Document ID: EPA-HQ-OAR-2004-0055-0003
Agency: epa
Document Type: Notice
Title: Part II of 1995 Federal Register Notice: National Emission Standards for Hazardous Air Pollutants:  Petroleum Refineries Regulations
Posted Date: 2004-05-10T04:00Z

75
For
the
reasons
set
out
in
the
preamble,
parts
60,
and
63
of
title
40,
chapter
I,
of
the
Code
of
Federal
Regulations
are
amended
as
follows:

PART
60­­
STANDARDS
OF
PERFORMANCE
FOR
NEW
STATIONARY
SOURCES
1.
The
authority
citation
for
part
60
continues
to
read
as
follows:

Authority:
sections
101,
111,
114,
116,
and
301
of
the
Clean
Air
Act
as
amended
(
42
U.
S.
C.
7401,
7411,
7414,
7416,

7601).

*
*
*
*
*

Subpart
VV
[
Amended]

*
*
*
*
*

2.
Section
60.481
is
amended
by
revising
the
definition
of
"
closed
vent
system"
to
read
as
follows:

§
60.481
Definitions.

*
*
*
*
*

Closed
vent
system
means
a
system
that
is
not
open
to
the
atmosphere
and
that
is
composed
of
piping,
connections,

and,
if
necessary,
flow­
inducing
devices
that
transport
gas
or
vapor
from
a
piece
or
pieces
of
equipment
to
a
control
device.
If
gas
or
vapor
from
regulated
equipment
is
routed
to
a
process
(
e.
g.,
to
a
petroleum
refinery
fuel
gas
system),
the
process
shall
not
be
considered
a
closed
vent
system
and
is
not
subject
to
the
closed
vent
system
standards.

*
*
*
*
*
76
3.
Section
60.482­
5
is
revised
to
read
as
follows:

§
60.482­
5
Standards:
Sampling
connection
systems.

(
a)
Each
sampling
connection
system
shall
be
equipped
with
a
closed­
purged,
closed­
loop,
or
closed­
vent
system,

except
as
provided
in
§
60.482­
1(
c).

(
b)
Each
closed­
purge,
closed­
loop,
or
closed­
vent
system
as
required
in
paragraph
(
a)
of
this
section
shall
comply
with
the
requirements
specified
in
paragraphs
(
b)(
1)

through
(
b)(
3)
of
this
section:

(
1)
Return
the
purged
process
fluid
directly
to
the
process
line;
or
(
2)
Collect
and
recycle
the
purged
process
fluid
to
a
process;
or
(
3)
Be
designed
and
operated
to
capture
and
transport
all
the
purged
process
fluid
to
a
control
device
that
complies
with
the
requirements
of
§
60.482­
10.

(
c)
In
situ
sampling
systems
and
sampling
systems
without
purges
are
exempt
from
the
requirements
of
paragraphs
(
a)
and
(
b)
of
this
section.

*
*
*
*
*

4.
Section
60.482­
10
is
amended
by
revising
paragraphs
(
f)
and
(
g)
and
adding
paragraphs
(
h)
through
(
l)

to
read
as
follows:
77
§
60.482­
10
Standards:
Closed
vent
systems
and
control
devices.

*
*
*
*
*

(
f)
Except
as
provided
in
paragraphs
(
i)
through
(
k)

of
this
section,
each
closed
vent
system
shall
be
inspected
according
to
the
procedures
and
schedule
specified
in
paragraphs
(
f)(
1)
and
(
f)(
2)
of
this
section.

(
1)
If
the
vapor
collection
system
or
closed
vent
system
is
constructed
of
hard­
piping,
the
owner
or
operator
shall
comply
with
the
requirements
specified
in
paragraphs
(
f)(
1)(
i)
and
(
f)(
1)(
ii)
of
this
section:

(
i)
Conduct
an
initial
inspection
according
to
the
procedures
in
§
60.485(
b),
and
(
ii)
Conduct
annual
visual
inspections
for
visible,

audible,
or
olfactory
indications
of
leaks.

(
2)
If
the
vapor
collection
system
or
closed
vent
system
is
constructed
of
ductwork,
the
owner
or
operator
shall:

(
i)
Conduct
an
initial
inspection
according
to
the
procedures
in
§
60.485(
b),
and
(
ii)
Conduct
annual
inspections
according
to
the
procedures
in
§
60.485(
b).

(
g)
Leaks,
as
indicated
by
an
instrument
reading
greater
than
500
parts
per
million
by
volume
above
background
or
by
visual
inspections,
shall
be
repaired
as
78
soon
as
practicable
except
as
provided
in
paragraph
(
h)
of
this
section.

(
1)
A
first
attempt
at
repair
shall
be
made
no
later
than
5
calendar
days
after
the
leak
is
detected.

(
2)
Repair
shall
be
completed
no
later
than
15
calendar
days
after
the
leak
is
detected.

(
h)
Delay
of
repair
of
a
closed
vent
system
for
which
leaks
have
been
detected
is
allowed
if
the
repair
is
technically
infeasible
without
a
process
unit
shutdown
or
if
the
owner
or
operator
determines
that
emissions
resulting
from
immediate
repair
would
be
greater
than
the
fugitive
emissions
likely
to
result
from
delay
of
repair.
Repair
of
such
equipment
shall
be
complete
by
the
end
of
the
next
process
unit
shutdown.

(
i)
If
a
vapor
collection
system
or
closed
vent
system
is
operated
under
a
vacuum,
it
is
exempt
from
the
inspection
requirements
of
paragraphs
(
f)(
1)(
i)
and
(
f)(
2)
of
this
section.

(
j)
Any
parts
of
the
closed
vent
system
that
are
designated,
as
described
in
paragraph
(
k)(
1)
of
this
section,
as
unsafe
to
inspect
are
exempt
from
the
inspection
requirements
of
paragraphs
(
f)(
1)(
i)
and
(
f)(
2)
of
this
section
if
they
comply
with
the
requirements
specified
in
paragraphs
(
j)(
1)
and
(
j)(
2):

(
1)
The
owner
or
operator
determines
that
the
equipment
is
unsafe
to
inspect
because
inspecting
personnel
79
would
be
exposed
to
an
imminent
or
potential
danger
as
a
consequence
of
complying
with
paragraphs
(
f)(
1)(
i)
or
(
f)(
2)

of
this
section;
and
(
2)
The
owner
or
operator
has
a
written
plan
that
requires
inspection
of
the
equipment
as
frequently
as
practicable
during
safe­
to­
inspect
times.

(
k)
Any
parts
of
the
closed
vent
system
that
are
designated,
as
described
in
paragraph
(
l)(
2)
of
this
section,
as
difficult
to
inspect
are
exempt
from
the
inspection
requirements
of
paragraphs
(
f)(
1)(
i)
and
(
f)(
2)

of
this
section
if
they
comply
with
the
requirements
specified
in
paragraphs
(
k)(
1)
through
(
k)(
3):

(
1)
The
owner
or
operator
determines
that
the
equipment
cannot
be
inspected
without
elevating
the
inspecting
personnel
more
than
2
meters
above
a
support
surface;
and
(
2)
The
process
unit
within
which
the
closed
vent
system
is
located
becomes
an
affected
facility
through
§
§
60.14
or
60.15,
or
the
owner
or
operator
designates
less
than
3.0
percent
of
the
total
number
of
closed
vent
system
equipment
as
difficult
to
inspect;
and
(
3)
The
owner
or
operator
has
a
written
plan
that
requires
inspection
of
the
equipment
at
least
once
every
5
years.
A
closed
vent
system
is
exempt
from
inspection
if
it
is
operated
under
a
vacuum.
80
(
l)
The
owner
or
operator
shall
record
the
information
specified
in
paragraphs
(
l)(
1)
through
(
l)(
5)
of
this
section.

(
1)
Identification
of
all
parts
of
the
closed
vent
system
that
are
designated
as
unsafe
to
inspect,
an
explanation
of
why
the
equipment
is
unsafe
to
inspect,
and
the
plan
for
inspecting
the
equipment.

(
2)
Identification
of
all
parts
of
the
closed
vent
system
that
are
designated
as
difficult
to
inspect,
an
explanation
of
why
the
equipment
is
difficult
to
inspect,

and
the
plan
for
inspecting
the
equipment.

(
3)
For
each
inspection
during
which
a
leak
is
detected,
a
record
of
the
information
specified
in
§
60.486(
c).

(
4)
For
each
inspection
conducted
in
accordance
with
§
60.485(
b)
during
which
no
leaks
are
detected,
a
record
that
the
inspection
was
performed,
the
date
of
the
inspection,
and
a
statement
that
no
leaks
were
detected.

(
5)
For
each
visual
inspection
conducted
in
accordance
with
paragraph
(
f)(
1)(
ii)
of
this
section
during
which
no
leaks
are
detected,
a
record
that
the
inspection
was
performed,
the
date
of
the
inspection,
and
a
statement
that
no
leaks
were
detected.

(
m)
Closed
vent
systems
and
control
devices
used
to
comply
with
provisions
of
this
subpart
shall
be
operated
at
all
times
when
emissions
may
be
vented
to
them.
81
*
*
*
*
*

Subpart
QQQ
[
Amended]

*
*
*
*
*

5.
Section
60.691
is
amended
by
revising
the
definition
of
"
closed
vent
system"
to
read
as
follows:

§
60.691
Definitions.

*
*
*
*
*

Closed
vent
system
means
a
system
that
is
not
open
to
the
atmosphere
and
that
is
composed
of
piping,
connections,

and,
if
necessary,
flow­
inducing
devices
that
transport
gas
or
vapor
from
an
emission
source
to
a
control
device.
If
gas
or
vapor
from
regulated
equipment
are
routed
to
a
process
(
e.
g.,
to
a
petroleum
refinery
fuel
gas
system),
the
process
shall
not
be
considered
a
closed
vent
system
and
is
not
subject
to
the
closed
vent
system
standards.

*
*
*
*
*

6.
Section
60.692­
3
is
amended
by
revising
paragraph
(
d)
to
read
as
follows:

§
60.692­
3
Standards:
Oil­
water
separators.

*
*
*
*
*

(
d)
Storage
vessels,
including
slop
oil
tanks
and
other
auxiliary
tanks
that
are
subject
to
the
standards
in
§
§
60.112,
60.112a,
and
60.112b
and
associated
requirements,

40
CFR
part
60
subparts
K,
Ka,
or
Kb
are
not
subject
to
the
requirements
of
this
section.

*
*
*
*
*
82
7.
Section
60.693­
2
is
amended
by
revising
paragraphs
(
a)(
1)(
i)
and
(
a)(
1)(
i)(
A)
as
follows:

§
60.693­
2
Alternative
standards
for
oil­
water
separators.

*
*
*
*
*

(
a)
*
*
*

(
1)
*
*
*

(
i)
The
primary
seal
shall
be
a
liquid­
mounted
seal
or
a
mechanical
shoe
seal.

(
A)
A
liquid­
mounted
seal
means
a
foam­
or
liquid­
filled
seal
mounted
in
contact
with
the
liquid
between
the
wall
of
the
separator
and
the
floating
roof.
A
mechanical
shoe
seal
means
a
metal
sheet
held
vertically
against
the
wall
of
the
separator
by
springs
or
weighted
levers
and
is
connected
by
braces
to
the
floating
roof.
A
flexible
coated
fabric
(
envelope)
spans
the
annular
space
between
the
metal
sheet
and
the
floating
roof.

*
*
*
*
*

8.
Section
60.695
is
amended
by
revising
paragraph
(
a)(
3)
as
follows:

§
60.695
Monitoring
of
operations.

*
*
*
*
*

(
a)
*
*
*

(
3)
*
*
*

(
i)
For
a
carbon
adsorption
system
that
regenerates
the
carbon
bed
directly
onsite,
a
monitoring
device
that
continuously
indicates
and
records
the
volatile
organic
83
compound
concentration
level
or
reading
of
organics
in
the
exhaust
gases
of
the
control
device
outlet
gas
stream
or
inlet
and
outlet
gas
stream
shall
be
used.

(
ii)
For
a
carbon
adsorption
system
that
does
not
regenerate
the
carbon
bed
directly
onsite
in
the
control
device
(
e.
g.,
a
carbon
canister),
the
concentration
level
of
the
organic
compounds
in
the
exhaust
vent
stream
from
the
carbon
adsorption
system
shall
be
monitored
on
a
regular
schedule,
and
the
existing
carbon
shall
be
replaced
with
fresh
carbon
immediately
when
carbon
breakthrough
is
indicated.
The
device
shall
be
monitored
on
a
daily
basis
or
at
intervals
no
greater
than
20
percent
of
the
design
carbon
replacement
interval,
whichever
is
greater.
As
an
alternative
to
conducting
this
monitoring,
an
owner
or
operator
may
replace
the
carbon
in
the
carbon
adsorption
system
with
fresh
carbon
at
a
regular
predetermined
time
interval
that
is
less
than
the
carbon
replacement
interval
that
is
determined
by
the
maximum
design
flow
rate
and
organic
concentration
in
the
gas
stream
vented
to
the
carbon
adsorption
system.

*
*
*
*
*

9.
Section
60.697
is
amended
by
revising
paragraphs
(
f)(
3)(
i),
(
f)(
3)(
ii),
and
(
f)(
3)(
x)
as
follows:
84
§
60.697
Recordkeeping
requirements.

*
*
*
*
*

(
f)
*
*
*

(
3)
*
*
*

(
i)
Documentation
demonstrating
that
the
control
device
will
achieve
the
required
control
efficiency
during
maximum
loading
conditions
shall
be
kept
for
the
life
of
the
facility.
This
documentation
is
to
include
a
general
description
of
the
gas
streams
that
enter
the
control
device,
including
flow
and
volatile
organic
compound
content
under
varying
liquid
level
conditions
(
dynamic
and
static)

and
manufacturer's
design
specifications
for
the
control
device.
If
an
enclosed
combustion
device
with
a
minimum
residence
time
of
0.75
seconds
and
a
minimum
temperature
of
816
oC
(
1,500
oF)
is
used
to
meet
the
95­
percent
requirement,
documentation
that
those
conditions
exist
is
sufficient
to
meet
the
requirements
of
this
paragraph.

(
ii)
For
a
carbon
adsorption
system
that
does
not
regenerate
the
carbon
bed
directly
onsite
in
the
control
device
such
as
a
carbon
canister,
the
design
analysis
shall
consider
the
vent
stream
composition,
constituent
concentrations,
flow
rate,
relative
humidity,
and
temperature.
The
design
analysis
shall
also
establish
the
design
exhaust
vent
stream
organic
compound
concentration
level,
capacity
of
carbon
bed,
type
and
working
capacity
of
activated
carbon
used
for
carbon
bed,
and
design
carbon
85
replacement
interval
based
on
the
total
carbon
working
capacity
of
the
control
device
and
source
operating
schedule.

*
*
*
*
*

(
x)
*
*
*

(
A)
Each
owner
or
operator
of
an
affected
facility
that
uses
a
carbon
adsorber
which
is
regenerated
directly
onsite
shall
maintain
continuous
records
of
the
volatile
organic
compound
concentration
level
or
reading
of
organics
of
the
control
device
outlet
gas
stream
or
inlet
and
outlet
gas
stream
and
records
of
all
3­
hour
periods
of
operation
during
which
the
average
volatile
organic
compound
concentration
level
or
reading
of
organics
in
the
exhaust
gases,
or
inlet
and
outlet
gas
stream,
is
more
than
20
percent
greater
than
the
design
exhaust
gas
concentration
level,
and
shall
keep
such
records
for
2
years
after
the
information
is
recorded.

(
B)
If
a
carbon
adsorber
that
is
not
regenerated
directly
onsite
in
the
control
device
is
used,
then
the
owner
or
operator
shall
maintain
records
of
dates
and
times
when
the
control
device
is
monitored,
when
breakthrough
is
measured,
and
shall
record
the
date
and
time
that
the
existing
carbon
in
the
control
device
is
replaced
with
fresh
carbon.

*
*
*
*
*
86
10.
Section
60.698
is
amended
by
revising
paragraph
(
d)(
3)
as
follows:

§
60.698
Reporting
requirements.

*
*
*
*
*

(
d)
*
*
*

(
3)
*
*
*

(
i)
Each
3­
hour
period
of
operation
during
which
the
average
volatile
organic
compound
concentration
level
or
reading
of
organics
in
the
exhaust
gases
from
a
carbon
adsorber
which
is
regenerated
directly
onsite
is
more
than
20
percent
greater
than
the
design
exhaust
gas
concentration
level
or
reading.

(
ii)
Each
occurrence
when
the
carbon
in
a
carbon
adsorber
system
that
is
not
regenerated
directly
onsite
in
the
control
device
is
not
replaced
at
the
predetermined
interval
specified
in
§
60.695(
a)(
3)(
ii).

*
*
*
*
*

PART
63­­
NATIONAL
EMISSION
STANDARDS
FOR
HAZARDOUS
AIR
POLLUTANTS
FOR
SOURCE
CATEGORIES
1.
The
authority
citation
for
part
63
continues
to
read
as
follows:

Authority:
sections
101,
112,
114,
116,
and
301
of
the
Clean
Air
Act
(
42
U.
S.
C.
7401,
et
seq.,
as
amended
by
Pub.
L.
101­
549,
104
Stat.
2399.).

*
*
*
*
*

Subpart
R
[
Amended]
87
*
*
*
*
*

2.
Section
63.420
is
amended
by
adding
the
following:

§
63.420
Applicability.

*
*
*
*
*

(
i)
A
bulk
gasoline
terminal
or
pipeline
breakout
station
with
a
Standard
Industrial
Classification
code
2911
located
within
a
contiguous
area
and
under
common
control
with
a
refinery
complying
with
subpart
CC,
§
§
63.646,

63.648,
63.649,
and
63.650
is
not
subject
to
subpart
R
standards,
except
as
specified
in
subpart
CC,
§
63.650.

*
*
*
*
*

3.
Part
63
is
amended
by
adding
subpart
CC
to
read
as
follows:

Subpart
CC­­
National
Emission
Standards
for
Hazardous
Air
Pollutants
from
Petroleum
Refineries
Sec.

63.640
Applicability
and
designation
of
source.

63.641
Definitions.

63.642
General
standards.

63.643
Miscellaneous
process
vents
provisions.

63.644
Monitoring
provisions
for
miscellaneous
process
vents.

63.645
Test
methods
and
procedures
for
miscellaneous
process
vents.

63.646
Storage
vessel
provisions.

63.647
Wastewater
provisions.
88
63.648
Equipment
leak
standards.

63.649
Alternative
means
of
emission
limitation:

connectors
in
gas/
vapor
service
and
light
liquid
service.

63.650
Gasoline
loading
rack
provisions.

63.651
Marine
vessel
tank
loading
operations
provisions.

63.652
Emissions
averaging
provisions.

63.653
Monitoring,
recordkeeping,
and
implementation
plan
for
emissions
averaging.

63.654
Reporting
and
recordkeeping.

63.655
through
63.679
[
Reserved]

§
63.640
Applicability
and
designation
of
affected
source.

(
a)
This
subpart
applies
to
petroleum
refining
process
units
and
to
related
emission
points
that
are
specified
in
paragraphs
(
c)(
5)
through
(
c)(
7)
of
this
section
that
are
located
at
a
plant
site
that
meet
the
criteria
in
paragraphs
(
a)(
1)
and
(
a)(
2)
of
this
section;

(
1)
Are
located
at
a
plant
site
that
is
a
major
source
as
defined
in
section
112(
a)
of
the
Clean
Air
Act;
and
(
2)
Emit
or
have
equipment
containing
or
contacting
one
or
more
of
the
hazardous
air
pollutants
listed
in
table
1
of
this
subpart.

(
b)
For
process
units
that
are
designed
and
operated
as
flexible
operation
units,
the
applicability
of
this
subpart
shall
be
determined
for
existing
sources
based
on
the
expected
utilization
for
the
5
years
following
promulgation
of
this
subpart
and
for
new
sources
based
on
89
the
expected
utilization
for
the
first
5
years
after
startup.

(
1)
If
the
predominant
use
of
the
flexible
operation
unit,
as
described
in
paragraphs
(
b)(
1)(
i)
and
(
b)(
1)(
ii)
of
this
section,
is
as
a
petroleum
refining
process
unit,
as
defined
in
§
63.641,
then
the
flexible
operation
unit
shall
be
subject
to
the
provisions
of
this
subpart.

(
i)
Except
as
provided
in
paragraph
(
b)(
1)(
ii)
of
this
section,
the
predominant
use
of
the
flexible
operation
unit
shall
be
the
use
representing
the
greatest
annual
operating
time.

(
ii)
If
the
flexible
operation
unit
is
used
as
a
petroleum
refining
process
unit
and
for
another
purpose
equally
based
on
operating
time,
then
the
predominant
use
of
the
flexible
operation
unit
shall
be
the
use
that
produces
the
greatest
annual
production
on
a
mass
basis.

(
2)
The
determination
of
applicability
of
this
subpart
to
petroleum
refining
process
units
that
are
designed
and
operated
as
flexible
operation
units
shall
be
reported
as
specified
in
§
63.654(
h)(
6)(
i).

(
c)
For
the
purpose
of
this
subpart,
the
affected
source
shall
comprise
all
emission
points,
in
combination,

listed
in
paragraphs
(
c)(
1)
through
(
c)(
7)
of
this
section
that
are
located
at
a
single
refinery
plant
site.
90
(
1)
All
miscellaneous
process
vents
from
petroleum
refining
process
units
meeting
the
criteria
in
paragraph
(
a)

of
this
section;

(
2)
All
storage
vessels
associated
with
petroleum
refining
process
units
meeting
the
criteria
in
paragraph
(
a)

of
this
section;

(
3)
All
wastewater
streams
and
treatment
operations
associated
with
petroleum
refining
process
units
meeting
the
criteria
in
paragraph
(
a)
of
this
section;

(
4)
All
equipment
leaks
from
petroleum
refining
process
units
meeting
the
criteria
in
paragraph
(
a)
of
this
section;

(
5)
All
gasoline
loading
racks
classified
under
Standard
Industrial
Classification
code
2911
meeting
the
criteria
in
paragraph
(
a)
of
this
section;
and
(
6)
All
marine
vessel
loading
operations
located
at
a
petroleum
refinery
meeting
the
criteria
in
paragraph
(
a)
of
this
section
and
the
applicability
criteria
of
subpart
Y,

§
63.560.

(
7)
All
storage
vessels
and
equipment
leaks
associated
with
a
bulk
gasoline
terminal
or
pipeline
breakout
station
classified
under
Standard
Industrial
Classification
code
2911
located
within
a
contiguous
area
and
under
common
control
with
a
refinery
meeting
the
criteria
in
paragraph
(
a)
of
this
section.
91
(
d)
The
affected
source
subject
to
this
subpart
does
not
include
the
emission
points
listed
in
paragraphs
(
d)(
1)

through
(
d)(
4)
of
this
section.

(
1)
Stormwater
from
segregated
stormwater
sewers;

(
2)
Spills;
and
(
3)
Equipment
that
is
intended
to
operate
in
organic
hazardous
air
pollutant
service,
as
defined
in
§
63.641
of
this
subpart,
for
less
than
300
hours
during
the
calendar
year.

(
4)
Catalytic
cracking
unit
and
catalytic
reformer
catalyst
regeneration
vents,
and
sulfur
plant
vents.

(
e)
The
owner
or
operator
shall
follow
the
procedures
specified
in
paragraphs
(
e)(
1)
and
(
e)(
2)
of
this
section
to
determine
whether
a
storage
vessel
is
part
of
a
source
to
which
this
subpart
applies.

(
1)
Where
a
storage
vessel
is
used
exclusively
by
a
process
unit,
the
storage
vessel
shall
be
considered
part
of
that
process
unit.

(
i)
If
the
process
unit
is
a
petroleum
refining
process
unit
subject
to
this
subpart,
then
the
storage
vessel
is
part
of
the
affected
source
to
which
this
subpart
applies.

(
ii)
If
the
process
unit
is
not
subject
to
this
subpart,
then
the
storage
vessel
is
not
part
of
the
affected
source
to
which
this
subpart
applies.
92
(
2)
If
a
storage
vessel
is
not
dedicated
to
a
single
process
unit,
then
the
applicability
of
this
subpart
shall
be
determined
according
to
the
provisions
in
paragraphs
(
e)(
2)(
i)
through
(
e)(
2)(
iii)
of
this
section.

(
i)
If
a
storage
vessel
is
shared
among
process
units
and
one
of
the
process
units
has
the
predominant
use,
as
determined
by
paragraphs
(
e)(
2)(
i)(
A)
and
(
e)(
2)(
i)(
B)
of
this
section,
then
the
storage
vessel
is
part
of
that
process
unit.

(
A)
If
the
greatest
input
on
a
volume
basis
into
the
storage
vessel
is
from
a
process
unit
that
is
located
on
the
same
plant
site,
then
that
process
unit
has
the
predominant
use.

(
B)
If
the
greatest
input
on
a
volume
basis
into
the
storage
vessel
is
provided
from
a
process
unit
that
is
not
located
on
the
same
plant
site,
then
the
predominant
use
shall
be
the
process
unit
that
receives
the
greatest
amount
of
material
on
a
volume
basis
from
the
storage
vessel
at
the
same
plant
site.

(
ii)
If
a
storage
vessel
is
shared
among
process
units
so
that
there
is
no
single
predominant
use,
and
at
least
one
of
those
process
units
is
a
petroleum
refining
process
unit
subject
to
this
subpart,
the
storage
vessel
shall
be
considered
to
be
part
of
the
petroleum
refining
process
unit
that
is
subject
to
this
subpart.
If
more
than
one
petroleum
refining
process
unit
is
subject
to
this
subpart,
the
owner
93
or
operator
may
assign
the
storage
vessel
to
any
of
the
petroleum
refining
process
units
subject
to
this
subpart.

(
iii)
If
the
predominant
use
of
a
storage
vessel
varies
from
year
to
year,
then
the
applicability
of
this
subpart
shall
be
determined
based
on
the
utilization
of
that
storage
vessel
during
the
year
preceding
promulgation
of
this
subpart.
This
determination
shall
be
reported
as
specified
in
§
63.654(
h)(
6)(
ii)
of
this
subpart.

(
f)
The
owner
or
operator
shall
follow
the
procedures
specified
in
paragraphs
(
f)(
1)
through
(
f)(
5)
of
this
section
to
determine
whether
a
miscellaneous
process
vent
from
a
distillation
unit
is
part
of
a
source
to
which
this
subpart
applies.

(
1)
If
the
greatest
input
to
the
distillation
unit
is
from
a
process
unit
located
on
the
same
plant
site,
then
the
distillation
unit
shall
be
assigned
to
that
process
unit.

(
2)
If
the
greatest
input
to
the
distillation
unit
is
provided
from
a
process
unit
that
is
not
located
on
the
same
plant
site,
then
the
distillation
unit
shall
be
assigned
to
the
process
unit
located
at
the
same
plant
site
that
receives
the
greatest
amount
of
material
from
the
distillation
unit.

(
3)
If
a
distillation
unit
is
shared
among
process
units
so
that
there
is
no
single
predominant
use,
as
described
in
paragraphs
(
f)(
1)
and
(
f)(
2)
of
this
section,

and
at
least
one
of
those
process
units
is
a
petroleum
94
refining
process
unit
subject
to
this
subpart,
the
distillation
unit
shall
be
assigned
to
the
petroleum
refining
process
unit
that
is
subject
to
this
subpart.
If
more
than
one
petroleum
refining
process
unit
is
subject
to
this
subpart,
the
owner
or
operator
may
assign
the
distillation
unit
to
any
of
the
petroleum
refining
process
units
subject
to
this
rule.

(
4)
If
the
process
unit
to
which
the
distillation
unit
is
assigned
is
a
petroleum
refining
process
unit
subject
to
this
subpart
and
the
vent
stream
contains
greater
than
20
parts
per
million
by
volume
total
organic
hazardous
air
pollutants,
then
the
vent
from
the
distillation
unit
is
considered
a
miscellaneous
process
vent
(
as
defined
in
§
63.641
of
this
subpart)
and
is
part
of
the
source
to
which
this
subpart
applies.

(
5)
If
the
predominant
use
of
a
distillation
unit
varies
from
year
to
year,
then
the
applicability
of
this
subpart
shall
be
determined
based
on
the
utilization
of
that
distillation
unit
during
the
year
preceding
promulgation
of
this
subpart.
This
determination
shall
be
reported
as
specified
in
§
63.654(
f)(
1)(
ii).

(
g)
The
provisions
of
this
subpart
do
not
apply
to
the
processes
specified
in
paragraphs
(
g)(
1)
through
(
g)(
7)
of
this
section.

(
1)
Research
and
development
facilities,
regardless
of
whether
the
facilities
are
located
at
the
same
plant
site
as
95
a
petroleum
refining
process
unit
that
is
subject
to
the
provisions
of
this
subpart;

(
2)
Equipment
that
does
not
contain
any
of
the
hazardous
air
pollutants
listed
in
table
1
of
this
subpart
that
is
located
within
a
petroleum
refining
process
unit
that
is
subject
to
this
subpart;

(
3)
Units
processing
natural
gas
liquids;

(
4)
Units
that
are
used
specifically
for
recycling
discarded
oil;

(
5)
Shale
oil
extraction
units;

(
6)
Ethylene
processes;
and
(
7)
Process
units
and
emission
points
subject
to
subparts
F,
G,
H,
and
I
of
this
part.

(
h)
Except
as
provided
in
paragraphs
(
k),
(
l),
or
(
m)

of
this
section,
sources
subject
to
this
subpart
are
required
to
achieve
compliance
on
or
before
the
dates
specified
in
paragraphs
(
h)(
1)
through
(
h)(
4)
of
this
section.

(
1)
New
sources
that
commence
construction
or
reconstruction
after
July
14,
1994
shall
be
in
compliance
with
this
subpart
upon
initial
startup
or
the
date
of
promulgation
of
this
subpart,
whichever
is
later,
as
provided
in
§
63.6(
b)
of
subpart
A
of
this
part.

(
2)
Except
as
provided
in
paragraphs
(
h)(
3)
through
(
h)(
5)
of
this
section,
existing
sources
shall
be
in
compliance
with
this
subpart
no
later
than
[
insert
date
96
3
years
after
date
of
publication
in
the
Federal
Register]

except
as
provided
in
§
63.6(
c)
of
subpart
A
of
this
part,

or
unless
an
extension
has
been
granted
by
the
Administrator
as
provided
in
§
63.6(
i)
of
subpart
A
of
this
part.

(
3)
Reserved.

(
4)
Existing
Group
1
floating
roof
storage
vessels
shall
be
in
compliance
with
§
63.646
at
the
next
degassing
and
cleaning
activity
or
within
10
years
after
promulgation
of
the
rule,
whichever
is
first.

(
5)
An
owner
or
operator
may
elect
to
comply
with
the
provisions
of
§
63.648(
c)
through
(
f)
as
an
alternative
to
the
provisions
of
§
63.648(
a)
and
(
b).
In
such
cases,
the
owner
or
operator
shall
comply
no
later
than
the
dates
specified
in
paragraphs
(
h)(
5)(
i)
through
(
h)(
5)(
iii)
of
this
section.

(
i)
Phase
I
(
see
table
2
of
this
subpart),
beginning
on
[
insert
date
3
years
after
date
of
publication
in
the
Federal
Register];

(
ii)
Phase
II
(
see
table
2
of
this
subpart),
beginning
no
later
than
[
insert
date
4
years
after
date
of
publication
in
the
Federal
Register];
and
(
iii)
Phase
III
(
see
table
2
of
this
subpart),

beginning
no
later
than
[
insert
date
5.5
years
after
date
of
publication
in
the
Federal
Register].

(
i)
If
an
additional
petroleum
refining
process
unit
is
added
to
a
plant
site
that
is
a
major
source
as
defined
97
in
section
112(
a)
of
the
Clean
Air
Act,
the
addition
shall
be
subject
to
the
requirements
for
a
new
source
if
it
meets
the
criteria
specified
in
paragraphs
(
i)(
1)
through
(
i)(
3):

(
1)
It
is
an
addition
that
meets
the
definition
of
construction
in
§
63.2
of
subpart
A
of
this
part;

(
2)
Such
construction
commenced
after
July
14,
1994;

and
(
3)
The
addition
has
the
potential
to
emit
10
tons
per
year
or
more
of
any
hazardous
air
pollutant
or
25
tons
per
year
or
more
of
any
combination
of
hazardous
air
pollutants.

(
j)
If
any
change
is
made
to
a
petroleum
refining
process
unit
subject
to
this
subpart,
the
change
shall
be
subject
to
the
requirements
for
a
new
source
if
it
meets
the
criteria
specified
in
paragraphs
(
j)(
1)
and
(
j)(
2):

(
1)
It
is
a
change
that
meets
the
definition
of
reconstruction
in
§
63.2
of
subpart
A
of
this
part;
and
(
2)
Such
reconstruction
commenced
after
July
14,
1994.

(
k)
If
an
additional
petroleum
refining
process
unit
is
added
to
a
plant
site
or
a
change
is
made
to
a
petroleum
refining
process
unit
and
the
addition
or
change
is
determined
to
be
subject
to
the
new
source
requirements
according
to
paragraphs
(
i)
or
(
j)
it
must
comply
with
the
requirements
specified
in
paragraphs
(
k)(
1)
and
(
k)(
2)
of
this
section:

(
1)
The
reconstructed
source,
addition,
or
change
shall
be
in
compliance
with
the
new
source
requirements
upon
98
initial
startup
of
the
reconstructed
source
or
by
the
date
of
promulgation
of
this
subpart,
whichever
is
later;
and
(
2)
The
owner
or
operator
of
the
reconstructed
source,

addition,
or
change
shall
comply
with
the
reporting
and
recordkeeping
requirements
that
are
applicable
to
new
sources.
The
applicable
reports
include,
but
are
not
limited
to:

(
i)
The
application
for
approval
of
construction
or
reconstruction
shall
be
submitted
as
soon
as
practical
before
the
construction
or
reconstruction
is
planned
to
commence
(
but
it
need
not
be
sooner
than
90
days
after
the
date
of
promulgation
of
this
subpart);

(
ii)
The
Notification
of
Compliance
Status
report
as
required
by
§
63.654(
f)
for
a
new
source,
addition,
or
change;

(
iii)
Periodic
Reports
and
Other
Reports
as
required
by
§
63.654(
g)
and
(
h);

(
iv)
Reports
and
notifications
required
by
§
60.487
of
subpart
VV
of
part
60
or
§
63.182
of
subpart
H
of
this
part.

The
requirements
for
subpart
H
are
summarized
in
table
3
of
this
subpart;

(
v)
Reports
required
by
40
CFR
61.357
of
subpart
FF;

(
vi)
Reports
and
notifications
required
by
§
63.428(
b),
(
c),
(
g)(
1),
and
(
h)(
1)
through
(
h)(
3)
of
subpart
R.
These
requirements
are
summarized
in
table
4
of
this
subpart;
and
99
(
vii)
Reports
and
notifications
required
by
§
§
63.566
and
63.567
of
subpart
Y
of
this
part.
These
requirements
are
summarized
in
table
5
of
this
subpart.

