iLLINOIS POLLUTION CONTROL BOARD
RECEIVED
CLERK~SOFFICE
OCT 03 ~OO~
IN THE MATTER OF:
)
)
NATURAL GAS-FIRED, PEAK-LOAD )
ELECTRICAL POWER GENERATING )
FACILITIES (PEAKER PLANTS)
)
Unit
CornEd:
RO -10
STATE OF ILLINOIS
Pollution Control Board
Zion 1
Zion 2
Dresden 1
Dresden 2
Dresden 3
Quad Citiesi
Quad Cities2
LaSatle 1
LaSalIe2
Byron I
Byron 2
Braidwood 1
Braidwood 2
Amergen:
Closed
Closed
Closed
2009
2011
2011
2012
2022
2023
2024
2026
2026
2027
RESPONSE TO
QUESTIONS OF CHARLES E. FISHER
1. What is the schedule for Illinois nuclear power plants to be permanently shut
down?
Licensø Exoiration Date
Clinton
2026
2. What is the
amount of energy imported into and exported from Illinois?
Since the Federal Energy Regulatory Commission allowed open access
(deregulation) in the interstate electric transmission
system,
many new players,
referred to as power marketers and independent power producers, have entered
the wholesale market. This, as well as other issues, makes the question,
‘What
amount of energy is imported and exported from Illinois?” very difficult to answer.
For example, CornEd’s total sales in 1999 were about 110 million megawatt
hours. CornEd purchased about Ii million, or 10 of that amount, from other
utilities and power marketers. About I million of that was from Illinois utilities.
CornEd sold about 19 million megawatt hours, or 17, to other utilities and
power marketers. About I million megawatt hours were sold to Illinois utilities.
CornEd sold the rest to power marketers or out-of-state utilities.
Where the consumer of CornEd-generated electricity is located is very difficult to
track lt is possible the power marketer resold the power to another Illinois utility
or to retail customers directly. Similarly, the out-of-state utility might resell the
power in Illinois, or to another state. Exact tracking of these transactions is not
possible through Commerce Commission records.
3.
What is the statutory cite of the electric choice law referred to in Executive
Director Fisher’s testimony?
Effective December 16, 1997, Public Act 90-561 added new Article XVI, entitled
the “Electric Service Customer Choice and Rate Relief Law of 1997,” to the
Public Utilities Act. Article XVI, as subsequently amended, may be found at 220
ILCS 5/1 6-101 through 16-130.
4. What are the siting requirements in other states?
Some states, mostly those that have enacted restructuring laws, have
established Siting Divisions or Siting Committees which are either separate from
the state PUC or a branch of the state PUC. States like California, New York
and Ohio, which have enacted electric restructuring laws, have Siting Divisions
or Siting Committees which determine where Peakers can be sited. States like
Wisconsin, which has not enacted electric restructuring laws, require traditional
certificates of convenience and necessity for Peakers. States like Kentucky,
which also has not enacted electric restructuring laws, does not require any pre-
approval, other than Kentucky EPA permitting and local zoning decisions prior to
the siting of a Peaker. Texas, which has enacted electric restructuring laws, has
a system similarto Illinois’s current system, where local zoning boards and the
state EPA are the only regulatory bodies which control siting and permitting,
respectively.
California Public Utilities Commission: California requires any electric
generating facility, including a Peaker, that is 50MW or larger to receive
certification from the Energy Facilities Siting and Environmental Protection
Division (“Siting Division”). Approximately 15 proposals for Peakers are
currently pending at the Siting Division. The Siting Division, instead of
adopting standards, makes its decision on a case by case basis through
comprehensive review. Environmental issues are considered and all
certifications for Peakers are open to the public. The Siting Division also
oversees construction and operation of the Peakers.
• Indiana
Utility
Regulatory
Commission (“IURC”):
Indiana requires its
public utilities to obtain a certificate of necessity prior to constructing electric
generating facilities, including Peakers. The IURC has held that lPPs in
Indiana are public utilities and requires that 1PPs obtain construction permits
from the IURC. Peakers must also obtain air emission permits and water use
permits.
Although there recently was some public outcry for a moratorium on
the construction of Peakers, no such moratorium is in effect. A summer study
committee entitled the Regulatory Flexibility Committee (“RFC”), comprised of
members from the Indiana House of Representatives’ and the Indiana
Senate’s Commerce Committee, has been appointed to study the issue of
Peaker siting. The RFC is scheduled to meet in mid October 2000.
• Kentucky Public Service Commission (“KPSC”): Although a number
of Peakers are close to being built in Kentucky, the KPSC has determined
that prior approval is not required for a Peaker as long as the Peaker sells the
electricity
it
generates wholesale on the market.
• New York State Public Service Commission: New York
requires that
any plant, including Peakers, which generates more than 80W must be
certified by the New York State Electric Siting Board, also known as the
Article X Siting Board. Proceedings are open to the public and consider but
can preempt local zoning.
• Public Utilities Commission of Ohio (“PUCO”): Ohio requires that any
plant, including Peakers, must be certified by the Power Siting Board if it
generates more than 50MW. Peakers will undergo an evaluation process
and the Power Siting Board will make its decision on a case by case basis.
No additional emission or noise requirements are necessary other than those
required by the Ohio EPA.
• Public Utility Commission ofTexas: Although Texas is projected to
install 20,000MW of combined-cycle gas turbines in the near future, Texas
does not have a siting commission for power plant projects. Instead, Texas
has a model similar to Illinois’s current model where the state EPA and local
zoning boards determine whether power plant projects can go forward, and
where they can be placed. Texas issues certificates of convenience and
necessity, but only for power plant projects initiated by utilities, and not
initiated by lPPs.
• Wisconsin Public Service Commission (“WPSC”): All electric
generating facilities, including Peakers, which provide more than 100 MW or
greater must receive a certificate of public convenience and necessity, an
environmental impact statement (“EIS”) must be prepared by the electric
provider, hearings are set, and the commission must then either approve or
deny.
I am also providing for the record a U.S. Environmental Protection Agency
public document entitled “National Combustion Turbine Projects” (attached).
National Combustion Turbine Projects
Last Updated 10/03/2000
State
(
REGIO
Permit
NI
Facility
#Of
~f
Turbine
Mode
Hours
.
NOx Urn~t
.
.
Control
~
.
CT Permit
11/97
Bridgeport En:rgy 2
—
V~A
NO’
Fo
8.760; 720 NG;42
ppmFO
SCR
10 ppm
GCP
1.hr
CT
Draft
Permit
12/98
PDC-EL Paso
Milford LLC (540
MW total)
2
ABB GT-24
CC
8 760• 720
Fo
2.0 ppm
NG; 9 ppm
FO
SCR
3-hr
2.Oppm
CatOx
1-hr
CT
Draft
Permit
6/99
Lake Road
Generating
(792 MW total)
3
ABB GT-24
NG
Fo
8 760’ 720
* FO
2.0 ppm
NG; 9 ppm
FO
8CR
3-hr
3.Oppm
CatOx
1-hr
MA
MA
permit
pde~r~it
10/97
Dighton Power
oa)
1
1
ABB GT24
ABB ST
NG
cc
CC
8,7;2o
8,760
~m
3.5 ppm
8CR
SCR
4 ppm
4 ppm
CatOx
CatOx
MA
1-hr
draft
permit
2/98
.
.
~
1
Sw 501G
8,760;720
3.5 ppm
NGI9
ppm
FO
SCR
4 ppm
CatOx
4E~
2
NO
CC
8,780
2.0 ppm
SCR
1-hr
3 ppm
CatOx
1-hr
NOx3~5ppm/Steam
MA
draft
permit
3/99
ANP Blackstone
(580 MW total)
2
ABB
GT-24
NO
CC
8,760
2.0 ppm
SCR
1-hr
3 ppm
CatOx
1-hr
NOx 3.5ppml Steam
Augmentation
MA
h”
Sithe Mystic
Development
(1550 MW total)
4
.
