Document ID: EPA-HQ-OW-2004-0032-0361
Agency: epa
Document Type: Supporting & Related Material
Title: 
Posted Date: 2005-08-18T04:00Z

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MEMORANDUM
TO:
Carey
Johnston,
EPA
FROM:
TJ
Finseth,
ERG
DATE:
4
February
2005
SUBJECT:
Steam
Electric
Demographic
Information
ERG
is
currently
collecting
industry
demographic
and
wastewater
characteristic
data
for
the
steam
electric
industry
in
support
of
the
2006
Effluent
Guidelines
Program
Plan.
This
memorandum
presents
a
preliminary
summary
of
the
demographic
information
for
the
year
2002
collected
by
the
Department
of
Energy's
Energy
Information
Administration
(
EIA).
The
EIA
information
will
be
combined
with
Toxic
Release
Inventory
(
TRI)
and
Permit
Compliance
System
(
PCS)
data
to
further
characterize
the
industry
by
investigating
wastewater
discharges
and
pollutant
loads.

Background
Water
discharges
from
the
steam
electric
power
generating
point
source
category
are
regulated
in
the
Code
of
Federal
Regulations
Title
40,
Part
423,
which
is
applicable
to:

"
discharges
resulting
from
the
operation
of
a
generating
unit
by
an
establishment
primarily
engaged
in
the
generation
of
electricity
for
distribution
and
sale
which
results
primarily
from
a
process
utilizing
fossil­
type
fuel
(
coal,
oil,
or
gas)
or
nuclear
fuel
in
conjunction
with
a
thermal
cycle
employing
the
steam
water
system
as
the
thermodynamic
medium."

ERG
used
the
definition
above
to
identify
steam
electric
facilities
from
publically­
available
information
reported
on
Form
EIA­
860.
All
electric
generating
plants,
which
have
a
nameplate
rating
of
one
megawatt
or
more
and
are
operating
or
plan
to
be
operating
within
five
years
of
the
year
of
submittal,
are
required
to
complete
Form
EIA­
860.
ERG
used
the
2002
information
to
initially
characterize
the
industry
by
capacity,
number
of
units,
and
energy
source.
The
information
contained
within
the
form
includes
the
following
facility
information:

°
Company
Name;
°
Facility
Name;
°
Plant
ID
(
Assigned
by
EIA);
Memorandum
February
4,
2005
Page
2
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°
North
American
Industry
Classification
System
(
NAICS)
code;
°
Generator
ID;
°
Nameplate
Capacity
­
The
maximum
rated
output
of
a
generator;
°
Prime
Mover
­
The
engine,
turbine,
water
wheel,
or
similar
machine
that
drives
an
electric
generator;
°
Energy
Source
­
The
primary
source
that
provides
the
power
that
is
converted
to
electricity
through
chemical,
mechanical,
or
other
means;
°
Month
and
year
of
initial
operation;
and
°
Type­
A
code
identifying
whether
the
parent
company
is
a
regulated
or
unregulated
company.

ERG
extracted
data
for
the
steam
electric
industry
using
the
definitions
of
prime
mover
and
energy
source.
Appendix
A
contains
a
list
of
the
prime
movers
and
Appendix
B
contains
a
list
of
the
energy
sources
included
in
the
EIA
data.
ERG
included
the
following
prime
movers
from
form
EIA­
860
in
the
initial
industry
characterization:

°
ST
­
Steam
Turbine;
°
CA
­
Combined
Cycle
Steam
Part;
°
CT
­
Combined
Cycle
Combustion
Turbine
Part;
and
°
CS
­
Combined
Cycle
Single
Shaft
(
combustion
turbine
and
steam
turbine
share
a
single
generator).

ERG
initially
assumed
that
combined
cycle
facilities
are
included
in
the
steam
electric
industry.
EIA
defines
combined
cycle
as
a
cogeneration
technology
in
which
additional
electricity
is
produced
sequentially
from
the
otherwise
lost
waste
heat
exiting
from
one
or
more
gas­
fired
conventional
boilers.
The
exiting
heat
is
routed
to
a
boiler
or
steam
turbine.
The
1996
Preliminary
Data
Summary
for
the
Steam
Electric
Point
Source
Category
(
PDS)
did
not
include
combined
cycle
facilities
in
the
steam
electric
category
since
the
majority
of
the
electricity
produced
at
these
facilities
is
provided
by
the
gas
turbines,
rather
than
steam
turbines.
The
PDS
stated
that
there
is
typically
a
65/
35
gas
turbine/
steam
turbine
split
for
these
facilities.
ERG
will
evaluate
whether
these
facilities
should
be
included
in
the
Steam
Electric
study.