(
l)
If
an
additional
petroleum
refining
process
unit
is
added
to
a
plant
site
or
if
a
miscellaneous
process
vent,

storage
vessel,
gasoline
loading
rack,
or
marine
tank
vessel
loading
operation
that
meets
the
criteria
in
paragraphs
(
c)(
1)
through
(
c)(
7)
of
this
section
is
added
to
an
existing
petroleum
refinery
or
if
another
deliberate
operational
process
change
creating
an
additional
Group
1
emission
point(
s)
(
as
defined
in
§
63.641)
is
made
to
an
existing
petroleum
refining
process
unit,
and
if
the
addition
or
process
change
is
not
subject
to
the
new
source
requirements
as
determined
according
to
paragraphs
(
i)
or
(
j)
of
this
section,
the
requirements
in
paragraphs
(
l)(
1)

through
(
l)(
3)
of
this
section
shall
apply.
Examples
of
process
changes
include,
but
are
not
limited
to,
changes
in
production
capacity,
or
feed
or
raw
material
where
the
change
requires
construction
or
physical
alteration
of
the
existing
equipment
or
catalyst
type,
or
whenever
there
is
replacement,
removal,
or
addition
of
recovery
equipment.

For
purposes
of
this
paragraph
and
paragraph
(
m)
of
this
section,
process
changes
do
not
include:
process
upsets,

unintentional
temporary
process
changes,
and
changes
that
are
within
the
equipment
configuration
and
operating
100
conditions
documented
in
the
Notification
of
Compliance
Status
report
required
by
§
63.654(
f).

(
1)
The
added
emission
point(
s)
and
any
emission
point(
s)
within
the
added
or
changed
petroleum
refining
process
unit
are
subject
to
the
requirements
for
an
existing
source.

(
2)
The
added
emission
point(
s)
and
any
emission
point(
s)
within
the
added
or
changed
petroleum
refining
process
unit
shall
be
in
compliance
with
this
subpart
by
the
dates
specified
in
paragraphs
(
l)(
2)(
i)
or
(
l)(
2)(
ii)
of
this
section,
as
applicable.

(
i)
If
a
petroleum
refining
process
unit
is
added
to
a
plant
site
or
an
emission
point(
s)
is
added
to
any
existing
petroleum
refining
process
unit,
the
added
emission
point(
s)

shall
be
in
compliance
upon
initial
startup
of
any
added
petroleum
refining
process
unit
or
emission
point(
s)
or
by
3
years
after
the
date
of
promulgation
of
this
subpart,

whichever
is
later.

(
ii)
If
a
deliberate
operational
process
change
to
an
existing
petroleum
refining
process
unit
causes
a
Group
2
emission
point
to
become
a
Group
1
emission
point
(
as
defined
in
§
63.641),
the
owner
or
operator
shall
be
in
compliance
upon
initial
startup
or
by
3
years
after
the
date
of
promulgation
of
this
subpart,
whichever
is
later,
unless
the
owner
or
operator
demonstrates
to
the
Administrator
that
achieving
compliance
will
take
longer
than
making
the
101
change.
If
this
demonstration
is
made
to
the
Administrator's
satisfaction,
the
owner
or
operator
shall
follow
the
procedures
in
paragraphs
(
m)(
1)
through
(
m)(
3)
of
this
section
to
establish
a
compliance
date.

(
3)
The
owner
or
operator
of
a
petroleum
refining
process
unit
or
of
a
storage
vessel,
miscellaneous
process
vent,
wastewater
stream,
gasoline
loading
rack,
or
marine
tank
vessel
loading
operation
meeting
the
criteria
in
paragraphs
(
c)(
1)
through
(
c)(
7)
of
this
section
that
is
added
to
a
plant
site
and
is
subject
to
the
requirements
for
existing
sources
shall
comply
with
the
reporting
and
recordkeeping
requirements
that
are
applicable
to
existing
sources
including,
but
not
limited
to,
the
reports
listed
in
paragraphs
(
l)(
3)(
i)
through
(
l)(
3)(
vii)
of
this
section.

A
process
change
to
an
existing
petroleum
refining
process
unit
shall
be
subject
to
the
reporting
requirements
for
existing
sources
including,
but
not
limited
to,
the
reports
listed
in
paragraphs
(
l)(
3)(
i)
through
(
l)(
3)(
vii)
of
this
section.
The
applicable
reports
include,
but
are
not
limited
to:

(
i)
The
Notification
of
Compliance
Status
report
as
required
by
§
63.654(
f)
for
the
emission
points
that
were
added
or
changed;

(
ii)
Periodic
Reports
and
other
reports
as
required
by
§
63.654(
g)
and
(
h);
102
(
iii)
Reports
and
notifications
required
by
sections
of
subpart
A
of
this
part
that
are
applicable
to
this
subpart,
as
identified
in
table
6
of
this
subpart.

(
iv)
Reports
and
notifications
required
by
§
63.182
of
subpart
H
of
this
part,
or
§
60.407
of
subpart
VV
of
part
60.
The
requirements
of
subpart
H
are
summarized
in
table
3
of
this
subpart;

(
v)
Reports
required
by
§
61.357
of
subpart
FF;

(
vi)
Reports
and
notifications
required
by
§
63.428(
b),
(
c),
(
g)(
1),
and
(
h)(
1)
through
(
h)(
3)
of
subpart
R
of
this
part.
These
requirements
are
summarized
in
table
4
of
this
subpart;
and
(
vii)
Reports
and
notifications
required
by
§
63.567
of
subpart
Y
of
this
part.
These
requirements
are
summarized
in
table
5
of
this
subpart.

(
m)
If
a
change
that
does
not
meet
the
criteria
in
paragraph
(
l)
of
this
section
is
made
to
a
petroleum
refining
process
unit
subject
to
this
subpart,
and
the
change
causes
a
Group
2
emission
point
to
become
a
Group
1
emission
point
(
as
defined
in
§
63.641),
then
the
owner
or
operator
shall
comply
with
the
requirements
of
this
subpart
for
existing
sources
for
the
Group
1
emission
point
as
expeditiously
as
practicable,
but
in
no
event
later
than
3
years
after
the
emission
point
becomes
Group
1.
103
(
1)
The
owner
or
operator
shall
submit
to
the
Administrator
for
approval
a
compliance
schedule,
along
with
a
justification
for
the
schedule.

(
2)
The
compliance
schedule
shall
be
submitted
within
180
days
after
the
change
is
made
or
the
information
regarding
the
change
is
known
to
the
source,
unless
the
compliance
schedule
has
been
previously
submitted
to
the
permitting
authority.
The
compliance
schedule
may
be
submitted
in
the
next
Periodic
Report
if
the
change
is
made
after
the
date
the
Notification
of
Compliance
Status
report
is
due.

(
3)
The
Administrator
shall
approve
or
deny
the
compliance
schedule
or
request
changes
within
120
calendar
days
of
receipt
of
the
compliance
schedule
and
justification.
Approval
is
automatic
if
not
received
from
the
Administrator
within
120
calendar
days
of
receipt.

(
n)
Overlap
of
subpart
CC
with
other
regulations
for
storage
vessels.

(
1)
After
the
compliance
dates
specified
in
paragraph
(
h)
of
this
section,
a
Group
1
or
Group
2
storage
vessel
that
is
part
of
an
existing
source
and
is
also
subject
to
the
provisions
of
40
CFR
part
60
subpart
Kb
is
required
to
comply
only
with
the
requirements
of
40
CFR
part
60
subpart
Kb.

(
2)
After
the
compliance
dates
specified
in
paragraph
(
h)
of
this
section
a
Group
1
storage
vessel
that
104
is
part
of
a
new
source
and
is
subject
to
40
CFR
part
60,

subpart
Kb
is
required
to
comply
only
with
this
subpart.

(
3)
After
the
compliance
dates
specified
in
paragraph
(
h)
of
this
section,
a
Group
2
storage
vessel
that
is
part
of
a
new
source
and
is
subject
to
the
control
requirements
in
§
60.112b
of
40
CFR
part
60,
subpart
Kb
is
required
to
comply
only
with
40
CFR
part
60,
subpart
Kb.

(
4)
After
the
compliance
dates
specified
in
paragraph
(
h)
of
this
section,
a
Group
2
storage
vessel
that
is
part
of
a
new
source
and
is
subject
to
the
§
60.110b
subpart
Kb,
but
is
not
required
to
apply
controls
by
§
63.110b
or
63.112b
of
subpart
Kb
is
required
to
comply
only
with
this
subpart.

(
5)
After
the
compliance
dates
specified
in
paragraph
(
h)
of
this
section
a
Group
1
storage
vessel
that
is
also
subject
to
the
provisions
of
40
CFR
part
60,

subparts
K
or
Ka
is
required
to
only
comply
with
the
provisions
of
this
subpart.

(
6)
After
compliance
dates
specified
in
paragraph
(
h)

of
this
section,
a
Group
2
storage
vessel
that
is
subject
to
the
control
requirements
of
40
CFR
part
60,
subparts
K
or
Ka
is
required
to
only
comply
with
the
provisions
of
40
CFR
part
60,
subparts
K
or
Ka.

(
7)
After
the
compliance
dates
specified
in
paragraph
(
h)
of
this
section,
a
Group
2
storage
vessel
that
is
subject
to
40
CFR
part
60,
subparts
K
or
Ka,
but
not
to
105
the
control
requirements
of
40
CFR
part
60,
subparts
K
or
Ka,
is
required
to
comply
only
with
this
subpart.

(
o)
Overlap
of
subpart
CC
with
other
regulations
for
wastewater.

(
1)
After
the
compliance
dates
specified
in
paragraph
(
h)
of
this
section
a
Group
1
wastewater
stream
managed
in
a
piece
of
equipment
that
is
also
subject
to
the
provisions
of
40
CFR
part
60,
subpart
QQQ
is
required
to
comply
only
with
this
subpart.

(
2)
After
the
compliance
dates
specified
in
paragraph
(
h)
of
this
section
a
Group
1
or
Group
2
wastewater
stream
that
is
conveyed,
stored,
or
treated
in
a
wastewater
stream
management
unit
that
also
receives
streams
subject
to
the
provisions
of
§
§
63.133
through
63.147
of
subpart
G
wastewater
provisions
of
this
part
shall
comply
as
specified
in
paragraphs
(
o)(
2)(
i)
through
(
o)(
2)(
iii)
of
this
section.
Compliance
with
the
provisions
of
paragraph
(
o)(
2)
of
this
section
shall
constitute
compliance
with
the
requirements
of
this
subpart
for
that
wastewater
stream.

(
i)
The
provisions
in
§
§
63.133
through
63.137
and
§
63.140
of
subpart
G
for
all
equipment
used
in
the
storage
and
conveyance
of
the
Group
1
or
Group
2
wastewater
stream.

(
ii)
The
provisions
in
both
40
CFR
part
61,
subpart
FF
and
in
§
§
63.138
and
63.139
of
subpart
G
for
the
treatment
and
control
of
the
Group
1
or
Group
2
wastewater
stream.
106
(
iii)
The
provisions
in
§
§
63.143
through
63.148
of
subpart
G
for
monitoring
and
inspections
of
equipment
and
for
recordkeeping
and
reporting
requirements.
The
owner
or
operator
is
not
required
to
comply
with
the
monitoring,

recordkeeping,
and
reporting
requirements
associated
with
the
treatment
and
control
requirements
in
40
CFR
part
61,

subpart
FF,
§
§
61.355
through
61.357.

(
p)
Overlap
of
subpart
CC
with
other
regulations
for
equipment
leaks.
After
the
compliance
dates
specified
in
paragraph
(
h)
of
this
section
equipment
leaks
that
are
also
subject
to
the
provisions
of
40
CFR
parts
60
and
61
are
required
to
comply
only
with
the
provisions
specified
in
this
subpart.

(
q)
For
overlap
of
subpart
CC
with
local
or
State
regulations,
the
permitting
authority
for
the
affected
source
may
allow
consolidation
of
the
monitoring,

recordkeeping,
and
reporting
requirements
under
this
subpart
with
the
monitoring,
recordkeeping,
and
reporting
requirements
under
other
applicable
requirements
in
40
CFR
parts
60,
61,
or
63,
and
in
any
40
CFR
part
52
approved
State
implementation
plan
provided
the
implementation
plan
allows
for
approval
of
alternative
monitoring,
reporting,
or
recordkeeping
requirements
and
provided
that
the
permit
contains
an
equivalent
degree
of
compliance
and
control.
107
§
63.641
Definitions.

All
terms
used
in
this
subpart
shall
have
the
meaning
given
them
in
the
Clean
Air
Act,
subpart
A
of
this
part,
and
in
this
section.
If
the
same
term
is
defined
in
subpart
A
and
in
this
section,
it
shall
have
the
meaning
given
in
this
section
for
purposes
of
this
subpart.

Affected
source
means
the
collection
of
emission
points
to
which
this
subpart
applies
as
determined
by
the
criteria
in
§
63.640.
The
term
"
affected
source,"
as
used
in
this
subpart,
has
the
same
meaning
as
the
term
"
affected
source"

in
subpart
A
of
this
part.

Aliphatic
means
open­
chained
structure
consisting
of
paraffin,
olefin
and
acetylene
hydrocarbons
and
derivatives.

Boiler
means
any
enclosed
combustion
device
that
extracts
useful
energy
in
the
form
of
steam
and
is
not
an
incinerator.

By
compound
means
by
individual
stream
components,
not
by
carbon
equivalents.

Car­
seal
means
a
seal
that
is
placed
on
a
device
that
is
used
to
change
the
position
of
a
valve
(
e.
g.,
from
opened
to
closed)
in
such
a
way
that
the
position
of
the
valve
cannot
be
changed
without
breaking
the
seal.

Closed
vent
system
means
a
system
that
is
not
open
to
the
atmosphere
and
is
configured
of
piping,
ductwork,

connections,
and,
if
necessary,
flow
inducing
devices
that
transport
gas
or
vapor
from
an
emission
point
to
a
control
108
device
or
back
into
the
process.
If
gas
or
vapor
from
regulated
equipment
is
routed
to
a
process
(
e.
g.,
to
a
petroleum
refinery
fuel
gas
system),
the
process
shall
not
be
considered
a
closed
vent
system
and
is
not
subject
to
closed
vent
system
standards.

Combustion
device
means
an
individual
unit
of
equipment
such
as
a
flare,
incinerator,
process
heater,
or
boiler
used
for
the
combustion
of
organic
hazardous
air
pollutant
vapors.

Connector
means
flanged,
screwed,
or
other
joined
fittings
used
to
connect
two
pipe
lines
or
a
pipe
line
and
a
piece
of
equipment.
A
common
connector
is
a
flange.
Joined
fittings
welded
completely
around
the
circumference
of
the
interface
are
not
considered
connectors
for
the
purpose
of
this
regulation.
For
the
purpose
of
reporting
and
recordkeeping,
connector
means
joined
fittings
that
are
accessible.

Continuous
record
means
documentation,
either
in
hard
copy
or
computer
readable
form,
of
data
values
measured
at
least
once
every
hour
and
recorded
at
the
frequency
specified
in
§
63.654(
i).

Continuous
recorder
means
a
data
recording
device
recording
an
instantaneous
data
value
or
an
average
data
value
at
least
once
every
hour.

Control
device
means
any
equipment
used
for
recovering,

removing,
or
oxidizing
organic
hazardous
air
pollutants.
109
Such
equipment
includes,
but
is
not
limited
to,
absorbers,

carbon
adsorbers,
condensers,
incinerators,
flares,
boilers,

and
process
heaters.
For
miscellaneous
process
vents
(
as
defined
in
this
section),
recovery
devices
(
as
defined
in
this
section)
are
not
considered
control
devices.

Delayed
coker
vent
means
a
vent
that
is
typically
intermittent
in
nature,
and
usually
occurs
only
during
the
initiation
of
the
depressuring
cycle
of
the
decoking
operation
when
vapor
from
the
coke
drums
cannot
be
sent
to
the
fractionator
column
for
product
recovery,
but
instead
is
routed
to
the
atmosphere
through
a
closed
blowdown
system
or
directly
to
the
atmosphere
in
an
open
blowdown
system.
The
emissions
from
the
decoking
phases
of
delayed
coker
operations,
which
include
coke
drum
deheading,
draining,
or
decoking
(
coke
cutting),
are
not
considered
to
be
delayed
coker
vents.

Distillate
receiver
means
overhead
receivers,
overhead
accumulators,
reflux
drums,
and
condenser(
s)
including
ejector­
condenser(
s)
associated
with
a
distillation
unit.

Distillation
unit
means
a
device
or
vessel
in
which
one
or
more
feed
streams
are
separated
into
two
or
more
exit
streams,
each
exit
stream
having
component
concentrations
different
from
those
in
the
feed
stream(
s).
The
separation
is
achieved
by
the
redistribution
of
the
components
between
the
liquid
and
the
vapor
phases
by
vaporization
and
condensation
as
they
approach
equilibrium
within
the
110
distillation
unit.
Distillation
unit
includes
the
distillate
receiver,
reboiler,
and
any
associated
vacuum
pump
or
steam
jet.

Emission
point
means
an
individual
miscellaneous
process
vent,
storage
vessel,
wastewater
stream,
or
equipment
leak
associated
with
a
petroleum
refinery
process
unit;
an
individual
storage
vessel
or
equipment
leak
associated
with
a
bulk
gas
terminal
or
pipeline
breakout
station
classified
under
Standard
Industrial
Classification
code
2911;
a
gasoline
loading
rack
classified
under
Standard
Industrial
Classification
code
2911;
or
a
marine
tank
vessel
loading
operation
located
at
a
petroleum
refinery.

Equipment
leak
means
emissions
of
organic
hazardous
air
pollutants
from
a
pump,
compressor,
pressure
relief
device,

sampling
connection
system,
open­
ended
valve
or
line,
valve,

or
instrumentation
system
"
in
organic
hazardous
air
pollutant
service"
as
defined
in
this
section.
Vents
from
wastewater
system
drains,
tank
mixers,
and
sample
valves
on
storage
tanks
are
not
equipment
leaks.

Flame
zone
means
the
portion
of
a
combustion
chamber
of
a
boiler
or
process
heater
occupied
by
the
flame
envelope
created
by
the
primary
fuel.

Flexible
operation
unit
means
a
process
unit
that
manufactures
different
products
periodically
by
alternating
raw
materials
or
operating
conditions.
These
units
are
also
referred
to
as
campaign
plants
or
blocked
operations.
111
Flow
indicator
means
a
device
that
indicates
whether
gas
is
flowing,
or
whether
the
valve
position
would
allow
gas
to
flow,
in
a
line.

Fuel
gas
system
means
the
offsite
and
onsite
piping
and
control
system
that
gathers
gaseous
streams
generated
by
refinery
operations,
may
blend
them
with
sources
of
gas,
if
available,
and
transports
the
blended
gaseous
fuel
at
suitable
pressures
for
use
as
fuel
in
heaters,
furnaces,

boilers,
incinerators,
gas
turbines,
and
other
combustion
devices
located
within
or
outside
of
the
refinery.
The
fuel
is
piped
directly
to
each
individual
combustion
device,
and
the
system
typically
operates
at
pressures
over
atmospheric.

The
gaseous
streams
can
contain
a
mixture
of
methane,
light
hydrocarbons,
hydrogen
and
other
miscellaneous
species.

Gasoline
loading
rack
means
the
loading
arms,
pumps,

meters,
shutoff
valves,
relief
valves,
and
other
piping
and
valves
necessary
to
fill
gasoline
cargo
tanks.

Group
1
gasoline
loading
rack
means
any
gasoline
loading
rack
classified
under
Standard
Industrial
Classification
code
2911
that
emits
from
the
vapor
collection
and
processing
system
10
milligrams
of
total
organic
compounds
per
liter
of
gasoline
loaded.

Group
1
marine
tank
vessel
means
a
vessel
loaded
at
any
land­
or
sea­
based
terminal
or
structure
that
loads
liquid
commodities
with
vapor
pressures
greater
than
or
equal
to
10.3
kilopascals
in
bulk
onto
marine
tank
vessels,
that
112
emits
greater
than
9.1
megagrams
of
any
individual
HAP
or
13.6
megagrams
of
any
combination
of
HAP
annually
after
[
insert
date
4
years
after
date
of
publication
in
the
Federal
Register].

Group
1
miscellaneous
process
vent
means
a
miscellaneous
process
vent
for
which
the
volatile
organic
compound
concentration,
or
the
total
organic
concentration
(
minus
ethane
and
methane),
is
greater
than
or
equal
to
20
parts
per
million
by
volume,
and
the
total
volatile
organic
compound
emissions
are
greater
than
or
equal
to
33
kilograms
per
day
for
existing
and
7
kilograms
per
day
for
new
sources
at
the
outlet
of
the
final
recovery
device
(
if
any)
and
prior
to
any
control
device
and
prior
to
discharge
to
the
atmosphere.

Group
1
storage
vessel
means
a
storage
vessel
at
an
existing
source
that
has
a
design
storage
capacity
greater
than
or
equal
to
177
cubic
meters
and
stored­
liquid
maximum
true
vapor
pressure
greater
than
or
equal
to
10.4
kilopascals
and
HAP
liquid
concentration
greater
than
4
percent
by
weight
total
organic
HAP;
a
storage
vessel
at
a
new
source
that
has
a
design
storage
capacity
greater
than
or
equal
to
151
cubic
meters
and
stored­
liquid
maximum
true
vapor
pressure
greater
than
or
equal
to
3.4
kilopascals
and
HAP
liquid
concentration
greater
than
2
percent
by
weight
total
organic
HAP;
or
a
storage
vessel
at
a
new
source
that
has
a
design
storage
capacity
greater
than
or
equal
to
113
76
cubic
meters
and
less
than
151
cubic
meters
and
stored­
liquid
maximum
true
vapor
pressure
greater
than
or
equal
to
77
kilopascals
and
HAP
liquid
concentration
greater
than
2
percent
by
weight
total
organic
HAP.

Group
1
wastewater
stream
means
a
wastewater
stream
at
a
petroleum
refinery
with
a
total
annual
benzene
loading
of
10
megagrams
per
year
or
greater
as
calculated
according
to
the
procedures
in
40
CFR
part
61.342
of
subpart
FF
of
part
61
that
has
a
flow
rate
of
0.02
liters
per
minute
or
greater,
a
benzene
concentration
of
10
parts
per
million
by
weight
or
greater,
and
is
not
exempt
from
control
requirements
under
the
provisions
of
40
CFR
part
61,

subpart
FF.

Group
2
gasoline
loading
rack
means
a
gasoline
loading
rack
classified
under
Standard
Industrial
Classification
code
2911
that
does
not
meet
the
definition
of
a
Group
1
gasoline
loading
rack.

Group
2
marine
tank
vessel
means
a
marine
tank
vessel
that
does
not
meet
the
definition
of
a
Group
1
marine
tank
vessel.

Group
2
miscellaneous
process
vent
means
a
miscellaneous
process
vent
that
does
not
meet
the
definition
of
a
Group
1
miscellaneous
process
vent.

Group
2
storage
vessel
means
a
storage
vessel
that
does
not
meet
the
definition
of
a
Group
1
storage
vessel.
114
Group
2
wastewater
stream
means
a
wastewater
stream
that
does
not
meet
the
definition
of
Group
1
wastewater
stream.

Hazardous
air
pollutant
or
HAP
means
one
of
the
chemicals
listed
in
section
112(
b)
of
the
Clean
Air
Act.

Incinerator
means
an
enclosed
combustion
device
that
is
used
for
destroying
organic
compounds.
Auxiliary
fuel
may
be
used
to
heat
waste
gas
to
combustion
temperatures.
Any
energy
recovery
section
present
is
not
physically
formed
into
one
manufactured
or
assembled
unit
with
the
combustion
section;
rather,
the
energy
recovery
section
is
a
separate
section
following
the
combustion
section
and
the
two
are
joined
by
ducts
or
connections
carrying
flue
gas.

In
heavy
liquid
service
means
that
the
piece
of
equipment
is
not
in
gas/
vapor
service
or
in
light
liquid
service.

In
light
liquid
service
means
that
the
piece
of
equipment
contains
a
liquid
that
meets
the
conditions
specified
in
§
60.593(
d)
of
part
60,
subpart
GGG.

In
organic
hazardous
air
pollutant
service
means
that
a
piece
of
equipment
either
contains
or
contacts
a
fluid
(
liquid
or
gas)
that
is
at
least
5
percent
by
weight
of
total
organic
HAP's
as
determined
according
to
the
provisions
of
§
63.180(
d)
of
subpart
H
of
this
part
and
table
1
of
this
subpart.
The
provisions
of
§
63.180(
d)
of
115
subpart
H
also
specify
how
to
determine
that
a
piece
of
equipment
is
not
in
organic
HAP
service.

Maximum
true
vapor
pressure
means
the
equilibrium
partial
pressure
exerted
by
the
stored
liquid
at
the
temperature
equal
to
the
highest
calendar­
month
average
of
the
liquid
storage
temperature
for
liquids
stored
above
or
below
the
ambient
temperature
or
at
the
local
maximum
monthly
average
temperature
as
reported
by
the
National
Weather
Service
for
liquids
stored
at
the
ambient
temperature,
as
determined:

(
1)
In
accordance
with
methods
specified
in
§
63.111
of
subpart
G
of
this
part;

(
2)
From
standard
reference
texts;
or
(
3)
By
any
other
method
approved
by
the
Administrator.

Miscellaneous
process
vent
means
a
gas
stream
containing
greater
than
20
parts
per
million
by
volume
organic
HAP
that
is
continuously
or
periodically
discharged
during
normal
operation
of
a
petroleum
refining
process
unit
meeting
the
criteria
specified
in
§
63.640(
a).

Miscellaneous
process
vents
include
gas
streams
that
are
discharged
directly
to
the
atmosphere,
gas
streams
that
are
routed
to
a
control
device
prior
to
discharge
to
the
atmosphere,
or
gas
streams
that
are
diverted
through
a
product
recovery
device
prior
to
control
or
discharge
to
the
atmosphere.
Miscellaneous
process
vents
include
vent
streams
from:
caustic
wash
accumulators,
distillation
tower
116
condensers/
accumulators,
flash/
knockout
drums,
reactor
vessels,
scrubber
overheads,
stripper
overheads,
vacuum
(
steam)
ejectors,
wash
tower
overheads,
water
wash
accumulators,
blowdown
condensers/
accumulators,
and
delayed
coker
vents.
Miscellaneous
process
vents
do
not
include:

(
1)
Gaseous
streams
routed
to
a
fuel
gas
system;

(
2)
Relief
valve
discharges;

(
3)
Leaks
from
equipment
regulated
under
§
63.648;

(
4)
Episodic
or
nonroutine
releases
such
as
those
associated
with
startup,
shutdown,
malfunction,
maintenance,

depressuring,
and
catalyst
transfer
operations;

(
5)
In
situ
sampling
systems
(
onstream
analyzers);

(
6)
Catalytic
cracking
unit
catalyst
regeneration
vents;

(
7)
Catalytic
reformer
regeneration
vents;

(
8)
Sulfur
plant
vents;

(
9)
Vents
from
control
devices
such
as
scrubbers,

boilers,
incinerators,
and
electrostatic
precipitators
applied
to
catalytic
cracking
unit
catalyst
regeneration
vents,
catalytic
reformer
regeneration
vents,
and
sulfur
plant
vents;

(
10)
Vents
from
any
stripping
operations
applied
to
comply
with
the
wastewater
provisions
of
this
subpart,

subpart
G
of
this
part,
or
40
CFR
part
61,
subpart
FF;

(
11)
Coking
unit
vents
associated
with
coke
drum
depressuring
at
or
below
a
coke
drum
outlet
pressure
of
117
15
pounds
per
square
inch
gauge,
deheading,
draining,
or
decoking
(
coke
cutting)
or
pressure
testing
after
decoking;

and
(
12)
Vents
from
storage
vessels.

Operating
permit
means
a
permit
required
by
40
CFR
parts
70
or
71.

Organic
hazardous
air
pollutant
or
organic
HAP
in
this
subpart,
means
any
of
the
organic
chemicals
listed
in
table
1
of
this
subpart.

Petroleum­
based
solvents
means
mixtures
of
aliphatic
hydrocarbons
or
mixtures
of
one
and
two
ring
aromatic
hydrocarbons.

Periodically
discharged
means
discharges
that
are
intermittent
and
associated
with
routine
operations.

Discharges
associated
with
maintenance
activities
or
process
upsets
are
not
considered
periodically
discharged
miscellaneous
process
vents
and
are
therefore
not
regulated
by
the
petroleum
refinery
miscellaneous
process
vent
provisions.

Petroleum
refining
process
unit
means
a
process
unit
used
in
an
establishment
primarily
engaged
in
petroleum
refining
as
defined
in
the
Standard
Industrial
Classification
code
for
petroleum
refining
(
2911),
and
used
primarily
for
the
following:

(
1)
Producing
transportation
fuels
(
such
as
gasoline,

diesel
fuels,
and
jet
fuels),
heating
fuels
(
such
as
118
kerosene,
fuel
gas
distillate,
and
fuel
oils),
or
lubricants;

(
2)
Separating
petroleum;
or
(
3)
Separating,
cracking,
reacting,
or
reforming
intermediate
petroleum
streams.

(
4)
Examples
of
such
units
include,
but
are
not
limited
to,
petroleum­
based
solvent
units,
alkylation
units,

catalytic
hydrotreating,
catalytic
hydrorefining,
catalytic
hydrocracking,
catalytic
reforming,
catalytic
cracking,

crude
distillation,
lube
oil
processing,
hydrogen
production,
isomerization,
polymerization,
thermal
processes,
and
blending,
sweetening,
and
treating
processes.

Petroleum
refining
process
units
also
include
sulfur
plants.

Plant
site
means
all
contiguous
or
adjoining
property
that
is
under
common
control
including
properties
that
are
separated
only
by
a
road
or
other
public
right­
of­
way.

Common
control
includes
properties
that
are
owned,
leased,

or
operated
by
the
same
entity,
parent
entity,
subsidiary,

or
any
combination
thereof.

Primary
fuel
means
the
fuel
that
provides
the
principal
heat
input
(
i.
e.,
more
than
50
percent)
to
the
device.
To
be
considered
primary,
the
fuel
must
be
able
to
sustain
operation
without
the
addition
of
other
fuels.

Process
heater
means
an
enclosed
combustion
device
that
primarily
transfers
heat
liberated
by
burning
fuel
directly
119
to
process
streams
or
to
heat
transfer
liquids
other
than
water.

Process
unit
means
the
equipment
assembled
and
connected
by
pipes
or
ducts
to
process
raw
and/
or
intermediate
materials
and
to
manufacture
an
intended
product.
A
process
unit
includes
any
associated
storage
vessels.
For
the
purpose
of
this
subpart,
process
unit
includes,
but
is
not
limited
to,
chemical
manufacturing
process
units
and
petroleum
refining
process
units.

Process
unit
shutdown
means
a
work
practice
or
operational
procedure
that
stops
production
from
a
process
unit
or
part
of
a
process
unit
during
which
it
is
technically
feasible
to
clear
process
material
from
a
process
unit
or
part
of
a
process
unit
consistent
with
safety
constraints
and
during
which
repairs
can
be
accomplished.
An
unscheduled
work
practice
or
operational
procedure
that
stops
production
from
a
process
unit
or
part
of
a
process
unit
for
less
than
24
hours
is
not
considered
a
process
unit
shutdown.
An
unscheduled
work
practice
or
operational
procedure
that
would
stop
production
from
a
process
unit
or
part
of
a
process
unit
for
a
shorter
period
of
time
than
would
be
required
to
clear
the
process
unit
or
part
of
the
process
unit
of
materials
and
start
up
the
unit,

or
would
result
in
greater
emissions
than
delay
of
repair
of
leaking
components
until
the
next
scheduled
process
unit
shutdown
is
not
considered
a
process
unit
shutdown.
The
use
120
of
spare
equipment
and
technically
feasible
bypassing
of
equipment
without
stopping
production
are
not
considered
process
unit
shutdowns.

Recovery
device
means
an
individual
unit
of
equipment
capable
of
and
used
for
the
purpose
of
recovering
chemicals
for
use,
reuse,
or
sale.
Recovery
devices
include,
but
are
not
limited
to,
absorbers,
carbon
adsorbers,
and
condensers.

Reference
control
technology
for
gasoline
loading
racks
means
a
vapor
collection
and
processing
system
used
to
reduce
emissions
due
to
the
loading
of
gasoline
cargo
tanks
to
10
milligrams
of
total
organic
compounds
per
liter
of
gasoline
loaded
or
less.

Reference
control
technology
for
marine
vessels
means
a
vapor
collection
system
and
a
control
device
that
reduces
captured
HAP
emissions
by
97
percent.

Reference
control
technology
for
miscellaneous
process
vents
means
a
combustion
device
used
to
reduce
organic
HAP
emissions
by
98
percent,
or
to
an
outlet
concentration
of
20
parts
per
million
by
volume.

Reference
control
technology
for
storage
vessels
means
either:

(
1)
An
internal
floating
roof
meeting
the
specifications
of
§
63.119(
b)
of
subpart
G
except
for
§
63.119(
b)(
5)
and
(
b)(
6);
121
(
2)
An
external
floating
roof
meeting
the
specifications
of
§
63.119(
c)
of
subpart
G
except
for
§
63.119(
c)(
2)

(
3)
An
external
floating
roof
converted
to
an
internal
floating
roof
meeting
the
specifications
of
§
63.119(
d)
of
subpart
G
except
for
§
63.119(
d)(
2);
or
(
4)
A
closed­
vent
system
to
a
control
device
that
reduces
organic
HAP
emissions
by
95­
percent,
or
to
an
outlet
concentration
of
20
parts
per
million
by
volume.

(
5)
For
purposes
of
emissions
averaging,
these
four
technologies
are
considered
equivalent.

Reference
control
technology
for
wastewater
means
the
use
of:

(
1)
Controls
specified
in
§
§
61.343
through
61.347
of
subpart
FF
of
part
61;

(
2)
A
treatment
process
that
achieves
the
emission
reductions
specified
in
table
7
of
this
subpart
for
each
individual
HAP
present
in
the
wastewater
stream
or
is
a
steam
stripper
that
meets
the
specifications
in
§
63.138(
g)

of
subpart
G
of
this
part;
and
(
3)
a
control
device
to
reduce
by
95
percent
(
or
to
an
outlet
concentration
of
20
parts
per
million
by
volume
for
combustion
devices)
the
organic
HAP
emissions
in
the
vapor
streams
vented
from
treatment
processes
(
including
the
steam
stripper
described
in
paragraph
(
2)
of
this
definition)

managing
wastewater.
122
Refinery
fuel
gas
means
a
gaseous
mixture
of
methane,

light
hydrocarbons,
hydrogen,
and
other
miscellaneous
species
(
nitrogen,
carbon
dioxide,
hydrogen
sulfide,
etc.)

that
is
produced
in
the
refining
of
crude
oil
and/
or
petrochemical
processes
and
that
is
separated
for
use
as
a
fuel
in
boilers
and
process
heaters
throughout
the
refinery.

Relief
valve
means
a
valve
used
only
to
release
an
unplanned,
nonroutine
discharge.
A
relief
valve
discharge
can
result
from
an
operator
error,
a
malfunction
such
as
a
power
failure
or
equipment
failure,
or
other
unexpected
cause
that
requires
immediate
venting
of
gas
from
process
equipment
in
order
to
avoid
safety
hazards
or
equipment
damage.

Research
and
development
facility
means
laboratory
and
pilot
plant
operations
whose
primary
purpose
is
to
conduct
research
and
development
into
new
processes
and
products,

where
the
operations
are
under
the
close
supervision
of
technically
trained
personnel,
and
is
not
engaged
in
the
manufacture
of
products
for
commercial
sale,
except
in
a
de
minimis
manner.