Mitsubishi
“I
NO
CC
8,760
2.0 ppm
SCR
1-hr
2 ppm
CatOx
1-hr
Netted out of PSD/NSR forNOx
MA
draft
permit
12/99
Cabot Power (350
~
1
Sw 5010 NO
CC
8,760
2.0 ppm
8CR
1-hr
2 ppm
CatOx
1-hr
ME
Energy LLC (150
MW total)
3
SW 2518 NO; C
8,7720 9 pPm/42
~
SCR
1-hr
5-loppm
GCP
ME
~
Rumford Power
Associates (265
Mwtotat)
1
—
CC
CC
8,760; 720
3.5ppm
SCR
24-hr
15 ppm
GCP
24-hr
24-hr
5/98 Co. (520 MW total)
2
NO
8,760
3.5ppm
GCP
24-hr
20 ppm
GCP
PSD Review only
IIQ~
~
A,...,,,...
a
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Date
Facility
#of
~
#of
DB
Turbine
Model
Fuel
—
Mode Hours
NOx Limit
Control
Method
Avg
Time
CO
Limit
Control
Method
Avg
Time
Comments
ME
Champion
International (250
MW total)
1
CC 8,760; 720
9PPITIJ
~
GCP
24-hr
9 ppm
GCP
24-hr
Netted out of PSD/NSR review,
8CR required if 9 ppm not
achievable
ME
Power
2
GE7FA
NG;
8,760; 720 S5ppm
8CR
24-hr
15 ppm
GCP 24-hr
ME
draft
Gorharn Energy
*
ABB GT..24
NO;
8,760; 720
NG;9 ppm
SCR
24-hr
5 ppm
CatOx 24-hr 3.5ppm NOx Steam injection
NH
NewingtonEn:rgy 7
2
GE 7FA
8.760; 720
2.5 ppm
8CR
3-hr
15 ppm
GCP
1-hr
—
NH
.
~
AES Londonderry
LLC
(720
MW total)
SW 501G
CC
8,760; 720
2.5 ppm
NO; 9 ppm
FO
SCR
3-hr
15 ppm
GCP
1-hr
Steam injection allowed at
. ppm
—
RI
DRAFT
11/97
Tiverton Power
Associates (265
MW total)
1
GE 7FA
NG
CC
8,760
3.5 ppm
SCR
1-hr
20 ppm
GCP
1-hr
RI
DRAFT
Reliant Energy:
Hope Generating
total)
2
SW 501F NO
CC
8,760
2.5 ppm
SCR
1-hr
15 ppm
GCP
1-hr
Advised NOx LAER at 2.Oppm
~
REGION2
.
,
~.:
..
.
:,,
.
NY
~,
.
Athens Generating
Co.
Bethlehem Energy
Center
1080MW
750MW
NG;
NG
Certificate decision in June.
Final PSD and 201 permits out
by end of May.
Response to stack height inter.
TOA2 in 8/5199. Our comments
out
9/28/99.
NY
NYPA Poletti
—
500 MW
NG
FO
EPA monitoring waiver approval
12/28/99. Protocol comments
out_12/10/99
Sithe Energy -
Tome Valley
827MW
NO
PSD application in 3/28/00.
Article
X
application
.
TwinTier Power
(Summit Energy)
—
520MW
MG
EPA waiver approval middle of
May. Revised protocol O.K.,
contingencies: 12113/99.
NY
Sunset Energy
Fleet
520 MW
NO;
FO
Protocol O.K. 3/20/00. Inventory
approval in progress.
NY
Amr. Nat. Power
Ramapo Energy
1100 MW NG
Monitoring waiver approved on
12/28/99. Protocol approved
3/21/00.
US Environmental Protection Agency
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit~
Facility
CTs
V~1
DR
Turbine
Model
Fuel
T
Mode
Hours
NOx Limit
Control
Method
Avg.
Time
CO Limit
Control
Method
Time
—
Comments
NY
~
Sithe Energy
Heritage Station
Southern Energy
at Bowline
—
—
—
—
800MW
750MW
MG
FO
Application in
2/23/00;
in
compliance/complete on
Application in 3/21/00. EJ issue
forP50 completeness.
NY
Con Edison - East
River
450MW
NG’
FO
Revised protocol in 4/11/00.
PSD and NSR applicability
analysis in 5/3/00.
NY
SCS Energy -
Astoria
1000 MW
NG’
FO
Protocol comments 12/21/99.
Revised waiver comments out
NY
S
P1
Have traw
550MW
.
~
Protocol comments out 1/4/00.
EPA approval of onsite data
NY
Keyspan -
Ravenswood
—
—
250MW
p~
Protocolcommentsout 3/16/00
(EPA
Glenville Energy
Park
520MW
NG
Revised data for Preliminary
Scoping Statement in 5/4/00
NY
Brookhaven
Energy Project
580 MW
MG
—
Preliminary Scoping Statement
—
—
—
;
in3/24/00
NJ
Dec-99
Mantua Creek
Generating
ABB GT-24
(881 MW
total)
,
MG,
FO
CC
2.5 ppm
MG; 6 ppm
FO
DLN SC
R
CatOx
NJ
Dec-99
cogen Technology
(‘150 MW~
cc
NG;6 ppm
DLN/SC
.
CatOx
NJ
Jan*00
AES Red Oak
Project
3
SW 5015
(816 MW
total)
NG
CC
3ppm
DLN/SC
R
CatOx
NJ
applic.
under
review
Tosco Bayway
Refinery Cogen
Project
1
~
0
SW 50105
‘130 M~
‘
NO;
refin.
~
CC
NJ
CC
applic.
under
.
review
.
.
Liberty Generating
Project
—
SW 501G
(1090 MW
total)
MG
2.5 ppm
DLN/SC
R
CatOX
.
review
PSEG Fossil LLC
Kearney
total)
NG;
FO
N~m
FO
DLN/SC
R
.
review
PSEG Fossil LLC
Bergen
(75~fl~
total)
N~
FO
CC
NG;9 ppm
~
FO
DLN/SC
R
IIC’~
~
~
A ——
Nationa’ Combustion Turbine Projects
Last
Updated 10/03/2000
State
NJ
Permit
Date
applic.
under
review
Facility
PSEG Fossil LLC
Linden
# of
CTs
3
#
of
DB
Turbine
Model
GE 7FA
(750 MW
total)
Fuel
~
FO
Mode
CC
Hours
NOx Limit
3.5 ppm
NG; 9 ppm
FO
control
Method
DLNISC
R
Avg
Time
CO Limit
Cozflrol
Method
Avg,
Time
Comments
NJ
.
review
PSEG Fossil LLC
Sewaren
total)
NG:
FO
CC
NG,9 ppm
FO
DLN/SC
R
NJ
Feb-00
~_____
PSEG Fossil LLC
Linden
2
GE 7EA
(170 MW
total)
NG~
FO
sc
SC
SC
12 ppm
NG; 42
ppm FO
DLN
NJ
NJ
applic.
under
review
PSEG F
•l LLC
Burlington
(CPU).. ~re
GE LM
6000(500
MW total)
(85
MW)
NG
NC
DLN
NJ
.
l)P~1~
review
Sithe Energy
(CPU) - Atlantic
2
170MW-
1st Phase,
350 MW-
2nd Phase.
HG
CC
DLN/SC
R
NJ
withdra
Sithe Energy
(CPU) -
Forkedriver
2
GE Frame
6(130 MW
total)
NC
SC
NJ
NJ
withdra
wn
applic.
on er
review
Sithe Energy
(CPU) - Sayerville
Sithe Energy
(CPU) - Gilbert
(840 MW
total)
100 MW
total
NC
NG
CC
CC
DLN/SC
R
addition of HRSG and steam
generator to existing turbine
NJ
C
.
review
Statoil Celtic, Inc.-
Kearney
750 MW
total
NG
CC
2.5ppm
DLNISC
R
CatOx
PR
Sep-98
.
AES Puerto Rico
454MW
total
coal
PR
PREPA-San Juan
2
464 MW
total
FO
REGIO
DE
draft
permit
N3
applic.
under
.
review
V1WAPA-St
Thomas
.
Hay Road -
Deleware
1
24 MW
~
SC by
2001 then
CC by
2003, +
550 MW
SC
:~
•
•
~______
.:
US Environmental Protection Aoencv
A
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Date
Facility
#~f
CTs
#of
DB
Turbine
Model
Fuel Mode
Hours
NOx Limit
Control
Method
Avg
Time
CO Limit
Control
Method
Avg
Tlm~
Comments
MD
applic.
under
.
review
ODEC Rock
Springs - Cecil
Co.,MD
1020 MW
total
SC
VA Sep-99
Virginia Power -
.
RemIngton, VA
500 MW
total
SC
VA
applic.
under
review
Dominion Energy -
Caroline County,
VA
500 MW
total
SC
VA A r-00
~
DosweU - Hanover
Co., VA
190 MW
total
.
VA
draft
.
permit
Wolf Hills -
.
Washington Co.,
VA
250 MW
total
SC
PA
‘
draft
permit
Ontelaunee
Energy - PA
544
MW
total
CC
CC
CC
—
PA Ma -00
y
Liberty Electric -
Eddystone
PA
—
500 MW
total
—
PA
applic.
under
review
Panda Brandywine
- Montgomery Co.,
PA
~c®
MW
total
PA
applic.
under
.
review
SWEC - Falls
.