ERG
included
the
following
energy
sources
in
the
initial
industry
study:

°
BIT
­
Anthracite
Coal,
Bituminous
Coal;
°
LIG
­
Lignite
Coal;
°
SUB
­
Subbituminous
Coal;
°
WC
­
Waste/
Other
Coal;
°
DFO
­
Distillate
Fuel
Oil;
°
JF
­
Jet
Fuel;
Memorandum
February
4,
2005
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3
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Coal
48%
Natural
Gas
32%

Nuclear
15%
Oil
5%
Total
Steam
Electric
Capacity:
707,450
Megawatts
°
KER
­
Kerosene;
°
RFO
­
Residual
Fuel
Oil;
°
WO
­
Oil­
Other
and
Waste
Oil,
Crude
Oil,
Liquid
Byproducts,
Oil
Waste,
Propane
(
Liquid),
Re­
Refined
Motor
Oil,
Sludge
Oil,
Tar
Oil)
;
°
NG
­
Natural
Gas;
and
°
NUC
­
Nuclear
(
Uranium,
Plutonium,
Thorium).

ERG
used
the
resulting
information
to
summarize
the
steam
electric
industry
demographics.

Industry
Summary
Figure
1
shows
the
distribution
of
the
energy
sources
used
in
the
steam
electric
industry.
The
figure
shows
that
most
of
the
electricity
produced
by
the
steam
electric
facilities
is
provided
by
coal
and
natural
gas.
There
are
1,457
steam
electric
facilities
reporting
on
Form
EIA­
860
with
a
total
electric
capacity
of
707,450
Megawatts.

Figure
1.
Distribution
of
Electricity
Production
in
the
Steam
Electric
Industry
Definition
of
Utility
and
Nonutility
Segments
Memorandum
February
4,
2005
Page
4
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The
electric
industry
can
be
divided
into
two
segments:
utilities
and
nonutilities.
The
EPA
Office
of
Compliance
Sector
Notebook
for
the
steam
electric
power
generation
industry
defines
the
terms
as
follows:

°
Utility
­
Facility
that
owns
generation,
transmission,
and
distribution
functions.
°
Nonutility
­
Facility
that
owns
only
generation
capabilities.

EIA
uses
the
terms
regulated
and
unregulated
entities
to
correspond
to
utilities
and
nonutilities.
Regulated
entities
sell
electricity
to
the
public
while
unregulated
entities
do
not
have
a
designated
franchised
service
area.
Utilities
are
categorized
under
NAICS
code
22
(
utilities).
According
to
information
obtained
from
EIA,
the
type
field
(
regulated/
unregulated)
can
be
used
to
separate
utilities
from
nonutilities.
However,
there
may
be
some
unregulated
facilities
that
are
run
by
regulated
utilities,
and
vice­
versa.
The
results
of
the
separation
of
utilities
and
nonutilities
show
there
are
663
utilities,
all
of
which
are
classified
under
NAICS
code
22.
Of
the
794
nonutilities,
484
are
classified
under
NAICS
code
22.
ERG
will
investigate
these
facilities
further
to
determine
if
it
is
more
appropriate
to
include
them
in
the
utility
segment
of
the
industry.

Comparison
of
EIA
Data
for
Utilities
and
Nonutilities
Utilities
provide
approximately
60%
(
430,991
Megawatts)
of
the
electricity
produced
in
the
steam
electric
industry
and
nonutilities
provide
the
other
40%
(
276,459
Megawatts).
Tables
1
and
2
present
the
capacity,
number
of
steam
electric
facilities,
and
number
of
steam
electric
generators
according
to
facility
size
for
utilities
and
nonutilities.
Facilities
may
have
multiple
generators.

Table
1.
Distribution
of
Steam
Electric
Utility
Facilities
by
Size
Memorandum
February
4,
2005
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5
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Plant
Capacity
0
­
50
Megawatts
51
­
100
Megawatts
101
­
200
Megawatts
201
­
300
Megawatts
301
­
400
Megawatts
401
­
500
Megawatts
Over
501
Megawatts
Total
Total
Utility
Capacity
(
MW)
2,525
4,919
12,544
13,735
14,233
19,285
363,750
430,991
Percent
of
Utility
Capacity
0.6%
1.1%
2.9%
3.2%
3.3%
4.5%
84.4%
100%
Number
of
Utility
Plants
95
66
86
55
40
43
278
663
Percent
of
Utility
Plants
14.3%
10.0%
13.0%
8.3%
6.0%
6.5%
41.9%
100%
Number
of
Utility
Generators
182
157
230
147
123
124
902
1,865
Percent
of
Utility
Generators
9.8%
8.4%
12.3%
7.9%
6.6%
6.6%
48.4%
100%