Storage
vessel
means
a
tank
or
other
vessel
that
is
used
to
store
organic
liquids
that
are
in
organic
HAP
service.
Storage
vessel
does
not
include:

(
1)
Vessels
permanently
attached
to
motor
vehicles
such
as
trucks,
railcars,
barges,
or
ships;
123
(
2)
Pressure
vessels
designed
to
operate
in
excess
of
204.9
kilopascals
and
without
emissions
to
the
atmosphere;

(
3)
Vessels
with
capacities
smaller
than
40
cubic
meters;

(
4)
Bottoms
receiver
tanks;
or
(
5)
Wastewater
storage
tanks.
Wastewater
storage
tanks
are
covered
under
the
wastewater
provisions.

Temperature
monitoring
device
means
a
unit
of
equipment
used
to
monitor
temperature
and
having
an
accuracy
of
+
1
percent
of
the
temperature
being
monitored
expressed
in
degrees
Celsius
or
+
0.5
oC),
whichever
is
greater.

Total
annual
benzene
means
the
total
amount
of
benzene
in
waste
streams
at
a
facility
on
an
annual
basis
as
determined
in
§
61.342
of
40
CFR
part
61,
subpart
FF.

Total
organic
compounds
or
TOC,
as
used
in
this
subpart,
means
those
compounds
excluding
methane
and
ethane
measured
according
to
the
procedures
of
Method
18
of
40
CFR
part
60,
appendix
A.
Method
25A
may
be
used
alone
or
in
combination
with
Method
18
to
measure
TOC
as
provided
in
§
63.645
of
this
subpart.

Wastewater
means
water
or
wastewater
that,
during
production
or
processing,
comes
into
direct
contact
with
or
results
from
the
production
or
use
of
any
raw
material,

intermediate
product,
finished
product,
byproduct,
or
waste
product
and
is
discharged
into
any
individual
drain
system.

Examples
are
feed
tank
drawdown;
water
formed
during
a
124
chemical
reaction
or
used
as
a
reactant;
water
used
to
wash
impurities
from
organic
products
or
reactants;
water
used
to
cool
or
quench
organic
vapor
streams
through
direct
contact;

and
condensed
steam
from
jet
ejector
systems
pulling
vacuum
on
vessels
containing
organics.

§
63.642
General
standards.

(
a)
Each
owner
or
operator
of
a
source
subject
to
this
subpart
is
required
to
apply
for
a
part
70
or
part
71
operating
permit
from
the
appropriate
permitting
authority.
If
the
EPA
has
approved
a
State
operating
permit
program
under
part
70,
the
permit
shall
be
obtained
from
the
State
authority.
If
the
State
operating
permit
program
has
not
been
approved,
the
source
shall
apply
to
the
EPA
Regional
Office
pursuant
to
part
71.

(
b)
Reserved.

(
c)
Table
6
of
this
subpart
specifies
the
provisions
of
subpart
A
of
this
part
that
apply
and
those
that
do
not
apply
to
owners
and
operators
of
sources
subject
to
this
subpart.

(
d)
Initial
performance
tests
and
initial
compliance
determinations
shall
be
required
only
as
specified
in
this
subpart.

(
1)
Performance
tests
and
compliance
determinations
shall
be
conducted
according
to
the
schedule
and
procedures
specified
in
this
subpart.
125
(
2)
The
owner
or
operator
shall
notify
the
Administrator
of
the
intention
to
conduct
a
performance
test
at
least
30
days
before
the
performance
test
is
scheduled.

(
3)
Performance
tests
shall
be
conducted
according
to
the
provisions
of
§
63.7(
e)
except
that
performance
tests
shall
be
conducted
at
maximum
representative
operating
capacity
for
the
process.
During
the
performance
test,
an
owner
or
operator
shall
operate
the
control
device
at
either
maximum
or
minimum
representative
operating
conditions
for
monitored
control
device
parameters,
whichever
results
in
lower
emission
reduction.

(
4)
Data
shall
be
reduced
in
accordance
with
the
EPA­
approved
methods
specified
in
the
applicable
section
or,

if
other
test
methods
are
used,
the
data
and
methods
shall
be
validated
according
to
the
protocol
in
Method
301
of
appendix
A
of
this
part.

(
e)
Each
owner
or
operator
of
a
source
subject
to
this
subpart
shall
keep
copies
of
all
applicable
reports
and
records
required
by
this
subpart
for
at
least
5
years
except
as
otherwise
specified
in
this
subpart.
All
applicable
records
shall
be
maintained
in
such
a
manner
that
they
can
be
readily
accessed.
Records
for
the
most
recent
2
years
shall
be
retained
onsite
at
the
source
or
shall
be
accessible
from
a
central
location
by
computer.
The
remaining
3
years
of
records
may
be
retained
offsite.

Records
may
be
maintained
in
hard
copy
or
computer­
readable
126
EA
=
0.02 EPV1

 EPV2

0.05 ES1

 ES2

 EGLR1C

 EGLR2

(
R)
 EMV1

 EMV2

 EWW1C

 EWW2
form
including,
but
not
limited
to,
on
paper,
microfilm,

computer,
floppy
disk,
magnetic
tape,
or
microfiche.

(
f)
All
reports
required
under
this
subpart
shall
be
sent
to
the
Administrator
at
the
addresses
listed
in
§
63.13
of
subpart
A
of
this
part.
If
acceptable
to
both
the
Administrator
and
the
owner
or
operator
of
a
source,
reports
may
be
submitted
on
electronic
media.

(
g)
The
owner
or
operator
of
an
existing
source
subject
to
the
requirements
of
this
subpart
shall
control
emissions
of
organic
HAP's
to
the
level
represented
by
the
following
equation:

where:

EA
=
Emission
rate,
megagrams
per
year,

allowed
for
the
source.

0.02

EPV1
=
Sum
of
the
residual
emissions,
megagrams
per
year,
from
all
Group
1
miscellaneous
process
vents,
as
defined
in
§
63.641.

EPV2
=
Sum
of
the
emissions,
megagrams
per
year,
from
all
Group
2
process
vents,
as
defined
in
§
63.641.
127
0.05

ES1
=
Sum
of
the
residual
emissions,
megagrams
per
year,
from
all
Group
1
storage
vessels,
as
defined
in
§
63.641.

ES2
=
Sum
of
the
emissions,
megagrams
per
year,
from
all
Group
2
storage
vessels,

as
defined
in
§
63.641.

EGLR1C
=
Sum
of
the
residual
emissions,
megagrams
per
year,
from
all
Group
1
gasoline
loading
racks,
as
defined
in
§
63.641.

EGLR2
=
Sum
of
the
emissions,
megagrams
per
year,
from
all
Group
2
gasoline
loading
racks,
as
defined
in
§
63.641.

(
R)

EMV1
=
Sum
of
the
residual
emissions
megagrams
per
year,
from
all
Group
1
marine
tank
vessels,
as
defined
in
§
63.641.

R
=
0.03
for
existing
sources,
0.02
for
new
sources
except
offshore
loading
terminals,
and
0.05
for
new
offshore
loading
terminals.

EMV2
=
Sum
of
the
emissions,
megagrams
per
year
from
all
Group
2
marine
tank
vessels,
as
defined
in
§
63.641.

EWW1C
=
Sum
of
the
residual
emissions
from
all
Group
1
wastewater
streams,
as
defined
in
§
63.641.
This
term
is
calculated
128
for
each
Group
1
stream
according
to
the
equation
for
EWWic
in
§
63.652(
h)(
6).

EWW2
=
Sum
of
emissions
from
all
Group
2
wastewater
streams,
as
defined
in
§
63.641.

The
emissions
level
represented
by
this
equation
is
dependent
on
the
collection
of
emission
points
in
the
source.
The
level
is
not
fixed
and
can
change
as
the
emissions
from
each
emission
point
change
or
as
the
number
of
emission
points
in
the
source
changes.

(
h)
The
owner
or
operator
of
a
new
source
subject
to
the
requirements
of
this
subpart
shall
control
emissions
of
organic
HAP's
to
the
level
represented
by
the
equation
in
paragraph
(
g)
of
this
section.

(
i)
The
owner
or
operator
of
an
existing
source
shall
demonstrate
compliance
with
the
emission
standard
in
paragraph
(
g)
of
this
section
by
following
the
procedures
specified
in
paragraph
(
k)
of
this
section
for
all
emission
points,
or
by
following
the
emissions
averaging
compliance
approach
specified
in
paragraph
(
l)
of
this
section
for
specified
emission
points
and
the
procedures
specified
in
paragraph
(
k)
of
this
section
for
all
other
emission
points
within
the
source.

(
j)
The
owner
or
operator
of
a
new
source
shall
demonstrate
compliance
with
the
emission
standard
in
paragraph
(
h)
of
this
section
only
by
following
the
129
procedures
in
paragraph
(
k)
of
this
section.
The
owner
or
operator
of
a
new
source
may
not
use
the
emissions
averaging
compliance
approach.

(
k)
The
owner
or
operator
of
an
existing
source
may
comply,
and
the
owner
or
operator
of
a
new
source
shall
comply,
with
the
miscellaneous
process
vent
provisions
in
§
§
63.643
through
63.645,
the
storage
vessel
provisions
in
§
63.646,
the
wastewater
provisions
in
§
63.647,
the
gasoline
loading
rack
provisions
in
§
63.650,
and
the
marine
tank
vessel
loading
operation
provisions
in
§
63.651
of
this
subpart.

(
1)
The
owner
or
operator
using
this
compliance
approach
shall
also
comply
with
the
requirements
of
§
63.654
as
applicable.

(
2)
The
owner
or
operator
using
this
compliance
approach
is
not
required
to
calculate
the
annual
emission
rate
specified
in
paragraph
(
g)
of
this
section.

(
l)
The
owner
or
operator
of
an
existing
source
may
elect
to
control
some
of
the
emission
points
within
the
source
to
different
levels
than
specified
under
§
§
63.643
through
63.647,
§
§
63.650
and
63.651
by
using
an
emissions
averaging
compliance
approach
as
long
as
the
overall
emissions
for
the
source
do
not
exceed
the
emission
level
specified
in
paragraph
(
g)
of
this
section.
The
owner
or
operator
using
emissions
averaging
shall
meet
the
130
requirements
in
paragraphs
(
l)(
1)
and
(
l)(
2)
of
this
section.

(
1)
Calculate
emission
debits
and
credits
for
those
emission
points
involved
in
the
emissions
average
according
to
the
procedures
specified
in
§
63.652;
and
(
2)
Comply
with
the
requirements
of
§
§
63.652,
63.653,

and
63.654,
as
applicable.

(
m)
A
State
may
restrict
the
owner
or
operator
of
an
existing
source
to
using
only
the
procedures
in
paragraph
(
k)
of
this
section
to
comply
with
the
emission
standard
in
paragraph
(
g)
of
this
section.
Such
a
restriction
would
preclude
the
source
from
using
an
emissions
averaging
compliance
approach.

§
63.643
Miscellaneous
process
vent
provisions.

(
a)
The
owner
or
operator
of
a
Group
1
miscellaneous
process
vent
as
defined
in
§
63.641
shall
comply
with
the
requirements
of
either
paragraphs
(
a)(
1)
or
(
a)(
2)
of
this
section.

(
1)
Reduce
emissions
of
organic
HAP's
using
a
flare
that
meets
the
requirements
of
§
63.11(
b)
of
subpart
A
of
this
part.

(
2)
Reduce
emissions
of
organic
HAP's,
using
a
control
device,
by
98
weight­
percent
or
to
a
concentration
of
20
parts
per
million
by
volume,
on
a
dry
basis,
corrected
to
3
percent
oxygen,
whichever
is
less
stringent.
Compliance
131
can
be
determined
by
measuring
either
organic
HAP's
or
TOC's
using
the
procedures
in
§
63.645.

(
b)
If
a
boiler
or
process
heater
is
used
to
comply
with
the
percentage
of
reduction
requirement
or
concentration
limit
specified
in
paragraph
(
a)(
2)
of
this
section,
then
the
vent
stream
shall
be
introduced
into
the
flame
zone
of
such
a
device,
or
in
a
location
such
that
the
required
percent
reduction
or
concentration
is
achieved.

Testing
and
monitoring
is
required
only
as
specified
in
§
63.644(
a)
and
§
63.645
of
this
subpart.

§
63.644
Monitoring
provisions
for
miscellaneous
process
vents.

(
a)
Except
as
provided
in
paragraph
(
b)
of
this
section,
each
owner
or
operator
of
a
Group
1
miscellaneous
process
vent
that
uses
a
combustion
device
to
comply
with
the
requirements
in
§
63.643(
a)
of
this
section
shall
install
the
monitoring
equipment
specified
in
paragraph
(
a)(
1),
(
a)(
2),
(
a)(
3),
or
(
a)(
4)
of
this
section,

depending
on
the
type
of
combustion
device
used.
All
monitoring
equipment
shall
be
installed,
calibrated,

maintained,
and
operated
according
to
manufacturer's
specifications.

(
1)
Where
an
incinerator
is
used,
a
temperature
monitoring
device
equipped
with
a
continuous
recorder
is
required.
132
(
i)
Where
an
incinerator
other
than
a
catalytic
incinerator
is
used,
a
temperature
monitoring
device
shall
be
installed
in
the
firebox
or
in
the
ductwork
immediately
downstream
of
the
firebox
in
a
position
before
any
substantial
heat
exchange
occurs.

(
ii)
Where
a
catalytic
incinerator
is
used,

temperature
monitoring
devices
shall
be
installed
in
the
gas
stream
immediately
before
and
after
the
catalyst
bed.

(
2)
Where
a
flare
is
used,
a
device
(
including
but
not
limited
to
a
thermocouple,
an
ultraviolet
beam
sensor,
or
an
infrared
sensor)
capable
of
continuously
detecting
the
presence
of
a
pilot
flame
is
required.

(
3)
Any
boiler
or
process
heater
with
a
design
heat
input
capacity
greater
than
or
equal
to
44
megawatt
or
any
boiler
or
process
heater
in
which
all
vent
streams
are
introduced
into
the
flame
zone
is
exempt
from
monitoring.

(
4)
Any
boiler
or
process
heater
less
than
44
megawatts
design
heat
capacity
where
the
vent
stream
is
not
introduced
into
the
flame
zone
is
required
to
use
a
temperature
monitoring
device
in
the
firebox
equipped
with
a
continuous
recorder.

(
b)
An
owner
or
operator
of
a
Group
1
miscellaneous
process
vent
may
request
approval
to
monitor
parameters
other
than
those
listed
in
paragraph
(
a)
of
this
section.

The
request
shall
be
submitted
according
to
the
procedures
133
specified
in
§
63.654(
h).
Approval
shall
be
requested
if
the
owner
or
operator:

(
1)
Uses
a
control
device
other
than
an
incinerator,

boiler,
process
heater,
or
flare;
or
(
2)
Uses
one
of
the
control
devices
listed
in
paragraph
(
a)
of
this
section,
but
seeks
to
monitor
a
parameter
other
than
those
specified
in
paragraph
(
a)
of
this
section.

(
c)
The
owner
or
operator
of
a
Group
1
miscellaneous
process
vent
using
a
vent
system
that
contains
bypass
lines
that
could
divert
a
vent
stream
away
from
the
control
device
used
to
comply
with
paragraph
(
a)
of
this
section
shall
comply
with
either
paragraph
(
c)(
1)
or
(
c)(
2)
of
this
section.
Equipment
such
as
low
leg
drains,
high
point
bleeds,
analyzer
vents,
open­
ended
valves
or
lines,
pressure
relief
valves
needed
for
safety
reasons,
and
equipment
subject
to
§
63.648
of
this
section
are
not
subject
to
this
paragraph.

(
1)
Install,
calibrate,
maintain,
and
operate
a
flow
indicator
that
determines
whether
a
vent
stream
flow
is
present
at
least
once
every
hour.
Records
shall
be
generated
as
specified
in
§
63.654(
h)
and
(
i).
The
flow
indicator
shall
be
installed
at
the
entrance
to
any
bypass
line
that
could
divert
the
vent
stream
away
from
the
control
device
to
the
atmosphere;
or
134
(
2)
Secure
the
bypass
line
valve
in
the
closed
position
with
a
car­
seal
or
a
lock­
and­
key
type
configuration.
A
visual
inspection
of
the
seal
or
closure
mechanism
shall
be
performed
at
least
once
every
month
to
ensure
that
the
valve
is
maintained
in
the
closed
position
and
the
vent
stream
is
not
diverted
through
the
bypass
line.

(
d)
The
owner
or
operator
shall
establish
a
range
that
ensures
compliance
with
the
emissions
standard
for
each
parameter
monitored
under
paragraphs
(
a)
and
(
b)
of
this
section.
In
order
to
establish
the
range,
the
information
required
in
§
63.654(
f)(
1)(
ii)
shall
be
submitted
in
the
Notification
of
Compliance
Status
report.

(
e)
Each
owner
or
operator
of
a
control
device
subject
to
the
monitoring
provisions
of
this
section
shall
operate
the
control
device
in
a
manner
consistent
with
the
minimum
and/
or
maximum
operating
parameter
value
or
procedure
required
to
be
monitored
under
paragraphs
(
a)
and
(
b)
of
this
section.
Operation
of
the
control
device
in
a
manner
that
constitutes
a
period
of
excess
emissions,
as
defined
in
§
63.654(
g)(
6),
or
failure
to
perform
procedures
required
by
this
section
shall
constitute
a
violation
of
the
applicable
emission
standard
of
this
subpart.

§
63.645
Test
methods
and
procedures
for
miscellaneous
process
vents.

(
a)
To
demonstrate
compliance
with
§
63.643,
an
owner
or
operator
shall
follow
§
63.116
except
for
§
63.116(
d)
and
135
(
e)
of
subpart
G
of
this
part
except
as
provided
in
paragraphs
(
b)
through
(
d)
of
this
section.

(
b)
All
references
to
§
63.113(
a)(
1)
or
(
a)(
2)
in
§
63.116
of
subpart
G
of
this
part
shall
be
replaced
with
§
63.643(
a)(
1)
or
(
a)(
2),
respectively.

(
c)
In
§
63.116(
c)(
4)(
ii)(
C)
of
subpart
G
of
this
part,
organic
HAP's
in
the
list
of
HAP's
in
table
1
of
this
subpart
shall
be
considered
instead
of
the
organic
HAP's
in
table
2
of
subpart
F
of
this
part.

(
d)
All
references
to
§
63.116(
b)(
1)
or
(
b)(
2)
shall
be
replaced
with
paragraphs
(
d)(
1)
and
(
d)(
2)
of
this
section,
respectively.

(
1)
Any
boiler
or
process
heater
with
a
design
heat
input
capacity
of
44
megawatts
or
greater.

(
2)
Any
boiler
or
process
heater
in
which
all
vent
streams
are
introduced
into
the
flame
zone.

(
e)
For
purposes
of
determining
the
TOC
emission
rate,

as
specified
under
paragraph
(
f)
of
this
section,
the
sampling
site
shall
be
after
the
last
product
recovery
device
(
as
defined
in
§
63.641
of
this
subpart)
(
if
any
recovery
devices
are
present)
but
prior
to
the
inlet
of
any
control
device
(
as
defined
in
§
63.641
of
this
subpart)
that
is
present,
prior
to
any
dilution
of
the
process
vent
stream,
and
prior
to
release
to
the
atmosphere.
136
(
1)
Methods
1
or
1A
of
40
CFR
part
60,
appendix
A,
as
appropriate,
shall
be
used
for
selection
of
the
sampling
site.

(
2)
No
traverse
site
selection
method
is
needed
for
vents
smaller
than
0.10
meter
in
diameter.

(
f)
Except
as
provided
in
paragraph
(
g)
of
this
section,
an
owner
or
operator
seeking
to
demonstrate
that
a
process
vent
TOC
mass
flow
rate
is
less
than
33
kilograms
per
day
for
an
existing
source
or
less
than
6.8
kilograms
per
day
for
a
new
source
in
accordance
with
the
Group
2
process
vent
definition
of
this
subpart
shall
determine
the
TOC
mass
flow
rate
by
the
following
procedures:

(
1)
The
sampling
site
shall
be
selected
as
specified
in
paragraph
(
e)
of
this
section.

(
2)
The
gas
volumetric
flow
rate
shall
be
determined
using
Methods
2,
2A,
2C,
or
2D
of
40
CFR
part
60,

appendix
A,
as
appropriate.

(
3)
Method
18
or
Method
25A
of
40
CFR
part
60,

appendix
A
shall
be
used
to
measure
concentration;

alternatively,
any
other
method
or
data
that
has
been
validated
according
to
the
protocol
in
Method
301
of
appendix
A
of
this
part
may
be
used.
If
Method
25A
is
used,

and
the
TOC
mass
flow
rate
calculated
from
the
Method
25A
measurement
is
greater
than
or
equal
to
33
kilograms
per
day
for
an
existing
source
or
6.8
kilograms
per
day
for
a
new
source,
Method
18
may
be
used
to
determine
any
non­
VOC
137
CTOC


x
i

1

n
j

1
Cji
X
hydrocarbons
that
may
be
deducted
to
calculate
the
TOC
(
minus
non­
VOC
hydrocarbons)
concentration
and
mass
flow
rate.
The
following
procedures
shall
be
used
to
calculate
parts
per
million
by
volume
concentration:

(
i)
The
minimum
sampling
time
for
each
run
shall
be
1
hour
in
which
either
an
integrated
sample
or
four
grab
samples
shall
be
taken.
If
grab
sampling
is
used,
then
the
samples
shall
be
taken
at
approximately
equal
intervals
in
time,
such
as
15­
minute
intervals
during
the
run.

(
ii)
The
TOC
concentration
(
CTOC)
is
the
sum
of
the
concentrations
of
the
individual
components
and
shall
be
computed
for
each
run
using
the
following
equation
if
Method
18
is
used:

where:

CTOC
=
Concentration
of
TOC
(
minus
methane
and
ethane),
dry
basis,
parts
per
million
by
volume.

Cji
=
Concentration
of
sample
component
j
of
the
sample
i,
dry
basis,
parts
per
million
by
volume.
138
E
=
K2

n
j

1
CjMj
Qs
n
=
Number
of
components
in
the
sample.

x
=
Number
of
samples
in
the
sample
run.

(
4)
The
emission
rate
of
TOC
(
minus
methane
and
ethane)
(
ETOC)
shall
be
calculated
using
the
following
equation
if
Method
18
is
used:

where:

E
=
Emission
rate
of
TOC
(
minus
methane
and
ethane)
in
the
sample,
kilograms
per
day.

K2
=
Constant,
2.494
x
10­
6
(
parts
per
million)­
1
(
gram­
mole
per
standard
cubic
meter)

(
kilogram
per
gram)
(
minutes
per
hour),
where
the
standard
temperature
(
standard
cubic
meter)
is
at
20
oC.

Cj
=
Concentration
on
a
dry
basis
of
organic
compound
j
in
parts
per
million
as
measured
by
Method
18
of
40
CFR
part
60,
appendix
A,

as
indicated
in
paragraph
(
f)(
3)
of
this
section.
Cj
includes
all
organic
compounds
measured
minus
methane
and
ethane.

Mj
=
Molecular
weight
of
organic
compound
j,
gram
per
gram­
mole.
139
E
=
K2
CTOC
Qs
Qs
=
Vent
stream
flow
rate,
dry
standard
cubic
meters
per
minute,
at
a
temperature
of
20
oC.

(
5)
If
Method
25A
is
used
the
emission
rate
of
TOC
(
ETOC)
shall
be
calculated
using
the
following
equation:

where:

E
=
Emission
rate
of
TOC
(
minus
methane
and
ethane)
in
the
sample,
kilograms
per
day.

K2
=
Constant,
2.494
x
10­
6
(
parts
per
million)­
1
(
gram­
mole
per
standard
cubic
meter)

(
kilogram
per
gram)
(
minutes
per
hour),
where
the
standard
temperature
(
standard
cubic
meter)
is
at
20
oC.

CTOC
=
Concentration
of
TOC
on
a
dry
basis
in
parts
per
million
volume
as
measured
by
Method
25A
of
40
CFR
part
60,
appendix
A,
as
indicated
in
paragraph
(
f)(
3)
of
this
section.

Qs
=
Vent
stream
flow
rate,
dry
standard
cubic
meters
per
minute,
at
a
temperature
of
20
oC.

(
g)
Engineering
assessment
may
be
used
to
determine
the
TOC
emission
rate
for
the
representative
operating
condition
expected
to
yield
the
highest
daily
emission
rate.
140
(
1)
Engineering
assessment
includes,
but
is
not
limited
to,
the
following:

(
i)
Previous
test
results
provided
the
tests
are
representative
of
current
operating
practices
at
the
process
unit.

(
ii)
Bench­
scale
or
pilot­
scale
test
data
representative
of
the
process
under
representative
operating
conditions.

(
iii)
TOC
emission
rate
specified
or
implied
within
a
permit
limit
applicable
to
the
process
vent.

(
iv)
Design
analysis
based
on
accepted
chemical
engineering
principles,
measurable
process
parameters,
or
physical
or
chemical
laws
or
properties.
Examples
of
analytical
methods
include,
but
are
not
limited
to:

(
A)
Use
of
material
balances
based
on
process
stoichiometry
to
estimate
maximum
TOC
concentrations;

(
B)
Estimation
of
maximum
flow
rate
based
on
physical
equipment
design
such
as
pump
or
blower
capacities;
and
(
C)
Estimation
of
TOC
concentrations
based
on
saturation
conditions.

(
v)
All
data,
assumptions,
and
procedures
used
in
the
engineering
assessment
shall
be
documented.

(
h)
The
owner
or
operator
of
a
Group
2
process
vent
shall
recalculate
the
TOC
emission
rate
for
each
process
vent,
as
necessary,
whenever
process
changes
are
made
to
determine
whether
the
vent
is
in
Group
1
or
Group
2.
141
Examples
of
process
changes
include,
but
are
not
limited
to,

changes
in
production
capacity,
production
rate,
or
catalyst
type,
or
whenever
there
is
replacement,
removal,
or
addition
of
recovery
equipment.
For
purposes
of
this
paragraph,

process
changes
do
not
include:
process
upsets;

unintentional,
temporary
process
changes;
and
changes
that
are
within
the
range
on
which
the
original
calculation
was
based.

(
1)
The
TOC
emission
rate
shall
be
recalculated
based
on
measurements
of
vent
stream
flow
rate
and
TOC
as
specified
in
paragraphs
(
e)
and
(
f)
of
this
section,
as
applicable,
or
on
best
engineering
assessment
of
the
effects
of
the
change.
Engineering
assessments
shall
meet
the
specifications
in
paragraph
(
g)
of
this
section.

(
2)
Where
the
recalculated
TOC
emission
rate
is
greater
than
33
kilograms
per
day
for
an
existing
source
or
greater
than
6.8
kilograms
per
day
for
a
new
source,
the
owner
or
operator
shall
submit
a
report
as
specified
in
§
63.654(
c),
(
d),
(
e),
(
f),
or
(
g),
or
(
h)
and
shall
comply
with
the
appropriate
provisions
in
§
63.643
by
the
dates
specified
in
§
63.640.

§
63.646
Storage
vessel
provisions.

(
a)
Each
owner
or
operator
of
a
Group
1
storage
vessel
subject
to
this
subpart
shall
comply
with
the
requirements
of
§
§
63.119
through
63.121
of
subpart
G
of
this
part
except
as
provided
in
paragraphs
(
b)
through
(
m)
of
this
section.
142
(
b)
As
used
in
this
section,
all
terms
not
defined
in
§
63.641
shall
have
the
meaning
given
them
in
40
CFR
part
63,
subparts
A
or
G.
The
Group
1
storage
vessel
definition
presented
in
§
63.641
shall
apply
in
lieu
of
the
Group
1
storage
vessel
definitions
presented
in
tables
5
and
6
of
§
63.119
of
subpart
G
of
this
part.

(
1)
An
owner
or
operator
may
use
good
engineering
judgement
or
test
results
to
determine
the
stored
liquid
weight
percent
total
organic
HAP
for
purposes
of
group
determination.
Data,
assumptions,
and
procedures
used
in
the
determination
shall
be
documented.

(
2)
When
an
owner
or
operator
and
the
Administrator
do
not
agree
on
whether
the
weight
percent
organic
HAP
in
the
stored
liquid
is
above
or
below
4
percent
for
existing
sources
and
2
percent
for
new
sources,
Method
18
of
40
CFR
part
60,
appendix
A
shall
be
used.

(
c)
The
following
paragraphs
do
not
apply
to
storage
vessels
at
existing
sources
subject
to
this
subpart:

§
63.119(
b)(
5),
(
b)(
6),
(
c)(
2),
and
(
d)(
2).

(
d)
References
shall
be
replaced
as
specified
in
paragraphs
(
d)(
1)
through
(
d)(
9)
of
this
section.

(
1)
All
references
to
§
63.100(
k)
of
subpart
F
of
this
part
(
or
the
schedule
provisions
and
the
compliance
date)

shall
be
replaced
with
§
63.640(
h),

(
2)
All
references
to
April
22,
1994
shall
be
replaced
with
[
insert
date
of
this
Federal
Register
publication].
143
(
3)
All
references
to
December
31,
1992
shall
be
replaced
with
July
15,
1994.

(
4)
All
references
to
the
compliance
dates
specified
in
§
63.100
of
subpart
F
shall
be
replaced
with
§
63.640(
h)

through
(
m).

(
5)
All
references
to
§
63.150
in
§
63.119
of
subpart
G
of
this
part
shall
be
replaced
with
§
63.652.

(
6)
All
references
to
§
63.113(
a)(
2)
of
subpart
G
shall
be
replaced
with
§
63.643(
a)(
2)
of
this
subpart.

(
7)
All
references
to
§
63.126(
b)(
1)
of
subpart
G
shall
be
replaced
with
§
63.422(
b)
of
subpart
R
of
this
part.

(
8)
All
references
to
§
63.128(
a)
of
subpart
G
shall
be
replaced
with
§
63.425,
paragraphs
(
a)
through
(
c)
and
(
e)
through
(
h)
of
subpart
R
of
this
part.

(
9)
All
references
to
§
63.139(
d)(
1)
in
§
63.120(
d)(
1)(
iii)
of
subpart
G
shall
be
replaced
with
§
61.355
of
subpart
FF
of
part
61.

(
e)
When
complying
with
the
inspection
requirements
of
§
63.120
of
subpart
G
of
this
part,
owners
and
operators
of
storage
vessels
at
existing
sources
subject
to
this
subpart
are
not
required
to
comply
with
the
provisions
for
gaskets,

slotted
membranes,
and
sleeve
seals.

(
f)
The
following
paragraphs
(
f)(
1),
(
f)(
2),
and
(
f)(
3)
of
this
section
apply
to
Group
1
storage
vessels
at
existing
sources:
144
(
1)
If
a
cover
or
lid
is
installed
on
an
opening
on
a
floating
roof,
the
cover
or
lid
shall
remain
closed
except
when
the
cover
or
lid
must
be
open
for
access.

(
2)
Rim
space
vents
are
to
be
set
to
open
only
when
the
floating
roof
is
not
floating
or
when
the
pressure
beneath
the
rim
seal
exceeds
the
manufacturer's
recommended
setting.

(
3)
Automatic
bleeder
vents
are
to
be
closed
at
all
times
when
the
roof
is
floating
except
when
the
roof
is
being
floated
off
or
is
being
landed
on
the
roof
leg
supports.

(
g)
Failure
to
perform
inspections
and
monitoring
required
by
this
section
shall
constitute
a
violation
of
the
applicable
standard
of
this
subpart.

(
h)
References
in
§
§
63.119
through
63.121
to
§
63.122(
g)(
1),
§
63.151,
and
references
to
initial
notification
requirements
do
not
apply.

(
i)
References
to
the
Implementation
Plan
in
§
63.120,

paragraphs
(
d)(
2)
and
(
d)(
3)(
i)
shall
be
replaced
with
the
Notification
of
Compliance
Status
report.

(
j)
References
to
the
Notification
of
Compliance
Status
report
in
§
63.152(
b)
shall
be
replaced
with
§
63.654(
f).

(
k)
References
to
the
Periodic
Reports
in
§
63.152(
c)

shall
be
replaced
with
§
63.654(
g).
145
(
l)
The
State
or
local
permitting
authority
can
waive
the
notification
requirements
of
§
§
63.120(
a)(
5),

63.120(
a)(
6),
63.120(
b)(
10)(
ii),
and
63.120(
b)(
10)(
iii)
for
all
or
some
storage
vessels
at
petroleum
refineries
subject
to
this
subpart.
The
State
or
local
permitting
authority
may
also
grant
permission
to
refill
storage
vessels
sooner
than
30
days
after
submitting
the
notifications
in
§
§
63.120(
a)(
6)
or
63.120(
b)(
10)(
iii)
for
all
storage
vessels
at
a
refinery
or
for
individual
storage
vessels
on
a
case­
by­
case
basis.

§
63.647
Wastewater
provisions.

(
a)
Except
as
provided
in
paragraph
(
b)
of
this
section,
each
owner
or
operator
of
a
Group
1
wastewater
stream
shall
comply
with
the
requirements
of
§
§
61.340
through
61.355
of
40
CFR
part
61
subpart
FF
for
each
process
wastewater
stream
that
meets
the
definition
in
§
63.641.

(
b)
As
used
in
this
section,
all
terms
not
defined
in
§
63.641
shall
have
the
meaning
given
them
in
the
Clean
Air
Act
or
in
40
CFR
part
61
subpart
FF,
§
61.341.

(
c)
Each
owner
or
operator
required
under
subpart
FF
of
40
CFR
part
61
to
perform
periodic
measurement
of
benzene
concentration
in
wastewater,
or
to
monitor
process
or
control
device
operating
parameters
shall
operate
in
a
manner
consistent
with
the
minimum
or
maximum
(
as
appropriate)
permitted
concentration
or
operating
parameter
values.
Operation
of
the
process,
treatment
unit,
or
146
control
device
resulting
in
a
measured
concentration
or
operating
parameter
value
outside
the
permitted
limits
shall
constitute
a
violation
of
the
emission
standards.
Failure
to
perform
required
leak
monitoring
for
closed
vent
systems
and
control
devices
or
failure
to
repair
leaks
within
the
time
period
specified
in
subpart
FF
shall
constitute
a
violation
of
the
standard.

§
63.648
Equipment
leak
standards.

(
a)
Each
owner
or
operator
of
an
existing
source
subject
to
the
provisions
of
this
subpart
shall
comply
with
the
provisions
of
40
CFR
part
60
subpart
VV
and
paragraph
(
b)
of
this
section
except
as
provided
in
paragraphs
(
a)(
1),
(
a)(
2)
and
(
c)
through
(
i)
of
this
section.
Each
owner
or
operator
of
a
new
source
subject
to
the
provisions
of
this
subpart
shall
comply
with
subpart
H
of
this
part
except
as
provided
in
paragraphs
(
c)
through
(
i)
of
this
section.

(
1)
For
purposes
of
compliance
with
this
section,
the
provisions
of
40
CFR
part
60,
subpart
VV
apply
only
to
equipment
in
organic
HAP
service,
as
defined
in
§
63.641
of
this
subpart.

(
2)
Calculation
of
percentage
leaking
equipment
components
for
subpart
VV
may
be
done
on
a
process
unit
basis
or
a
sourcewide
basis.
Once
the
owner
or
operator
has
decided,
all
subsequent
calculations
shall
be
on
the
same
basis
unless
a
permit
change
is
made.
147
(
b)
The
use
of
monitoring
data
generated
before
[
insert
date
of
Federal
Register
publication]
to
qualify
for
less
frequent
monitoring
of
valves
and
pumps
as
provided
under
40
CFR
part
60
subpart
VV
or
subpart
H
of
this
part
and
paragraph
(
c)
of
this
section
(
i.
e.,
quarterly
or
semiannually)
is
governed
by
the
requirements
of
(
b)(
1)
and
(
b)(
2)
of
this
paragraph.

