
Electrostatic
Precipitator
Secondary
Current
and
Voltage
or
Total
Power
Input.
a.
Collecting
the
secondary
current
and
voltage
or
total
power
input
monitoring
system
data
for
the
electrostatic
precipitator
according
to
6
§
3.7525
and
§
63.7535;
and
b.
educing
the
data
to
3­
hour
block
averages;
and
c.
Maintaining
the
3­
hour
average
secondary
current
and
voltage
or
total
power
input
at
or
above
the
operating
limits
established
during
the
performance
test
according
to
§
63.7530(
c).

7.
Fuel
Pollutant
Content.
a.
Only
burning
the
fuel
types
and
fuel
mixtures
used
to
demonstrate
compliance
with
the
applicable
emission
limit
according
to
§
63.7530(
c)
or
(
d)
as
applicable;
and
b.
Keeping
monthly
records
of
fuel
use
according
to
§
63.7540(
a).
108
Table
9
to
Subpart
DDDDD
of
Part
63
 
Requirements
for
Reports
As
stated
in
§
63.7550,
you
must
comply
with
the
following
requirements
for
reports:

You
must
submit
a(
n)
The
report
must
contain...
You
must
submit
the
report...

1.
compliance
report
a.
information
required
in
§
63.7550(
c)(
1)­

(
11)

AND
b.
if
there
are
no
deviations
from
any
emission
limitation
(
emission
limit
and
operating
limit)
that
applies
to
you
and
there
are
no
deviations
from
the
requirements
for
work
practice
standards
in
Table
8
to
this
subpart
that
apply
to
you,
a
statement
that
there
were
no
deviations
from
the
emission
limitations
and
work
practice
standards
during
the
reporting
period.
If
there
were
no
periods
during
which
the
continuous
monitoring
systems,
including
continuous
emissions
monitoring
system,
continuous
opacity
monitoring
system,
and
operating
parameter
monitoring
systems,
were
outof
control
as
specified
in
§
63.8(
c)(
7),

a
statement
that
there
were
no
periods
during
the
which
the
continuous
monitoring
systems
were
out­
of­
control
during
the
reporting
period
AND
c.
if
you
have
a
deviation
from
any
emission
limitation
(
emission
limit
and
operating
limit)
or
work
practice
standard
during
the
reporting
period,
the
report
must
semiannually
according
to
the
requirements
in
§
63.7550(
b).
109
You
must
submit
a(
n)
The
report
must
contain...
You
must
submit
the
report...

contain
the
information
in
§
63.7550(
d).

If
there
were
periods
during
which
the
continuous
monitoring
systems,
including
continuous
emissions
monitoring
system,

continuous
opacity
monitoring
system,

and
operating
parameter
monitoring
systems,
were
out­
of­
control,
as
specified
in
§
63.8(
c)(
7),
the
report
must
contain
the
information
in
§
63.7550(
e)

AND
d.
if
you
had
a
startup,
shutdown,
or
malfunction
during
the
reporting
period
and
you
took
actions
consistent
with
your
startup,
shutdown,
and
malfunction
plan,
the
compliance
report
must
include
the
information
in
§
63.10(
d)(
5)(
i)
110
a.
actions
taken
for
the
event
and
And
i.
by
fax
or
telephone
within
2
working
days
after
starting
actions
inconsistent
with
the
plan;

and
2.
an
immediate
startup,

shutdown,
and
malfunction
report
if
you
had
a
startup,

shutdown,
or
malfunction
during
the
reporting
period
that
is
not
consistent
with
your
startup,
shutdown,
and
malfunction
plan
b.
The
information
in
§
63.10(
d)(
5)(
ii)
ii.
by
letter
within
7
ting
authority.