Township, PA
500 MW
total
CC
PA
applic.
under
.
review
FPL - Marcus
Hook, PA
750 MW
total
CC
PA
applic.
under
.
review
.
Limenck -
.
.
Limerick, PA
500 MW
total
CC
applic.
under
.
review
ODEC - Louisa
County
500 MW
total
SC
REGION 4
~‘
AL
12-97
1
1
NG
CC
8,760
15 ppm
DLN
0.07 lb/MMBtu
GCP
Power Augmentation
AL
5-98
AIa~mp~P~wer
-
Cogeneration
1
1
MG
CC
8,760
9 ppm;
lb/MMBtu
DR
DLN
0,O8ib/MMBtu
GCP
US Environmental Protection Agency
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Date
Facility
CTs
i~
DB
Turbine
Model
Fuel
Mode
Hours
NOx Umit
Control
Møthod
Avg
Time
Co Umit
Control
Method
Time
Comments
AL
8-98
Alabama Power,
(170~V)
8,760
DLN/SC
lbLtu
GCP
AL
8-99
Alabama Power,
1
1
NO
CC
8,760
DLN/SC
GCP
AL
199
Mobile
Energy,
LLC - Hog Bayou
1
1
1
GE 7FA
(168
MW)
NO;
FO
CC
8,760;
675 FO
35
NG
ppm w/
FO
DLN/SC
R;Wi
0.040
lb/MMBtu ~
0.058
lb/mmBtu FO
GCP
AL
Alabama Power -
C::~~n
Facility
1
(1 70 f~VV)
—
NG
8,760
0
U
DLN/SC
lbLt~tu
GCP
AL
11-99
Tenaska Alabama
Partners
GE 7FA
~‘170M’~’
‘
NG;
FO
CC
8,760; 720
FO
3.95 ppm
NG; 11.3
ppm FO
OLN/SC
R;
WIISCR
32.9 ppm NO:
46.7 ppm
NG/FO
GCP
AL
4-00
Georgia Power -
8
8
(170MW) NG
CC
8,760
DLN/SC
ib/MMBtu
GCP
AL
AL
draft
.
permit
applic.
~
Alabama Electric
Cooperative -
Gantt Plant
South Eastern
Energy Corp.
2
6
2
6 if
CC
SW 501F
(166
MW)
GE 7FA or
SW 501 F
NG
NG
CC
SC or
cc
8,760
8,760
3.5 ppm /
0.013
ib/MMBtu
9 or25 or
3.5 ppm
DLN/SC
R
DLN u1~
SC/SCR
0057
lb/MMBtu~
9or 19 or22
ppm
GCP
GCP
For NOx and CO: SC w/GE or
SC w/SW5O1 F or CC (either)
AL u~e~
review
Calpin:Solutia -
3
SW5OIF
NO
CC
8.780
4.0 ppm
SCR
15 ppm
GCP
AL
applic.
under
review
Calpine BP Amoco
3
SW5O1 F
~180
M~AI~
‘
NG
CC
8,760
4.0 ppm
SCR
15 ppm
GCP
AL
applic.
under
review
Tenaska Alabama
II Generating
Station
3
GE 7FA
(170
MW)
FO
NG
CC
876O~720
‘ FO
15/42 ppm
(SC); 4/42
ppm (CC)
DLN/Wl’
SCR/WI
0.058/ 0.062
lb/mmBtu (SC
& CC)
GCP
AL
applic.
under
review
Hillabee Energy
Center
—
22
SW5O1G
(229
MW)
8,760
3.5 ppm
DLN/SC
R
10/12/25/26
ppm
GCP
75-100Joad/DF/PA/PA+DF (up
to 2,000 hr/yr PA mode)
AL
.
applic.
under
.
review
f’
auccaneer ~.3as
Pipeline Company
Solar Mars
‘~5000~
‘‘
“
(15,000
hpj
NO
SC
8,760
30 ppm
DLN
50 ppm
GCP
—
US Environmental Prntec~tinnAn~r~c~v
A
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Date
FacIlity’
.
‘
#01
CTs
#01
DB
Turbine
Model
—:—~-
Fuel
NG
F
—
Mode
Sc
(later
CC)
Hours
,
.
.
NOxLlrnlt
‘ . .“
Control
Méthód
‘Avg,,
lime
‘‘
.
‘CO
Limit:”
.
.
.Cont~ot
Method
‘.
‘Time
/~
. :‘~,
:.ciy’ments.
FL
7-10-
98
City of Lakeland,
Mcintosh Power
Plant
1
1
—
SW 501G
(230
MW)
7,008; 250
FO
25ppm
until
5/2002, 9
ppm after,
7.5 ppm if
~
NG;
42ppmor
15 ppm FO
DLN or
5CR; WI
or 5CR
25 ppm NG;
90 ppm FO
GCP
Power Augmentation
.
FL
12-4-
98
SantaRosa
Energy Center,
Sterling Fibers
Mfg. Facility
1
—
GE 7FA
(167 MW)
NC
CC
8,760
9 ppm, 9.8
ppm w/ DB
DLN
9 ppm; 24
ppm
Wi
DB
GCP
If a different CT is used, SCR
may be required to meet 6 ppm
NOx)
FL
11-99
Kissimmee Utility
Authority, Cane
Island Power Park
Unit 3
1
GE 7FA
(167 MW)
—
NC;
FO
CC
8,760;
720 FO
3.5 ppm
NC
; 15
ppm FO
SCR
12 ppm, 20
ppm
wI
DB
NC: 30 ppm
FO
GCP
FL
draft
permit.
Duke Energy -
New Smyma
Beach
2
—
GE 7FA
(165 MW)
NG
CC
8,760
8 ppm or6
ppm
DLN or
SCR
12 ppm
GCP
FL
FL
FL
10-99
11-99
11-99
Polk Power
(TECO)
Oleander Power
Lake Worth
Generation
2
5
11
GE7 FA
(165 MW)
- GE 7FA
(190 MW)
GE 7FA
(170 MW)
NC;
FO
F~R~T
FO
ii~
FO
SC
SC
~
5,130; 750
FO
3,390;
1 000 FO
8,760;
1,000 FO
10.5ppm
NC; 42
ppmFO
9 ppm NC;
42 ppm FO
9 ppm NC;
42 ppm FO
DLN; WI
DLN; WI
DLN; ~
15 ppm NC;
33 ppm FO
12 ppm NC;
20 ppm FO
12 ppm NC:
20 ppm FO
GCP
GcP
GCP
FL
FL
draft
permit
10-99
Hines Energy ~
FPC)
Hardee Power
Partners (TECO)
2
1
SW5O1F
(165
MW)
GE 7EA
(75 MW)
NG;
FO
1I~
FO
8,760,
1,000 FO
8,760; 876
FO
6 ppm NG
full load;
42ppmFO
9 ppm NC;
42 ppm FO
SCR; WI
DLN;WI
25 ppm NC -
full load; 30
pp!nFO
25 ppm NG;
20 ppm FO
GCP
GCP
FL
12-99
Reliant Energy
Osceola
3
GE 7FA
(170 MW)
NC;
FO
SC
~
SC
3,000:
2 000 FO
‘
10.5 ppm
NG42
~
ppmFO
DLNWI
.
‘
10.5 ppm NG;
20 ppm FO
GCP
FL
FL
12-99
Florida Power
Corp., Intercession
City
3
GE 7EA
(87 MW)
NC;
FO
NG;
FO
3,390;
1,000 FO
9 ppm NG;
DLN; WI
42 ppm FO
25 ppm NC;
20 ppm FO
GCP
10-99
Jacksonville
Electric Authority -
Brandy Branch
3
GE 7FA
(170 MW)
4,000: 800
FO
10.5 ppm
NG; 42
ppmFO
DLN; WI
15 ppm NG;
20 ppm FO
GCP
US Environmental Protection Agency
7
National
Combustion Turbine Projects
Last Updated 10/03/2000
Permit
Facility
Fuel Mode
HoLrs
NOX
Limit
~CQUrnlt.
‘cCommentS
FL
draft
permit
Gulf Power - Smith
Station
22
GE 7FA
(170 MW)
NG
—
CC
8 760
‘
9 ppm.
10.1 ppm
wIDB,
13.6
ppm w/ DB
& steam
aug.
DLN
l3ppm,16
ppm w/ DB, 23
ppm
wI
OB &
steam aug.
GCP
Netting out of PSD for NOx and
Co
Florida Power &
Light - Sanford
8
GE 7FA
(170
MW)
NG,
FO
8,760; 500
CC
FO
9 ppm NG;
42 ppm FO
DLN; WI
12 ppm NC;
20 ppm FO
GCP
.