(
1)
Monitoring
data
must
meet
the
test
methods
and
procedures
specified
in
§
60.485(
b)
of
40
CFR
part
60,

subpart
VV
or
§
63.180(
b)(
1)
through
(
b)(
5)
of
subpart
H
of
this
part
except
for
minor
departures.

(
2)
Departures
from
the
criteria
specified
in
§
60.485(
b)
of
40
CFR
part
60
subpart
VV
or
§
63.180(
b)(
1)

through
(
b)(
5)
of
subpart
H
of
this
part
or
from
the
monitoring
frequency
specified
in
subpart
VV
or
in
paragraph
(
c)
of
this
section
(
such
as
every
6
weeks
instead
of
monthly
or
quarterly)
are
minor
and
do
not
significantly
affect
the
quality
of
the
data.
An
example
of
a
minor
departure
is
monitoring
at
a
slightly
different
frequency
(
such
as
every
6
weeks
instead
of
monthly
or
quarterly).

Failure
to
use
a
calibrated
instrument
is
not
considered
a
minor
departure.

(
c)
In
lieu
of
complying
with
the
existing
source
provisions
of
paragraph
(
a)
in
this
section,
an
owner
or
operator
may
elect
to
comply
with
the
requirements
of
§
§
63.161
through
63.169,
63.171,
63.172,
63.175,
63.176,
148
63.177,
63.179,
and
63.180
of
subpart
H
of
this
part
except
as
provided
in
paragraphs
(
c)(
1)
through
(
c)(
10)
and
(
e)

through
(
i)
of
this
section.

(
1)
The
instrument
readings
that
define
a
leak
for
light
liquid
pumps
subject
to
§
63.163
of
subpart
H
of
this
part
and
gas/
vapor
and
light
liquid
valves
subject
to
§
63.168
of
subpart
H
of
this
part
are
specified
in
table
2
of
this
subpart.

(
2)
In
phase
III
of
the
valve
standard,
the
owner
or
operator
may
monitor
valves
for
leaks
as
specified
in
paragraphs
(
c)(
2)(
i)
or
(
c)(
2)(
ii)
of
this
section.

(
i)
If
the
owner
or
operator
does
not
elect
to
monitor
connectors,
then
the
owner
or
operator
shall
monitor
valves
according
to
the
frequency
specified
in
table
8
of
this
subpart.

(
ii)
If
an
owner
or
operator
elects
to
monitor
connectors
according
to
the
provisions
of
§
63.649,

paragraphs
(
b),
(
c),
or
(
d),
then
the
owner
or
operator
shall
monitor
valves
at
the
frequencies
specified
in
table
9
of
this
subpart.

(
3)
The
owner
or
operator
shall
decide
no
later
than
the
first
required
monitoring
period
after
the
phase
I
compliance
date
specified
in
§
63.640(
h)
whether
to
calculate
the
percentage
leaking
valves
on
a
process
unit
basis
or
on
a
sourcewide
basis.
Once
the
owner
or
operator
149
has
decided,
all
subsequent
calculations
shall
be
on
the
same
basis
unless
a
permit
change
is
made.

(
4)
The
owner
or
operator
shall
decide
no
later
than
the
first
monitoring
period
after
the
phase
III
compliance
date
specified
in
§
63.640(
h)
whether
to
monitor
connectors
according
to
the
provisions
in
§
63.649,
paragraphs
(
b),

(
c),
or
(
d).

(
5)
Connectors
in
gas/
vapor
service
or
light
liquid
service
are
subject
to
the
requirements
for
connectors
in
heavy
liquid
service
in
§
63.169
of
subpart
H
of
this
part
(
except
for
the
agitator
provisions).
The
leak
definition
for
valves,
connectors,
and
instrumentation
systems
subject
to
§
63.169
is
1,000
parts
per
million.

(
6)
In
phase
III
of
the
pump
standard,
except
as
provided
in
paragraph
(
c)(
7),
owners
or
operators
that
achieve
less
than
10
percent
of
light
liquid
pumps
leaking
or
three
light
liquid
pumps
leaking,
whichever
is
greater,

shall
monitor
light
liquid
pumps
monthly.

(
7)
Owners
or
operators
that
achieve
less
than
3
percent
of
light
liquid
pumps
leaking
or
one
light
liquid
pump
leaking,
whichever
is
greater,
shall
monitor
light
liquid
pumps
quarterly.

(
8)
An
owner
or
operator
may
make
the
election
described
in
paragraphs
(
c)(
3)
and
(
c)(
4)
of
this
section
at
any
time
except
that
any
election
to
change
after
the
150
initial
election
shall
be
treated
as
a
permit
modification
according
to
the
terms
of
part
70
of
this
chapter.

(
9)
When
complying
with
the
requirements
of
§
63.138(
e)(
3)(
i)
of
subpart
H
of
this
part,
non­
repairable
valves
shall
be
included
in
the
calculation
of
percent
leaking
valves
the
first
time
the
valve
is
identified
as
leaking
and
non­
repairable.
Otherwise,
a
number
of
nonrepairable
valves
up
to
a
maximum
of
1
percent
per
year
of
the
total
number
of
valves
in
organic
HAP
service
up
to
a
maximum
of
3
percent
may
be
excluded
from
calculation
of
percent
leaking
valves
for
subsequent
monitoring
periods.

When
the
number
of
non­
repairable
valves
exceeds
3
percent
of
the
total
number
of
valves
in
organic
HAP
service,
the
number
of
non­
repairable
valves
exceeding
3
percent
of
the
total
number
shall
be
included
in
the
calculation
of
percent
leaking
valves.

(
10)
If
in
phase
III
of
the
valve
standard
any
valve
is
designated,
as
described
in
40
CFR
§
60.4685(
e)(
2),
as
having
no
detectable
emissions
the
owner
or
operator
has
the
option
of
following
the
provisions
of
§
60.482­
7(
f)
of
subpart
VV
of
part
60.
If
an
owner
or
operator
chooses
to
comply
with
the
provisions
of
40
CFR
§
60.482­
7(
f),
the
valve
is
exempt
from
the
valve
monitoring
provisions
of
§
63.168
of
subpart
H
of
this
part.

(
d)
Upon
startup
of
new
sources,
the
owner
or
operator
shall
comply
with
§
63.163(
a)(
1)(
ii)
of
subpart
H
of
this
151
part
for
light
liquid
pumps
and
§
63.168(
a)(
1)(
ii)
of
subpart
H
of
this
part
for
gas/
vapor
and
light
liquid
valves.

(
e)
For
reciprocating
pumps
in
heavy
liquid
service,

owners
and
operators
are
not
required
to
comply
with
the
requirements
in
§
63.169
of
subpart
H
of
this
part.

(
f)
Reciprocating
pumps
in
light
liquid
service
are
exempt
from
§
§
63.163
and
60.482
if
recasting
the
distance
piece
or
reciprocating
pump
replacement
is
required.

(
g)
Compressors
in
hydrogen
service
are
exempt
from
the
requirements
of
paragraphs
(
a)
and
(
c)
of
this
section
if
an
owner
or
operator
demonstrates
that
a
compressor
is
in
hydrogen
service.

(
1)
Each
compressor
is
presumed
not
to
be
in
hydrogen
service
unless
an
owner
or
operator
demonstrates
that
the
piece
of
equipment
is
in
hydrogen
service.

(
2)
For
a
piece
of
equipment
to
be
considered
in
hydrogen
service,
it
must
be
determined
that
the
percentage
hydrogen
content
can
be
reasonably
expected
always
to
exceed
50
percent
by
volume.

(
i)
For
purposes
of
determining
the
percentage
hydrogen
content
in
the
process
fluid
that
is
contained
in
or
contacts
a
compressor,
the
owner
or
operator
shall
use
either:

(
A)
Procedures
that
conform
to
those
specified
in
§
60.593(
b)(
2)
of
40
part
60,
subpart
GGG.
152
(
B)
Engineering
judgment
to
demonstrate
that
the
percentage
content
exceeds
50
percent
by
volume,
provided
the
engineering
judgment
demonstrates
that
the
content
clearly
exceeds
50
percent
by
volume.

(
1)
When
an
owner
or
operator
and
the
Administrator
do
not
agree
on
whether
a
piece
of
equipment
is
in
hydrogen
service,
the
procedures
in
paragraph
(
g)(
2)(
i)(
A)
of
this
section
shall
be
used
to
resolve
the
disagreement.

(
2)
If
an
owner
or
operator
determines
that
a
piece
of
equipment
is
in
hydrogen
service,
the
determination
can
be
revised
only
by
following
the
procedures
in
paragraph
(
g)(
2)(
i)(
A)
of
this
section.

(
h)
Each
owner
or
operator
of
a
source
subject
to
the
provisions
of
this
subpart
must
maintain
all
records
for
a
minimum
of
5
years.

(
i)
Reciprocating
compressors
are
exempt
from
seal
requirements
if
recasting
the
distance
piece
or
compressor
replacement
is
required.

§
63.649
Alternative
means
of
emission
limitation:

connectors
in
gas/
vapor
service
and
light
liquid
service.

(
a)
If
an
owner
or
operator
elects
to
monitor
valves
according
to
the
provisions
of
§
63.648(
c)(
2)(
ii),
the
owner
or
operator
shall
implement
one
of
the
connector
monitoring
programs
specified
in
paragraphs
(
b),
(
c),
or
(
d)
of
this
section.
153
(
b)
Random
200
connector
alternative.
The
owner
or
operator
shall
implement
a
random
sampling
program
for
accessible
connectors
of
2.0
inches
nominal
diameter
or
greater.
The
program
does
not
apply
to
inaccessible
or
unsafe­
to­
monitor
connectors,
as
defined
in
§
63.174
of
subpart
H.
The
sampling
program
shall
be
implemented
source­
wide.

(
1)
Within
the
first
12
months
after
the
phase
III
compliance
date
specified
in
§
63.640(
h),
a
sample
of
200
connectors
shall
be
randomly
selected
and
monitored
using
Method
21
of
40
CFR
part
60,
appendix
A.

(
2)
The
instrument
reading
that
defines
a
leak
is
1,000
parts
per
million.

(
3)
When
a
leak
is
detected,
it
shall
be
repaired
as
soon
as
practicable,
but
no
later
than
15
calendar
days
after
the
leak
is
detected
except
as
provided
in
paragraph
(
e)
of
this
section.
A
first
attempt
at
repair
shall
be
made
no
later
than
5
calendar
days
after
the
leak
is
detected.

(
4)
If
a
leak
is
detected,
the
connector
shall
be
monitored
for
leaks
within
the
first
3
months
after
its
repair.

(
5)
After
conducting
the
initial
survey
required
in
paragraph
(
b)(
1)
of
this
section,
the
owner
or
operator
shall
conduct
subsequent
monitoring
of
connectors
at
the
154
frequencies
specified
in
paragraphs
(
b)(
5)(
i)

through
(
b)(
5)(
iv)
of
this
section.

(
i)
If
the
percentage
leaking
connectors
is
2.0
percent
or
greater,
the
owner
or
operator
shall
survey
a
random
sample
of
200
connectors
once
every
6
months.

(
ii)
If
the
percentage
leaking
connectors
is
1.0
percent
or
greater
but
less
than
2.0
percent,
the
owner
or
operator
shall
survey
a
random
sample
of
200
connectors
once
per
year.

(
iii)
If
the
percentage
leaking
connectors
is
0.5
percent
or
greater
but
less
than
1.0
percent,
the
owner
or
operator
shall
survey
a
random
sample
of
200
connectors
once
every
2
years.

(
iv)
If
the
percentage
leaking
connectors
is
less
than
0.5
percent,
the
owner
or
operator
shall
survey
a
random
sample
of
200
connectors
once
every
4
years.

(
6)
Physical
tagging
of
the
connectors
to
indicate
that
they
are
subject
to
the
monitoring
provisions
is
not
required.
Connectors
may
be
identified
by
the
area
or
length
of
pipe
and
need
not
be
individually
identified.

(
c)
Connector
inspection
alternative.
The
owner
or
operator
shall
implement
a
program
to
monitor
all
accessible
connectors
in
gas/
vapor
service
that
are
2.0
inches
(
nominal
diameter)
or
greater
and
inspect
all
accessible
connectors
in
light
liquid
service
that
are
2
inches
(
nominal
diameter)

or
greater
as
described
in
paragraphs
(
c)(
1)
through
(
c)(
7)
155
of
this
section.
The
program
does
not
apply
to
inaccessible
or
unsafe­
to­
monitor
connectors.

(
1)
Within
12
months
after
the
phase
III
compliance
date
specified
in
§
63.640(
h),
all
connectors
in
gas/
vapor
service
shall
be
monitored
using
Method
21
of
40
CFR
part
60
appendix
A.
The
instrument
reading
that
defines
a
leak
is
1,000
parts
per
million.

(
2)
All
connectors
in
light
liquid
service
shall
be
inspected
for
leaks.
A
leak
is
detected
if
liquids
are
observed
to
be
dripping
at
a
rate
greater
than
three
drops
per
minute.

(
3)
When
a
leak
is
detected,
it
shall
be
repaired
as
soon
as
practicable,
but
no
later
than
15
calendar
days
after
the
leak
is
detected
except
as
provided
in
paragraph
(
e)
of
this
section.
A
first
attempt
at
repair
shall
be
made
no
later
than
5
calendar
days
after
the
leak
is
detected.

(
4)
If
a
leak
is
detected,
connectors
in
gas/
vapor
service
shall
be
monitored
for
leaks
within
the
first
3
months
after
repair.
Connectors
in
light
liquid
service
shall
be
inspected
for
indications
of
leaks
within
the
first
3
months
after
repair.
A
leak
is
detected
if
liquids
are
observed
to
be
dripping
at
a
rate
greater
than
three
drops
per
minute.

(
5)
After
conducting
the
initial
survey
required
in
paragraphs
(
c)(
1)
and
(
c)(
2)
of
this
section,
the
owner
or
156
%
CL

[
(
CL

CAN)/(
Ct

CC)]
x
100
operator
shall
conduct
subsequent
monitoring
at
the
frequencies
specified
in
paragraphs
(
c)(
5)(
i)

through
(
c)(
5)(
iii)
of
this
section.

(
i)
If
the
percentage
leaking
connectors
is
2.0
percent
or
greater,
the
owner
or
operator
shall
monitor
or
inspect,
as
applicable,
the
connectors
once
per
year.

(
ii)
If
the
percentage
leaking
connectors
is
1.0
percent
or
greater
but
less
than
2.0
percent,
the
owner
or
operator
shall
monitor
or
inspect,
as
applicable,
the
connectors
once
every
2
years.

(
iii)
If
the
percentage
leaking
connectors
is
less
than
1.0
percent,
the
owner
or
operator
shall
monitor
or
inspect,
as
applicable,
the
connectors
once
every
4
years.

(
6)
The
percentage
leaking
connectors
shall
be
calculated
for
connectors
in
gas/
vapor
service
and
for
connectors
in
light
liquid
service.
The
data
for
the
two
groups
of
connectors
shall
not
be
pooled
for
the
purpose
of
determining
the
percentage
leaking
connectors.

(
i)
The
percentage
leaking
connectors
shall
be
calculated
as
follows:

where:

%
CL
=
Percentage
leaking
connectors.

CL
=
Number
of
connectors
including
nonrepairables,
157
measured
at
1,000
parts
per
million
or
greater,

by
Method
21
of
40
CFR
part
60,
appendix
A.

CAN
=
Number
of
allowable
nonrepairable
connectors,
as
determined
by
monitoring,
not
to
exceed
3
percent
of
the
total
connector
population,
Ct.

Ct
=
Total
number
of
monitored
connectors,
including
nonrepairables,
in
the
process
unit.

Cc
=
Optional
credit
for
removed
connectors
=
0.67
x
net
number
(
i.
e.,
the
total
number
of
connectors
removed
minus
the
total
added)
of
connectors
in
organic
HAP
service
removed
from
the
process
unit
after
the
applicability
date
set
forth
in
§
63.640(
h)(
4)(
iii)
for
existing
process
units,
and
after
the
date
of
start­
up
for
new
process
units.
If
credits
are
not
taken,
then
Cc
=
0.

(
ii)
Nonrepairable
connectors
shall
be
included
in
the
calculation
of
percentage
leaking
connectors
the
first
time
the
connector
is
identified
as
leaking
and
nonrepairable.

Otherwise,
a
number
of
nonrepairable
connectors
up
to
a
maximum
of
1
percent
per
year
of
the
total
number
of
connectors
in
organic
HAP
service
up
to
a
maximum
of
3
percent
may
be
excluded
from
calculation
of
percentage
leaking
connectors
for
subsequent
monitoring
periods.

(
iii)
If
the
number
of
nonrepairable
connectors
exceeds
3
percent
of
the
total
number
of
connectors
in
158
organic
HAP
service,
the
number
of
nonrepairable
connectors
exceeding
3
percent
of
the
total
number
shall
be
included
in
the
calculation
of
the
percentage
leaking
connectors.

(
7)
Physical
tagging
of
the
connectors
to
indicate
that
they
are
subject
to
the
monitoring
provisions
is
not
required.
Connectors
may
be
identified
by
the
area
or
length
of
pipe
and
need
not
be
individually
identified.

(
d)
Subpart
H
program.
The
owner
or
operator
shall
implement
a
program
to
comply
with
the
provisions
in
§
63.174
of
this
part.

(
e)
Delay
of
repair
of
connectors
for
which
leaks
have
been
detected
is
allowed
if
repair
is
not
technically
feasible
by
normal
repair
techniques
without
a
process
unit
shutdown.
Repair
of
this
equipment
shall
occur
by
the
end
of
the
next
process
unit
shutdown.

(
1)
Delay
of
repair
is
allowed
for
equipment
that
is
isolated
from
the
process
and
that
does
not
remain
in
organic
HAP
service.

(
2)
Delay
of
repair
for
connectors
is
also
allowed
if:

(
i)
The
owner
or
operator
determines
that
emissions
of
purged
material
resulting
from
immediate
repair
would
be
greater
than
the
fugitive
emissions
likely
to
result
from
delay
of
repair,
and
(
ii)
When
repair
procedures
are
accomplished,
the
purged
material
would
be
collected
and
destroyed
or
recovered
in
a
control
device.
159
(
f)
Any
connector
that
is
designated
as
an
unsafe­
to­
repair
connector
is
exempt
from
the
requirements
of
paragraphs
(
b)(
3)
and
(
b)(
4),
(
c)(
3)
and
(
c)(
4),
or
(
d)

of
this
section
if:

(
1)
The
owner
or
operator
determines
that
repair
personnel
would
be
exposed
to
an
immediate
danger
as
a
consequence
of
complying
with
paragraphs
(
b)(
3)
and
(
b)(
4),

(
c)(
3)
and
(
c)(
4),
of
this
section;
or
(
2)
The
connector
will
be
repaired
before
the
end
of
the
next
scheduled
process
unit
shutdown.

(
g)
The
owner
or
operator
shall
maintain
records
to
document
that
the
connector
monitoring
or
inspections
have
been
conducted
as
required
and
to
document
repair
of
leaking
connectors
as
applicable.

§
63.650
Gasoline
loading
rack
provisions.

(
a)
Except
as
provided
in
paragraphs
(
b)
through
(
c)

of
this
section,
each
owner
or
operator
of
a
gasoline
loading
rack
classified
under
Standard
Industrial
Classification
code
2911
located
within
a
contiguous
area
and
under
common
control
with
a
petroleum
refinery
shall
comply
with
subpart
R,
§
§
63.421,
63.422(
a)
through
(
d),

63.425(
a)
through
(
c),
63.425(
e)
through
(
h),
63.427(
a)
and
(
b),
and
63.428(
b),
(
c),
(
g)(
1),
and
(
h)(
1)
through
(
h)(
3).

(
b)
As
used
in
this
section,
all
terms
not
defined
in
§
63.641
shall
have
the
meaning
given
them
in
subpart
A
or
160
in
40
CFR
part
63,
subpart
R.
The
§
63.641
definition
of
"
affected
source"
applies
under
this
section.

(
c)
Gasoline
loading
racks
regulated
under
this
subpart
are
subject
to
the
compliance
dates
specified
in
§
63.640(
h).

§
63.651
Marine
tank
vessel
loading
operation
provisions.

(
a)
Except
as
provided
in
paragraphs
(
b)
through
(
c)

of
this
section,
each
owner
or
operator
of
a
marine
tank
vessel
loading
operation
located
at
a
petroleum
refinery
shall
comply
with
the
requirements
of
§
§
63.560
through
63.567
of
40
CFR
part
63,
subpart
Y.

(
b)
As
used
in
this
section,
all
terms
not
defined
in
§
63.641
shall
have
the
meaning
given
them
in
subpart
A
or
in
40
CFR
part
63,
subpart
Y.
The
§
63.641
definition
of
"
affected
source"
applies
under
this
section.

(
c)
The
Initial
Notification
Report
under
§
63.567(
b)

is
not
required.

§
63.652
Emissions
averaging
provisions.

(
a)
This
section
applies
to
owners
or
operators
of
existing
sources
who
seek
to
comply
with
the
emission
standard
in
§
63.642(
g)
by
using
emissions
averaging
according
to
§
63.642(
l)
rather
than
following
the
provisions
of
§
§
63.643
through
63.647,
and
§
§
63.650
and
63.651.
Existing
marine
tank
vessel
loading
operations
unable
to
comply
with
the
standard
by
using
emissions
averaging
are
those
marine
tank
vessels
subject
to
40
CFR
161
§
63.562(
e)
of
this
part
and
the
Valdez
Marine
Terminal
source.

(
b)
The
owner
or
operator
shall
develop
and
submit
for
approval
an
Implementation
Plan
containing
all
of
the
information
required
in
§
63.653(
d)
for
all
points
to
be
included
in
an
emissions
average.
The
Implementation
Plan
shall
identify
all
emission
points
to
be
included
in
the
emissions
average.
This
must
include
any
Group
1
emission
points
to
which
the
reference
control
technology
(
defined
in
§
63.641)
is
not
applied
and
all
other
emission
points
being
controlled
as
part
of
the
average.

(
c)
The
following
emission
points
can
be
used
to
generate
emissions
averaging
credits
if
control
was
applied
after
November
15,
1990
and
if
sufficient
information
is
available
to
determine
the
appropriate
value
of
credits
for
the
emission
point:

(
1)
Group
2
emission
points;

(
2)
Group
1
storage
vessels,
Group
1
wastewater
streams,
Group
1
gasoline
loading
racks,
Group
1
marine
tank
vessels,
and
Group
1
miscellaneous
process
vents
that
are
controlled
by
a
technology
that
the
Administrator
or
permitting
authority
agrees
has
a
higher
nominal
efficiency
than
the
reference
control
technology.
Information
on
the
nominal
efficiencies
for
such
technologies
must
be
submitted
and
approved
as
provided
in
paragraph
(
i)
of
this
section;

and
162
(
3)
Emission
points
from
which
emissions
are
reduced
by
pollution
prevention
measures.
Percentages
of
reduction
for
pollution
prevention
measures
shall
be
determined
as
specified
in
paragraph
(
j)
of
this
section.

(
i)
For
a
Group
1
emission
point,
the
pollution
prevention
measure
must
reduce
emissions
more
than
the
reference
control
technology
would
have
had
the
reference
control
technology
been
applied
to
the
emission
point
instead
of
the
pollution
prevention
measure
except
as
provided
in
paragraph
(
c)(
3)(
ii)
of
this
section.

(
ii)
If
a
pollution
prevention
measure
is
used
in
conjunction
with
other
controls
for
a
Group
1
emission
point,
the
pollution
prevention
measure
alone
does
not
have
to
reduce
emissions
more
than
the
reference
control
technology,
but
the
combination
of
the
pollution
prevention
measure
and
other
controls
must
reduce
emissions
more
than
the
reference
control
technology
would
have
had
it
been
applied
instead.

(
d)
The
following
emission
points
cannot
be
used
to
generate
emissions
averaging
credits:

(
1)
Emission
points
already
controlled
on
or
before
November
15,
1990
unless
the
level
of
control
is
increased
after
November
15,
1990,
in
which
case
credit
will
be
allowed
only
for
the
increase
in
control
after
November
15,
1990;
163
(
2)
Group
1
emission
points
that
are
controlled
by
a
reference
control
technology
unless
the
reference
control
technology
has
been
approved
for
use
in
a
different
manner
and
a
higher
nominal
efficiency
has
been
assigned
according
to
the
procedures
in
paragraph
(
i)
of
this
section.
For
example,
it
is
not
allowable
to
claim
that
an
internal
floating
roof
meeting
only
the
specifications
stated
in
the
reference
control
technology
definition
in
§
63.641
(
i.
e.,

that
meets
the
specifications
of
§
63.119(
b)
of
subpart
G
but
does
not
have
controlled
fittings
per
§
63.119(
b)(
5)
and
(
b)(
6)
of
subpart
G)
applied
to
a
storage
vessel
is
achieving
greater
than
95
percent
control;

(
3)
Emission
points
on
shutdown
process
units.

Process
units
that
are
shut
down
cannot
be
used
to
generate
credits
or
debits;

(
4)
Wastewater
that
is
not
process
wastewater
or
wastewater
streams
treated
in
biological
treatment
units.

These
two
types
of
wastewater
cannot
be
used
to
generate
credits
or
debits.
Group
1
wastewater
streams
cannot
be
left
undercontrolled
or
uncontrolled
to
generate
debits.

For
the
purposes
of
this
section,
the
terms
"
wastewater"
and
"
wastewater
stream"
are
used
to
mean
process
wastewater;
and
(
5)
Emission
points
controlled
to
comply
with
a
State
or
Federal
rule
other
than
this
subpart,
unless
the
level
of
control
has
been
increased
after
November
15,
1990
above
what
is
required
by
the
other
State
or
Federal
rule.
Only
164
the
control
above
what
is
required
by
the
other
State
or
Federal
rule
will
be
credited.
However,
if
an
emission
point
has
been
used
to
generate
emissions
averaging
credit
in
an
approved
emissions
average,
and
the
point
is
subsequently
made
subject
to
a
State
or
Federal
rule
other
than
this
subpart,
the
point
can
continue
to
generate
emissions
averaging
credit
for
the
purpose
of
complying
with
the
previously
approved
average.

(
e)
For
all
points
included
in
an
emissions
average,

the
owner
or
operator
shall:

(
1)
Calculate
and
record
monthly
debits
for
all
Group
1
emission
points
that
are
controlled
to
a
level
less
stringent
than
the
reference
control
technology
for
those
emission
points.
Equations
in
paragraph
(
g)
of
this
section
shall
be
used
to
calculate
debits.

(
2)
Calculate
and
record
monthly
credits
for
all
Group
1
or
Group
2
emission
points
that
are
overcontrolled
to
compensate
for
the
debits.
Equations
in
paragraph
(
h)
of
this
section
shall
be
used
to
calculate
credits.
Emission
points
and
controls
that
meet
the
criteria
of
paragraph
(
c)

of
this
section
may
be
included
in
the
credit
calculation,

whereas
those
described
in
paragraph
(
d)
of
this
section
shall
not
be
included.

(
3)
Demonstrate
that
annual
credits
calculated
according
to
paragraph
(
h)
of
this
section
are
greater
than
165
or
equal
to
debits
calculated
for
the
same
annual
compliance
period
according
to
paragraph
(
g)
of
this
section.

(
i)
The
initial
demonstration
in
the
Implementation
Plan
that
credit­
generating
emission
points
will
be
capable
of
generating
sufficient
credits
to
offset
the
debits
from
the
debit­
generating
emission
points
must
be
made
under
representative
operating
conditions.

(
ii)
After
the
compliance
date,
actual
operating
data
will
be
used
for
all
debit
and
credit
calculations.

(
4)
Demonstrate
that
debits
calculated
for
a
quarterly
(
3­
month)
period
according
to
paragraph
(
g)
of
this
section
are
not
more
than
1.30
times
the
credits
for
the
same
period
calculated
according
to
paragraph
(
h)
of
this
section.

Compliance
for
the
quarter
shall
be
determined
based
on
the
ratio
of
credits
and
debits
from
that
quarter,
with
30
percent
more
debits
than
credits
allowed
on
a
quarterly
basis.

(
5)
Record
and
report
quarterly
and
annual
credits
and
debits
in
the
Periodic
Reports
as
specified
in
§
63.654(
g)(
8).
Every
fourth
Periodic
Report
shall
include
a
certification
of
compliance
with
the
emissions
averaging
provisions
as
required
by
§
63.654(
g)(
8)(
iii).

(
f)
Debits
and
credits
shall
be
calculated
in
accordance
with
the
methods
and
procedures
specified
in
paragraphs
(
g)
and
(
h)
of
this
section,
respectively,
and
shall
not
include
emissions
from
the
following:
166
(
1)
More
than
20
individual
emission
points.
Where
pollution
prevention
measures
(
as
specified
in
paragraph
(
j)(
1)
of
this
section)
are
used
to
control
emission
points
to
be
included
in
an
emissions
average,
no
more
than
25
emission
points
may
be
included
in
the
average.

For
example,
if
two
emission
points
to
be
included
in
an
emissions
average
are
controlled
by
pollution
prevention
measures,
the
average
may
include
up
to
22
emission
points.

(
2)
Periods
of
startup,
shutdown,
and
malfunction
as
described
in
the
source's
startup,
shutdown,
and
malfunction
plan
required
by
§
63.6(
e)(
3)
of
subpart
A
of
this
part.

(
3)
For
emission
points
for
which
continuous
monitors
are
used,
periods
of
excess
emissions
as
defined
in
§
63.654(
g)(
6)(
i).
For
these
periods,
the
calculation
of
monthly
credits
and
debits
shall
be
adjusted
as
specified
in
paragraphs
(
f)(
3)(
i)
through
(
f)(
3)(
iii)
of
this
section.

(
i)
No
credits
would
be
assigned
to
the
creditgenerating
emission
point.

(
ii)
Maximum
debits
would
be
assigned
to
the
debitgenerating
emission
point.

(
iii)
The
owner
or
operator
may
use
the
procedures
in
paragraph
(
l)
of
this
section
to
demonstrate
to
the
Administrator
that
full
or
partial
credits
or
debits
should
be
assigned.

(
g)
Debits
are
generated
by
the
difference
between
the
actual
emissions
from
a
Group
1
emission
point
that
is
167
Debits
=

n
i

1
EPViACTUAL

(
0.02)
EPViu

n
i

1
(
ESiACTUAL

(
0.05)
ESiu)

n
i

1
(
EGLRiACTUAL

EGLRiC)

n
i

1
(
EMViACTUAL

(
0.03)
EMViu)
uncontrolled
or
is
controlled
to
a
level
less
stringent
than
the
reference
control
technology,
and
the
emissions
allowed
for
Group
1
emission
point.
Debits
shall
be
calculated
as
follows:

(
1)
The
overall
equation
for
calculating
sourcewide
debits
is:

where:

Debits
and
all
terms
of
the
equation
are
in
units
of
megagrams
per
month,
and
EPViACTUAL
=
Emissions
from
each
Group
1
miscellaneous
process
vent
i
that
is
uncontrolled
or
is
controlled
to
a
level
less
stringent
than
the
reference
control
technology.
This
is
calculated
according
to
paragraph
(
g)(
2)
of
this
section.

(
0.02)
EPViu
=
Emissions
from
each
Group
1
miscellaneous
process
vent
i
if
the
168
reference
control
technology
had
been
applied
to
the
uncontrolled
emissions,
calculated
according
to
paragraph
(
g)(
2)
of
this
section.

ESiACTUAL
=
Emissions
from
each
Group
1
storage
vessel
i
that
is
uncontrolled
or
is
controlled
to
a
level
less
stringent
than
the
reference
control
technology.
This
is
calculated
according
to
paragraph
(
g)(
3)
of
this
section.

(
0.05)
ESiu
=
Emissions
from
each
Group
1
storage
vessel
i
if
the
reference
control
technology
had
been
applied
to
the
uncontrolled
emissions,
calculated
according
to
paragraph
(
g)(
3)
of
this
section.

EGLRiACTUAL
=
Emissions
from
each
Group
1
gasoline
loading
rack
i
that
is
uncontrolled
or
is
controlled
to
a
level
less
stringent
than
the
reference
control
technology.
This
is
calculated
according
to
paragraph
(
g)(
4)
of
this
section.

EGLRic
=
Emissions
from
each
Group
1
gasoline
loading
rack
i
if
the
169
reference
control
technology
had
been
applied
to
the
uncontrolled
emissions.
This
is
calculated
according
to
paragraph
(
g)(
4)
of
this
section.

EMVACTUAL
=
Emissions
from
each
Group
1
marine
tank
vessel
i
that
is
uncontrolled
or
is
controlled
to
a
level
less
stringent
than
the
reference
control
technology.
This
is
calculated
according
to
paragraph
(
g)(
5)
of
this
section.

(
0.03)
EMViu
=
Emissions
from
each
Group
1
marine
tank
vessel
i
if
the
reference
control
technology
had
been
applied
to
the
uncontrolled
emissions
calculated
according
to
paragraph
(
g)(
5)
of
this
section.

n
=
The
number
of
Group
1
emission
points
being
included
in
the
emissions
average.
The
value
of
n
is
not
necessarily
the
same
for
each
kind
of
emission
point.

(
2)
Emissions
from
miscellaneous
process
vents
shall
be
calculated
as
follows:
170
EPViu

(
2.494
x
10

9)
Qh

n
j

1
Cj
Mj
(
i)
For
purposes
of
determining
miscellaneous
process
vent
stream
flow
rate,
organic
HAP
concentrations,
and
temperature,
the
sampling
site
shall
be
after
the
final
product
recovery
device,
if
any
recovery
devices
are
present;
before
any
control
device
(
for
miscellaneous
process
vents,
recovery
devices
shall
not
be
considered
control
devices);
and
before
discharge
to
the
atmosphere.

Method
1
or
1A
of
part
60,
appendix
A
shall
be
used
for
selection
of
the
sampling
site.

(
ii)
The
following
equation
shall
be
used
for
each
miscellaneous
process
vent
i
to
calculate
EPViu:

where:

EPViu
=
Uncontrolled
process
vent
emission
rate
from
miscellaneous
process
vent
i,
megagrams
per
month.

Q
=
Vent
stream
flow
rate,
dry
standard
cubic
meters
per
minute,
measured
using
Methods
2,

2A,
2C,
or
2D
of
part
60
appendix
A,
as
appropriate.
171
h
=
Monthly
hours
of
operation
during
which
positive
flow
is
present
in
the
vent,
hours
per
month.

Cj
=
Concentration,
parts
per
million
by
volume,

dry
basis,
of
organic
HAP
j
as
measured
by
Method
18
of
part
60
appendix
A.

Mj
=
Molecular
weight
of
organic
HAP
j,
gram
per
gram­
mole.

n
=
Number
of
organic
HAP's
in
the
miscellaneous
process
vent
stream.

(
A)
The
values
of
Q,
Cj,
and
Mj
shall
be
determined
during
a
performance
test
conducted
under
representative
operating
conditions.
The
values
of
Q,
Cj,
and
Mj
shall
be
established
in
the
Notification
of
Compliance
Status
report
and
must
be
updated
as
provided
in
paragraph
(
g)(
2)(
ii)(
B)

of
this
section.