Table
2.
Distribution
of
Steam
Electric
Nonutility
Facilities
by
Size
Plant
Capacity
0
­
50
Megawatts
51
­
100
Megawatts
101
­
200
Megawatts
201
­
300
Megawatts
301
­
400
Megawatts
401
­
500
Megawatts
Over
501
Megawatts
Total
Total
Nonutility
Capacity
(
MW)
4,745
7,764
12,848
11,578
12,388
11,556
215,580
276,459
Percent
of
Nonutility
Capacity
2%
3%
5%
4%
4%
4%
78%
100%
Number
of
Nonutility
Plants
280
108
93
47
36
26
204
794
Percent
of
Nonutility
Plants
35%
14%
12%
6%
5%
3%
26%
100%
Number
of
Nonutility
Generators
558
262
259
132
99
76
734
2,120
Percent
of
Nonutility
Generators
26%
12%
12%
6%
5%
4%
35%
100%

The
data
in
Tables
1
and
2
show
that
the
majority
of
the
capacity
is
generated
by
large
facilities
(>
500
Megawatts),
for
both
segments
of
this
industry.
The
largest
number
of
utility
facilities
are
also
over
500
Megawatts.
However,
the
greatest
number
of
nonutilities
is
in
the
smallest
size
range,
0
to
50
Megawatts.

Figures
2
and
3
show
the
energy
sources
used
within
each
segment
of
the
steam
electric
industry.
The
majority
of
the
capacity
for
the
utilities
is
provided
by
coal
(
60%),
while
the
majority
of
the
capacity
for
the
nonutilities
is
provided
by
natural
gas
(
51%).
Memorandum
February
4,
2005
Page
6
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0
50
100
150
200
250
300
Coal
Oil
Natural
Gas
Nuclear
Capacity
(
Thousand
MW)
60%

4%
20%
16%
Total
Existing
Capacity:
430,991
Megawatts
0
20
40
60
80
100
120
140
160
Coal
Oil
Natural
Gas
Nuclear
Capacity
(
Thousand
MW)

28%

7%
51%

14%
Total
Existing
Capacity:
276,459
Megawatts
Figure
2.
Share
of
Capacity
at
U.
S.
Electric
Utilities
by
Energy
Source,
2002
Figure
3.
Share
of
Capacity
at
U.
S.
Electric
Nonutilities
by
Energy
Source,
2002
Memorandum
February
4,
2005
Page
7
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0
50
100
150
200
250
300
prior
to
1951
1951­
1960
1961­
1970
1971­
1980
1981­
1990
1991­
2002
Initial
Year
of
Operation
for
2002
Reporters
Capacity
(
Thousand
MW)

Coal
Oil
Natural
Gas
Nuclear
Total
Capacity
for
2002
Reporters
0
20
40
60
80
100
120
140
160
Prior
to
1951
1951­
1960
1961­
1970
1971­
1980
1981­
1990
1991­
2002
Initial
Year
of
Operation
for
2002
Reporters
Capacity
(
Thousand
MW)

Coal
Oil
Natural
Gas
Nuclear
Total
Capacity
for
2002
Reporters
Figures
4
and
5
use
the
initial
year
of
startup
to
present
historical
trends
for
the
steam
electric
category.
These
plots
show
the
electricity
capacity
added
in
each
decade.
The
largest
increase
in
coal­
fired
utility
capacity
occurred
in
the
1970s.
During
the
1990s
the
growth
of
the
utility
segment
slowed
while
growth
in
the
nonutility
segment
increased.

Figure
4.
Capacity
Additions
at
U.
S.
Electric
Utilities
by
Energy
Source
Figure
5.
Capacity
Additions
at
U.
S.
Electric
Nonutilities
by
Energy
Source
Memorandum
February
4,
2005
Page
8
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0
50
100
150
200
250
300
350
Prior
to
1951
1951­
1960
1961­
1970
1971­
1980
1981­
1990
1991­
2002
Year
of
Initial
Operation
Number
of
Generator
Additions
Coal
Oil
Natural
Gas
Nuclear
0
100
200
300
400
500
600
700
Prior
to
1951
1951­
1960
1961­
1970
1971­
1980
1981­
1990
1991­
2002
Year
of
Initial
Operation
Number
of
Generator
Additions
Coal
Oil
Natural
Gas
Nuclear
Industry
trends
for
the
utilities
and
the
nonutilities
can
also
be
seen
by
the
number
of
generators
built.
Figures
6
and
7
show
the
number
of
generators
that
have
been
added
to
each
industry
segment
by
energy
source.