Repowering, 4 units FO
FL
12-99 Corp. - V~o~
(170MW)
SC
io
DLN:WI
GCP
Netting out of PSD for NOx and
FL
2-00
Gainesville
Regional Utilities,
Kelly Generating
Station
1
GE lEA
(83 MW)
NG;
FO
8,760;
1,000 FO
9 ppm NG;
42 ppm FO
DLN~~
‘
20 ppm NO;
20 ppm FO
GCP
Netting out of PSD review for
NOx
FL
100
IPS Avon Park -
Shady Hills
GE 7FA
(170 MW)
1~
FO
3,390;
1.000 FO
9 ppm NG;
42 ppm FO
DLN WI
•
12 ppm NC;
20 ppm FO
GCP
FL
p~t
Palmetto Power
3
NO
SC
3,750
15 ppm
DLN
25 ppm
GCP
FL
appIic.
Un er
review
Granite Power
Partners
3
(180 MW)
NG;
FO
,.,
S~
3,000; 500
FO
10.5/15/15/
25 ppm
NC; 42
ppm FO
LILN
12/16/10/6
ppm NC;
23/20/28/25
ppm FO
GCP
4 vendor options: GE 7FNSW
501 F/SW 501 D5NABB GT-24
FL
FL
draft
ermit
IPS Avon Park
Corp. - DeSoto
Power Proiect
GE 7FA
(170 MW)
NC;
FO
—
Sc
—
3,390;
1.000 FO
9 ppm NC;
42 ppm FO
DLN~WI
•
12 ppm NG;
20 ppm FO
GCP
~______
.
applic.
under
review
.
Florida Power &
Light - Martin
Power Plant
2
GE 7FA
(170 MW)
NG;
FO
SC
3,390; 500
FO
10.5ppm
NC (15
ppm HPM); DLN, WI
42
m FO
l2ppmNG
(15 ppm
HPM); 20 ppm
FO
GCP
HPM = High Power Mode
(power augmentation)
FL
un
review
~:
NG CC
8,760
4ppm
DLN/SC
~25/16/3W50
ppm)
GCP
2
no
GA
12-98
Ten:sk:
Georgia
6
1
SC 30~0
NG,42 DLN;WI
GCP
US Environmental Protection Agency
8.
National
Combustion Turbine Projects
Last Updated 10/03/2000
State
Facility
#of
i~?Turbine
Mode
HoUr~ NOxUmIt
~~r’
~COUmit.~
Córnménts
GA
6-99
w
G
Generating;
Thomaston
4
GE 7FA
(170 MW)
NO;
FO
1
(
4,760;
1,687 FO
2 ppm NO
l5ppm3O
day avg.
for peak
firing ; 42
ppm FO
DLN; ~
15 ppm NO;
20 ppm FO
GCP
GA
10-99
Heard County
NO
SC
4000
15 ppm
DLN
25 ppm
GCP
GA
8-99
Georgia Power,
Jackson County
16
GE lEA
(76 MW)
NG;
FO
SC
12 ppm NG
(lSppm3O
4,000;
day avg.
1,000 FO
for peak
firing) ; 42
ppm FO
DLN~
~
0.101
lb/MMBtu NG;
0.046
lb/MMBtu FO
GCP
E :!
Georgia Power-
8
8
(170MW) NO
CC
8,760
~‘
DLN/SC
Ib/MMBtu
GCP
Kentucky Pioneer
2
~~n
KY
applic.
under
review
Duke Energy-
8
SC
12/9 ppm
NG; 42
ppm FO
DLN;WI 1-hr
25
GCP
.,
~________________________
MS
MS
11-97
12-98
LSPowerUmited
Mississippi Power
Corp., Plant Daniel
3
~
swsolG
GE 7FA
(170 MW)
NO
CC
8.760
8,760
lb/MMBtu
DLN; ~
DLN/SC
R
0.057
lb/MMBtu
Gcp
GCP
MS
MS
MS
4-00
pit
~
urait
permit
Cogentrix nergy,
Caledonia Power
Project
2
2
33
(i7~W)
(i7~iW)
(j7~W)
~
‘.?L
NO
NG
NG
NO
CC
CC
CC
CC
8,760
8,760
8,760
8,760
3.5 ppm
3.5 ppm
(10.8 ppm
3 5ppm
DLNISC
DLN/SC
D~
DLN/SC
20 ppm
20 ppm
9 ppm
GCP
GCP
GCP
GCP
revised application to add 8CR
(182 MW)
(w/D8?)
R
I ic~
Irn,,rr..rtrnc.nI~I ~
~
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Facility
Turbine
Fuel
Mode
Hours NOx Limit
.~
CO
Umit
Comments
MS
.
une
review
DuKe Energy
Southaven
8
GE 7EA
(80 MW)
MG;
FO
2,500; (
500 FO
l2ppmNG
15 ppm ~
hr avg.); 42
ppm FO
DLN Wi
~
20 ppm MG;
25 ppm FO
GCP
MS
review
Warren Power
2
~
2 (17~W)
~
MG
MG
CC
SC
8,760
2,000
3.5 ppm
9 ppm
DLN/SC
DLN
24-hr
25 ppm
GCP
GCP
24-hr
MS
review
Lone ~ne19y
3
MG
CC
8,760
3.5 ppm
SCR
10/25/30/17
GCP
Base/PA/PA+DF/DF
MS
review
Mississippi Energy
NC
CC
8,760
3.5 ppm
SCR
25 ppm
GCP
:
NC
11-99
Carolina Power &
Light, Richmond
Co.
7
——
GE 7FA
(170 MW)
NG•
FO
—
SC
—
2 ~
~
9 ppm NG
at startup,
10.5 ppm
long-term;
42ppmFO
DLN; WI
15
m NG
2O~mFO
GCP
,
NC
applic.
~
Carolina Power &
Light, Richmond
2
GE 7FA
(170 MW)
NC;
FO
CC
8,760;
1,000 FO
9 ppm NG;
42 ppm FO
DLN; WI
15 ppm MG;
20 ppm FO
Modification to previous permit
to switch 2 SC - CC
NC
11-99
(170MW)
SC
SC
SC &
CC
9 ppm NG
lO5pprn
42ppmFO
DLN; WI
GCP
—
NC 6-99
P~~y)
5
~J
25 ppm NC
until 4/01,
until4/02, DLN; WI
after; 42
ppmFO
GCP
appi~c.
NC
under
—
review
Butler-Warner
Generation Plant
2
GE 7FA
(170 MW)
—
MG;
FO
8,760; 500 9 ppm NG;
.
FO
42 ppm FO DLN, WI
9 ppm NC; 41
ppm FO
G
US Environmental Protection Agency
10
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Date
Facility
# of
CTs
# of
DR
Turbine
Model
Fuel Mode
Hours
NOx Limit
Control
Method
Avg
Time
CO Limit
Control
Method
Avg
Time
Comments
SC
Rainey Generating 4
DLN;WI
P iN 20
GCP
sc
12-99
•
aPlic
review
Broad River
Energy (SlçyGen)
Sc Gas & Electric
Urquhart
2
GE 7FA
(171 MW)
GE 7FA
(150 MW)
NG,
FO
NG,
FO
3,000;
500 FO
8,760;
8,760 FO
9 ppm NO;
42 ppm FO
45
m
pp
DLN WI
•
15 ppm NG;
20 ppm FO
12 ppm NG;
20 ppm FO
GCP
~
Netting out of NOx and S02
PSD Review
TN
799
NA, Johnsonville
Fossil Plant
GE 7EA
(85 MW)
NO;
FO
see
comment
DLN; WI
?
25 ppm NG;
20 ppm FO
GCP
10 NO base mode, 10 NG
peaking, 10 FO base
1~N
m
799
aPlic
review
NA, Galiatin
Fossil Plant
NA, Lagoon
Creek Plant
——
GE 7EA
(85 MW)
GE lEA
(110 MW)
NO;
FO
Nc~
FO
NO
CC
see
comment
see
comment
FO
ppm/i 27
TPY NG;
42ppmFO
DLN; WI
?
DLN; WI
?
30j5
day
25 ppm NG;
20 ppm FO
25 ppm NO;
20 ppm FO
GCP
OCR
10 NG base mode, 10 NO
peaking, 10 FO base
~
of NOx is based on a 9 ppm
j~.::~~
2 2
GE P0158
8,760
25 ppm
DLN
25 ppm
GCP
REGION5
IL
IL
Dec-98
Dec-98
McDoneliEnergy
Peoples Gas,
McDonell Energy
10
~
0
250 MW
170 MW
etha
etha
ne
CC
SC
8,760
1,500
4.5 ppm
15 ppm
SCR
DLN
1-hr
1-hr
lb/mmBtu
0.031
lb/mmBtu
GCP
GCP
BACT; c xCat rejected at
BACT; operational
IL
Jan-99
Illinois Power
Tilton
44 MW
NO
SC
2,352
0.1 MMBtu
WI
Synth Minor; operating
IL
1L
Jan-99
Indeck Pleasant
Valley
2
—
150 MW
NG
SC
SC
1,500
15 ppm
DLN
Synth Minor; rejected by county
Feb-99
Dynegy, Rock Rd.