(
B)
If
there
is
a
change
in
capacity
utilization
other
than
a
change
in
monthly
operating
hours,
or
if
any
other
change
is
made
to
the
process
or
product
recovery
equipment
or
operation
such
that
the
previously
measured
values
of
Q,

Cj,
and
Mj
are
no
longer
representative,
a
new
performance
test
shall
be
conducted
to
determine
new
representative
values
of
Q,
Cj,
and
Mj.
These
new
values
shall
be
used
to
calculate
debits
and
credits
from
the
time
of
the
change
forward,
and
the
new
values
shall
be
reported
in
the
next
Periodic
Report.
172
EPViACTUAL

EPViu
x
1

Percent
reduction
100%
(
iii)
The
following
procedures
and
equations
shall
be
used
to
calculate
EPViACTUAL:

(
A)
If
the
vent
is
not
controlled
by
a
control
device
or
pollution
prevention
measure,
EPViACTUAL
=
EPViu,
where
EPViu
is
calculated
according
to
the
procedures
in
paragraphs
(
g)(
2)(
i)
and
(
g)(
2)(
ii)
of
this
section.

(
B)
If
the
vent
is
controlled
using
a
control
device
or
a
pollution
prevention
measure
achieving
less
than
98­
percent
reduction,

(
1)
The
percent
reduction
shall
be
measured
according
to
the
procedures
in
§
63.116
of
subpart
G
if
a
combustion
control
device
is
used.
For
a
flare
meeting
the
criteria
in
§
63.116(
a)
of
subpart
G,
or
a
boiler
or
process
heater
meeting
the
criteria
in
§
63.645(
d)
of
this
subpart
or
§
63.116(
b)
of
subpart
G,
the
percentage
of
reduction
shall
be
98
percent.
If
a
noncombustion
control
device
is
used,

percentage
of
reduction
shall
be
demonstrated
by
a
performance
test
at
the
inlet
and
outlet
of
the
device,
or,

if
testing
is
not
feasible,
by
a
control
design
evaluation
and
documented
engineering
calculations.
173
EGLRiu

(
1.20
x
10

7)
SPMG
T
(
2)
For
determining
debits
from
miscellaneous
process
vents,
product
recovery
devices
shall
not
be
considered
control
devices
and
cannot
be
assigned
a
percentage
of
reduction
in
calculating
EPViACTUAL.
The
sampling
site
for
measurement
of
uncontrolled
emissions
is
after
the
final
product
recovery
device.

(
3)
Procedures
for
calculating
the
percentage
of
reduction
of
pollution
prevention
measures
are
specified
in
paragraph
(
j)
of
this
section.

(
3)
Emissions
from
storage
vessels
shall
be
calculated
as
specified
in
§
63.150(
g)(
3)
of
subpart
G.

(
4)
Emissions
from
gasoline
loading
racks
shall
be
calculated
as
follows:

(
i)
The
following
equation
shall
be
used
for
each
gasoline
loading
rack
i
to
calculate
EGLRiu:

where:

EGLRiu
=
Uncontrolled
transfer
HAP
emission
rate
from
gasoline
loading
rack
i,
megagrams
per
month
S
=
Saturation
factor,
dimensionless
(
see
table
33
of
subpart
G).
174
P


j

n
1
Pj
Gj
G
P
=
Weighted
average
rack
partial
pressure
of
organic
HAP's
transferred
at
the
rack
during
the
month,
kilopascals.

M
=
Weighted
average
molecular
weight
of
organic
HAP's
transferred
at
the
gasoline
loading
rack
during
the
month,
gram
per
gram­
mole.

G
=
Monthly
volume
of
gasoline
transferred
from
gasoline
loading
rack,
liters
per
month.

T
=
Weighted
rack
bulk
liquid
loading
temperature
during
the
month,
degrees
kelvin
(
degrees
Celsius
oC
+
273).

(
ii)
The
following
equation
shall
be
used
for
each
gasoline
loading
rack
i
to
calculate
the
weighted
average
rack
partial
pressure:

where:

Pj
=
Maximum
true
vapor
pressure
of
individual
organic
HAP
transferred
at
the
rack,

kilopascals.

G
=
Monthly
volume
of
organic
HAP
transferred,

liters
per
month,
and
175
G


j

n
1
Gj
M


j

n
1
Mj
Gj
G
Gj
=
Monthly
volume
of
individual
organic
HAP
transferred
at
the
gasoline
loading
rack,

liters
per
month.

n
=
Number
of
organic
HAP's
transferred
at
the
gasoline
loading
rack.

(
iii)
The
following
equation
shall
be
used
for
each
gasoline
loading
rack
i
to
calculate
the
weighted
average
rack
molecular
weight:

where:

Mj
=
Molecular
weight
of
individual
organic
HAP
transferred
at
the
rack,
gram
per
gram­
mole.

G,
Gj,
and
n
are
as
defined
in
paragraph
(
g)(
4)(
ii)
of
this
section.
176
T


j

n
1
Tj
Gj
G
EGLR
ic

1
x
10

8
G
(
iv)
The
following
equation
shall
be
used
for
each
gasoline
loading
rack
i
to
calculate
the
monthly
weighted
rack
bulk
liquid
loading
temperature:

Tj
=
Average
annual
bulk
temperature
of
individual
organic
HAP
loaded
at
the
gasoline
loading
rack,

kelvin
(
degrees
Celsius
oC
+
273).

G,
Gj,
and
n
are
as
defined
in
paragraph
(
g)(
4)(
ii)
of
this
section.

(
v)
The
following
equation
shall
be
used
to
calculate
EGLRic:

G
is
as
defined
in
paragraph
(
g)(
4)(
ii)
of
this
section.

(
vi)
The
following
procedures
and
equations
shall
be
used
to
calculate
EGLRiACTUAL:

(
A)
If
the
gasoline
loading
rack
is
not
controlled,

EGLRiACTUAL
=
EGLRiu,
where
EGLRiu
is
calculated
using
the
177
EGLRiACTUAL

EGLRiu
1

Percent
reduction
100%
equations
specified
in
paragraphs
(
g)(
4)(
i)
through
(
g)(
4)(
iv)
of
this
section.

(
B)
If
the
gasoline
loading
rack
is
controlled
using
a
control
device
or
a
pollution
prevention
measure
not
achieving
the
requirement
of
less
than
10
milligrams
of
TOC
per
liter
of
gasoline
loaded,

(
1)
The
percent
reduction
for
a
control
device
shall
be
measured
according
to
the
procedures
and
test
methods
specified
in
§
63.128(
a)
of
subpart
G.
If
testing
is
not
feasible,
the
percentage
of
reduction
shall
be
determined
through
a
design
evaluation
according
to
the
procedures
specified
in
§
63.128(
h)
of
subpart
G.

(
2)
Procedures
for
calculating
the
percentage
of
reduction
for
pollution
prevention
measures
are
specified
in
paragraph
(
j)
of
this
section.

(
5)
Emissions
from
marine
tank
vessel
loading
shall
be
calculated
as
follows:

(
i)
The
following
equation
shall
be
used
for
each
marine
tank
vessel
i
to
calculate
EMViu:
178
EMViu


m
i

1
(
Qi)(
Fi)(
Pi)

where:

EMViu
=
Uncontrolled
marine
tank
vessel
HAP
emission
rate
from
marine
tank
vessel
i,
megagrams
per
month.

Qi
=
Quantity
of
commodity
loaded
(
per
vessel
type),
liters.

Fi
=
Emission
factor,
megagrams
per
liter.

Pi
=
Percent
HAP.

m
=
Number
of
combinations
of
commodities
and
vessel
types
loaded.

Emission
factors
shall
be
based
on
test
data
or
emission
estimation
procedures
specified
in
§
63.565(
l)
of
subpart
Y.

(
ii)
The
following
procedures
and
equations
shall
be
used
to
calculate
EMViACTUAL:

(
A)
If
the
marine
tank
vessel
is
not
controlled,

EMViACTUAL
=
EMViu,
where
EMViu
is
calculated
using
the
equations
specified
in
paragraph
(
g)(
5)(
i)
of
this
section.

(
B)
If
the
marine
tank
vessel
is
controlled
using
a
control
device
or
a
pollution
prevention
measure
achieving
less
than
97­
percent
reduction,
179
EMViACTUAL

EMViu
1

Percent
reduction
100%

(
1)
The
percent
reduction
for
a
control
device
shall
be
measured
according
to
the
procedures
and
test
methods
specified
in
§
63.565(
c)
of
subpart
Y.
If
testing
is
not
feasible,
the
percentage
of
reduction
shall
be
determined
through
a
design
evaluation
according
to
the
procedures
specified
in
§
63.128(
h)
of
subpart
G.

(
2)
Procedures
for
calculating
the
percentage
of
reduction
for
pollution
prevention
measures
are
specified
in
paragraph
(
j)
of
this
section.

(
h)
Credits
are
generated
by
the
difference
between
emissions
that
are
allowed
for
each
Group
1
and
Group
2
emission
point
and
the
actual
emissions
from
a
Group
1
or
Group
2
emission
point
that
has
been
controlled
after
November
15,
1990
to
a
level
more
stringent
than
what
is
required
by
this
subpart
or
any
other
State
or
Federal
rule
or
statute.
Credits
shall
be
calculated
as
follows:

(
1)
The
overall
equation
for
calculating
sourcewide
credits
is:
180
Credits
=
D

n
i

1
(
0.02)
EPV1iu

EPV1iACTUAL

D

m
i

1
EPV2iBASE

EPV2iACTUAL
D

n
i

1
(
0.05)
ES1iu

ES1iACTUAL

D

m
i

1
ES2iBASE

ES2iACTUAL

D

n
i

1
EGLRic

EGLR1iACTUAL

D

m
i

1
EGLR2iBASE

EGLR2iACTUAL

D

n
i

1
(
0.03)
EMV1iu

EMV1iACTUAL

D

m
i

1
EMV2iBASE

EMV2iACTUAL

D

n
i

1
EWW1ic

EWW1iACTUAL

D

m
i

1
EWW2iBASE

EWW2iACTUAL
where:

Credits
and
all
terms
of
the
equation
are
in
units
of
megagrams
per
month,
the
baseline
date
is
November
15,
1990,

and
D
=
Discount
factor
=
0.9
for
all
credit­
generating
emission
points
except
those
controlled
by
a
pollution
prevention
measure,
which
will
not
be
discounted.

EPV1iACTUAL
=
Emissions
for
each
Group
1
miscellaneous
process
vent
i
that
is
controlled
to
a
level
more
stringent
than
the
reference
control
technology,
calculated
according
to
paragraph
(
h)(
2)
of
this
section.
181
(
0.02)
EPV1iu
=
Emissions
from
each
Group
1
miscellaneous
process
vent
i
if
the
reference
control
technology
had
been
applied
to
the
uncontrolled
emissions.
EPV1iu
is
calculated
according
to
paragraph
(
h)(
2)
of
this
section.

EPV2iBASE
=
Emissions
from
each
Group
2
miscellaneous
process
vent;
at
the
baseline
date,
as
calculated
in
paragraph
(
h)(
2)
of
this
section.

EPV2iACTUAL
=
Emissions
from
each
Group
2
miscellaneous
process
vent
that
is
controlled,
calculated
according
to
paragraph
(
h)(
2)
of
this
section.

ES1iACTUAL
=
Emissions
from
each
Group
1
storage
vessel
i
that
is
controlled
to
a
level
more
stringent
than
the
reference
control
technology,

calculated
according
to
paragraph
(
h)(
3)
of
this
section.

(
0.05)
ES1iu
=
Emissions
from
each
Group
1
storage
vessel
i
if
the
reference
control
technology
had
been
applied
to
the
uncontrolled
emissions.
ES1iu
is
182
calculated
according
to
paragraph
(
h)(
3)
of
this
section.

ES2iACTUAL
=
Emissions
from
each
Group
2
storage
vessel
i
that
is
controlled,

calculated
according
to
paragraph
(
h)(
3)
of
this
section.

ES2iBASE
=
Emissions
from
each
Group
2
storage
vessel
i
at
the
baseline
date,
as
calculated
in
paragraph
(
h)(
3)
of
this
section.

EGLR1iACTUAL
=
Emissions
from
each
Group
1
gasoline
loading
rack
i
that
is
controlled
to
a
level
more
stringent
than
the
reference
control
technology,
calculated
according
to
paragraph
(
h)(
4)
of
this
section.

EGLRic
=
Emissions
from
each
Group
1
gasoline
loading
rack
i
if
the
reference
control
technology
had
been
applied
to
the
uncontrolled
emissions.
EGLRiu
is
calculated
according
to
paragraph
(
h)(
4)
of
this
section.

EGRL2iACTUAL
=
Emissions
from
each
Group
2
gasoline
loading
rack
i
that
is
183
controlled,
calculated
according
to
paragraph
(
h)(
4)
of
this
section.

EGLR2iBASE
=
Emissions
from
each
Group
2
gasoline
loading
rack
i
at
the
baseline
date,
as
calculated
in
paragraph
(
h)(
4)
of
this
section.

EMV1iACTUAL
=
Emissions
from
each
Group
1
marine
tank
vessel
i
that
is
controlled
to
a
level
more
stringent
than
the
reference
control
technology,

calculated
according
to
paragraph
(
h)(
4)
of
this
section.

(
0.03)
EMV1iu
=
Emissions
from
each
Group
1
marine
tank
vessel
i
if
the
reference
control
technology
had
been
applied
to
the
uncontrolled
emissions.

EMV1iu
is
calculated
according
to
paragraph
(
h)(
5)
of
this
section.

EMV2iACTUAL
=
Emissions
from
each
Group
2
marine
tank
vessel
i
that
is
controlled,

calculated
according
to
paragraph
(
h)(
5)
of
this
section.

EMV2iBASE
=
Emissions
from
each
Group
2
marine
tank
vessel
i
at
the
baseline
date,

as
calculated
in
paragraph
(
h)(
5)

of
this
section.
184
EWW1iACTUAL
=
Emissions
from
each
Group
1
wastewater
stream
i
that
is
controlled
to
a
level
more
stringent
than
the
reference
control
technology,
calculated
according
to
paragraph
(
h)(
6)
of
this
section.

EWW1ic
=
Emissions
from
each
Group
1
wastewater
stream
i
if
the
reference
control
technology
had
been
applied
to
the
uncontrolled
emissions,
calculated
according
to
paragraph
(
h)(
6)
of
this
section.

EWW2iACTUAL
=
Emissions
from
each
Group
2
wastewater
stream
i
that
is
controlled,
calculated
according
to
paragraph
(
h)(
6)
of
this
section.

EWW2iBASE
=
Emissions
from
each
Group
2
wastewater
stream
i
at
the
baseline
date,
calculated
according
to
paragraph
(
h)(
6)
of
this
section.

n
=
Number
of
Group
1
emission
points
included
in
the
emissions
average.

The
value
of
n
is
not
necessarily
the
same
for
each
kind
of
emission
point.
185
m
=
Number
of
Group
2
emission
points
included
in
the
emissions
average.

The
value
of
m
is
not
necessarily
the
same
for
each
kind
of
emission
point.

(
i)
For
an
emission
point
controlled
using
a
reference
control
technology,
the
percentage
of
reduction
for
calculating
credits
shall
be
no
greater
than
the
nominal
efficiency
associated
with
the
reference
control
technology,

unless
a
higher
nominal
efficiency
is
assigned
as
specified
in
paragraph
(
h)(
1)(
ii)
of
this
section.

(
ii)
For
an
emission
point
controlled
to
a
level
more
stringent
than
the
reference
control
technology,
the
nominal
efficiency
for
calculating
credits
shall
be
assigned
as
described
in
paragraph
(
i)
of
this
section.
A
reference
control
technology
may
be
approved
for
use
in
a
different
manner
and
assigned
a
higher
nominal
efficiency
according
to
the
procedures
in
paragraph
(
i)
of
this
section.

(
iii)
For
an
emission
point
controlled
using
a
pollution
prevention
measure,
the
nominal
efficiency
for
calculating
credits
shall
be
determined
as
described
in
paragraph
(
j)
of
this
section.

(
2)
Emissions
from
process
vents
shall
be
determined
as
follows:

(
i)
Uncontrolled
emissions
from
miscellaneous
process
vents,
EPV1iu,
shall
be
calculated
according
to
the
186
EPV1iACTUAL

EPV1iu
1

Nominal
efficiency
%

100%

EPV2iACTUAL

EPV2iu
x
1

Percent
reduction
100%
procedures
and
equation
for
EPViu
in
paragraphs
(
g)(
2)(
i)

and
(
g)(
2)(
ii)
of
this
section.

(
ii)
Actual
emissions
from
miscellaneous
process
vents
controlled
using
a
technology
with
an
approved
nominal
efficiency
greater
than
98
percent
or
a
pollution
prevention
measure
achieving
greater
than
98
percent
emission
reduction,
EPV1iACTUAL,
shall
be
calculated
according
to
the
following
equation:

(
iii)
The
following
procedures
shall
be
used
to
calculate
actual
emissions
from
Group
2
process
vents,

EPV2iACTUAL:

(
A)
For
a
Group
2
process
vent
controlled
by
a
control
device,
a
recovery
device
applied
as
a
pollution
prevention
project,
or
a
pollution
prevention
measure,
if
the
control
achieves
a
percentage
of
reduction
less
than
or
equal
to
a
98
percent
reduction,
187
(
1)
EPV2iu
shall
be
calculated
according
to
the
equations
and
procedures
for
EPViu
in
paragraphs
(
g)(
2)(
i)

and
(
g)(
2)(
ii)
of
this
section
except
as
provided
in
paragraph
(
h)(
2)(
iii)(
A)(
3)
of
this
section.

(
2)
The
percentage
of
reduction
shall
be
calculated
according
to
the
procedures
in
paragraphs
(
g)(
2)(
iii)(
B)(
1)

through
(
g)(
2)(
iii)(
B)(
3)
of
this
section
except
as
provided
in
paragraph
(
h)(
2)(
iii)(
A)(
4)
of
this
section.

(
3)
If
a
recovery
device
was
added
as
part
of
a
pollution
prevention
project,
EPV2iu
shall
be
calculated
prior
to
that
recovery
device.
The
equation
for
EPViu
in
paragraph
(
g)(
2)(
ii)
of
this
section
shall
be
used
to
calculate
EPV2iu;
however,
the
sampling
site
for
measurement
of
vent
stream
flow
rate
and
organic
HAP
concentration
shall
be
at
the
inlet
of
the
recovery
device.

(
4)
If
a
recovery
device
was
added
as
part
of
a
pollution
prevention
project,
the
percentage
of
reduction
shall
be
demonstrated
by
conducting
a
performance
test
at
the
inlet
and
outlet
of
that
recovery
device.

(
B)
For
a
Group
2
process
vent
controlled
using
a
technology
with
an
approved
nominal
efficiency
greater
than
a
98
percent
or
a
pollution
prevention
measure
achieving
greater
than
98
percent
reduction,
188
EPV2iACTUAL

EPV2iu
1

Nominal
efficiency
%

100%

EPV2iBASE

EPV2iu
1

Percent
reduction
%

100%
(
iv)
Emissions
from
Group
2
process
vents
at
baseline,

EPV2iBASE,
shall
be
calculated
as
follows:

(
A)
If
the
process
vent
was
uncontrolled
on
November
15,
1990,
EPV2iBASE
=
EPV2iu,
and
shall
be
calculated
according
to
the
procedures
and
equation
for
EPViu
in
paragraphs
(
g)(
2)(
i)
and
(
g)(
2)(
ii)
of
this
section.

(
B)
If
the
process
vent
was
controlled
on
November
15,
1990,

where
EPV2iu
is
calculated
according
to
the
procedures
and
equation
for
EPViu
in
paragraphs
(
g)(
2)(
i)
and
(
g)(
2)(
ii)
of
this
section.
The
percentage
of
reduction
shall
be
calculated
according
to
the
procedures
specified
in
paragraphs
(
g)(
2)(
iii)(
B)(
1)
through
(
g)(
2)(
iii)(
B)(
3)
of
this
section.
189
(
C)
If
a
recovery
device
was
added
to
a
process
vent
as
part
of
a
pollution
prevention
project
initiated
after
November
15,
1990,
EPV2iBASE
=
EPV2iu,
where
EPV2iu
is
calculated
according
to
paragraph
(
h)(
2)(
iii)(
A)(
3)
of
this
section.

(
3)
Emissions
from
storage
vessels
shall
be
determined
as
specified
in
§
63.150(
h)(
3)
of
subpart
G,
except
as
follows:

(
i)
All
references
to
§
63.119(
b)
in
§
63.150(
h)(
3)
of
subpart
G
shall
be
replaced
with:
§
63.119(
b)
or
§
63.119(
b)
except
for
§
63.119(
b)(
5)
and
(
b)(
6).

(
ii)
All
references
to
§
63.119(
c)
in
§
63.150(
h)(
3)

of
subpart
G
shall
be
replaced
with:
§
63.119(
c)
or
§
63.119(
c)
except
for
§
63.119(
c)(
2).

(
iii)
All
references
to
§
63.119(
d)
in
§
63.150(
h)(
3)

of
subpart
G
shall
be
replaced
with:
§
63.119(
d)
or
§
63.119(
d)
except
for
§
63.119(
d)(
2).

(
4)
Emissions
from
gasoline
loading
racks
shall
be
determined
as
follows:

(
i)
Uncontrolled
emissions
from
Group
1
gasoline
loading
racks,
EGLR1iu,
shall
be
calculated
according
to
the
procedures
and
equations
for
EGLRiu
as
described
in
paragraphs
(
g)(
4)(
i)
through
(
g)(
4)(
iv)
of
this
section.

(
ii)
Emissions
from
Group
1
gasoline
loading
racks
if
the
reference
control
technology
had
been
applied,
EGLRic,
190
EGLR1iACTUAL

EGLR1iu
1

Nominal
efficiency
100%

EGLR2iACTUAL

EGLR2iu
1

Percent
reduction
100%
shall
be
calculated
according
to
the
procedures
and
equations
in
paragraph
(
g)(
4)(
v)
of
this
section.

(
iii)
Actual
emissions
from
Group
1
gasoline
loading
racks
controlled
to
less
than
10
milligrams
of
TOC
per
liter
of
gasoline
loaded;
EGLRiACTUAL,
shall
be
calculated
according
to
the
following
equation:

(
iv)
The
following
procedures
shall
be
used
to
calculate
actual
emissions
from
Group
2
gasoline
loading
racks,
EGLR2iACTUAL:

(
A)
For
a
Group
2
gasoline
loading
rack
controlled
by
a
control
device
or
a
pollution
prevention
measure
achieving
emissions
reduction
but
where
emissions
are
greater
than
the
10
milligrams
of
TOC
per
liter
of
gasoline
loaded
requirement,
191
EGLR2iACTUAL

EGLR2iu
1

Nominal
efficiency
100%
(
1)
EGLR2iu
shall
be
calculated
according
to
the
equations
and
procedures
for
EGLRiu
in
paragraphs
(
g)(
4)(
i)

through
(
g)(
4)(
iv)
of
this
section.

(
2)
The
percentage
of
reduction
shall
be
calculated
according
to
the
procedures
in
paragraphs
(
g)(
4)(
vi)(
B)(
1)

and
(
g)(
4)(
vi)(
B)(
2)
of
this
section.

(
B)
For
a
Group
2
gasoline
loading
rack
controlled
using
a
technology
with
an
approved
nominal
efficiency
greater
than
98
percent
or
a
pollution
prevention
measure
achieving
greater
than
a
98­
percent
reduction,

(
v)
Emissions
from
Group
2
gasoline
loading
racks
at
baseline,
EGLR2iBASE,
shall
be
calculated
as
follows:

(
A)
If
the
gasoline
loading
rack
was
uncontrolled
on
November
15,
1990,
EGLR2iBASE
=
EGLR2iu,
and
shall
be
calculated
according
to
the
procedures
and
equations
for
EGLRiu
in
paragraphs
(
g)(
4)(
i)
through
(
g)(
4)(
iv)
of
this
section.

(
B)
If
the
gasoline
loading
rack
was
controlled
on
November
15,
1990,
192
EGLR2iBASE

EGLR2iu
1

Percent
reduction
100%

EMV1iACTUAL

EMV1iu
1

Nominal
efficiency
100%
where
EGLR2iu
is
calculated
according
to
the
procedures
and
equations
for
EGLRiu
in
paragraphs
(
g)(
4)(
i)
through
(
g)(
4)(
iv)
of
this
section.
Percentage
of
reduction
shall
be
calculated
according
to
the
procedures
in
paragraphs
(
g)(
4)(
vi)(
B)(
1)
and
(
g)(
4)(
vi)(
B)(
2)
of
this
section.

(
5)
Emissions
from
marine
tank
vessels
shall
be
determined
as
follows:

(
i)
Uncontrolled
emissions
from
Group
1
marine
tank
vessels,
EMV1iu,
shall
be
calculated
according
to
the
procedures
and
equations
for
EMViu
as
described
in
paragraph
(
g)(
5)(
i)
of
this
section.

(
ii)
Actual
emissions
from
Group
1
marine
tank
vessels
controlled
using
a
technology
or
pollution
prevention
measure
with
an
approved
nominal
efficiency
greater
than
97
percent,
EMViACTUAL,
shall
be
calculated
according
to
the
following
equation:
193
EMV2iACTUAL

EMV2iu
1

Percent
reduction
100%

EMV2iACTUAL

EMV2iu
1

Nominal
efficiency
100%
(
iii)
The
following
procedures
shall
be
used
to
calculate
actual
emissions
from
Group
2
marine
tank
vessels,

EMV2iACTUAL:

(
A)
For
a
Group
2
marine
tank
vessel
controlled
by
a
control
device
or
a
pollution
prevention
measure
achieving
a
percentage
of
reduction
less
than
or
equal
to
97
percent
reduction,

(
1)
EMV2iu
shall
be
calculated
according
to
the
equations
and
procedures
for
EMViu
in
paragraph
(
g)(
5)(
i)
of
this
section.

(
2)
The
percentage
of
reduction
shall
be
calculated
according
to
the
procedures
in
paragraphs
(
g)(
5)(
ii)(
B)(
1)

and
(
g)(
5)(
ii)(
B)(
2)
of
this
section.

(
B)
For
a
Group
2
marine
tank
vessel
controlled
using
a
technology
or
a
pollution
prevention
measure
with
an
approved
nominal
efficiency
greater
than
97
percent,
194
EMV2iBASE

EMV2iu
1

Percent
reduction
100%
(
iv)
Emissions
from
Group
2
marine
tank
vessels
at
baseline,
EMV2iBASE,
shall
be
calculated
as
follows:

(
A)
If
the
marine
terminal
was
uncontrolled
on
November
15,
1990,
EMV2iBASE
equals
EMV2iu,
and
shall
be
calculated
according
to
the
procedures
and
equations
for
EMViu
in
paragraph
(
g)(
5)(
i)
of
this
section.

(
B)
If
the
marine
tank
vessel
was
controlled
on
November
15,
1990,

where
EMV2iu
is
calculated
according
to
the
procedures
and
equations
for
EMViu
in
paragraph
(
g)(
5)(
i)
of
this
section.

Percentage
of
reduction
shall
be
calculated
according
to
the
procedures
in
paragraphs
(
g)(
5)(
ii)(
B)(
1)
and
(
g)(
5)(
ii)(
B)(
2)
of
this
section.

(
6)
Emissions
from
wastewater
shall
be
determined
as
follows:

(
i)
For
purposes
of
paragraphs
(
h)(
4)(
ii)
through
(
h)(
4)(
vi)
of
this
section,
the
following
terms
will
have
the
meaning
given
them
in
paragraphs
(
h)(
6)(
i)(
A)
through
(
h)(
6)(
i)(
C)
of
this
section.

(
A)
Correctly
suppressed
means
that
a
wastewater
stream
is
being
managed
according
to
the
requirements
of
195
EWWic

(
6.0

10

8)
Qi
Hi

s
m

1
1

Frm
Fem
HAPim

(
0.05)
(
6.0

10

8)
Qi
Hi

s
m

1
Frm
HAPim
§
§
61.343
through
61.347
or
§
61.342(
c)(
l)(
iii)
of
40
CFR
part
61,
subpart
FF,
as
applicable,
and
the
emissions
from
the
waste
management
units
subject
to
those
requirements
are
routed
to
a
control
device
that
reduces
HAP
emissions
by
95
percent
or
greater.

(
B)
Treatment
process
has
the
meaning
given
in
§
61.341
of
40
CFR
part
61,
subpart
FF
except
that
it
does
not
include
biological
treatment
units.

(
C)
Vapor
control
device
means
the
control
device
that
receives
emissions
vented
from
a
treatment
process
or
treatment
processes.

(
ii)
The
following
equation
shall
be
used
for
each
wastewater
stream
i
to
calculate
EWWic:

where:

EWWic
=
Monthly
wastewater
stream
emission
rate
if
wastewater
stream
i
were
controlled
by
the
reference
control
technology,
megagrams
per
month.
196
Qi
=
Average
flow
rate
for
wastewater
stream
i,

liters
per
minute.

Hi
=
Number
of
hours
during
the
month
that
wastewater
stream
i
was
generated,
hours
per
month.

Frm
=
Fraction
removed
of
organic
HAP
m
in
wastewater,
from
table
7
of
this
subpart,

dimensionless.

Fem
=
Fraction
emitted
of
organic
HAP
m
in
wastewater
from
table
7
of
this
subpart,

dimensionless.

s
=
Total
number
of
organic
HAP's
in
wastewater
stream
i.

HAPim
=
Average
concentration
of
organic
HAP
m
in
wastewater
stream
i,
parts
per
million
by
weight.

(
A)
HAPim
shall
be
determined
for
the
point
of
generation
or
at
a
location
downstream
of
the
point
of
generation.
Wastewater
samples
shall
be
collected
using
the
sampling
procedures
specified
in
Method
25D
of
40
CFR
part
60,
appendix
A.
Where
feasible,
samples
shall
be
taken
from
an
enclosed
pipe
prior
to
the
wastewater
being
exposed
to
the
atmosphere.
When
sampling
from
an
enclosed
pipe
is
not
feasible,
a
minimum
of
three
representative
samples
shall
be
collected
in
a
manner
to
minimize
exposure
of
the
sample
to
the
atmosphere
and
loss
of
organic
HAP's
prior
to
197
sampling.
The
samples
collected
may
be
analyzed
by
either
of
the
following
procedures:

(
1)
A
test
method
or
results
from
a
test
method
that
measures
organic
HAP
concentrations
in
the
wastewater,
and
that
has
been
validated
pursuant
to
section
5.1
or
5.3
of
Method
301
of
appendix
A
of
this
part
may
be
used;
or
(
2)
Method
305
of
appendix
A
of
this
part
may
be
used
to
determine
Cim,
the
average
volatile
organic
HAP
concentration
of
organic
HAP
m
in
wastewater
stream
i,
and
then
HAPim
may
be
calculated
using
the
following
equation:

HAPim
=
Cim/
Fmm,

where
Fmm
for
organic
HAP
m
is
obtained
from
table
7
of
this
subpart.

(
B)
Values
for
Qi,
HAPim,
and
Cim
shall
be
determined
during
a
performance
test
conducted
under
representative
conditions.
The
average
value
obtained
from
three
test
runs
shall
be
used.
The
values
of
Qi,
HAPim,
and
Cim
shall
be
established
in
the
Notification
of
Compliance
Status
report
and
must
be
updated
as
provided
in
paragraph
(
h)(
6)(
i)(
C)
of
this
section.

(
C)
If
there
is
a
change
to
the
process
or
operation
such
that
the
previously
measured
values
of
Qi,
HAPim,
and
Cim
are
no
longer
representative,
a
new
performance
test
shall
be
conducted
to
determine
new
representative
values
of
Qi,
HAPim,
and
Cim.
These
new
values
shall
be
used
to
calculate
debits
and
credits
from
the
time
of
the
change
198
EWW1iACTUAL

(
6.0

10

8)
Qi
Hi

s
m

1
Fem
HAPim
1

PRim

0.05
(
6.0

10

8)
Qi
Hi

s
m

1
HAPim
PRim
forward,
and
the
new
values
shall
be
reported
in
the
next
Periodic
Report.

(
iii)
The
following
equations
shall
be
used
to
calculate
EWW1iACTUAL
for
each
Group
1
wastewater
stream
i
that
is
correctly
suppressed
and
is
treated
to
a
level
more
stringent
than
the
reference
control
technology.

(
A)
If
the
Group
1
wastewater
stream
i
is
controlled
using
a
treatment
process
or
series
of
treatment
processes
with
an
approved
nominal
reduction
efficiency
for
an
individually
speciated
HAP
that
is
greater
than
that
specified
in
table
7
of
this
subpart,
and
the
vapor
control
device
achieves
a
percentage
of
reduction
equal
to
95
percent,
the
following
equation
shall
be
used:

where:

EWWiACTUAL
=
Monthly
wastewater
stream
emission
rate
if
wastewater
stream
i
is
treated
to
a
level
more
stringent
than
the
reference
control
technology,
megagrams
per
month.
199
PRim

HAPim

in

HAPim

out
HAPim

in
PRim
=
The
efficiency
of
the
treatment
process,
or
series
of
treatment
processes,
that
treat
wastewater
stream
i
in
reducing
the
emission
potential
of
organic
HAP
m
in
wastewater,

dimensionless,
as
calculated
by:

where:

HAPim­
in
=
Average
concentration
of
organic
HAP
m,
parts
per
million
by
weight,
as
defined
and
determined
according
to
paragraph
(
h)(
6)(
ii)(
A)
of
this
section,
in
the
wastewater
entering
the
first
treatment
process
in
the
series.

HAPim­
out
=
Average
concentration
of
organic
HAP
m,
parts
per
million
by
weight,
as
defined
and
determined
according
to
paragraph
(
h)(
6)(
ii)(
A)
of
this
section,
in
the
wastewater
exiting
the
last
treatment
process
in
the
series.

All
other
terms
are
as
defined
and
determined
in
paragraph
(
h)(
6)(
ii)
of
this
section.
200
EWW1iACTUAL

(
6.0

10

8)
Qi
Hi

s
m

1
Fem
HAPim
1

Am

1

Nominal
efficiency
%

100
(
6.0

10

8)
Qi
Hi

s
m

1
HAPim
Am
(
B)
If
the
Group
1
wastewater
stream
i
is
not
controlled
using
a
treatment
process
or
series
of
treatment
processes
with
an
approved
nominal
reduction
efficiency
for
an
individually
speciated
HAP
that
is
greater
than
that
specified
in
table
7
of
this
subpart,
but
the
vapor
control
device
has
an
approved
nominal
efficiency
greater
than
95
percent,
the
following
equation
shall
be
used:

where:

Nominal
efficiency
=
Approved
reduction
efficiency
of
the
vapor
control
device,

dimensionless,
as
determined
according
to
the
procedures
in
§
63.652(
i).

Am
=
The
efficiency
of
the
treatment
process,
or
series
of
treatment
processes,
that
treat
wastewater
stream
i
in
reducing
the
emission
potential
of
organic
HAP
m
in
wastewater,
dimensionless.
201
All
other
terms
are
as
defined
and
determined
in
paragraphs
(
h)(
6)(
ii)
and
(
h)(
6)(
iii)(
A)
of
this
section.

(
1)
If
a
steam
stripper
meeting
the
specifications
in
the
definition
of
reference
control
technology
for
wastewater
is
used,
Am
shall
be
equal
to
the
value
of
Frm
given
in
table
7
of
this
subpart.