Figure
6.
Generator
Additions
at
U.
S.
Electric
Utilities
by
Energy
Source
Figure
7.
Generator
Additions
at
U.
S.
Electric
Nonutilities
by
Energy
Source
Memorandum
February
4,
2005
Page
9
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These
data
suggest
that
in
recent
years
the
nonutility
segment
has
been
growing
at
a
faster
rate
than
the
utilities
segment.
According
to
the
PDS,
this
growth
may
be
due
to
energy
legislation
in
the
late
1970s,
specifically
the
Public
Utility
Regulatory
Act
(
PURPA)
of
1978.
Provisions
of
this
act
encouraged
the
development
of
cogeneration
and
small
power
production
by
loosening
the
economic,
regulatory,
and
institutional
barriers.

Nonutility
Industries
The
nonutility
segment
contains
facilities
from
42
different
NAICS
codes.
Appendix
C
contains
a
list
of
the
industries,
the
number
of
facilities
represented,
and
the
total
capacity
for
all
the
facilities.
The
industries
that
are
represented
most
frequently
in
the
steam
electric
nonutility
segment
include
the
following:

°
Chemical
Manufacturing;
°
Educational
Services;
°
Food
Manufacturing;
°
Newsprint
Mills.
°
Oil
and
Gas
Extraction;
°
Paperboard
Mills;
and
°
Petroleum
Refineries.

ERG
will
investigate
this
segment
of
the
industry
further
to
determine
if
there
are
unique
wastewater
characteristics
and
treatment
needs
for
nonutilities.
As
mentioned
previously,
ERG
included
combined
cycle
facilities
in
the
steam
electric
industry.
Combined
cycle
facilities
represent
about
45%
of
the
nonutility
segment.
We
will
also
evaluate
whether
combined
cycle
facilities
should
be
included
in
the
steam
electric
industry.
ERG
will
use
additional
data
from
TRI,
PCS,
and
industry
groups
to
study
the
nonutility
segment.

Next
Steps
ERG
will
continue
to
develop
industry
profile
information
using
data
from
EIA.
This
preliminary
demographic
information
will
be
combined
with
information
from
TRI
and
PCS
to
characterize
the
wastewater
discharge
from
this
industry.
ERG
will
use
this
information
to
answer
the
following
questions:

1.
What
waste
streams
are
driving
the
pollutant
loads?
How
do
the
top
pollutants
vary
between
the
high
and
low
flow
waste
streams?

2.
What
impact
do
non­
detect
values
have
on
the
estimation
of
pollutant
loads?
Memorandum
February
4,
2005
Page
10
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3.
What
are
the
differences
in
the
quantity
of
pollutants
by
energy
source
(
coal,
oil,
natural
gas)?

4.
Are
there
differences
in
the
top
pollutants
for
utility
versus
nonutility
facilities?

5.
Nonutilities
are
a
growing
segment
of
the
steam
electric
industry.
Are
certain
industries
driving
the
nonutility
pollutant
loads?

6.
What
are
the
top
pollutants
for
combined
cycle
plants?
Should
these
facilities
be
examined
further
in
the
steam
electric
study?

ERG
will
use
the
results
from
this
preliminary
industry
profile
along
with
results
of
the
analyses
listed
above
to
recommend
additional
data
gathering
activities
(
site
visits,
collection
of
permit
application
materials,
etc.).

References
1.
U.
S.
Department
of
Energy,
Energy
Information
Administration.
www.
eia.
doe.
gov.

2.
U.
S.
Environmental
Protection
Agency.
Preliminary
Data
Summary
for
the
Steam
Electric
Point
Source
Category,
EPA­
821­
Z­
96­
010,
Washington,
DC,
1996.