Power
2
—
121 MW
NO
1,300
25 ppm
DLN
Synth Minor; operational
IL
Feb-99 Dynegy, Rock Rd.
Power
1
35 MW
NG
SC
1,300
42 ppm
Synth Minor; operational
IL
IL
Feb-99
Mar-99
Indeck Libertyvilie
Soyland Power
Alsey
2
2
150 MW
30 MW
NO
~‘
FO
SC
SC
2,000
475
15 ppm
DLN
Synth Minor awaiting city
approval
Synth Minor; under construction
IL
Mar-99
Soyland Power
Alsoy
2
22.5 MW
NG:
FO
SC
460
WI
Synth Minor; under construction
US Environmental Protection Agency
11
National Combustion Turbine Projects
Last Updated
10/03/2000
State
IL
Permit
Date
Jun-99
Facllltyi
.
LS Power, Kendall
Energy
1?
CTs
4
4
i~?
D8
Turbine’
Model
220 MW
Fuel
—
NG
..
Mode
SC
“
2
Hours;:
1,048
‘
NOx,Llrnft
~..‘
25 ppm
Control
~‘
Method
DLN
Avg.
Time
1-hr
“‘
‘
CO
~
Llrnlt~
~
Control
Method
Avg.
Time
~,.
$
:~:‘,~: Comments
Synth Minor
IL
Jun-99
LS Power, Kendall
Energy
4
220 MW
NG
—
CC
SC
8,760
4.5 ppm
SCR
1-hr
0.0626w/DB,
0.QSllno DB;
75
load
GCP
BACT; Ox Cat rejected at
$4083/ton
IL
Jun-99
Union Electric,
Gibson City Power
2
135 MW
1,500
25ppm
NG; 42
ppmFO
DLN
Synth Minor; under construction
IL
Jun-99
Union Electric,
Kinmundy Power
2
135 MW
~d
1,500
9 ppm NO;
42 ppm FO
DLN
Synth Minor; under construction
IL
Jul-99
Reliant Energy,
Cardinal
3
3
—
211 MW NG,
RFG
CC
CC
8,760
3.5 ppm
NO; 4.5
ppm RFG
SCR
8 hr/I
hr
0.0472
lb/mmBtu
GCP
BACT & LAER (NOx); Co-
located with refinery, separate
source; Ox Cat rejected at
IL
—
Sep-89
Mid America,
Cordova Energy
Center
2
0
290 MW
—
NG
8.760
4.5 ppm
SCR
1-hr
.0547
Ib/mmBtu:
loads 75.
after 9/2001
0.054
GCP
BACT; Ox Cat rejected at
$1 307/ton
IL
Sep-99
Enron, Des
Plaines Green
Land
8
1
0
83 MW
NO
NO
—
SC
SC
3,250
8/12/15
ppm
DLN
an/mo!
hr
Ib/mmBtu
(45F), .089
lb/mmBtu
(4SF)
GCP
BACT; Ox Cat rejected at
$6800/ton
IL
Oct-99
Dynegy. Rock Rd.
Power
121 MW
1,450
15ppm
DLN
SynthMinor
IL
Dec-99
Reliant Energy,
McHenry County
Plant
3
——
170 MW
NG
SC
2,800 max
(800 avg)
9 ppm
DLN
—
Synth Minor
0.054
IL
Jan-00
Enron, Kendall
New Century
8
0
83 MW
NG
SC
3,300
9/12/15
ppm
DLN
an/mo!
hr
lb/mmBtu
(451~, .089
lb/mmBtu
(.c45F)
GCP
—
BACT; Ox Cat rejected at
$8700/ton
—
2,549
IL
Jan-00
LS Power, Nelson
Project
4
220 MW
FO
SC
CC
total,
2,000
each
25/15
DLN
1-hr
~
Synth Minor; minor until test
under 15 ppm
IL
Jan-00
LS Power, Nelson
Project
—
4
—
4
220 MW
—
NO;
FO
8,760
4.5 ppm
NO; 16
ppm FO
SCR
1-hr
0.0626 w/DB,
0.051mb DB;
75
load
GCP
BACT; Ox Cat rejected at
$3100/ton
BACT for CO and VOC only -
IL
I
Feb-00
Ameren CIPS
i
2
2
600MW
NO
CC
8,760
0.06lb/mmBtu
GCP
3 hr
netting out of NOx, PM and S02
-
--
review; replacing coal boilers;
Ox Cat rejected at $3400/ton
US Environmental Protection Aciencv
12
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Date
Facility
# of
CTs
# of
DB
Turbine
Model
Fuel Mode
Hours
NOx Limit
ControlMethod Avg
Time
CO Limit
Coritçol
Method
Avg
Time
Comments
IL
Holland Energy
2
—
2
680 MW
—
CC
8,760
2 000’ 500
sc
‘ ~
~
4.5 ppm
ppm); 16
(loppm)
SCR (24hr)
0.12 NGw/DB
GCP
1-hr
1-hr
BACT;SCR:ost$8,900/tor~Ox
IL
IL
draft
perm~t
Duke Energy
8
0
83 MW
NG
FO
15 ppm NO
(12 ppm);
42 ppm FO
DLN
1 hr
(ann.):
1 hr
GCP
BACT; SCR rejected at
$27,689/ton; Ox. Cat rejected at
$6,931/ton
applic.
under
review
.
Constellation
2
168MW
SCR
BACT
IL
applic,
under
review
Soyland Power
Alsey
1
25 MW
NO;
FO
SC
.
Synth MInor
IN
Dec-98
PSI- Fayette
ea ing aion
412
4~45or
2©170
MW
NG
SC
peaking
25 ppm
either
DLN or
~
15 ppm
Syn. Minor
IN
IN
Jan-99
PSI-Wabash
Peaking Station
LM 6000
(43 MW)
NO;
FO
NO;
FO
SC
SC
3,000
ppm FO
DLN and
WI
42 ppm NO; 8
ppm FO
lhr
ioa~
Syn. Minor
J
U
I
-
Vermillion
Generating Station
—
8
—
0
GE 7EA
(80 MW)
2 500
‘
12/15 ppm
‘~c~
p
DLN and
WI
a
~
•
25 ppm NG;
20 ppm FO
GEP-25
ppm
(NO); 20
ppm DO
BACT; Usage limit of 20,336
MMCF NG-12 consec. months.
Also 2 Emergency Generators; 1
Emergency Diesel Fire Pump; 4
Diesel Storage Tanks; SCR ~
$19,309/ton (avg.); Ox Cat c~
90 Control, rejected at
$8,977/ton
IN
Jul-99
.
Cinergy
Corporation
GE
LM6000
(43 MW)
NG;
FO
SC
3,000
25ppm
NO; 28
ppm FO
DLN and
WI
42 ppm NO; 6
ppm FO
Synth Minor
IN
Jul-99 AES, Greenfield 4/2
4~45or
2@170
MW
NG
SC
peaking
25 ppm
either
DLN or
WI
15 ppm
Synth Minor
IN
Aug-99
.
Indianapolis
Power and Light
1
GE
71 21 EA
(957 MW)
NO;
F°
SC
peaking
25ppm
NO; 42
ppm FO
WI
Synth Minor
IN
Sep-99 Power and Light
GE (88.4
NO
SC
peaking
DLN
anlhr
Synth Minor
I l~
tnu.rnnnrnntai D,~tap4ie,n A nan,,,,
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Date
Facility
i~?
CTs
#of
DB
Turbine
Model
—
Fuel
Mode
Hours
NOx Umit
Control
Method
Avg
Time
CO Limit
ControL
Method
Avg
Time
Comments
IN
applac.
Ufl
0S
Generating Station
GE
7EA
(80
MW)
MG
SC
15 ppm MG
2,500
(12 Ppm):
DLN
1 hr
(ann.);
BACT
IN
IN
d ft
~
p
appl.
(10-99)
West Fork Land
Development
(ENRON)
Parke County
4
2
SW
501 D5A
(135
MW)
225
MW?
MG
~
FO
Sc
CC
966
8,760
25
3.5, ?? FO
Wi
DLN and
SCR
an/hr
12 ppm
unknown
Synth Minor
BACT
under
2
(1~4W) NC
CC
8,760
Dt~N~nd
ppric
LAER
IN
.
applic.
under
review
LSP
4
.