(
2)
If
an
alternative
control
device
is
used,
the
percentage
of
reduction
must
be
determined
using
the
equation
and
methods
specified
in
paragraph
(
h)(
6)(
iii)(
A)

of
this
section
for
determining
PRim.
If
the
value
of
PRim
is
greater
than
or
equal
to
the
value
of
Frm
given
in
table
7
of
this
subpart,
then
Am
equals
Frm
unless
a
higher
nominal
efficiency
has
been
approved.
If
a
higher
nominal
efficiency
has
been
approved
for
the
treatment
process,
the
owner
or
operator
shall
determine
EWW1iACTUAL
according
to
paragraph
(
h)(
6)(
iii)(
B)
of
this
section
rather
than
(
h)(
6)(
iii)(
A).
If
PRim
is
less
than
the
value
of
FRm
given
in
table
7
of
this
subpart,
emissions
averaging
shall
not
be
used
for
this
emission
point.

(
C)
If
the
Group
1
wastewater
stream
i
is
controlled
using
a
treatment
process
or
series
of
treatment
processes
with
an
approved
nominal
reduction
efficiency
for
an
individually
speciated
hazardous
air
pollutant
that
is
greater
than
that
specified
in
table
7
of
this
subpart,
and
the
vapor
control
device
has
an
approved
nominal
efficiency
202
EWW1iACTUAL

(
6.0

10

8)
Qi
Hi

s
m

1
Fem
HAPim
1

PRim

1

Nominal
efficiency
%

100
(
6.0

10

8)
Qi
Hi

s
m

1
HAPim
PRim
EWW2iBASE

(
6.0
x
10

8)
Qi
Hi

s
m

1
Fem
HAPim
greater
than
95
percent,
the
following
equation
shall
be
used:

where
all
terms
are
as
defined
and
determined
in
paragraphs
(
h)(
6)(
ii)
and
(
h)(
6)(
iii)(
A)
of
this
section.

(
iv)
The
following
equation
shall
be
used
to
calculate
EWW2iBASE
for
each
Group
2
wastewater
stream
i
that
on
November
15,
1990
was
not
correctly
suppressed
or
was
correctly
suppressed
but
not
treated:

where:

EWW2iBASE
=
Monthly
wastewater
stream
emission
rate
if
wastewater
stream
i
is
not
correctly
suppressed,

megagrams
per
month.

Qi,
Hi,
s,
Fem,
and
HAPim
are
as
defined
and
determined
according
to
paragraphs
(
h)(
6)(
ii)
and
(
h)(
6)(
iii)(
A)
of
this
section.
203
EWW2iBASE

(
6.0

10

8)
Qi
Hi

s
m

1
Fem
HAPim
1

PRim

1

Ri
100%
(
6.0

10

8)
Qi
Hi

s
m

1
HAPim
PRim
(
v)
The
following
equation
shall
be
used
to
calculate
EWW2iBASE
for
each
Group
2
wastewater
stream
i
on
November
15,
1990
was
correctly
suppressed.
EWW2iBASE
shall
be
calculated
as
if
the
control
methods
being
used
on
November
15,
1990
are
in
place
and
any
control
methods
applied
after
November
15,
1990
are
ignored.
However,

values
for
the
parameters
in
the
equation
shall
be
representative
of
present
production
levels
and
stream
properties.

where
Ri
is
calculated
according
to
paragraph
(
h)(
6)(
vii)
of
this
section
and
all
other
terms
are
as
defined
and
determined
according
to
paragraphs
(
h)(
6)(
ii)
and
(
h)(
6)(
iii)(
A)
of
this
section.

(
vi)
For
Group
2
wastewater
streams
that
are
correctly
suppressed,
EWW2iACTUAL
shall
be
calculated
according
to
the
equation
for
EWW2iBASE
in
paragraph
(
h)(
6)(
v)
of
this
section.
EWW2iACTUAL
shall
be
calculated
with
all
control
methods
in
place
accounted
for.
204
(
vii)
The
reduction
efficiency,
Ri,
of
the
vapor
control
device
shall
be
demonstrated
according
to
the
following
procedures:

(
A)
Sampling
sites
shall
be
selected
using
Method
1
or
1A
of
40
CFR
part
60,
appendix
A,
as
appropriate.

(
B)
The
mass
flow
rate
of
organic
compounds
entering
and
exiting
the
control
device
shall
be
determined
as
follows:

(
1)
The
time
period
for
the
test
shall
not
be
less
than
3
hours
during
which
at
least
three
runs
are
conducted.

(
2)
A
run
shall
consist
of
a
1­
hour
period
during
the
test.
For
each
run:

(
i)
The
volume
exhausted
shall
be
determined
using
Methods
2,
2A,
2C,
or
2D
of
40
CFR
part
60
appendix
A,
as
appropriate;

(
ii)
The
organic
concentration
in
the
vent
stream
entering
and
exiting
the
control
device
shall
be
determined
using
Method
18
of
40
CFR
part
60,
appendix
A.

Alternatively,
any
other
test
method
validated
according
to
the
procedures
in
Method
301
of
appendix
A
of
this
part
may
be
used.

(
3)
The
mass
flow
rate
of
organic
compounds
entering
and
exiting
the
control
device
during
each
run
shall
be
205
Ea

0.0416
106
x
m

m
p

1
Vap

n
p

1
Caip
MWi
Eb

0.0416
106
x
m

m
p

1
Vbp

n
p

1
Cbip
MWi
calculated
as
follows:

where:

Ea
=
Mass
flow
rate
of
organic
compounds
exiting
the
control
device,
kilograms
per
hour.

Eb
=
Mass
flow
rate
of
organic
compounds
entering
the
control
device,
kilograms
per
hour.

Vap
=
Average
volumetric
flow
rate
of
vent
stream
exiting
the
control
device
during
run
p
at
standards
conditions,
cubic
meters
per
hour.

Vbp
=
Average
volumetric
flow
rate
of
vent
stream
entering
the
control
device
during
run
p
at
standards
conditions,
cubic
meters
per
hour.

p
=
Run.

m
=
Number
of
runs.

Caip
=
Concentration
of
organic
compound
i
measured
in
the
vent
stream
exiting
the
control
device
during
run
p
as
determined
by
Method
18
of
40
CFR
part
60
appendix
A,
parts
per
million
by
volume
on
a
dry
basis.
206
R

Eb

Ea
Eb
x
100
Cbip
=
Concentration
of
organic
compound
i
measured
in
the
vent
stream
entering
the
control
device
during
run
p
as
determined
by
Method
18
of
40
CFR
part
60,
appendix
A,
parts
per
million
by
volume
on
a
dry
basis.

MWi
=
Molecular
weight
of
organic
compound
i
in
the
vent
stream,
kilograms
per
kilogram­
mole.

n
=
Number
of
organic
compounds
in
the
vent
stream.

0.0416
=
Conversion
factor
for
molar
volume,

kilogramsmole
per
cubic
meter
at
293
kelvin
and
760
millimeters
mercury
absolute.

(
C)
The
organic
reduction
efficiency
for
the
control
device
shall
be
calculated
as
follows:

where:

R
=
Total
organic
reduction
efficiency
for
the
control
device,
percentage.

Eb
=
Mass
flow
rate
of
organic
compounds
entering
the
control
device,
kilograms
per
hour.

Ea
=
Mass
flow
rate
of
organic
compounds
exiting
the
control
device,
kilograms
per
hour.
207
(
i)
The
following
procedures
shall
be
followed
to
establish
nominal
efficiencies.
The
procedures
in
paragraphs
(
i)(
1)
through
(
i)(
6)
of
this
section
shall
be
followed
for
control
technologies
that
are
different
in
use
or
design
from
the
reference
control
technologies
and
achieve
greater
percentages
of
reduction
than
the
percentages
of
efficiency
assigned
to
the
reference
control
technologies
in
§
63.641.

(
1)
In
those
cases
where
the
owner
or
operator
is
seeking
permission
to
take
credit
for
use
of
a
control
technology
that
is
different
in
use
or
design
from
the
reference
control
technology,
and
the
different
control
technology
will
be
used
in
more
than
three
applications
at
a
single
plant
site,
the
owner
or
operator
shall
submit
the
information
specified
in
paragraphs
(
i)(
1)(
i)
through
(
i)(
1)(
iv)
of
this
section
to
the
Administrator
in
writing:

(
i)
Emission
stream
characteristics
of
each
emission
point
to
which
the
control
technology
is
or
will
be
applied
including
the
kind
of
emission
point,
flow,
organic
HAP
concentration,
and
all
other
stream
characteristics
necessary
to
design
the
control
technology
or
determine
its
performance;

(
ii)
Description
of
the
control
technology
including
design
specifications;

(
iii)
Documentation
demonstrating
to
the
Administrator's
satisfaction
the
control
efficiency
of
the
208
control
technology.
This
may
include
performance
test
data
collected
using
an
appropriate
EPA
method
or
any
other
method
validated
according
to
Method
301
of
appendix
A
of
this
part.
If
it
is
infeasible
to
obtain
test
data,

documentation
may
include
a
design
evaluation
and
calculations.
The
engineering
basis
of
the
calculation
procedures
and
all
inputs
and
assumptions
made
in
the
calculations
shall
be
documented;
and
(
iv)
A
description
of
the
parameter
or
parameters
to
be
monitored
to
ensure
that
the
control
technology
will
be
operated
in
conformance
with
its
design
and
an
explanation
of
the
criteria
used
for
selection
of
that
parameter
(
or
parameters).

(
2)
The
Administrator
shall
determine
within
120
calendar
days
whether
an
application
presents
sufficient
information
to
determine
nominal
efficiency.
The
Administrator
reserves
the
right
to
request
specific
data
in
addition
to
the
items
listed
in
paragraph
(
i)(
1)
of
this
section.

(
3)
The
Administrator
shall
determine
within
120
calendar
days
of
the
submittal
of
sufficient
data
whether
a
control
technology
shall
have
a
nominal
efficiency
and
the
level
of
that
nominal
efficiency.
If,
in
the
Administrator's
judgment,
the
control
technology
achieves
a
level
of
emission
reduction
greater
than
the
reference
control
technology
for
a
particular
kind
of
emission
point,
209
the
Administrator
will
publish
a
Federal
Register
notice
establishing
a
nominal
efficiency
for
the
control
technology.

(
4)
The
Administrator
may
grant
conditional
permission
to
take
emission
credits
for
use
of
the
control
technology
on
requirements
that
may
be
necessary
to
ensure
operation
and
maintenance
to
achieve
the
specified
nominal
efficiency.

(
5)
In
those
cases
where
the
owner
or
operator
is
seeking
permission
to
take
credit
for
use
of
a
control
technology
that
is
different
in
use
or
design
from
the
reference
control
technology
and
the
different
control
technology
will
be
used
in
no
more
than
three
applications
at
a
single
plant
site,
the
information
listed
in
paragraphs
(
i)(
1)(
i)
through
(
i)(
1)(
iv)
can
be
submitted
to
the
permitting
authority
for
the
source
for
approval
instead
of
the
Administrator.

(
i)
In
these
instances,
use
and
conditions
for
use
of
the
control
technology
can
be
approved
by
the
permitting
authority.
The
permitting
authority
shall
follow
the
procedures
specified
in
paragraphs
(
i)(
2)
through
(
i)(
4)
of
this
section
except
that,
in
these
instances,
a
Federal
Register
notice
is
not
required
to
establish
the
nominal
efficiency
for
the
different
technology.

(
ii)
If,
in
reviewing
the
submittal,
the
permitting
authority
believes
the
control
technology
has
broad
applicability
for
use
by
other
sources,
the
permitting
210
authority
shall
submit
the
information
provided
in
the
application
to
the
Director
of
the
EPA
Office
of
Air
Quality
Planning
and
Standards.
The
Administrator
shall
review
the
technology
for
broad
applicability
and
may
publish
a
Federal
Register
notice;
however,
this
review
shall
not
affect
the
permitting
authority's
approval
of
the
nominal
efficiency
of
the
control
technology
for
the
specific
application.

(
6)
If,
in
reviewing
an
application
for
a
control
technology
for
an
emission
point,
the
Administrator
or
permitting
authority
determines
the
control
technology
is
not
different
in
use
or
design
from
the
reference
control
technology,
the
Administrator
or
permitting
authority
shall
deny
the
application.

(
j)
The
following
procedures
shall
be
used
for
calculating
the
efficiency
(
percentage
of
reduction)
of
pollution
prevention
measures:

(
1)
A
pollution
prevention
measure
is
any
practice
that
meets
the
criteria
of
paragraphs
(
j)(
1)(
i)
and
(
j)(
1)(
ii)
of
this
section.

(
i)
A
pollution
prevention
measure
is
any
practice
that
results
in
a
lesser
quantity
of
organic
HAP
emissions
per
unit
of
product
released
to
the
atmosphere
prior
to
outof
process
recycling,
treatment,
or
control
of
emissions
while
the
same
product
is
produced.

(
ii)
Pollution
prevention
measures
may
include:

substitution
of
feedstocks
that
reduce
HAP
emissions,
211
alterations
to
the
production
process
to
reduce
the
volume
of
materials
released
to
the
environment,
equipment
modifications;
housekeeping
measures,
and
in­
process
recycling
that
returns
waste
materials
directly
to
production
as
raw
materials.
Production
cutbacks
do
not
qualify
as
pollution
prevention.

(
2)
The
emission
reduction
efficiency
of
pollution
prevention
measures
implemented
after
November
15,
1990
can
be
used
in
calculating
the
actual
emissions
from
an
emission
point
in
the
debit
and
credit
equations
in
paragraphs
(
g)

and
(
h)
of
this
section.

(
i)
For
pollution
prevention
measures,
the
percentage
of
reduction
used
in
the
equations
in
paragraphs
(
g)(
2)
and
(
g)(
3)
of
this
section
and
paragraphs
(
h)(
2)
through
(
h)(
4)

of
this
section
is
the
difference
in
percentage
between
the
monthly
organic
HAP
emissions
for
each
emission
point
after
the
pollution
prevention
measure
for
the
most
recent
month
versus
monthly
emissions
from
the
same
emission
point
before
the
pollution
prevention
measure,
adjusted
by
the
volume
of
product
produced
during
the
two
monthly
periods.

(
ii)
The
following
equation
shall
be
used
to
calculate
the
percentage
of
reduction
of
a
pollution
prevention
measure
for
each
emission
point.
212
Percent
reduction

EB

Epp
x
PB
Ppp
EB
x
100%

where:

Percent
reduction
=
Efficiency
of
pollution
prevention
measure
(
percentage
of
organic
HAP
reduction).

EB
=
Monthly
emissions
before
the
pollution
prevention
measure,
megagrams
per
month,

determined
as
specified
in
paragraphs
(
j)(
2)(
ii)(
A),
(
j)(
2)(
ii)(
B),
and
(
j)(
2)(
ii)(
C)
of
this
section.

Epp
=
Monthly
emissions
after
the
pollution
prevention
measure,
megagrams
per
month,
as
determined
for
the
most
recent
month,

determined
as
specified
in
paragraphs
(
j)(
2)(
ii)(
D)
or
(
j)(
2)(
ii)(
E)
of
this
section.

PB
=
Monthly
production
before
the
pollution
prevention
measure,
megagrams
per
month,

during
the
same
period
over
which
EB
is
calculated.

Ppp
=
Monthly
production
after
the
pollution
prevention
measure,
megagrams
per
month,
as
determined
for
the
most
recent
month.
213
EB

n
i

1
(
6.0

10

8)
QBi
HBi

s
m

1
Fem
HAPBim
(
A)
The
monthly
emissions
before
the
pollution
prevention
measure,
EB,
shall
be
determined
in
a
manner
consistent
with
the
equations
and
procedures
in
paragraphs
(
g)(
2),
(
g)(
3),
(
g)(
4),
and
(
g)(
5)
of
this
section
for
miscellaneous
process
vents,
storage
vessels,

gasoline
loading
racks,
and
marine
tank
vessels.

(
B)
For
wastewater,
EB
shall
be
calculated
as
follows:

where:

n
=
Number
of
wastewater
streams.

QBi
=
Average
flow
rate
for
wastewater
stream
i
before
the
pollution
prevention
measure,

liters
per
minute.

HBi
=
Number
of
hours
per
month
that
wastewater
stream
i
was
discharged
before
the
pollution
prevention
measure,
hours
per
month.

s
=
Total
number
of
organic
HAP's
in
wastewater
stream
i.

Fem
=
Fraction
emitted
of
organic
HAP
m
in
wastewater
from
table
7
of
this
subpart,

dimensionless.
214
Epp

n
i

1
(
6.0

10

8)
Qppi
Hppi

s
m

1
Fem
HAPppim
HAPBim
=
Average
concentration
of
organic
HAP
m
in
wastewater
stream
i,
defined
and
determined
according
to
paragraph
(
h)(
6)(
ii)(
A)(
2)
of
this
section,
before
the
pollution
prevention
measure,
parts
per
million
by
weight,
as
measured
before
the
implementation
of
the
pollution
measure.

(
C)
If
the
pollution
prevention
measure
was
implemented
prior
to
July
14,
1994,
records
may
be
used
to
determine
EB.

(
D)
The
monthly
emissions
after
the
pollution
prevention
measure,
Epp,
may
be
determined
during
a
performance
test
or
by
a
design
evaluation
and
documented
engineering
calculations.
Once
an
emissions­
to­
production
ratio
has
been
established,
the
ratio
can
be
used
to
estimate
monthly
emissions
from
monthly
production
records.

(
E)
For
wastewater,
Epp
shall
be
calculated
using
the
following
equation:

where
n,
Q,
H,
s,
Fem,
and
HAP
are
defined
and
determined
as
described
in
paragraph
(
j)(
2)(
ii)(
B)
of
this
section
except
215
that
Qppi,
Hppi,
and
HAPppim
shall
be
determined
after
the
pollution
prevention
measure
has
been
implemented.

(
iii)
All
equations,
calculations,
test
procedures,

test
results,
and
other
information
used
to
determine
the
percentage
of
reduction
achieved
by
a
pollution
prevention
measure
for
each
emission
point
shall
be
fully
documented.

(
iv)
The
same
pollution
prevention
measure
may
reduce
emissions
from
multiple
emission
points.
In
such
cases,
the
percentage
of
reduction
in
emissions
for
each
emission
point
must
be
calculated.

(
v)
For
the
purposes
of
the
equations
in
paragraphs
(
h)(
2)
through
(
h)(
6)
of
this
section
used
to
calculate
credits
for
emission
points
controlled
more
stringently
than
the
reference
control
technology,
the
nominal
efficiency
of
a
pollution
prevention
measure
is
equivalent
to
the
percentage
of
reduction
of
the
pollution
prevention
measure.
When
a
pollution
prevention
measure
is
used,
the
owner
or
operator
of
a
source
is
not
required
to
apply
to
the
Administrator
for
a
nominal
efficiency
and
is
not
subject
to
paragraph
(
i)
of
this
section.

(
k)
The
owner
or
operator
shall
demonstrate
that
the
emissions
from
the
emission
points
proposed
to
be
included
in
the
average
will
not
result
in
greater
hazard
or,
at
the
option
of
the
State
or
local
permitting
authority,
greater
risk
to
human
health
or
the
environment
than
if
the
emission
216
points
were
controlled
according
to
the
provisions
in
§
§
63.643
through
63.647,
and
§
§
63.650
and
63.651.

(
1)
This
demonstration
of
hazard
or
risk
equivalency
shall
be
made
to
the
satisfaction
of
the
State
or
local
permitting
authority.

(
i)
The
State
or
local
permitting
authority
may
require
owners
and
operators
to
use
specific
methodologies
and
procedures
for
making
a
hazard
or
risk
determination.

(
ii)
The
demonstration
and
approval
of
hazard
or
risk
equivalency
may
be
made
according
to
any
guidance
that
the
EPA
makes
available
for
use.

(
2)
Owners
and
operators
shall
provide
documentation
demonstrating
the
hazard
or
risk
equivalency
of
their
proposed
emissions
average
in
their
Implementation
Plan.

(
3)
An
emissions
averaging
plan
that
does
not
demonstrate
an
equivalent
or
lower
hazard
or
risk
to
the
satisfaction
of
the
State
or
local
permitting
authority
shall
not
be
approved.
The
State
or
local
permitting
authority
may
require
such
adjustments
to
the
emissions
averaging
plan
as
are
necessary
in
order
to
ensure
that
the
average
will
not
result
in
greater
hazard
or
risk
to
human
health
or
the
environment
than
would
result
if
the
emission
points
were
controlled
according
to
§
§
63.643
through
63.647,
and
§
§
63.650
and
63.651.

(
4)
A
hazard
or
risk
equivalency
demonstration
shall:
217
(
i)
Be
a
quantitative,
bona
fide
chemical
hazard
or
risk
assessment;

(
ii)
Account
for
differences
in
chemical
hazard
or
risk
to
human
health
or
the
environment;
and
(
iii)
Meet
any
requirements
set
by
the
State
or
local
permitting
authority
for
such
demonstrations.

(
l)
For
periods
of
excess
emissions,
an
owner
or
operator
may
request
that
the
provisions
of
paragraphs
(
l)(
1)
through
(
l)(
4)
of
this
section
be
followed
instead
of
the
procedures
in
paragraphs
(
f)(
3)(
i)
and
(
f)(
3)(
ii)
of
this
section.

(
1)
The
owner
or
operator
shall
notify
the
Administrator
of
excess
emissions
in
the
Periodic
Reports
as
required
in
§
63.654(
g)(
6).

(
2)
The
owner
or
operator
shall
demonstrate
that
other
types
of
monitoring
data
or
engineering
calculations
are
appropriate
to
establish
that
the
control
device
for
the
emission
point
was
operating
in
such
a
fashion
to
warrant
assigning
full
or
partial
credits
and
debits.
This
demonstration
shall
be
made
to
the
Administrator's
satisfaction,
and
the
Administrator
may
establish
procedures
for
demonstrating
compliance
that
are
acceptable.

(
3)
The
owner
or
operator
shall
provide
documentation
of
the
period
of
excess
emissions
and
the
other
type
of
monitoring
data
or
engineering
calculations
to
be
used
to
demonstrate
that
the
control
device
for
the
emission
point
218
was
operating
in
such
a
fashion
to
warrant
assigning
full
or
partial
credits
and
debits.

(
4)
The
Administrator
may
assign
full
or
partial
credit
and
debits
upon
review
of
the
information
provided.

§
63.653
Monitoring,
recordkeeping,
and
implementation
plan
for
emission
averaging.

(
a)
For
each
emission
point
included
in
an
emissions
average,
the
owner
or
operator
shall
perform
testing,

monitoring,
recordkeeping,
and
reporting
equivalent
to
that
required
for
Group
1
emission
points
complying
with
§
§
63.643
through
63.647,
and
§
§
63.650
and
63.651.
The
specific
requirements
for
miscellaneous
process
vents,

storage
vessels,
wastewater,
gasoline
loading
racks,
and
marine
tank
vessels
are
identified
in
paragraphs
(
a)(
1)

through
(
a)(
8)
of
this
section.

(
1)
The
source
shall
implement
the
following
testing,

monitoring,
recordkeeping,
and
reporting
procedures
for
each
miscellaneous
process
vent
equipped
with
a
flare,

incinerator,
boiler,
or
process
heater:

(
i)
Conduct
initial
performance
tests
to
determine
the
percentage
of
reduction
as
specified
in
§
63.645
of
this
subpart
and
§
63.116
of
subpart
G;
and
(
ii)
Monitor
the
operating
parameters
specified
in
§
63.644,
as
appropriate
for
the
specific
control
device.

(
2)
The
source
shall
implement
the
following
procedures
for
each
miscellaneous
process
vent,
equipped
219
with
a
carbon
adsorber,
absorber,
or
condenser
but
not
equipped
with
a
control
device:

(
i)
Determine
the
flow
rate
and
organic
HAP
concentration
using
the
methods
specified
in
§
63.115(
a)(
1)

and
(
a)(
2),
§
63.115(
b)(
1)
and
(
b)(
2),
and
§
63.115(
c)(
3)
of
subpart
G;
and
(
ii)
Monitor
the
operating
parameters
specified
in
§
63.114
of
subpart
G,
as
appropriate
for
the
specific
recovery
device.

(
3)
The
source
shall
implement
the
following
procedures
for
each
storage
vessel
controlled
with
an
internal
floating
roof,
external
roof,
or
a
closed
vent
system
with
a
control
device,
as
appropriate
to
the
control
technique:

(
i)
Perform
the
monitoring
or
inspection
procedures
in
§
63.646
of
this
subpart
and
§
63.120
of
subpart
G;
and
(
ii)
For
closed
vent
systems
with
control
devices,

conduct
an
initial
design
evaluation
as
specified
in
§
63.646
of
this
subpart
and
§
63.120(
d)
of
subpart
G.

(
4)
For
each
gasoline
loading
rack
that
is
controlled,

perform
the
testing
and
monitoring
procedures
specified
in
§
§
63.425
and
63.427
of
subpart
R
of
this
part.

(
5)
For
each
marine
tank
vessel
that
is
controlled,

perform
the
compliance,
monitoring,
and
performance
testing,

procedures
specified
in
§
§
63.563,
63.564,
and
63.565
of
subpart
Y
of
this
part.
220
(
6)
The
source
shall
implement
the
following
procedures
for
wastewater
emission
points,
as
appropriate
to
the
control
techniques:

(
i)
For
wastewater
treatment
processes,
conduct
tests
as
specified
in
§
61.355
of
subpart
FF
of
part
60;

(
ii)
Conduct
inspections
and
monitoring
as
specified
in
§
§
61.343
through
61.349
and
§
61.354
of
40
CFR
part
61,

subpart
FF.

(
8)
If
an
emission
point
in
an
emissions
average
is
controlled
using
a
pollution
prevention
measure
or
a
device
or
technique
for
which
no
monitoring
parameters
or
inspection
procedures
are
specified
in
§
§
63.643
through
63.647
and
§
§
63.650
and
63.651,
the
owner
or
operator
shall
establish
a
site­
specific
monitoring
parameter
and
shall
submit
the
information
specified
in
§
63.654(
h)(
4)
in
the
Implementation
Plan.

(
b)
Records
of
all
information
required
to
calculate
emission
debits
and
credits
and
records
required
by
§
63.654
shall
be
retained
for
5
years.

(
c)
Notifications
of
Compliance
Status
report,

Periodic
Reports,
and
other
reports
shall
be
submitted
as
required
by
§
63.654.

(
d)
Each
owner
or
operator
of
an
existing
source
who
elects
to
comply
with
§
63.654(
g)
and
(
h)
by
using
emissions
averaging
for
any
emission
points
shall
submit
an
Implementation
Plan.
221
(
1)
The
Implementation
Plan
shall
be
submitted
no
later
than
18
months
prior
to
the
compliance
date
in
§
63.640(
h).
This
information
may
be
submitted
in
an
operating
permit
application,
in
an
amendment
to
an
operating
permit
application,
in
a
separate
submittal,
or
in
any
combination
of
the
three.
If
an
owner
or
operator
submits
the
information
specified
in
paragraph
(
d)(
2)
of
this
section
at
different
times,
and/
or
in
different
submittals,
later
submittals
may
refer
to
earlier
submittals
instead
of
duplicating
the
previously
submitted
information.

(
2)
The
Implementation
Plan
shall
include
the
information
specified
in
paragraphs
(
d)(
2)(
i)
through
(
d)(
2)(
ix)
of
this
section
for
all
points
included
in
the
average.

(
i)
The
identification
of
all
emission
points
in
the
planned
emissions
average
and
notation
of
whether
each
emission
point
is
a
Group
1
or
Group
2
emission
point
as
defined
in
§
63.641.

(
ii)
The
projected
annual
emission
debits
and
credits
for
each
emission
point
and
the
sum
for
the
emission
points
involved
in
the
average
calculated
according
to
§
63.652.

The
annual
projected
credits
must
be
greater
than
the
projected
debits,
as
required
under
§
63.652(
e)(
3).

(
iii)
The
specific
control
technology
or
pollution
prevention
measure
that
will
be
used
for
each
emission
point
222
included
in
the
average
and
date
of
application
or
expected
date
of
application.

(
iv)
The
specific
identification
of
each
emission
point
affected
by
a
pollution
prevention
measure.
To
be
considered
a
pollution
prevention
measure,
the
criteria
in
§
63.652(
j)(
1)
must
be
met.
If
the
same
pollution
prevention
measure
reduces
or
eliminates
emissions
from
multiple
emission
points
in
the
average,
the
owner
or
operator
must
identify
each
of
these
emission
points.

(
v)
A
statement
that
the
compliance
demonstration,

monitoring,
inspection,
recordkeeping,
and
reporting
provisions
in
paragraphs
(
a),
(
b),
and
(
c)
of
this
section
that
are
applicable
to
each
emission
point
in
the
emissions
average
will
be
implemented
beginning
on
the
date
of
compliance.

(
vi)
Documentation
of
the
information
listed
in
paragraphs
(
d)(
2)(
vi)(
A)
through
(
d)(
2)(
vi)(
D)
of
this
section
for
each
emission
point
included
in
the
average.

(
A)
The
values
of
the
parameters
used
to
determine
whether
each
emission
point
in
the
emissions
average
is
Group
1
or
Group
2.

(
B)
The
estimated
values
of
all
parameters
needed
for
input
to
the
emission
debit
and
credit
calculations
in
§
63.652(
g)
and
(
h).
These
parameter
values
or,
as
appropriate,
limited
ranges
for
the
parameter
values,
shall
be
specified
in
the
source's
Implementation
Plan
as
223
enforceable
operating
conditions.
Changes
to
these
parameters
must
be
reported
in
the
next
Periodic
Report.

(
C)
The
estimated
percentage
of
reduction
if
a
control
technology
achieving
a
lower
percentage
of
reduction
than
the
efficiency
of
the
reference
control
technology,
as
defined
in
§
63.641,
is
or
will
be
applied
to
the
emission
point.

(
D)
The
anticipated
nominal
efficiency
if
a
control
technology
achieving
a
greater
percentage
emission
reduction
than
the
efficiency
of
the
reference
control
technology
is
or
will
be
applied
to
the
emission
point.
The
procedures
in
§
63.652(
i)
shall
be
followed
to
apply
for
a
nominal
efficiency.

(
vii)
The
information
specified
in
§
63.654(
h)(
4)
for:

(
A)
Each
miscellaneous
process
vent
controlled
by
a
pollution
prevention
measure
or
control
technique
for
which
monitoring
parameters
or
inspection
procedures
are
not
specified
in
paragraphs
(
a)(
1)
or
(
a)(
2)
of
this
section;

and
(
B)
Each
storage
vessel
controlled
by
a
pollution
prevention
measure
or
a
control
technique
other
than
an
internal
or
external
floating
roof
or
a
closed
vent
system
with
a
control
device.

(
viii)
Documentation
of
the
information
listed
in
paragraphs
(
d)(
2)(
viii)(
A)
through
(
d)(
2)(
viii)(
G)
of
this
224
section
for
each
process
wastewater
stream
included
in
the
average.

(
A)
The
information
used
to
determine
whether
the
wastewater
stream
is
a
Group
1
or
Group
2
wastewater
stream.

(
B)
The
estimated
values
of
all
parameters
needed
for
input
to
the
wastewater
emission
credit
and
debit
calculations
in
§
63.652(
h)(
6).

(
C)
The
estimated
percentage
of
reduction
if
the
wastewater
stream
is
or
will
be
controlled
using
a
treatment
process
or
series
of
treatment
processes
that
achieves
an
emission
reduction
less
than
or
equal
to
the
emission
reduction
specified
in
table
7
of
this
subpart.

(
D)
The
estimated
percentage
of
reduction
if
a
control
technology
achieving
less
than
or
equal
to
95
percent
emission
reduction
is
or
will
be
applied
to
the
vapor
stream(
s)
vented
and
collected
from
the
treatment
processes.

(
E)
The
estimated
percentage
of
reduction
if
a
pollution
prevention
measure
is
or
will
be
applied.

(
F)
The
anticipated
nominal
efficiency
if
the
owner
or
operator
plans
to
apply
for
a
nominal
efficiency
under
§
63.652(
i).
A
nominal
efficiency
shall
be
applied
for
if:

(
1)
A
control
technology
is
or
will
be
applied
to
the
wastewater
stream
and
achieves
an
emission
reduction
greater
than
the
emission
reduction
specified
in
table
7
of
this
subpart;
or
225
(
2)
A
control
technology
achieving
greater
than
95
percent
emission
reduction
is
or
will
be
applied
to
the
vapor
stream(
s)
vented
and
collected
from
the
treatment
processes.

(
G)
For
each
pollution
prevention
measure,
treatment
process,
or
control
device
used
to
reduce
air
emissions
of
organic
HAP's
from
wastewater
and
for
which
no
monitoring
parameters
or
inspection
procedures
are
specified
in
§
63.647,
the
information
specified
in
§
63.654(
h)(
4)
shall
be
included
in
the
Implementation
Plan.

(
ix)
Documentation
required
in
§
63.652(
k)

demonstrating
the
hazard
or
risk
equivalency
of
the
proposed
emissions
average.

(
3)
The
Administrator
shall
determine
within
120
calendar
days
whether
the
Implementation
Plan
submitted
presents
sufficient
information.
The
Administrator
shall
either
approve
the
Implementation
Plan,
request
changes,
or
request
that
the
owner
or
operator
submit
additional
information.
Once
the
Administrator
receives
sufficient
information,
the
Administrator
shall
approve,
disapprove,
or
request
changes
to
the
plan
within
120
calendar
days.

§
63.654
Reporting
and
recordkeeping
requirements.

(
a)
Each
owner
or
operator
subject
to
the
wastewater
provisions
in
§
63.647
shall
comply
with
the
recordkeeping
and
reporting
provisions
in
§
§
61.356
and
61.357
of
40
CFR
part
61
subpart
FF.
There
are
no
additional
reporting
and
226
recordkeeping
requirements
for
wastewater
under
this
subpart
unless
a
wastewater
stream
is
included
in
an
emissions
average.
Recordkeeping
and
reporting
for
emissions
averages
are
specified
in
§
63.653
and
in
paragraphs
(
f)(
5)
and
(
g)(
8)
of
this
section.

(
b)
Each
owner
or
operator
subject
to
the
gasoline
loading
rack
provisions
in
§
63.650
shall
comply
with
the
recordkeeping
and
reporting
provisions
in
§
63.428(
b)
and
(
c),
(
g)(
1),
and
(
h)(
1)
through
(
h)(
3)
of
subpart
R
of
this
part.
These
requirements
are
summarized
in
table
4
of
this
subpart.
There
are
no
additional
reporting
and
recordkeeping
requirements
for
gasoline
loading
racks
under
this
subpart
unless
a
loading
rack
is
included
in
an
emissions
average.

Recordkeeping
and
reporting
for
emissions
averages
are
specified
in
§
63.653
and
in
paragraphs
(
f)(
5)
and
(
g)(
8)
of
this
section.

(
c)
Each
owner
or
operator
subject
to
the
marine
tank
vessel
loading
operation
standards
in
§
63.651
shall
comply
with
the
recordkeeping
and
reporting
provisions
in
§
§
63.566
and
63.567(
a)
and
§
63.567(
c)
through
(
i)
of
subpart
Y
of
this
part.
These
requirements
are
summarized
in
table
5
of
this
subpart.
There
are
no
additional
reporting
and
recordkeeping
requirements
for
marine
tank
vessel
loading
operations
under
this
subpart
unless
marine
tank
vessel
loading
operations
are
included
in
an
emissions
average.

Recordkeeping
and
reporting
for
emissions
averages
are
227
specified
in
§
63.653
and
in
paragraphs
(
f)(
5)
and
(
g)(
8)
of
this
section.