3.
U.
S.
Environmental
Protection
Agency,
Profile
of
the
Fossil
Fuel
Electric
Power
Generation
Industry,
EPA
Office
of
Compliance
Sector
Notebook
Project,
EPA/
310­
R097­
007,
September
1997.
A­
1
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Appendix
A
Prime
Mover
Prime
Mover
Description
ST
Steam
Turbine,
including
nuclear,
geothermal,
and
solar
(
does
not
include
combined
cycle)
GT
Combustion
(
Gas)
Turbine
(
includes
jet
engine
design)
IC
Internal
Combustion
Engine
(
diesel,
piston)
CA
Combined
Cycle
Steam
Part
CT
Combined
Cycle
Combustion
Turbine
Part
(
type
of
coal
must
be
reported
as
energy
source
for
integrated
coal)
CS
Combined
Cycle
Single
Shaft
(
combustion
turbine
and
steam
turbine
share
a
single
generator
CC
Combined
Cycle
Total
Unit
(
use
only
for
plants/
generators
that
are
in
planning
stage,
for
which
specific
generator
details
cannot
be
provided)
HY
Hydraulic
Turbine
(
includes
turbines
associated
with
delivery
of
water
by
pipeline)
PS
Hydraulic
Turbine
­
Reversible
(
pumped
storage)
PV
Photovoltaic
WT
Wind
Turbine
CE
Compressed
Air
Energy
Storage
FC
Fuel
Cell
OT
Other
NA
Unknown
at
this
time
(
use
only
for
plants/
generators
that
are
in
planning
stage,
for
which
specific
generator
details
cannot
be
provided.)

Note:
Prime
movers
listed
in
bold
were
included
in
the
initial
steam
electric
study.
B­
1
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Appendix
B
Energy
Source
Energy
Source
Description
BIT
Anthracite
Coal,
Bituminous
Coal
LIG
Lignite
Coal
SUB
Subbituminous
Coal
WC
Waste/
Other
Coal
(
Anthracite
Culm,
Bituminous
Gob,
Fine
Coal,
Lignite
Waste,
Waste
Coal)
SC
Coal­
based
Synfuel
and
include
briquettes,
pellets,
or
extrusions,
which
are
formed
by
binding
materials
and
processes
that
recycle
material
DFO
Distillate
Fuel
Oil
(
includes
all
Diesel
and
No.
1,
No.
2,
and
No.
4
Fuel
Oils)
JF
Jet
Fuel
KER
Kerosene
RFO
Residual
Fuel
Oil
(
Includes
No.
5
and
No.
6
Fuel
Oils
and
Bunker
C
Fuel
Oil)
WO
Oil­
Other
and
Waste
Oil
(
Butane
(
Liquid),
Crude
Oil,
Liquid
Byproducts,
Oil
Waste,
Propane
(
Liquid),
Re­
Refined
Motor
Oil,
Sludge
Oil,
Tar
Oil)
PC
Petroleum
Coke
NG
Natural
Gas
BFG
Blast­
Furnace
Gas
OG
Other
Gas
(
Butane,
Coal
Processes,
Coke­
Oven,
Refinery,
and
other
processes)
PG
Propane
NUC
Nuclear
(
Uranium,
Plutonium,
Thorium)
AB
Agriculture
Crop
Byproducts/
Straw/
Energy
Crops
BLQ
Black
Liquor
GEO
Geothermal
LFG
Landfill
Gas
MSW
Municipal
Solid
Waste
OBS
Other
Biomass
Solids
(
Animal
Manure
and
Waste,
Solid
Byproducts,
and
other
solid
biomass
not
specified)
OBL
Other
Biomass
Liquids
(
Ethanol,
Fish
Oil,
Liquid
Acetonitrile
Waste,
Medical
Waste,
Tall
Oil,
Waste
Alcohol,
and
other
biomass
liquids
not
specified)
OBG
Other
Biomass
Gases
(
Digester
Gas,
Methane,
and
other
biomass
gases)
OTH
Other
(
Batteries,
Chemicals,
Coke
Breeze,
Hydrogen,
Pitch,
Sulfur,
Tar
Coal,
and
miscellaneous
technologies)
PUR
Purchased
Steam
SLW
Sludge
Waste
SUN
Solar
(
Photovoltaic,
Thermal)
TDF
Tires
B­
2
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WAT
Water
(
Conventional,
Pumped
Storage)

Energy
Source
Energy
Source
Description
WDS
Wood/
Wood
Waste
Solids
(
Paper
Pellets,
Railroad
Ties,
Utility
Poles,
Wood
chips,
and
other
wood
solids)
WDL
Wood
Waste
Liquids
(
Red
Liquor,
Sludge
wood,
Spent
Sulfite
Liquor,
and
other
wood
related
liquids
not
specified)
WND
Wind
NA
Not
Available
Note:
Energy
sources
listed
in
bold
were
included
in
the
initial
steam
electric
study.