200 MW?
NG•
‘
FO
~ITHE
‘
R
8,760
3.5 ppm;
4.5
wIDB,
16 FO
DLN/Wl
and
5CR
33.1 ppm -
234.3(50
d’~~
oa ~ -T~~J
ppm- 168
ppm (50
load) FO
BACT
Ml
Feb-99 Wyandotte Energy 2
500 MW
MG
CC
8,760
45I~~~33SCR
3-5 ppm
Cat Ox
LAER; SCR cost $5600/ton
MN Nov-98
LSP-Cottage
Grove
(245 M~
FO
Sc
1,700 FO
NG;16
ppm FO
8CR
1-hr
1200 Iblhr,
1200 lb/hr FO
Cat Ox 1-hr
BACT
MN
draft
permit
Lakefield Junction
—
6
—
GE model
PG7I21EA
(92 MW)
N•
G,
F°
7,300
9 base, 25
peak, 42
FO
DLN, Wi 3-hr
25 m NG~
20~’ FO
ppm
GCP
3-hr
—
PSD; SCR rejected ~
$11,500/ton: Ox Cat rejected at
$3000/ton
MN
draft
permit
Pleasant Valley
3
SW
V.84.3A &
501 05A
(155 MW &
134MW)
•
~‘
8,760
35 ppm
NG; 42
ppm FO
DLN, WI
35
NG~
35~~FO
~
PSO
—
OH
Jul-99
Duke Energy
Madison LLC
8
GE 7EA
(60
MW)
NO;
FO
2,500 HG;
500 FO
ppm) NC;
DLN
42 ppm FO
1 hr
(ann.)
25/25; 20120
FO
hr/an
$19000/tonOx Cat rejected at
$9000/ton
US Environmental Protection Agency
14
National Combustion Turbine Projects
Last Updated 10/03/2000
State F~
Facility
Fuel
Mcde
Control ~V9..
12 ppm NG;
WI
Jan-99 RockGen Energy
3
GE 7FA
‘175 M~A~
‘
NG~
FO
SC
3,800
Total, 800
FO
12115 ppm
NG; 42
ppm FO
OLN
24
hr/inst;
1 hr
15 ppm FO
(load75)
&
24 ppm FO
DLN
GEP
1-hr
BACT; SCR not chosen; cost
$23,018/ton; Ox Cat rejected at
$15 K/ton
—
(load75)
WI
Feb-99
Manitowoc Public
Utility
1
GE Frame
M~
NG;
FO
Sc
2,328
Total
ppm FO
WI
1-hr 50 ppm NG &
FO
1-hr
BACT
WI
Feb-99 Southern Energy
2
‘
~‘
SC
8,760
Total, 699
FO
12/15 ppm
NG; 42
ppm FO
DLN
24
hr/inst;
1 hr
12 ppm NG;
15 ppm FO
(Ioad75)
&
24 ppm FO
24-hr
/1-hr
FO
.
BACT; Ox Cat rejected at $14
K/to~~
(Ioad75)
25 ppm NG
(100 load)/
WI
Jul-98
Wisconsin Public
1
(~2~~)
SC
4 000
Total,
2,000 FO
9piNGI
DLN
hr nat
gas,
FO
45 ppm (75
load)! 100
ppm (60
load); 20 ppm
FO
GEP
1-hr
BACT SCR rejected at
$13,866/ton; Ox Cat rejected at
$6053/ton Incremental Cost
WI
draft
ermit
p
Wisconsin Electric 1
GE 7EA
‘85 M~’~
‘
N0
FO
SC
178,000
MWhrs
2 000 h
‘100 hr
~
wer
aug.
9 ppm NO
(20 ppm
w/power
aug~);42
ppm FO
DLN
24-hr,
1-hr
FO
25 ppm NG
(100 load)!
45 ppm (75
toad)! 100
ppm (60
load); 20 ppm
FO
GEP
1-hr
BACT; SCR rejected at
$10,257/ton; Ox Cat rejected at
$5884/ton incremental cost
~~io N6
—
AK
AK
final
permit
Jonesboro City
Water & Lights
2 - 23 MW.
1 -44 MW
~________
draft
permit
Cross Oil Refinery
- Mod
15 MW
CC
AK
draft
.
permit
Gen Power
610MW
total
CC
AK
AK
AK
final
.
permit
.
Pine Bluff Energy
250 MW
draft
permit
Pine Bluff Energy -
Mod
250 MW
—
CC
CC
draft
permit
Union Generating
Station
10
260 MW
AK
final
.
permit
KN Power
7
510 MW
total
AK
Paragould Electric 4
4 MW total
SC
US Environmental Protection Agency
15
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Date
Facility
1~?
Cis
#of
DB
Turbine
Model
Fuel Mode
Hours
NOx Limit
Control
Method
Avg
Time
CO Umit
Co~tcol
Method
Time
Comments
AK
Arkansas Electric
Coop
1
3 MW
SC
—
LA
applic.
under
review
Cogentrix - Eunis
800 MW
total
cc
LA aPkc.
.
review
Cogentrix -
Bogolosa
800 MW
total
LA apj~
review
Cogentrix -
Sterhngton
800 MW
total
CC
LA
appiic.
under
review
Cogentrix - Acadia
.~00MW
total
sc
LA
Calcasieu Power
370 MW
total
cc
LA
Entergy - Monroe
CC
LA
draft
permit
Baton Rouge
Energy
225 MW
total
?
—
NM
final
permit
El Paso
Electric/Rio
Grande Power
Plant,
261 MW
total
NM
final
permit
Lordsburg
Limited/i 00 MW
Repowering,
100MW
total
—
NM
NM
shutdo
wn
Lea County/North
Lovington,
—
49.5 MW
total
final
.
permit
Plains
.
Eiectnc/Escalante
Plant
200-300
MWtotal
NM
final
.
permit
PNMISan Juan,
1798 MW
total
NM
NM
final
permit
final
Southwestern
Public
Service/Cunningh
am,
Southwestern
.
Public Service/
Maddox
511 MW
total
292 MW
permit
total
US Environmental Protection Agency
16
National Combustion Turbine Projects
Last Updated 10/03/2000
State
NM
•
Pert
Facility
Wf
T~
HOUrS,
NOxUmit
~1
1
Comments
no TV
.
permit
require
d
Southwestern
Public
.
Service/Carlsbad
16 MW
total
NM
final
permit
Williams Field
Seivices/Milagro
Cogen,
62 MW
total
NM
uralL
permit
Raton Public
Service/Raton
Plant
11.25 MW
total
.
.
OK Mar-99
AECI-Chouteau
2
530M’~
total
—
:
OK Oct-99 Cogeatrlx -Jenks
3
800 MW
total
c~
OK
Oct-99
C&SW
2
320 MW
total
OK Jan-00 Panda - Coweta
4
1000 MW
total
cc
OK Feb-00
OG&E-Hrshoe
2
90 MW
total
Sc
OK Jan-00 Duke-Newcastle
2
520 MW
total
cc
OK
OK
Ma1-00
applic.
under
.
review
ONEOK -Edmond
Energetix -
.
Arcadia
4
3
360 total
825 MW
total
SC
CC
OK
applic.
under
.
review
Energetix -
Thunderbird
3
825 MW
total
CC
OK
pp
under
.
review
Kiowa Power
4
1200 MW
total
CC
OK
under
.
review
SmithCoGen
2
total
CC
TX
Jan-99
Lubbock Power &
Light
2
LM6000
(42 MW)
15ppm
SCR
25ppm
—
TX
Oct-98
Midlothian Energy
Ltd. (Venus) (1080
MW total)
4
AB8 GT24
1175 M~A~
‘
9/5 ppm
SCR
25 ppm
US Environmental Protection Agency
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Date
Facility
I~
CTe
~?
DB
Turbine
Model
Fuel Mode
Hours
NOx Limit
Control
Method
Avg
Time
CO Limit
CQntroJ
Method
Avg
Time
Comments
TX
Oct-98
City Public Service
(500 MW total)
2
GE 7FA
(170
MW)
9 ppm
SCR
25 ppm
TX Dec-98
Calpine Magic
Valley (700 MW
total)
2
SW5OIG
‘230 M~A~
‘
12/9 ppm
SCR
25 ppm
TX Oct-98
Lamar Power
Part.
(Panda Pans)
(1000
MW
total)
4
(~~ZA
“~
9 ppm
DLN
18 ppm
TX Oct-99
Union Carbide
1
F6B(39
9 ppm
DLN
25 ppm
TX
applic.
Ufld&
Air Products, Inc.