(
d)
Each
owner
or
operator
subject
to
the
equipment
leaks
standards
in
§
63.648
shall
comply
with
the
recordkeeping
and
reporting
provisions
in
paragraphs
(
d)(
1)

through
(
d)(
3)
of
this
section.

(
1)
Sections
60.486
and
60.487
of
subpart
VV
of
part
60,
or
§
§
63.181
and
63.182
of
subpart
H
of
this
part
except
for
§
63.182,
paragraphs
(
b),
(
c)(
2),
and
(
c)(
4).

(
2)
The
Notification
of
Compliance
Status
report
required
by
§
63.182(
c)
of
subpart
H
and
the
initial
semiannual
report
required
by
§
60.487(
b)
of
40
CFR
part
60,

subpart
VV
shall
be
submitted
within
150
days
of
the
compliance
date
specified
in
§
63.640(
h);
the
requirements
of
subpart
H
of
this
part
are
summarized
in
table
3
of
this
subpart.

(
3)
An
owner
or
operator
who
determines
that
a
compressor
qualifies
for
the
hydrogen
service
exemption
in
§
63.646
shall
also
keep
a
record
of
the
demonstration
required
by
§
63.646.

(
e)
Each
owner
or
operator
of
a
source
subject
to
this
subpart
shall
submit
the
reports
listed
in
paragraphs
(
e)(
1)

through
(
e)(
3)
of
this
section
except
as
provided
in
paragraph
(
h)(
5)
of
this
section,
and
shall
keep
records
as
described
in
paragraph
(
i)
of
this
section.
228
(
1)
A
Notification
of
Compliance
Status
report
as
described
in
paragraph
(
f)
of
this
section;

(
2)
Periodic
Reports
as
described
in
paragraph
(
g)
of
this
section;
and
(
3)
Other
reports
as
described
in
paragraph
(
h)
of
this
section.

(
f)
Each
owner
or
operator
of
a
source
subject
to
this
subpart
shall
submit
a
Notification
of
Compliance
Status
report
within
150
days
after
the
compliance
dates
specified
in
§
63.640(
h).
This
information
may
be
submitted
in
an
operating
permit
application,
in
an
amendment
to
an
operating
permit
application,
in
a
separate
submittal,
or
in
any
combination
of
the
three.
If
the
required
information
has
been
submitted
before
the
date
150
days
after
the
compliance
date
specified
in
§
63.640(
h),
a
separate
Notification
of
Compliance
Status
report
is
not
required
within
150
days
after
the
compliance
dates
specified
in
§
63.640(
h).
If
an
owner
or
operator
submits
the
information
specified
in
paragraphs
(
f)(
1)
through
(
f)(
5)
of
this
section
at
different
times,
and/
or
in
different
submittals,
later
submittals
may
refer
to
earlier
submittals
instead
of
duplicating
and
resubmitting
the
previously
submitted
information.

(
1)
The
Notification
of
Compliance
Status
report
shall
include
the
information
specified
in
paragraphs
(
f)(
1)(
i)

through
(
f)(
1)(
v)
of
this
section.
229
(
i)
For
storage
vessels,
this
report
shall
include
the
information
specified
in
paragraphs
(
f)(
1)(
i)(
A)
through
(
f)(
1)(
i)(
D)
of
this
section.

(
A)
Identification
of
each
storage
vessel
subject
to
this
subpart,
whether
the
vessel
is
Group
1
or
Group
2,
and
the
method
of
compliance
for
each
Group
1
storage
vessel
that
is
not
included
in
an
emissions
average
(
i.
e.,
internal
floating
roof,
external
floating
roof,
or
closed­
vent
system
and
control
device).

(
B)
If
a
closed
vent
system
and
a
control
device
other
than
a
flare
is
used
to
comply
with
§
63.646
the
owner
or
operator
shall
submit:

(
1)
A
description
of
the
parameter
or
parameters
to
be
monitored
to
ensure
that
the
control
device
is
being
properly
operated
and
maintained,
an
explanation
of
the
criteria
used
for
selection
of
that
parameter
(
or
parameters),
and
the
frequency
with
which
monitoring
will
be
performed;
and
either
(
2)
The
design
evaluation
documentation
specified
in
§
63.120(
d)(
1)(
i)
of
subpart
G,
if
the
owner
or
operator
elects
to
prepare
a
design
evaluation;
or
(
3)
If
the
owner
or
operator
elects
to
submit
the
results
of
a
performance
test,
identification
of
the
storage
vessel
and
control
device
for
which
the
performance
test
will
be
submitted,
and
identification
of
the
emission
230
point(
s)
that
share
the
control
device
with
the
storage
vessel
and
for
which
the
performance
test
will
be
conducted.

(
C)
If
a
closed
vent
system
and
control
device
other
than
a
flare
is
used,
the
owner
or
operator
shall
submit:

(
1)
The
operating
range
for
each
monitoring
parameter.

The
specified
operating
range
shall
represent
the
conditions
for
which
the
control
device
is
being
properly
operated
and
maintained.

(
2)
If
a
performance
test
is
conducted
instead
of
a
design
evaluation,
results
of
the
performance
test
demonstrating
that
the
control
device
achieves
greater
than
or
equal
to
the
required
control
efficiency.
A
performance
test
conducted
prior
to
the
compliance
date
of
this
subpart
can
be
used
to
comply
with
this
requirement,
provided
that
the
test
was
conducted
using
EPA
methods
and
that
the
test
conditions
are
representative
of
current
operating
practices.

(
D)
If
a
closed
vent
system
and
a
flare
is
used,
the
owner
or
operator
shall
submit:

(
1)
Flare
design
(
e.
g.,
steam­
assisted,
air­
assisted,

or
nonassisted);

(
2)
All
visible
emission
readings,
heat
content
determinations,
flow
rate
measurements,
and
exit
velocity
determinations
made
during
the
compliance
determination
required
by
§
63.120(
e)
of
subpart
G
of
this
part;
and
231
(
3)
All
periods
during
the
compliance
determination
when
the
pilot
flame
is
absent.

(
ii)
For
miscellaneous
process
vents,
identification
of
each
miscellaneous
process
vent
subject
to
this
subpart,

whether
the
process
vent
is
Group
1
or
Group
2,
and
the
method
of
compliance
for
each
Group
1
miscellaneous
process
vent
that
is
not
included
in
an
emissions
average
(
e.
g.,
use
of
a
flare
or
other
control
device
meeting
the
requirements
of
§
63.643(
a)).

(
iii)
For
miscellaneous
process
vents
controlled
by
control
devices
required
to
be
tested
under
§
63.645
of
this
subpart
and
§
63.116(
c)
of
subpart
G
of
this
part,

performance
test
results
including
the
information
in
paragraphs
(
f)(
1)(
iii)(
A)
and
(
B)
of
this
section.
Results
of
a
performance
test
conducted
prior
to
the
compliance
date
of
this
subpart
can
be
used
provided
that
the
test
was
conducted
using
the
methods
specified
in
§
63.645
and
that
the
test
conditions
are
representative
of
current
operating
conditions.

(
A)
The
percentage
of
reduction
of
organic
HAP's
or
TOC,
or
the
outlet
concentration
of
organic
HAP's
or
TOC
(
parts
per
million
by
volume
on
a
dry
basis
corrected
to
3
percent
oxygen),
determined
as
specified
in
§
63.116(
c)
of
subpart
G
of
this
part;
and
(
B)
The
value
of
the
monitored
parameters
specified
in
table
10
of
this
subpart,
or
a
site­
specific
parameter
232
approved
by
the
permitting
authority,
averaged
over
the
full
period
of
the
performance
test,

(
iv)
For
miscellaneous
process
vents
controlled
by
flares,
performance
test
results
including
the
information
in
paragraphs
(
f)(
1)(
iv)(
A)
and
(
B)
of
this
section;

(
A)
All
visible
emission
readings,
heat
content
determinations,
flow
rate
measurements,
and
exit
velocity
determinations
made
during
the
compliance
determination
required
by
§
63.645
of
this
subpart
and
§
63.116(
a)
of
subpart
G
of
this
part,
and
(
B)
A
statement
of
whether
a
flame
was
present
at
the
pilot
light
over
the
full
period
of
the
compliance
determination.

(
v)
For
equipment
leaks
complying
with
§
63.648(
c)

(
i.
e.,
complying
with
the
requirements
of
subpart
H
of
this
part),
the
Notification
of
Compliance
Report
Status
report
information
required
by
§
63.182(
c)
of
subpart
H
and
whether
the
percentage
of
leaking
valves
will
be
reported
on
a
process
unit
basis
or
a
sourcewide
basis.

(
2)
If
initial
performance
tests
are
required
by
§
§
63.643
through
63.653
of
this
subpart,
the
Notification
of
Compliance
Status
report
shall
include
one
complete
test
report
for
each
test
method
used
for
a
particular
source.

(
i)
For
additional
tests
performed
using
the
same
method,
the
results
specified
in
paragraph
(
f)(
1)
of
this
233
section
shall
be
submitted,
but
a
complete
test
report
is
not
required.

(
ii)
A
complete
test
report
shall
include
a
sampling
site
description,
description
of
sampling
and
analysis
procedures
and
any
modifications
to
standard
procedures,

quality
assurance
procedures,
record
of
operating
conditions
during
the
test,
record
of
preparation
of
standards,
record
of
calibrations,
raw
data
sheets
for
field
sampling,
raw
data
sheets
for
field
and
laboratory
analyses,
documentation
of
calculations,
and
any
other
information
required
by
the
test
method.

(
iii)
Performance
tests
are
required
only
if
specified
by
§
§
63.643
through
63.653
of
this
subpart.
Initial
performance
tests
are
required
for
some
kinds
of
emission
points
and
controls.
Periodic
testing
of
the
same
emission
point
is
not
required.

(
3)
For
each
monitored
parameter
for
which
a
range
is
required
to
be
established
under
§
63.120(
d)
of
subpart
G
of
this
part
for
storage
vessels
or
§
63.644
for
miscellaneous
process
vents,
the
Notification
of
Compliance
Status
report
shall
include
the
information
in
paragraphs
(
f)(
3)(
i)

through
(
f)(
3)(
iii)
of
this
section.

(
i)
The
specific
range
of
the
monitored
parameter(
s)

for
each
emission
point;

(
ii)
The
rationale
for
the
specific
range
for
each
parameter
for
each
emission
point,
including
any
data
and
234
calculations
used
to
develop
the
range
and
a
description
of
why
the
range
ensures
compliance
with
the
emission
standard.

(
A)
If
a
performance
test
is
required
by
this
subpart
for
a
control
device,
the
range
shall
be
based
on
the
parameter
values
measured
during
the
performance
test
supplemented
by
engineering
assessments
and
manufacturer's
recommendations.
Performance
testing
is
not
required
to
be
conducted
over
the
entire
range
of
permitted
parameter
values.

(
B)
If
a
performance
test
is
not
required
by
this
subpart
for
a
control
device,
the
range
may
be
based
solely
on
engineering
assessments
and
manufacturers'

recommendations.

(
iii)
A
definition
of
the
source's
operating
day
for
purposes
of
determining
daily
average
values
of
monitored
parameters.
The
definition
shall
specify
the
times
at
which
an
operating
day
begins
and
ends.

(
4)
Results
of
any
continuous
monitoring
system
performance
evaluations
shall
be
included
in
the
Notification
of
Compliance
Status
report.

(
5)
For
emission
points
included
in
an
emissions
average,
the
Notification
of
Compliance
Status
report
shall
include
the
values
of
the
parameters
needed
for
input
to
the
emission
credit
and
debit
equations
in
§
63.652(
g)
and
(
h),

calculated
or
measured
according
to
the
procedures
in
§
63.652(
g)
and
(
h),
and
the
resulting
credits
and
debits
235
for
the
first
quarter
of
the
year.
The
first
quarter
begins
on
the
compliance
date
specified
in
§
63.640.

(
g)
The
owner
or
operator
of
a
source
subject
to
this
subpart
shall
submit
Periodic
Reports
no
later
than
60
days
after
the
end
of
each
6­
month
period
when
any
of
the
compliance
exceptions
specified
in
paragraphs
(
g)(
1)
through
(
g)(
6)
of
this
section
occur.
The
first
6­
month
period
shall
begin
on
the
date
the
Notification
of
Compliance
Status
report
is
required
to
be
submitted.
A
Periodic
Report
is
not
required
if
none
of
the
compliance
exceptions
specified
in
paragraphs
(
g)(
1)
through
(
g)(
6)
of
this
section
occurred
during
the
6­
month
period
unless
emissions
averaging
is
utilized.
Quarterly
reports
must
be
submitted
for
emission
points
included
in
emissions
averages,
as
provided
in
paragraph
(
g)(
8)
of
this
section.
An
owner
or
operator
may
submit
reports
required
by
other
regulations
in
place
of
or
as
part
of
the
Periodic
Report
required
by
this
paragraph
if
the
reports
contain
the
information
required
by
paragraphs
(
g)(
1)
through
(
g)(
8)
of
this
section.

(
1)
For
storage
vessels,
Periodic
Reports
shall
include
the
information
specified
for
Periodic
Reports
in
(
g)(
2)
through
(
g)(
5)
of
this
subpart
except
that
information
related
to
gaskets,
slotted
membranes,
and
sleeve
seals
is
not
required
for
storage
vessels
that
are
part
of
an
existing
source.
236
(
2)
An
owner
or
operator
who
elects
to
comply
with
§
63.646
by
using
a
fixed
roof
and
an
internal
floating
roof
or
by
using
an
external
floating
roof
converted
to
an
internal
floating
roof
shall
submit
the
results
of
each
inspection
conducted
in
accordance
with
§
63.120(
a)
of
subpart
G
of
this
part
in
which
a
failure
is
detected
in
the
control
equipment.

(
i)
For
vessels
for
which
annual
inspections
are
required
under
§
63.120(
a)(
2)(
i)
or
(
a)(
3)(
ii)
of
subpart
G
of
this
part,
the
specifications
and
requirements
listed
in
paragraphs
(
g)(
2)(
i)(
A)
through
(
g)(
2)(
i)(
C)
of
this
section
apply.

(
A)
A
failure
is
defined
as
any
time
in
which
the
internal
floating
roof
is
not
resting
on
the
surface
of
the
liquid
inside
the
storage
vessel
and
is
not
resting
on
the
leg
supports;
or
there
is
liquid
on
the
floating
roof;
or
the
seal
is
detached
from
the
internal
floating
roof;
or
there
are
holes,
tears,
or
other
openings
in
the
seal
or
seal
fabric;
or
there
are
visible
gaps
between
the
seal
and
the
wall
of
the
storage
vessel.

(
B)
Except
as
provided
in
paragraph
(
g)(
2)(
i)(
C)
of
this
section,
each
Periodic
Report
shall
include
the
date
of
the
inspection,
identification
of
each
storage
vessel
in
which
a
failure
was
detected,
and
a
description
of
the
failure.
The
Periodic
Report
shall
also
describe
the
nature
237
of
and
date
the
repair
was
made
or
the
date
the
storage
vessel
was
emptied.

(
C)
If
an
extension
is
utilized
in
accordance
with
§
63.120(
a)(
4)
of
subpart
G
of
this
part,
the
owner
or
operator
shall,
in
the
next
Periodic
Report,
identify
the
vessel;
include
the
documentation
specified
in
§
63.120(
a)(
4)
of
subpart
G
of
this
part;
and
describe
the
date
the
storage
vessel
was
emptied
and
the
nature
of
and
date
the
repair
was
made.

(
ii)
For
vessels
for
which
inspections
are
required
under
§
63.120(
a)(
2)(
ii),
(
a)(
3)(
i),
or
(
a)(
3)(
iii)
of
subpart
G
of
this
part
(
i.
e.,
internal
inspections),
the
specifications
and
requirements
listed
in
paragraphs
(
g)(
2)(
ii)(
A)
and
(
g)(
2)(
ii)(
B)
of
this
section
apply.

(
A)
A
failure
is
defined
as
any
time
in
which
the
internal
floating
roof
has
defects;
or
the
primary
seal
has
holes,
tears,
or
other
openings
in
the
seal
or
the
seal
fabric;
or
the
secondary
seal
(
if
one
has
been
installed)

has
holes,
tears,
or
other
openings
in
the
seal
or
the
seal
fabric;
or,
for
a
storage
vessel
that
is
part
of
a
new
source,
the
gaskets
no
longer
close
off
the
liquid
surface
from
the
atmosphere;
or,
for
a
storage
vessel
that
is
part
of
a
new
source,
the
slotted
membrane
has
more
than
a
10
percent
open
area.
238
(
B)
Each
Periodic
Report
shall
include
the
date
of
the
inspection,
identification
of
each
storage
vessel
in
which
a
failure
was
detected,
and
a
description
of
the
failure.
The
Periodic
Report
shall
also
describe
the
nature
of
and
date
the
repair
was
made.

(
3)
An
owner
or
operator
who
elects
to
comply
with
§
63.646
by
using
an
external
floating
roof
shall
meet
the
periodic
reporting
requirements
specified
in
paragraphs
(
g)(
3)(
i)
through
(
g)(
3)(
iii)
of
this
section.

(
i)
The
owner
or
operator
shall
submit,
as
part
of
the
Periodic
Report,
documentation
of
the
results
of
each
seal
gap
measurement
made
in
accordance
with
§
63.120(
b)
of
subpart
G
of
this
part
in
which
the
seal
and
seal
gap
requirements
of
§
63.120(
b)(
3),
(
b)(
4),
(
b)(
5),
or
(
b)(
6)
of
subpart
G
of
this
part
are
not
met.
This
documentation
shall
include
the
information
specified
in
paragraphs
(
g)(
3)(
i)(
A)
through
(
g)(
3)(
i)(
D)
of
this
section.

(
A)
The
date
of
the
seal
gap
measurement.

(
B)
The
raw
data
obtained
in
the
seal
gap
measurement
and
the
calculations
described
in
§
63.120(
b)(
3)
and
(
b)(
4)

of
subpart
G
of
this
part.

(
C)
A
description
of
any
seal
condition
specified
in
§
63.120(
b)(
5)
or
(
b)(
6)
of
subpart
G
of
this
part
that
is
not
met.
239
(
D)
A
description
of
the
nature
of
and
date
the
repair
was
made,
or
the
date
the
storage
vessel
was
emptied.

(
ii)
If
an
extension
is
utilized
in
accordance
with
§
63.120(
b)(
7)(
ii)
or
(
b)(
8)
of
subpart
G
of
this
part,
the
owner
or
operator
shall,
in
the
next
Periodic
Report,

identify
the
vessel;
include
the
documentation
specified
in
§
63.120(
b)(
7)(
ii)
or
(
b)(
8)
of
subpart
G
of
this
part,
as
applicable;
and
describe
the
date
the
vessel
was
emptied
and
the
nature
of
and
date
the
repair
was
made.

(
iii)
The
owner
or
operator
shall
submit,
as
part
of
the
Periodic
Report,
documentation
of
any
failures
that
are
identified
during
visual
inspections
required
by
§
63.120(
b)(
10)
of
subpart
G
of
this
part.
This
documentation
shall
meet
the
specifications
and
requirements
in
paragraphs
(
g)(
3)(
iii)(
A)
and
(
g)(
3)(
iii)(
B)
of
this
section.

(
A)
A
failure
is
defined
as
any
time
in
which
the
external
floating
roof
has
defects;
or
the
primary
seal
has
holes
or
other
openings
in
the
seal
or
the
seal
fabric;
or
the
secondary
seal
has
holes,
tears,
or
other
openings
in
the
seal
or
the
seal
fabric;
or,
for
a
storage
vessel
that
is
part
of
a
new
source,
the
gaskets
no
longer
close
off
the
liquid
surface
from
the
atmosphere;
or,
for
a
storage
vessel
that
is
part
of
a
new
source,
the
slotted
membrane
has
more
than
10
percent
open
area.
240
(
B)
Each
Periodic
Report
shall
include
the
date
of
the
inspection,
identification
of
each
storage
vessel
in
which
a
failure
was
detected,
and
a
description
of
the
failure.
The
Periodic
Report
shall
also
describe
the
nature
of
and
date
the
repair
was
made.

(
4)
An
owner
or
operator
who
elects
to
comply
with
§
63.646
by
using
an
external
floating
roof
converted
to
an
internal
floating
roof
shall
comply
with
the
periodic
reporting
requirements
of
paragraph
(
g)(
2)
of
this
section.

(
5)
An
owner
or
operator
who
elects
to
comply
with
§
63.646
by
installing
a
closed
vent
system
and
control
device
shall
submit,
as
part
of
the
next
Periodic
Report,

the
information
specified
in
paragraphs
(
g)(
5)(
i)
through
(
g)(
5)(
iii)
of
this
section.

(
i)
The
Periodic
Report
shall
include
the
information
specified
in
paragraphs
(
g)(
5)(
i)(
A)
and
(
g)(
5)(
i)(
B)
of
this
section
for
those
planned
routine
maintenance
operations
that
would
require
the
control
device
not
to
meet
the
requirements
of
§
63.119(
e)(
1)
or
(
e)(
2)
of
subpart
G
of
this
part,
as
applicable.

(
A)
A
description
of
the
planned
routine
maintenance
that
is
anticipated
to
be
performed
for
the
control
device
during
the
next
6
months.
This
description
shall
include
the
type
of
maintenance
necessary,
planned
frequency
of
maintenance,
and
lengths
of
maintenance
periods.
241
(
B)
A
description
of
the
planned
routine
maintenance
that
was
performed
for
the
control
device
during
the
previous
6
months.
This
description
shall
include
the
type
of
maintenance
performed
and
the
total
number
of
hours
during
those
6
months
that
the
control
device
did
not
meet
the
requirements
of
§
63.119(
e)(
1)
or
(
e)(
2)
of
subpart
G
of
this
part,
as
applicable,
due
to
planned
routine
maintenance.

(
ii)
If
a
control
device
other
than
a
flare
is
used,

the
Periodic
Report
shall
describe
each
occurrence
when
the
monitored
parameters
were
outside
of
the
parameter
ranges
documented
in
the
Notification
of
Compliance
Status
report.

The
description
shall
include:
identification
of
the
control
device
for
which
the
measured
parameters
were
outside
of
the
established
ranges,
and
causes
for
the
measured
parameters
to
be
outside
of
the
established
ranges.

(
iii)
If
a
flare
is
used,
the
Periodic
Report
shall
describe
each
occurrence
when
the
flare
does
not
meet
the
general
control
device
requirements
specified
in
§
63.11(
b)

of
subpart
A
of
this
part
and
shall
include:
identification
of
the
flare
that
does
not
meet
the
general
requirements
specified
in
§
63.11(
b)
of
subpart
A
of
this
part,
and
reasons
the
flare
did
not
meet
the
general
requirements
specified
in
§
63.11(
b)
of
subpart
A
of
this
part.

(
6)
For
miscellaneous
process
vents
for
which
continuous
parameter
monitors
are
required
by
this
subpart,
242
periods
of
excess
emissions
shall
be
identified
in
the
Periodic
Reports
and
shall
be
used
to
determine
compliance
with
the
emission
standards.

(
i)
Period
of
excess
emission
means
any
of
the
following
conditions:

(
A)
An
operating
day
when
the
daily
average
value
of
a
monitored
parameter,
except
presence
of
a
flare
pilot
flame,

is
outside
the
range
specified
in
the
Notification
of
Compliance
Status
report.
Monitoring
data
recorded
during
periods
of
monitoring
system
breakdown,
repairs,
calibration
checks
and
zero
(
low­
level)
and
high­
level
adjustments
shall
not
be
used
in
computing
daily
average
values
of
monitored
parameters.

(
B)
An
operating
day
when
all
pilot
flames
of
a
flare
are
absent.

(
C)
An
operating
day
when
monitoring
data
required
to
be
recorded
in
paragraphs
(
i)(
3)(
i)
and
(
ii)
of
this
section
are
available
for
less
than
75
percent
of
the
operating
hours.

(
D)
For
data
compression
systems
approved
under
paragraph
(
h)(
5)(
iii)
of
this
section,
an
operating
day
when
the
monitor
operated
for
less
than
75
percent
of
the
operating
hours
or
a
day
when
less
than
18
monitoring
values
were
recorded.

(
ii)
For
miscellaneous
process
vents,
excess
emissions
shall
be
reported
for
the
operating
parameters
specified
in
243
table
10
of
this
subpart
unless
other
site­
specific
parameter(
s)
have
been
approved
by
the
operating
permit
authority.

(
iii)
Periods
of
startup,
shutdown,
and
malfunction
that
meet
the
definitions
in
§
63.2
of
subpart
A
of
this
part
and
periods
of
performance
testing
and
monitoring
system
calibration
shall
not
be
considered
periods
of
excess
emissions.
Malfunctions
may
include
process
unit,
control
device,
or
monitoring
system
malfunctions.

(
7)
If
a
performance
test
for
determination
of
compliance
for
a
new
emission
point
subject
to
this
subpart
or
for
an
emission
point
that
has
changed
from
Group
2
to
Group
1
is
conducted
during
the
period
covered
by
a
Periodic
Report,
the
results
of
the
performance
test
shall
be
included
in
the
Periodic
Report.

(
i)
Results
of
the
performance
test
shall
include
the
percentage
of
emissions
reduction
or
outlet
pollutant
concentration
reduction
(
whichever
is
needed
to
determine
compliance)
and
the
values
of
the
monitored
operating
parameters.

(
ii)
The
complete
test
report
shall
be
maintained
onsite.

(
8)
The
owner
or
operator
of
a
source
shall
submit
quarterly
reports
for
all
emission
points
included
in
an
emissions
average.
244
(
i)
The
quarterly
reports
shall
be
submitted
no
later
than
60
calendar
days
after
the
end
of
each
quarter.
The
first
report
shall
be
submitted
with
the
Notification
of
Compliance
Status
report
no
later
than
150
days
after
the
compliance
date
specified
in
§
63.640.

(
ii)
The
quarterly
reports
shall
include:

(
A)
The
information
specified
in
this
paragraph
and
in
paragraphs
(
g)(
2)
through
(
g)(
7)
of
this
section
for
all
storage
vessels
and
miscellaneous
process
vents
included
in
an
emissions
average;

(
B)
The
information
required
to
be
reported
by
§
63.428(
h)(
1)
of
subpart
R
of
this
part
for
each
gasoline
loading
rack
included
in
an
emissions
average,
unless
this
information
has
already
been
submitted
in
a
separate
report;

(
C)
The
information
required
to
be
included
in
quarterly
reports
by
§
§
63.567(
f)
and
63.567(
i)(
2)
of
subpart
Y
of
this
part
for
each
marine
tank
vessel
loading
operation
included
in
an
emissions
average,
unless
the
information
has
already
been
submitted
in
a
separate
report;

(
D)
Any
information
pertaining
to
each
wastewater
stream
included
in
an
emissions
average
that
the
source
is
required
to
report
under
the
Implementation
Plan
for
the
source;

(
E)
The
credits
and
debits
calculated
each
month
during
the
quarter;
245
(
F)
A
demonstration
that
debits
calculated
for
the
quarter
are
not
more
than
1.30
times
the
credits
calculated
for
the
quarter,
as
required
under
§
63.652(
e)(
4);

(
G)
The
values
of
any
inputs
to
the
credit
and
debit
equations
in
§
63.652(
g)
and
(
h)
that
change
from
month
to
month
during
the
quarter
or
that
have
changed
since
the
previous
quarter;
and
(
H)
Any
other
information
the
source
is
required
to
report
under
the
Implementation
Plan
for
the
source.

(
iii)
Every
fourth
quarterly
report
shall
include
the
following:

(
A)
A
demonstration
that
annual
credits
are
greater
than
or
equal
to
annual
debits
as
required
by
§
63.652(
e)(
3);
and
(
B)
A
certification
of
compliance
with
all
the
emissions
averaging
provisions
in
§
63.652
of
this
subpart.

(
h)
Other
reports
shall
be
submitted
as
specified
in
subpart
A
of
this
part
and
as
follows:

(
1)
Reports
of
startup,
shutdown,
and
malfunction
required
by
§
63.10(
d)(
5)
of
subpart
A
of
this
part;
and
(
2)
For
storage
vessels,
notifications
of
inspections
as
specified
in
paragraphs
(
h)(
2)(
i)
and
(
h)(
2)(
ii)
of
this
section;

(
i)
In
order
to
afford
the
Administrator
the
opportunity
to
have
an
observer
present,
the
owner
or
operator
shall
notify
the
Administrator
of
the
refilling
of
246
each
Group
1
storage
vessel
that
has
been
emptied
and
degassed.

(
A)
Except
as
provided
in
paragraphs
(
h)(
2)(
i)(
B)
and
(
C)
of
this
section,
the
owner
or
operator
shall
notify
the
Administrator
in
writing
at
least
30
calendar
days
prior
to
filling
or
refilling
of
each
storage
vessel
with
organic
HAP's
to
afford
the
Administrator
the
opportunity
to
inspect
the
storage
vessel
prior
to
refilling.

(
B)
Except
as
provided
in
paragraph
(
h)(
2)(
i)(
C)
of
this
section,
if
the
internal
inspection
required
by
§
§
63.120(
a)(
2),
63.120(
a)(
3),
or
63.120(
b)(
10)
of
subpart
G
of
this
part
is
not
planned
and
the
owner
or
operator
could
not
have
known
about
the
inspection
30
calendar
days
in
advance
of
refilling
the
vessel
with
organic
HAP's,
the
owner
or
operator
shall
notify
the
Administrator
at
least
7
calendar
days
prior
to
refilling
of
the
storage
vessel.

Notification
may
be
made
by
telephone
and
immediately
followed
by
written
documentation
demonstrating
why
the
inspection
was
unplanned.
This
notification,
including
the
written
documentation,
may
also
be
made
in
writing
and
sent
so
that
it
is
received
by
the
Administrator
at
least
7
calendar
days
prior
to
the
refilling.

(
C)
The
State
or
local
permitting
authority
can
waive
the
notification
requirements
of
paragraphs
(
h)(
2)(
i)(
A)

and/
or
(
h)(
2)(
i)(
B)
of
this
section
for
all
or
some
storage
vessels
at
petroleum
refineries
subject
to
this
subpart.
247
The
State
or
local
permitting
authority
may
also
grant
permission
to
refill
storage
vessels
sooner
than
30
days
after
submitting
the
notification
required
by
paragraph
(
h)(
2)(
i)(
A)
of
this
section,
or
sooner
than
7
days
after
submitting
the
notification
required
by
paragraph
(
h)(
2)(
i)(
B)
of
this
section
for
all
storage
vessels,
or
for
individual
storage
vessels
on
a
case­
by­
case
basis.

(
ii)
In
order
to
afford
the
Administrator
the
opportunity
to
have
an
observer
present,
the
owner
or
operator
of
a
storage
vessel
equipped
with
an
external
floating
roof
shall
notify
the
Administrator
of
any
seal
gap
measurements.
The
notification
shall
be
made
in
writing
at
least
30
calendar
days
in
advance
of
any
gap
measurements
required
by
§
63.120(
b)(
1)
or
(
b)(
2)
of
subpart
G
of
this
part.
The
State
or
local
permitting
authority
can
waive
this
notification
requirement
for
all
or
some
storage
vessels
subject
to
the
rule
or
can
allow
less
than
30
calendar
days
notice.

(
3)
For
owners
or
operators
of
sources
required
to
request
approval
for
a
nominal
control
efficiency
for
use
in
calculating
credits
for
an
emissions
average,
the
information
specified
in
§
63.652(
h).

(
4)
The
owner
or
operator
who
requests
approval
to
monitor
a
different
parameter
than
those
listed
in
§
63.644
for
miscellaneous
process
vents
or
who
is
required
by
248
§
63.653(
a)(
8)
to
establish
a
site­
specific
monitoring
parameter
for
a
point
in
an
emissions
average
shall
submit
the
information
specified
in
paragraphs
(
h)(
4)(
i)
through
(
h)(
4)(
iii)
of
this
section.
For
new
or
reconstructed
sources,
the
information
shall
be
submitted
with
the
application
for
approval
of
construction
or
reconstruction
required
by
§
63.5(
d)
of
subpart
A
and
for
existing
sources,

and
the
information
shall
be
submitted
no
later
than
18
months
prior
to
the
compliance
date.
The
information
may
be
submitted
in
an
operating
permit
application,
in
an
amendment
to
an
operating
permit
application,
or
in
a
separate
submittal.

(
i)
A
description
of
the
parameter(
s)
to
be
monitored
to
determine
whether
excess
emissions
occur
and
an
explanation
of
the
criteria
used
to
select
the
parameter(
s).

(
ii)
A
description
of
the
methods
and
procedures
that
will
be
used
to
demonstrate
that
the
parameter
can
be
used
to
determine
excess
emissions
and
the
schedule
for
this
demonstration.
The
owner
or
operator
must
certify
that
they
will
establish
a
range
for
the
monitored
parameter
as
part
of
the
Notification
of
Compliance
Status
report
required
in
paragraphs
(
e)
and
(
f)
of
this
section.

(
iii)
The
frequency
and
content
of
monitoring,

recording,
and
reporting
if:
monitoring
and
recording
are
not
continuous;
or
if
periods
of
excess
emissions,
as
defined
in
paragraph
(
g)(
6)
of
this
section,
will
not
be
249
identified
in
Periodic
Reports
required
under
paragraphs
(
e)

and
(
g)
of
this
section.
The
rationale
for
the
proposed
monitoring,
recording,
and
reporting
system
shall
be
included.

(
5)
An
owner
or
operator
may
request
approval
to
use
alternatives
to
the
continuous
operating
parameter
monitoring
and
recordkeeping
provisions
listed
in
paragraph
(
i)
of
this
section.

(
i)
Requests
shall
be
submitted
with
the
Application
for
Approval
of
Construction
or
Reconstruction
for
new
sources
and
no
later
than
18
months
prior
to
the
compliance
date
for
existing
sources.
The
information
may
be
submitted
in
an
operating
permit
application,
in
an
amendment
to
an
operating
permit
application,
or
in
a
separate
submittal.

Requests
shall
contain
the
information
specified
in
paragraphs
(
h)(
5)(
iii)
through
(
h)(
5)(
iv)
of
this
section,

as
applicable.

(
ii)
The
provisions
in
§
63.8(
f)(
5)(
i)
of
subpart
A
of
this
part
shall
govern
the
review
and
approval
of
requests.

(
iii)
An
owner
or
operator
may
request
approval
to
use
an
automated
data
compression
recording
system
that
does
not
record
monitored
operating
parameter
values
at
a
set
frequency
(
for
example
once
every
hour)
but
records
all
values
that
meet
set
criteria
for
variation
from
previously
recorded
values.

(
A)
The
requested
system
shall
be
designed
to:
250
(
1)
Measure
the
operating
parameter
value
at
least
once
every
hour.

(
2)
Record
at
least
24
values
each
day
during
periods
of
operation.

(
3)
Record
the
date
and
time
when
monitors
are
turned
off
or
on.

(
4)
Recognize
unchanging
data
that
may
indicate
the
monitor
is
not
functioning
properly,
alert
the
operator,
and
record
the
incident.

(
5)
Compute
daily
average
values
of
the
monitored
operating
parameter
based
on
recorded
data.

(
B)
The
request
shall
contain
a
description
of
the
monitoring
system
and
data
compression
recording
system
including
the
criteria
used
to
determine
which
monitored
values
are
recorded
and
retained,
the
method
for
calculating
daily
averages,
and
a
demonstration
that
the
system
meets
all
criteria
of
paragraph
(
h)(
5)(
iii)(
A)
of
this
section.

(
iv)
An
owner
or
operator
may
request
approval
to
use
other
alternative
monitoring
systems
according
to
the
procedures
specified
in
§
63.8(
f)
of
subpart
A
of
this
part.