(240 MW total)
1
SW5OI F
(168MW)
9~~5ppm
SCR
20 ppm
(Reactivated 11/15/99), NOl 3
~
& NOx)
TX Dec-98
Duke Energy
Hidalgo, LP (520
MW
total)
2
GE 7FA
‘170 MtA~
‘
9 ppm
DLN
20 ppm
TX
Feb-99
Panda Guadalupe
Power (1000 MW
total)
4
GE 7FA
‘170
MAF~
‘
9 ppm
DLN
15 ppm
TX
Apr-99
Fina/BASF
(amend -
Substitute) (78
2
F6B (39
MtAA
‘
9 ppm
DLN/SC
R
25 ppm
Cogen for Boiler, N007 (VOC
onlu Nox 162
“
TX
TX
Nov-99
May-99 T~~7~Y
2
3
—
(168MW)
~
9 ppm
9 ppm
DLN
DLN
7 ppm
25 ppm
TX Jun-99
k-lays Energy
Project (1080 MW
total)
4
—
ABB GT24
(175MW)
5 ppm
DLN/SC
R
5(25) ppm
—
TX
TX
Dec-99
Ennis-Tractabel
Power Co.. Inc.
(350 MW total)
1
—
G
(250 M~
‘
9 ppm
SCR
20 ppm
Jun-99
Sabine Riv~r
Works Cogen LP
(440 MW total)
2
GE 7FA
‘170 M~A
‘
GE 7FA
6 ppm
SCR
15 ppm
TX
KHE
2/2
‘I
(82MW)
8/9 ppm
DLN
9/25 ppm
TX Dec-99
3
(170MW)
9 ppm
DLN
9 ppm
TX
Mar-00
Mobil (40MW
SW5O1F
9/9 ppm DLN/SC
10/25 ppm_-
US Environmental Protection Agency
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Data
Facility
i~
CTs
ii~
OS
Turbine
Model
Fuel Mode
Hours
NOx Limit
Control
Method
Avg
Time
CO Limit
Contr9l
Method Time
Comments
TX Nov-99
Cogen Lyondeil
~urbi
#7)
SW5O1F
(160 MW)
25 ppm
DLN
25 ppm
TX Feb-00
City of Garland
1
~‘M6
9 ppm
DLN
25 ppm
TX Dec-99
Rio Nogales
Power Project LP
(780 MW total)
GE 7FA
‘170
M~AA
‘
9 ppm
DLN
7.4 ppm
TX Nov-99
Odessa-Ector
Power Partners LP
(1000 MW total)
4
—
GE 7FA
‘170 M
‘
W)
9 ppm
DLN
9 ppm
—
TX Jan-00
Archer Power
Partners LP (1000
MW total)
4
GE 7FA
‘170 M~”~
‘
9 ppm
DLN
9 ppm
TX
TX
Feb-00
AES Aurora (1000
GE 7FA
cvII
(183MW)
9 ppm
DLN
25 ppm
KHE
Freestone Power
Project LPm (1070
MW total)
4
GE 7FA
‘175 M~
‘ —
—
9 ppm
DLN
20 ppm
TX
TX
TX
Sep-99
GenTex Power
Corp. & Calpine
(500 MW total)
2
SW5O1F
‘180 M~A
‘
5 ppm
SCR
10/25 ppm
Jan-00
Duke Ennorgy
Kaufman (440 MW
total)
2
—
GE 7FA
(170 MW)
—
9 ppm
DLN
20 ppm
Feb-00
Corpus Christi
Cogeneration LP
(708 MW total)
—
3
GE 7FA
~ M~
‘
8 ppm
DLN
15 ppm
TX Feb-00
2
(170MW)
9 ppm
DLN
20 ppm
TX
TX
Nov-99
Midlothian Energy
(add #5 & #6) (550
MW total)
2
ABB GT24
(
175 MVV)
5 ppm
SCR
25 ppm
Mar-00
Gateway Power
Project, LP (800
MWtotal)
GE 7FA
‘170
MtAA
‘
—
9 ppm
DLN
7.4 ppm
TX Dec-99
Reliant Energy -
Channelview (820
MW total)
4
SW5O1F
‘183
MtA!~
‘
3 ppm
DLN/SC
R
23 ppm
N017 (NOx and VOC)
TX
applic.
under
review
Chambers Energy
Facility (2200 MW
total)
8
ABB GT24
(180MW)
3.5 ppm
DLN/SC
R
20 ppm
CatOx
N019 (NOx and VOC)
US Environmental Protection Agency
19
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Date
FaciIIt~j
i~
CTs DB
Turbine
Model
Fuel Mode
Hours
NOx Limit
Control
Method
Avg
Ti
CO Limit
Confr~iMethod
Time
Comments
TX
Mar-00
Coastal Power
Company (550
MW total)
2
GE 7FA
‘170
M~A~
9 ppm
DLN
20 ppm
TX Mar-00
Cobisa-Forney, LP
(1774 MW total)
GE 7FA
(170 MW)
9 ppm
DLN
15 ppm
TX
TX
Feb-00
applic.
~
Caipine Corp. (750
LG&E Power Inc.
(1600 MW total)
6
—
(180MW)
GE 7FA
(170 MW)
3.5 ppm
9 ppm
DLNISC
SCR
15 ppm
15 ppm
N020 (NOx and VOC)
TX
Mar-00
Duke Energy Jack.
LP (520 MW total)
2
GE 7FA
(170 MW)
9 ppm
DLN
20 ppm
TX Mar-00
Caipine(740 MW
—
3.5 ppm
5CR
25 ppm
—
N021 (NOxand VOC)
TX
applic.
under
review
Wise Counts,
Power Co., LLC
(800 MW total)
2
SW5OIG
‘350
MtAA
‘
5 ppm
SCR
9 ppm
CatOx
TX
applic.
under
review
West Texas
Energy LP (1500
MW total)
6
ABB-GT24
/180
MtAA
‘
.
5 ppm
SCR
5 ppm
N024 VOC (1 28f for NOx)
TX
TX
applic.
under
review
under
review
Texas Industrial
Power (193 MW
total)
~
1
2
GE 7FA
(1~MW)
~
3.5 ppm
5 ppm
SCR
SCR
30 ppm
26 ppm
N023 (NOx and VOC)
,
TX
.
apphc.
under
review
Cottonwood
Energy Co., LP
(600 MW total)
4
GE7FA
1170 M~An,
‘SW5O;
(180 MW)
5 ppm
SCR
REGION7
;~
.
;
,
KS
5-88
Empire District
2
227.5
mm8tulhr
NG
42ppm
WI
KS
draft
permit
Western
Resources
3
—
2- 100
MW, 1 -
180 MW
NG;
~
Sc
15 ppm
NG; 42
ppmFO
DLN; WI
~‘
NOx limits are for 70 load.
NSPS limits will apply at 70
Load
MO
1-96
Kansas City
Power & Light -
Jackson
1
(200 MW) NO
SC
MO
~~it
AECI - Nodaway
2
(100 MW) NG
Sc
25 ppm
DLN
90 ppm
GCP
US Environmental Protection Agency
20
National Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Oat
Facility
# of
CTs
# of
OB
Turbine
Model
Fuel Mode
Ho~rs
NOx Limit
Control
~
Avg
Time
CO Limit
Control
Method
Avg
Time
Comments
p’~~e~itAECI
- St. Francis
1
(250
MW)
CC
4~m
SCR
3-hr
10 ppm NG
GCP
MO
dr
Empire District -
Empire District -
1
~
1
I
NO
NO
CC
CC
4 ppm
4 ppm
SCR
SCR
30 day
30 day
10 ppm
10 ppm
GCP
GCP
recommissioned to CC
MO
under
1
1
(200 MW) NO
CC
5 ppm
5CR
25 ppm
GCP
Retrofit w/ duct burner~waste
MO
applic.
under
review
.
K
City Powe
2
(75 MW)
NG
SC
9 ppm
DLN
25ppm
GOP
MO
Ic
~~er
review
Duke Energy-
Audrain
8
GE lEA
(80 MW)
NO;
FO
SC 2,500; 500
FO
l2ppmNG
(15 ppm 1-
hr avg.); 42
ppm FO
DLN~WI
‘
20 ppm No;
25 ppm FO
GCP
MO
applic,
under
review
DuenergYk E
-
8
•
E
~
NO
SC
2,500
~
12 ppm (15
ppm 1-hr
avg.)
DLN
~
20 ppm
GOP
NE
799
Omaha Public
(25 MW)
SC
Sc
NG;42
ppmFO
WI
NE
6-99
.
Lincoln Electric
System
1
(90 MW)
NG;
FO
25ppm
No; 42
ppm FO
DLN; WI
REGION 8
o
.
0
.0.
o
CO
final
4/99
Colorado Energy
Management
(mod. to CO
Power
PartnerslBrush
Cogen) (+ 50
2
1969
Westingho
use 251AA
NG
—
SC
4,000
(both CT8)
30 ppm for
first 24
months,
then 25
ppm
custom
low-NOx
burners
1-hr
60 ppm
GCP
1-hr
—
permit action also required NOx
emission reductions on 2 other
identical units from permitted 42
ppm immediately to 30 ppm and
further to 25 ppm in 24 months.
CO
Colorado Springs
Utilities/Nixon (66
2
P06541(B)
NO
(bthCTs)
15 ppm
DLN
1-hr
did not trigger BACT for CO
CO
Fultori
Cogeneration/Man
chief (284 MW)
2
V843Al
.
NG
SC
8,760
15 ppm
DLN
1-hr
10 ppm
OCP
1-hr
US Environmental Protection Agency
21
National
Combustion Turbine Projects
Last Updated 10/03/2000
State
Permit
Date
‘
Facility;
.
1~?
~
1~?~Turbine
Model
Fuel
.
Mode
~
Hours.:
-~
NOx Limit
~
Control
Method
Av~.
Tin~i
~‘~j~j~
qontrot.
Method
;
Tim i’
Comments
.‘.::.
-
CO
—
appkc.
11199
KN Energy/Front
Range Energy
Associates - Ft.
Lupton (160
MW)
4
GE
LM6000
NG
SC
25 ppm
(proposed)
WI
24-hr
project originally PSD
application; State drafted syn
minor permit w/ operating hours
restrictions
in
7/99; EPA
commented to State concerning
single source issue
wI
adjacent
PSCo facility; PSCo appealed to
US 10th circuit court - currently
—
applic.
3/00
Platte River Power
Authority/Rawhide
(82
MW)
1
GE Frame
7EA
NG
NG
—
SC
8,760
9 ppm
DLN
—
plan startup 5/2002; CO PTE
below significance level so didn’t
do BACT; characterized as
peaking plant, but not restricted
in operating hours
CO
draft
permit
5/00
Public Service Co.
of Colo./Ft. St.
Vram Unit 4 (242
MW)
1
—
1
—
GE
PG7241
(FA)
SC/C
SC/C
CC
8,760
4 ppm
(CC); 9
ppm (SC)
DLN+SC
•
R (CC),
DLN
(SC)
8 ppm (CC &
SC), 20 ppm
(CC wI OH)
CCP
1-hr
plan startup 6/2001;
CO
.
applic.
11/99
Front Range
Power Project/Ray
Nixon Sta.,
Fountain, CO (480
MW)
2
—
2
GE Frame
7
NO
—
8,760
9 ppm/16
ppm wI DB
DLN
25 ppm
(proposed)
GCP
—
1-hr
1-hr
plan to begin construction 1/01,
existingoperationCob
7/02;SpringsPSDUtils/Nixonmod to
coal-fired power plant; revising
application to net out of PSO for
NOx using reductions at coal-
fired unit; applicant calculated
PTE_using_95_ca
applic.
4/00
North Amer.
Power
Group/Kiowa
Creek (900-
4
GE7FA or
equivalent
NG
8,760
4 ppm
(proposed)
SCR
23,2 ppm
(proposed)
GCP
plan to begin construction spring
2001, operation spring 2004;
proposed project may trigger
112(g)
SD
applic.
11/99
Black Hills Power
& Light/Lange CT
Facility (80 MW)
2
GE
LM6000PD
NG
SC
8,760
25ppm
(proposed)
DLN
24-hr
25 ppm
(proposed)
GCP
Characterized as peaking plant,
but not restricted in operating
hours
w~
final
Black
Mills Power
& Light/Niel
—
2
—
GE
—
NG
—
SC
8,780
25 ppm
.
DLN
24-hr
25 ppm
GCP
1-hr
Region provided written
comment disagreeing W/ NOx
8ACT determination;
3/00
Simpson 11(80
MW)
LM6000PD
,
charactenzed as peaking plant,
bur not restricted in operating
hours
US Environmental Protection Agency
22
National
Combustion Turbine Projects
Last Updated
10/03/2000
Mode
Permit
Date
Facility
1~I
CTs DB
Turbine
Model
Fuel
Hours
NOx UmIt
Control
Method
Avg
Time
CO Umit
Control
Method
Avg
Time
Comments
final
Two Elk
•
Partner:
(33 MW
turbine)
•
1
LM5000
NG
SC
8,760
25 ppm
DLN
1-hr
25 ppm
GCP
1-hr
Facility
is
250 MW coal-fired
.
steam
electric plus 33 MW NG
CT; characterized as peaking
plant, but not restricted in
operating_hours
REGION9
.
CC
~.
..
•,
.
~.
•
..
(EPA)
Calpine - South
Point Generating
5~t~iW
3 ppm
SCR
3-hr
Griffith Energy,
LLC
650 MW
total
—
CC
3 ppm
SCR
0.5 ppm
Reliant Energy -
Desert Basin
Generating Project
580 MW
total
cc
3 ppm
SCR
24-hr
24 ppm
3-hr
AES Antelope
Valley
1000 MW
total
CC
CC
—
Blythe Energy
520 MW
total
2.5 ppm
5CR
1 hr
10 ppm 80;
20 ppm © 70-
80
3-hr
CA
3-hr
Delta Energy
Center -Calpine
and Bechtel
—
—
880
total
MW
2.5 ppm
SCR
1-hr
10ppm
Pollutant Trading - 1:1 VOC for
NOx (nonattainment), 4:1 S02
for PMIO (attainment)
CA
Sempra/OXY - Elk
Hills
680-720
MW total
—
CA
OXY & Sempra
Energy; Elk Hdls
Power LLC (Joint
venture)
—
—
500 MW
total
CC
CC
CC
2.5 ppm
SCR;
3-hr
4
ppm
CatOx 24-hr
24-hr
Pollutant Trading - NOx for
PMIO; PSD Permit must be
issued by EPA
CA
draft
permit
High Desert Power
Project LLC
700 MW
total
2.5 ppm
SCR
1-hr
4
ppm
CatOx
CA
.
USGen~ting-
4
—
ABS ~262
—
2.5 ppm
SCRor
SCONO 1-hr
CA
Long Beach
District Energy
Facility (ENRON)
500 MW
total
—
CA
Calpine and
Bechtel - Metcalf
Energy
2
600 MW
total
CA
Midway Sunset
Cogeneration Co.
500 MW
total
US Environmental Protection Anencv
National Combustion Turbine Projects
Last Updated
10/03/2000
State
Permit
racmty,
Fue!
Mode
Hours
NOX Limit
‘
CO
Umtt~
Comments.~
CA
5-99
-
~
2
—
~________
530 MW
—
CC
cc
2.5 ppm
SCR
1-hr
6 ppm
3-hr
AFC submitted to CEC on
5r1199;
Monterey Bay unified
APCD to issue ATC early 2000;
2 x 15 MW upgrade
SteamTurbine rotor when SCR
CA
Duke Energy -
Mono Bay
530 MW
total
CA
—
Calpine and
Bechtel - Newark
Energy Center
600 MW
total
—
CA
PG&E Generating
Otay Mesa
510 MW
total
2 ppm
SCONO
x/SCR
backup
PollutantTrading -
VOC
reduc.
for NOx inc.; District plans to
issue PDOC in March 2000
CA
Pastoria Power
Project
750 MW
total
CC
2.5 ppm
XONONI
SCR
Backup
1-hr
6 ppm
CatOx
Pollutant Trading - NOx in lieu of
PMIO
CA
6-99
Pittsburg District
Energy Facility
(ENRON)
500 MW
oa~
CC
2.5 ppm
SCR
1-hr
6 ppm
CatOx
3-hr
CA
.
AES South City
550 MW
total
SC/C
C
CA
CA
Sunlaw Cogen
Partners
Texaco Global -
Sunrise
Cogeneration
—
800 MW
total
320 MW
total
CC
cc
1 -2ppm
2.5 ppm
~ONO
~
SCR
1-hr
1 -2 ppm
9 ppm
CA
11-99
Calpin:-Sutter
CC
2.5 ppm
SCR
1-hr
4 ppm
EPA
~
to
CA
Campbell Cogen
CA
applic.
under
review
Ogden Pacific
Power~Three
Mountain Power
500 MW
total
CC
2.5 ppm
SCR
1-hr
10 ppm
CatOx
3-hr
Application: 1/99; District to
issue P50 permit
Abbreviations:
CT = Combustion Turbin DB = Duct Burner
GE = General Electric
NG = Nat. Gas
SW = Seimens Westingh FO = Fuel Oil
SC = Simple Cycle
CC = Combined Cycle
DLN = Dry-Low NOx
WI Water Injection
SCR Selective Catalytic Reduction
CatOx = Catalytic Oxidation
GCP = Good Combus. Prac.
US Environmental Protection Aciencv
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