(
6)
The
owner
or
operator
shall
submit
the
information
specified
in
paragraphs
(
h)(
6)(
i)
through
(
h)(
6)(
iii)
of
this
section,
as
applicable.
For
existing
sources,
this
information
shall
be
submitted
no
later
than
18
months
prior
to
the
compliance
date.
For
a
new
source,
the
information
shall
be
submitted
with
the
application
for
approval
of
251
construction
or
reconstruction
required
by
§
63.5(
d)
of
subpart
A
of
this
part.
The
information
may
be
submitted
in
an
operating
permit
application,
in
an
amendment
to
an
operating
permit
application,
or
in
a
separate
submittal.

(
i)
The
determination
of
applicability
of
this
subpart
to
petroleum
refining
process
units
that
are
designed
and
operated
as
flexible
operation
units.

(
ii)
The
determination
of
applicability
of
this
subpart
to
any
storage
vessel
for
which
use
varies
from
year
to
year.

(
iii)
The
determination
of
applicability
of
this
subpart
to
any
distillation
unit
for
which
use
varies
from
year
to
year.

(
i)
Recordkeeping.

(
1)
Each
owner
or
operator
subject
to
the
storage
vessel
provisions
in
§
63.646
shall
keep
the
records
specified
in
§
63.123
of
subpart
G
of
this
part
except
as
specified
in
paragraphs
(
i)(
1)(
i)
through
(
i)(
1)(
iv)
of
this
section.

(
i)
Records
related
to
gaskets,
slotted
membranes,
and
sleeve
seals
are
not
required
for
storage
vessels
within
existing
sources.

(
ii)
All
references
to
§
63.122
in
§
63.123
of
subpart
G
of
this
part
shall
be
replaced
with
§
63.654(
e),

(
iii)
All
references
to
§
63.150
in
§
63.123
of
subpart
G
of
this
part
shall
be
replaced
with
§
63.652.
252
(
iv)
If
a
storage
vessel
is
determined
to
be
Group
2
because
the
weight
percent
total
organic
HAP
of
the
stored
liquid
is
less
than
or
equal
to
4
percent
for
existing
sources
or
2
percent
for
new
sources,
a
record
of
any
data,

assumptions,
and
procedures
used
to
make
this
determination
shall
be
retained.

(
2)
Each
owner
or
operator
required
to
report
the
results
of
performance
tests
under
paragraphs
(
f)
and
(
g)(
7)

of
this
section
shall
retain
a
record
of
all
reported
results
as
well
as
a
complete
test
report,
as
described
in
paragraph
(
f)(
2)(
ii)
of
this
section
for
each
emission
point
tested.

(
3)
Each
owner
or
operator
required
to
continuously
monitor
operating
parameters
under
§
63.644
for
miscellaneous
process
vents
or
under
§
§
63.652
and
63.653
for
emission
points
in
an
emissions
average
shall
keep
the
records
specified
in
paragraphs
(
i)(
3)(
i)
through
(
i)(
3)(
v)

of
this
section
unless
an
alternative
recordkeeping
system
has
been
requested
and
approved
under
paragraph
(
h)
of
this
section.

(
i)
The
monitoring
system
shall
measure
data
values
at
least
once
every
hour.

(
ii)
The
owner
or
operator
shall
record
either:

(
A)
Each
measured
data
value;
or
(
B)
Block
average
values
for
1
hour
or
shorter
periods
calculated
from
all
measured
data
values
during
each
period.
253
If
values
are
measured
more
frequently
than
once
per
minute,

a
single
value
for
each
minute
may
be
used
to
calculate
the
hourly
(
or
shorter
period)
block
average
instead
of
all
measured
values.

(
iii)
Daily
average
values
of
each
continuously
monitored
parameter
shall
be
calculated
for
each
operating
day
and
retained
for
5
years
except
as
specified
in
paragraph
(
i)(
3)(
iv)
of
this
section.

(
A)
The
daily
average
shall
be
calculated
as
the
average
of
all
values
for
a
monitored
parameter
recorded
during
the
operating
day.
The
average
shall
cover
a
24­
hour
period
if
operation
is
continuous,
or
the
number
of
hours
of
operation
per
day
if
operation
is
not
continuous.

(
B)
The
operating
day
shall
be
the
period
defined
in
the
Notification
of
Compliance
Status
report.
It
may
be
from
midnight
to
midnight
or
another
daily
period.

(
iv)
If
all
recorded
values
for
a
monitored
parameter
during
an
operating
day
are
within
the
range
established
in
the
Notification
of
Compliance
Status
report,
the
owner
or
operator
may
record
that
all
values
were
within
the
range
and
retain
this
record
for
5
years
rather
than
calculating
and
recording
a
daily
average
for
that
day.
For
these
days,

the
records
required
in
paragraph
(
i)(
3)(
ii)
of
this
section
shall
also
be
retained
for
5
years.

(
v)
Monitoring
data
recorded
during
periods
of
monitoring
system
breakdowns,
repairs,
calibration
checks,
254
and
zero
(
low­
level)
and
high­
level
adjustments
shall
not
be
included
in
any
average
computed
under
this
subpart.

Records
shall
be
kept
of
the
times
and
durations
of
all
such
periods
and
any
other
periods
during
process
or
control
device
operation
when
monitors
are
not
operating.

(
4)
All
other
information
required
to
be
reported
under
paragraphs
(
a)
through
(
h)
of
this
section
shall
be
retained
for
5
years.

§
§
63.655
through
63.679
Reserved.
255
Table
1.
HAZARDOUS
AIR
POLLUTANTS
Chemical
name
CAS
numbera
Benzene
71432
Biphenyl
92524
Butadiene
(
1,3)
10990
Carbon
disulfide
75150
Carbonyl
sulfide
463581
Cresol
(
mixed
isomersb)
1319773
Cresol
(
m­)
108394
Cresol
(
o­)
95487
Cresol
(
p­)
106445
Cumene
98828
Dibromoethane
(
1,2)
(
ethylene
dibromide)
106934
Dichloroethane
(
1,2)
107062
Diethanolamine
111422
Ethylbenzene
100414
Ethylene
glycol
107211
Hexane
110543
Methanol
67561
Methyl
ethyl
ketone
(
2­
butanone)
78933
Methyl
isobutyl
ketone
(
hexone)
108101
Methyl
tert
butyl
ether
1634044
Naphthalene
91203
Phenol
108952
Toluene
108883
Trimethylpentane
(
2,2,4)
540841
Xylene
(
mixed
isomersb)
1330207
xylene
(
m­)
108383
xylene
(
o­)
95476xylene
(
p­
)
106423
TABLE
1.
HAZARDOUS
AIR
POLLUTANTS
(
CONCLUDED)
256
a
CAS
number
=
Chemical
Abstract
Service
registry
number
assigned
to
specific
compounds,
isomers,
or
mixtures
of
compounds.
b
Isomer
means
all
structural
arrangements
for
the
same
number
of
atoms
of
each
element
and
does
not
mean
salts,
esters,
or
derivatives.
257
TABLE
2.
LEAK
DEFINITIONS
FOR
PUMPS
AND
VALVES
Standarda
Phase
Leak
definition
(
parts
per
million)

§
63.163
I
10,000
(
pumps)
II
5,000
III
2,000
§
63.168
I
10,000
(
valves)
II
1,000
III
1,000
a
Subpart
H
of
this
part.
258
TABLE
3.
EQUIPMENT
LEAK
RECORDKEEPING
AND
REPORTING
REQUIREMENTS
FOR
SOURCES
COMPLYING
WITH
§
63.648
OF
SUBPART
CC
BY
COMPLIANCE
WITH
SUBPART
H
OF
THIS
PARTa
Reference
(
section
of
subpart
H
of
this
part)
Description
Comment
63.181(
a)
Recordkeeping
system
requirements
Except
for
§
§
63.181(
b)(
2)(
iii)
and
63.181(
b)(
9).

63.181(
b)
Records
required
for
process
unit
equipment
Except
for
§
§
63.181(
b)(
2)(
iii)
and
63.181(
b)(
9).

63.181(
c)
Visual
inspection
documentation
Except
for
§
§
63.181(
b)(
2)(
iii)
and
63.181(
b)(
9).

63.181(
d)
Leak
detection
record
requirements
Except
for
§
63.181(
d)(
8).

63.181(
e)
Compliance
requirements
for
pressure
tests
for
batch
product
process
equipment
trains
This
subsection
does
not
apply
to
subpart
CC.

63.181(
f)
Compressor
compliance
test
records
63.181(
g)
Closed­
vent
systems
and
control
device
record
requirements
63.181(
h)
Process
unit
quality
improvement
program
records
63.181(
i)
Heavy
liquid
service
determination
record
63.181(
j)
Equipment
identification
record
63.181(
k)
Enclosed­
vented
process
unit
emission
limitation
record
requirements
63.182(
a)
Reports
63.182(
b)
Initial
notification
report
requirements
TABLE
3.
EQUIPMENT
LEAK
RECORDKEEPING
AND
REPORTING
REQUIREMENTS
FOR
SOURCES
COMPLYING
WITH
§
63.648
OF
SUBPART
CC
BY
COMPLIANCE
WITH
SUBPART
H
OF
THIS
PARTa
(
CONCLUDED)
259
Reference
(
section
of
subpart
H
of
this
part)
Description
Comment
63.182(
c)
Notification
of
compliance
status
report
Except
in
§
63.182(
2);
change
"
within
90
days
of
the
compliance
dates"
to
"
within
150
days
of
the
compliance
dates."

63.182(
d)
Periodic
report
Except
for
§
§
63.182(
d)(
2)(
vii),
(
d)(
2)(
viii),
and
(
d)(
3).

a
This
table
does
not
include
all
the
requirements
delineated
under
the
referenced
sections.
See
referenced
sections
for
specific
requirements.
260
TABLE
4.
GASOLINE
DISTRIBUTION
EMISSION
POINT
RECORDKEEPING
AND
REPORTING
REQUIREMENTSa
Reference
(
section
of
subpart
R
of
this
part)
Description
Comment
63.428(
b)
Records
of
test
results
for
each
gasoline
cargo
tank
loaded
at
the
facility
63.428(
c)
Continuous
monitoring
data
recordkeeping
requirements
63.428(
g)(
1)
Semiannual
report
loading
rack
information
Required
to
be
submitted
with
the
periodic
report
required
under
40
CFR
part
63
subpart
CC.

63.428(
h)(
1)
through
(
h)(
3)
Excess
emissions
report
loading
rack
information
Required
to
be
submitted
with
the
periodic
report
required
under
40
CFR
part
63
subpart
CC.

63.428(
i)
Records
and
annual
reports
for
facilities
meeting
§
63.420(
c)
(
emissions
screening
factor
<
1.0,
but

0.5).
The
information
required
under
this
paragraph
is
to
be
submitted
with
the
Periodic
Report
required
under
40
CFR
part
63
subpart
CC.

63.428(
j)
Records
and
reports
for
facilities
meeting
§
63.420(
d)
(
emissions
screening
factor
<
0.5).
The
information
required
under
this
paragraph
is
to
be
submitted
with
the
periodic
report
required
under
40
CFR
part
63
subpart
CC.

a
This
table
does
not
include
all
the
requirements
delineated
under
the
referenced
sections.
See
referenced
sections
for
specific
requirements.
261
TABLE
5.
MARINE
VESSEL
LOADING
AND
UNLOADING
OPERATIONS
RECORDKEEPING
AND
REPORTING
REQUIREMENTSa
Reference
(
section
of
subpart
Y
of
this
part)
Description
Comment
63.566(
a)
Performance
test/
site
test
plan
The
information
required
under
this
paragraph
is
to
be
submitted
with
the
notification
of
compliance
status
report
required
under
40
CFR
part
63
subpart
CC.

63.566(
b)
Performance
test
data
requirements
63.567(
a)
General
Provisions
(
subpart
A)
applicability
63.567(
c)
Vent
system
valve
bypass
recordkeeping
requirements
63.567(
d)
Continuous
equipment
monitoring
recordkeeping
requirements
63.567(
e)
Flare
recordkeeping
requirements
63.567(
f)
Quarterly
report
requirements
The
information
required
under
this
paragraph
is
to
be
submitted
with
the
periodic
report
required
under
40
CFR
part
63
subpart
CC.
TABLE
5.
MARINE
VESSEL
LOADING
AND
UNLOADING
OPERATIONS
RECORDKEEPING
AND
REPORTING
REQUIREMENTSa
(
CONCLUDED)
262
Reference
(
section
of
subpart
Y
of
this
part)
Description
Comment
63.567(
g)
Marine
vessel
vapor­
tightness
documentation
63.567(
h)
Documentation
file
maintenance
63.567(
i)
Emission
estimation
reporting
and
recordkeeping
procedures
a
This
table
does
not
include
all
the
requirements
delineated
under
the
referenced
sections.
See
referenced
sections
for
specific
requirements.
263
TABLE
6.
GENERAL
PROVISIONS
APPLICABILITY
TO
SUBPART
CCa
Reference
Applies
to
subpart
CCb
Comment
63.1(
a)(
1)
Yes
63.1(
a)(
2)
Yes
63.1(
a)(
3)
Yes
63.1(
a)(
4)
No
Subpart
CC
(
this
table)
specifies
applicability
of
each
paragraph
in
subpart
A
to
subpart
CC.
63.1(
a)(
5)­
63.1(
a)(
9)
No
63.1(
a)(
10)
No
Subpart
CC
and
other
cross­
referenced
subparts
specify
calendar
or
operating
day.
63.1(
a)(
11)
Yes
63.1(
a)(
12)
Yes
63.1(
a)(
13)
Yes
63.1(
a)(
14)
Yes
63.1(
b)(
1)
No
Subpart
CC
specifies
its
own
applicability.
63.1(
b)(
2)
Yes
63.1(
b)(
3)
No
63.1(
c)(
1)
No
Subpart
CC
explicitly
specifies
requirements
that
apply.
63.1(
c)(
2)
No
Area
sources
are
not
subject
to
subpart
CC.
63.1(
c)(
3)
No
63.1(
c)(
4)
Yes
63.1(
c)(
5)
Yes
Except
that
sources
are
not
required
to
submit
notifications
overridden
by
this
table.
63.1(
d)
No
63.1(
e)
No
63.2
Yes
§
63.641
of
subpart
CC
specifies
that
if
the
same
term
is
defined
in
subparts
A
and
CC,
it
shall
have
the
meaning
given
in
subpart
CC.
TABLE
6.
GENERAL
PROVISIONS
APPLICABILITY
TO
SUBPART
CCa
264
Reference
Applies
to
subpart
CCb
Comment
63.3
No
Units
of
measure
are
spelled
out
in
subpart
CC.
63.4(
a)(
1)­
63.4(
a)(
3)
Yes
63.4(
a)(
4)
No
Reserved.
63.4(
a)(
5)
Yes
63.4(
b)
Yes
63.4(
c)
Yes
63.5(
a)(
1)
Yes
Except
replace
term
"
source"
and
"
stationary
source"
in
§
63.5(
a)(
1)
of
subpart
A
with
"
affected
source."
63.5(
a)(
2)
Yes
63.5(
b)(
1)
Yes
63.5(
b)(
2)
No
Reserved.
63.5(
b)(
3)
Yes
63.5(
b)(
4)
Yes
Except
the
cross­
reference
to
§
63.9(
b)
is
changed
to
§
63.9(
b)(
4)
and
(
5).
Subpart
CC
overrides
§
63.9(
b)(
2)
and
(
b)(
3).
63.5(
b)(
5)
Yes
63.5(
b)(
6)
Yes
63.5(
c)
No
Reserved.
63.5(
d)(
1)(
i)
Yes
Except
that
the
application
shall
be
submitted
as
soon
as
practicable
before
startup
but
no
later
than
90
days
(
rather
than
60
days)
after
the
promulgation
date
of
subpart
CC
if
the
construction
or
reconstruction
had
commenced
and
initial
startup
had
not
occurred
before
the
promulgation
of
subpart
CC.
TABLE
6.
GENERAL
PROVISIONS
APPLICABILITY
TO
SUBPART
CCa
265
Reference
Applies
to
subpart
CCb
Comment
63.5(
d)(
1)(
ii)
Yes
Except
that
for
affected
sources
subject
to
subpart
CC,
emission
estimates
specified
in
§
63.5(
d)(
1)(
ii)(
H)
are
not
required.
63.5(
d)(
1)(
iii)
No
Subpart
CC
requires
submittal
of
the
Notification
of
compliance
status
report
in
§
63.654(
e).
63.5(
d)(
2)
No
63.5(
d)(
3)
Yes
Except
§
63.5(
d)(
3)(
ii)
does
not
apply.
63.5(
d)(
4)
Yes
63.5(
e)
Yes
63.5(
f)(
1)
Yes
63.5(
f)(
2)
Yes
Except
that
the
"
60
days"
in
the
cross­
referenced
§
63.5(
d)(
1)
is
changed
to
"
90
days,"
and
the
crossreference
to
(
b)(
2)
does
not
apply.
63.6(
a)
Yes
63.6(
b)(
1)
No
Subpart
CC
specifies
compliance
dates
for
sources
subject
to
subpart
CC.
63.6(
b)(
2)
No
63.6(
b)(
3)
Yes
63.6(
b)(
4)
No
May
apply
when
standards
are
proposed
under
section
112(
f)
of
the
Clean
Air
Act.
63.6(
b)(
5)
No
§
63.654(
d)
of
subpart
CC
includes
notification
requirements.
63.6(
b)(
6)
No
63.6(
b)(
7)
No
63.6(
c)(
1)
No
§
63.640
of
subpart
CC
specifies
the
compliance
date.
TABLE
6.
GENERAL
PROVISIONS
APPLICABILITY
TO
SUBPART
CCa
266
Reference
Applies
to
subpart
CCb
Comment
63.6(
c)(
2)­
63.6(
c)(
4)
No
63.6(
c)(
5)
Yes
63.6(
d)
No
63.6(
e)
Yes
Does
not
apply
to
Group
2
emission
points.
b
63.6(
f)(
1)
Yes
63.6(
f)(
2)(
i)
Yes
63.6(
f)(
2)(
ii)
Yes
Subpart
CC
specifies
the
use
of
monitoring
data
in
determining
compliance
with
subpart
CC.
63.6(
f)(
2)(
iii)
(
A),
(
B),
and
(
C)
Yes
63.6(
f)(
2)(
iii)
(
D)
No
63.6(
f)(
2)(
iv)
Yes
63.6(
f)(
2)(
v)
Yes
63.6(
f)(
3)
Yes
63.6(
g)
Yes
63.6(
h)
No
Subpart
CC
does
not
require
opacity
and
visible
emission
standards.
63.6(
i)
Yes
Except
for
§
63.6(
i)(
15),
which
is
reserved.
63.6(
j)
Yes
63.7(
a)(
1)
No
Subpart
CC
specifies
required
testing
and
compliance
demonstration
procedures.
63.7(
a)(
2)
No
Test
results
must
be
submitted
in
the
Notification
of
compliance
status
report
due
150
days
after
compliance
date,
as
specified
in
§
63.654(
d)
of
subpart
CC.
63.7(
a)(
3)
Yes
63.7(
b)
No
TABLE
6.
GENERAL
PROVISIONS
APPLICABILITY
TO
SUBPART
CCa
267
Reference
Applies
to
subpart
CCb
Comment
63.7(
c)
No
63.7(
d)
Yes
63.7(
e)(
1)
Yes
63.7(
e)(
2)
Yes
63.7(
e)(
3)
No
Subpart
CC
specifies
test
methods
and
procedures.
63.7(
e)(
4)
Yes
63.7(
f)
No
Subpart
CC
specifies
applicable
methods
and
provides
alternatives.
63.7(
g)
No
Performance
test
reporting
specified
in
§
63.654(
d).
63.7(
h)(
1)
Yes
63.7(
h)(
2)
Yes
63.7(
h)(
3)
Yes
Yes,
except
site­
specific
test
plans
shall
not
be
required,
and
where
§
63.7(
g)(
3)
specifies
submittal
by
the
date
the
site­
specific
test
plan
is
due,
the
date
shall
be
90
days
prior
to
the
notification
of
compliance
status
report
in
§
63.654(
d).
63.7(
h)(
4)
No
63.7(
h)(
5)
Yes
63.8(
a)
No
63.8(
b)(
1)
Yes
63.8(
b)(
2)
No
Subpart
CC
specifies
locations
to
conduct
monitoring.
63.8(
b)(
3)
Yes
63.8(
c)(
1)(
i)
Yes
63.8(
c)(
1)(
ii)
No
Addressed
by
periodic
reports
in
§
63.654(
e)
of
subpart
CC.
63.8(
c)(
1)(
iii)
Yes
63.8(
c)(
2)
Yes
TABLE
6.
GENERAL
PROVISIONS
APPLICABILITY
TO
SUBPART
CCa
268
Reference
Applies
to
subpart
CCb
Comment
63.8(
c)(
3)
Yes
63.8(
c)(
4)
No
Subpart
CC
specifies
monitoring
frequency
in
§
63.641
and
§
63.654(
g)(
3)
of
subpart
CC.
63.8(
c)(
5)­
63.8(
c)(
8)
No
63.8(
d)
No
63.8(
e)
No
63.8(
f)(
1)
Yes
63.8(
f)(
2)
Yes
63.8(
f)(
3)
Yes
63.8(
f)(
4)(
i)
No
Timeframe
for
submitting
request
is
specified
in
§
63.654(
f)(
4)
of
subpart
CC.
63.8(
f)(
4)(
ii)
Yes
63.8(
f)(
4)(
iii)
No
63.8(
f)(
5)(
i)
Yes
63.8(
f)(
5)(
ii)
No
63.8(
f)(
5)(
iii)
Yes
63.8(
f)(
6)
No
Subpart
CC
does
not
require
continuous
emission
monitors.
63.8(
g)
No
Subpart
CC
specifies
data
reduction
procedures
in
§
63.654(
h)(
3).
63.9(
a)
Yes
Except
that
the
owner
or
operator
does
not
need
to
send
a
copy
of
each
notification
submitted
to
the
Regional
Office
of
the
EPA
as
stated
in
§
63.9(
a)(
4)(
ii).
63.9(
b)(
1)(
i)
No
Specified
in
§
63.654(
d)(
2)
of
subpart
CC.
63.9(
b)(
1)(
ii)
No
63.9(
b)(
2)
No
An
initial
notification
report
is
not
required
under
subpart
CC.
TABLE
6.
GENERAL
PROVISIONS
APPLICABILITY
TO
SUBPART
CCa
269
Reference
Applies
to
subpart
CCb
Comment
63.9(
b)(
3)
No
63.9(
b)(
4)
Yes
Except
that
the
notification
in
§
63.9(
b)(
4)(
i)
shall
be
submitted
at
the
time
specified
in
§
63.654(
d)(
2)
of
subpart
CC.
63.9(
b)(
5)
Yes
Except
that
the
notification
in
§
63.9(
b)(
5)
shall
be
submitted
at
the
time
specified
in
§
63.654(
d)(
2)
of
subpart
CC.
63.9(
c)
Yes
63.9(
d)
Yes
63.9(
e)
No
63.9(
f)
No
63.9(
g)
No
63.9(
h)
No
Subpart
CC
§
63.652(
d)
specifies
notification
of
compliance
status
report
requirements.
63.9(
i)
Yes
63.9(
j)
No
63.10(
a)
Yes
63.10(
b)(
1)
No
§
63.644(
d)
of
subpart
CC
specifies
record
retention
requirements.
63.10(
b)(
2)(
i)
Yes
63.10(
b)(
2)(
ii)
Yes
63.10(
b)(
2)(
iii)
No
63.10(
b)(
2)(
iv)
Yes
63.10(
b)(
2)(
v)
Yes
63.10(
b)(
2)(
vi)­
(
ix)
No
63.10(
b)(
2)(
x)
Yes
63.10(
b)(
2)
(
xii)­(
xiv)
No
63.10(
b)(
3)
No
63.10(
c)
No
63.10(
d)(
1)
No
TABLE
6.
GENERAL
PROVISIONS
APPLICABILITY
TO
SUBPART
CCa
(
CONCLUDED)
270
Reference
Applies
to
subpart
CCb
Comment
63.10(
d)(
2)
No
§
63.654(
d)
of
subpart
CC
specifies
performance
test
reporting.
63.10(
d)(
3)
No
63.10(
d)(
4)
Yes
63.10(
d)(
5)(
i)
Yes
Except
that
reports
required
by
§
63.10(
d)(
5)(
i)
may
be
submitted
at
the
same
time
as
periodic
reports
specified
in
§
63.654(
e)
of
subpart
CC.
63.10(
d)(
5)(
ii)
Yes
63.10(
e)
No
63.10(
f)
Yes
63.11­
63.15
Yes
a
Wherever
subpart
A
specifies
"
postmark"
dates,
submittals
may
be
sent
by
methods
other
than
the
U.
S.
Mail
(
e.
g.,
by
fax
or
courier).
Submittals
shall
be
sent
by
the
specified
dates,
but
a
postmark
is
not
required.
b
The
plan,
and
any
records
or
reports
of
startup,
shutdown,
and
malfunction
do
not
apply
to
Group
2
emission
points.
271
TABLE
7.
FRACTION
MEASURED
(
Fm),
FRACTION
EMITTED
(
Fe),
AND
FRACTION
REMOVED
(
Fr)
FOR
HAP
COMPOUNDS
IN
WASTEWATER
STREAMS
Chemical
Name
CAS
Numbera
Fm
Fe
Fr
Benzene
71432
1.00
0.80
0.99
Biphenyl
92524
0.86
0.45
0.99
Butadiene
(
1,3­)
106990
1.00
0.98
0.99
Carbon
disulfide
75150
1.00
0.92
0.99
Cumene
98828
1.00
0.88
0.99
Dichloroethane
(
1,2­)
(
Ethylene
dichloride)
107062
1.00
0.64
0.99
Ethylbenzene
100414
1.00
0.83
0.99
Hexane
110543
1.00
1.00
0.99
Methanol
67561
0.85
0.17
0.31
Methyl
ethyl
ketone
(
2­
Butanone)
78933
0.99
0.48
0.95
Methyl
isobutyl
ketone
(
Hexone)
108101
0.98
0.53
0.99
Methyl
tert­
butyl
ether
1634044
1.00
0.57
0.99
Naphthalene
91203
0.99
0.51
0.99
Trimethylpentane
(
2,2,4­)
540841
1.00
1.00
0.99
Xylene
(
m­)
108383
1.00
0.82
0.99
Xylene
(
o­)
95476
1.00
0.79
0.99
Xylene
(
p­)
106423
1.00
0.82
0.99
a
CAS
numbers
refer
to
the
Chemical
Abstracts
Service
registry
number
assigned
to
specific
compounds,
isomers,
or
mixtures
of
compounds.
272
TABLE
8.
VALVE
MONITORING
FREQUENCY
FOR
PHASE
III
Performance
level
Leaking
valvesa
(%)
Valve
monitoring
frequency
>
4
Monthly
or
QIPb
<
4
Quarterly
<
3
Semiannual
<
2
Annual
a
Percent
leaking
valves
is
calculated
as
a
rolling
average
of
two
consecutive
monitoring
periods.
b
QIP
=
Quality
improvement
program.
Specified
in
§
63.175
of
subpart
H
of
this
part.
273
TABLE
9.
VALVE
MONITORING
FREQUENCY
FOR
ALTERNATIVE
Performance
level
Leaking
valvesa
(%)
Valve
monitoring
frequency
under
§
63.649
alternative
>
5
Monthly
or
QIPb
<
5
Quarterly
<
4
Semiannual
<
3
Annual
a
Percent
leaking
valves
is
calculated
as
a
rolling
average
of
two
consecutive
monitoring
periods.
b
QIP
=
Quality
improvement
program.
Specified
in
§
63.175
of
subpart
H
of
this
part.
TABLE
10.
MISCELLANEOUS
PROCESS
VENTS­­
MONITORING,
RECORDKEEPING
AND
REPORTING
REQUIREMENTS
FOR
COMPLYING
WITH
98
WEIGHT­
PERCENT
REDUCTION
OF
TOTAL
ORGANIC
HAP
EMISSIONS
OR
A
LIMIT
OF
20
PARTS
PER
MILLION
BY
VOLUME
Control
device
Parameters
to
be
monitoreda
Recordkeeping
and
reporting
requirements
for
monitored
parameters
Thermal
incinerator
Firebox
temperatureb
(
63.644(
a)(
1)(
i))
1.
Continuous
recordsc
2.
Record
and
report
the
firebox
temperature
averaged
over
the
full
period
of
the
performance
test
­
NCSd
3.
Record
the
daily
average
firebox
temperature
for
each
operating
daye
4.
Report
all
daily
average
temperatures
that
are
outside
the
range
established
in
the
NCS
or
operating
permit
and
all
operating
days
when
insufficient
monitoring
data
are
collectedf
­
PRg
Catalytic
incinerator
Temperature
upstream
and
downstream
of
the
catalyst
bed
(
63.644(
a)(
1)(
ii))
1.
Continuous
recordsc
2.
Record
and
report
the
upstream
and
downstream
temperatures
and
the
temperature
difference
across
the
catalyst
bed
averaged
over
the
full
period
of
the
performance
test
­
NCSd
3.
Record
the
daily
average
upstream
temperature
and
temperature
difference
across
the
catalyst
bed
for
each
operating
daye
4.
Report
all
daily
average
upstream
temperatures
that
are
outside
the
range
established
in
the
NCS
or
operating
permit
­

PRg
5.
Report
all
daily
average
temperature
differences
across
the
catalyst
bed
that
are
outside
the
range
established
in
the
NCS
or
operating
permit
­
PRg
6.
Report
all
operating
days
when
insufficient
monitoring
data
are
collectedf
TABLE
10.
MISCELLANEOUS
PROCESS
VENTS­­
MONITORING,
RECORDKEEPING
AND
REPORTING
REQUIREMENTS
FOR
COMPLYING
WITH
98
WEIGHT­
PERCENT
REDUCTION
OF
TOTAL
ORGANIC
HAP
EMISSIONS
OR
A
LIMIT
OF
20
PARTS
PER
MILLION
BY
VOLUME
Control
device
Parameters
to
be
monitoreda
Recordkeeping
and
reporting
requirements
for
monitored
parameters
Boiler
or
process
heater
with
a
design
heat
capacity
less
than
44
megawatts
where
the
vent
stream
is
not
introduced
into
the
flame
zoneh,
i
Firebox
temperatureb
(
63.644(
a)(
4))
1.
Continuous
recordsc
2.
Record
and
report
the
firebox
temperature
averaged
over
the
full
period
of
the
performance
test
­
NCSd
3.
Record
the
daily
average
firebox
temperature
for
each
operating
daye
4.
Report
all
daily
average
firebox
temperatures
that
are
outside
the
range
established
in
the
NCS
or
operating
permit
and
all
operating
days
when
insufficient
monitoring
data
are
collectedf
­
PRg
TABLE
10.
MISCELLANEOUS
PROCESS
VENTS­­
MONITORING,
RECORDKEEPING
AND
REPORTING
REQUIREMENTS
FOR
COMPLYING
WITH
98
WEIGHT­
PERCENT
REDUCTION
OF
TOTAL
ORGANIC
HAP
EMISSIONS
OR
A
LIMIT
OF
20
PARTS
PER
MILLION
BY
VOLUME
Control
device
Parameters
to
be
monitoreda
Recordkeeping
and
reporting
requirements
for
monitored
parameters
Flare
Presence
of
a
flame
at
the
pilot
light
(
63.644(
a)(
2))
1.
Hourly
records
of
whether
the
monitor
was
continuously
operating
and
whether
a
pilot
flame
was
continuously
present
during
each
hour.

2.
Record
and
report
the
presence
of
a
flame
at
the
pilot
light
over
the
full
period
of
the
compliance
determination
­
NCSd
3.
Record
the
times
and
durations
of
all
periods
when
all
pilot
flames
for
a
flare
are
absent
or
the
monitor
is
not
operating
4.
Report
the
times
and
durations
of
all
periods
when
all
pilot
flames
for
a
flare
are
absent
or
the
monitor
is
not
operatingAll
Control
DevicesPresence
of
flow
diverted
to
the
atmosphere
from
the
control
device
(
63.644(
c)(
1))
or
1.
Hourly
records
of
whether
the
flow
indicator
was
operating
and
whether
flow
was
detected
at
any
time
during
each
hour.

2.
Record
and
report
the
times
and
durations
of
all
periods
when
the
vent
stream
is
diverted
through
a
bypass
line
or
the
monitor
is
not
operating
­
PRg
Monthly
inspections
of
sealed
valves
[
63.644(
c)(
2)]
1.
Records
that
monthly
inspections
were
performed
2.
Record
and
report
all
monthly
inspections
that
show
the
valves
are
not
closed
or
the
seal
has
been
changed
­
PRg
a
Regulatory
citations
are
listed
in
parentheses.

b
Monitor
may
be
installed
in
the
firebox
or
in
the
ductwork
immediately
downstream
of
the
firebox
before
any
substantial
heat
exchange
is
encountered.
TABLE
10.
MISCELLANEOUS
PROCESS
VENTS­­
MONITORING,
RECORDKEEPING,
AND
REPORTING
REQUIREMENTS
FOR
COMPLYING
WITH
98
WEIGHT­
PERCENT
REDUCTION
OF
TOTAL
ORGANIC
HAP
EMISSIONS
OR
A
LIMIT
OF
20
PARTS
PER
MILLION
BY
VOLUME
(
CONCLUDED)

c
"
Continuous
records"
is
defined
in
§
63.641.

d
NCS
=
Notification
of
compliance
status
report
described
in
§
63.654.

e
The
daily
average
is
the
average
of
all
recorded
parameter
values
for
the
operating
day.
If
all
recorded
values
during
an
operating
day
are
within
the
range
established
in
the
NCS
or
operating
permit,
a
statement
to
this
effect
can
be
recorded
instead
of
the
daily
average.

f
When
a
period
of
excess
emission
is
caused
by
insufficient
monitoring
data,
as
described
in
§
63.654(
g)(
6)(
i)(
C)
or
(
D),
the
duration
of
the
period
when
monitoring
data
were
not
collected
shall
be
included
in
the
Periodic
Report.

g
PR
=
Periodic
Reports
described
in
§
63.654(
g).

h
No
monitoring
is
required
for
boilers
and
process
heaters
with
a
design
heat
capacity
>
44
megawatts
or
for
boilers
and
process
heaters
where
all
vent
streams
are
introduced
into
the
flame
zone.
No
recordkeeping
or
reporting
associated
with
monitoring
is
required
for
such
boilers
and
process
heaters.

i
Process
vents
that
are
routed
to
refinery
fuel
gas
systems
are
not
regulated
under
this
subpart.

No
monitoring,
recordkeeping,
or
reporting
is
required
for
boilers
and
process
heaters
that
combust
refinery
fuel
gas.
271
272
273
TABLE
10.
MISCELLANEOUS
PROCESS
VENTS­­
MONITORING,
RECORDKEEPING
REQUIREMENTS
FOR
COMPLYING
WITH
98
WEIGHT­
PERCENT
RED
ORGANIC
HAP
EMISSIONS
OR
A
LIMIT
OF
20
PARTS
PER
MILL
(
CONCLUDED)
TABLE
10.
MISCELLANEOUS
PROCESS
VENTS­­
MONITORING,
RECORDKEEPING
REQUIREMENTS
FOR
COMPLYING
WITH
98
WEIGHT­
PERCENT
REDU
ORGANIC
HAP
EMISSIONS
OR
A
LIMIT
OF
20
PARTS
PER
MIL
274