This filing submitted on recycled paper.
BEFORE THE POLLUTION CONTROL BOARD
OF THE STATE OF ILLINOIS
IN THE MATTER OF:
)
)
NATURAL GAS-FIRED, PEAK-LOAD
)
PCB No. R01-10
ELECTRICAL POWER GENERATING
)
FACILITIES (PEAKER PLANTS)
)
NOTICE
Dorothy M. Gunn, Clerk
Amy L. Jackson, Hearing Officer
Illinois Pollution Control Board
Illinois Pollution Control Board
James R. Thompson Center
600 South Second Street
100 West Randolph Street
Suite 402
Suite 11-500
Springfield, IL 62704
Chicago, IL 60601
PLEASE TAKE NOTICE that I have today filed with the office of the Clerk of the Pollution
Control Board ADDITIONAL COMMENTS, copies of which are herewith served upon you.
Respectfully submitted,
ILLINOIS ENVIRONMENTAL PROTECTION AGENCY
____________________________
Scott O. Phillips
Deputy Counsel
Division of Legal Counsel
1021 North Grand Avenue, East
P.O. Box 19276
Springfield, Illinois 62794-9276
217/782-5544
217/782-9143 (TDD)
Dated: November 6, 2000
This filing submitted on recycled paper.
BEFORE THE POLLUTION CONTROL BOARD
OF THE STATE OF ILLINOIS
IN THE MATTER OF:
)
)
NATURAL GAS-FIRED, PEAK-LOAD
)
PCB No. R01-10
ELECTRICAL POWER GENERATING
)
FACILITIES (PEAKER PLANTS)
)
ADDITIONAL COMMENTS
NOW COMES the Illinois Environmental Protection Agency (“Agency” or “Illinois
EPA”), by one of its attorneys, Scott O. Phillips, Deputy Counsel, and hereby files additional
comments as follows:
1.
In the Hearing Officer’s order dated September 25, 2000, the Hearing Officer asked
the Illinois EPA a series of questions. The Illinois EPA responded to those questions
in its AGENCY RESPONSE TO QUESTIONS FROM HEARING OFFICER
ORDER DATED SEPTEMBER 25, 2000, filed on October 4, 2000. Also, the Illinois
EPA responded to these questions at the Pollution Control Board’s (“Board’s”) public
hearing on October 6, 2000. In its written response and at hearing, the Illinois EPA
deferred responding to Questions 18, 19, and 20 contained in the Hearing Officer’s
order so that the Illinois EPA could provide the Board with the most current
information possible on the permit-related statistics requested by the Board.
Comment: Attached Exhibit 1 is a summary listing of natural gas-fired turbine
electrical power plant projects since 1998, updated as of November 2, 2000. This
summary is in chronological order based upon the date that an application for the
plant was first received (or the date of expiration or withdrawal).
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2
Also attached is Exhibit 2 which contains a printout of a spreadsheet listing in more
detail these permit-related statistics requested by the Board. Attached Exhibit 3 is an
electronic copy of this spreadsheet in Microsoft Excel format. Attached Exhibit 4
contains an explanation of certain columns within this spreadsheet. Note that in
spreadsheet cells where no information is provided, such as emissions limitation
information, this typically means that the information is not yet available because the
construction permit application is still pending.
2.
At the Board’s public hearing held on October 6, 2000, Board Member Kezelis
inquired as to the use of actual, pound-per-hour emissions data used modeling.
Comment: For modeling purposes, the Illinois EPA requires that applicants for new
peakers use the maximum permitted hourly emission rate to address the NAAQS for
each criteria pollutant having an NAAQS expressed as a “short-term” average. For
PM-10 (24-hour NAAQS), SO
2
(24-hour and 3-hour NAAQS), and CO (1-hour and
8-hour NAAQS) the maximum hourly emission rate is assumed for an operating rate
of 24 hours per day. The Illinois EPA also requires applicants to perform evaluations
of impacts during reduced-load operation and startup in order to assure that the
emissions for these configurations will not threaten air quality. For NO
2
(annual
NAAQS), the emissions (or operating rates) permitted on an annual basis are assumed
in the modeling.
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3
“Actual” emissions are not used since the source is modeled prior to construction and
therefore actual emission data is not available. However, after the source is built, in
order for the source to remain in compliance with its permit conditions, the actual
emissions cannot exceed the permitted emissions that were used for modeling the
source.
3.
At the Board’s public hearing held on October 6, 2000, the Board inquired as to how
localized impacts are assessed, and what methodologies are employed to make the
modeling conservative.
Comment: There are several aspects of the modeling process that ensure the
conservatism of the results. First, as mentioned previously, the modeling incorporates
emission rates that reflect maximum operating rates at maximum permitted hourly
emissions on a continuous basis (i.e., 24 hours per days). This assumption is applied
not only for the proposed source but for all background sources included in the
modeling as well. Second, the maximum modeled impacts are added to a
conservatively estimated background concentration determined from nearby
monitoring stations (typically the highest monitored values for the worst of three
years of data are used to estimate background concentrations). Third, concentrations
are calculated by the model using five years of hourly meteorological observations to
determine worst-case conditions. In other words, the worst-case meteorological
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4
conditions are assumed to occur at the same time as the highest background
concentrations are observed and at the same time that the new source and all other
sources are operating at maximum load conditions. Finally, concentrations are
evaluated at all locations off plant property, including but not limited to the locations
of nearby schools and residences. Typically the highest concentrations reported in
modeling studies are predicted to occur at or immediately downwind of plant fence
lines, in areas with little or no population exposure.
4.
At the Board’s public hearing held on October 6, 2000, the Board requested an
explanation of the term “small, if not insignificant” used by the Illinois EPA in
describing air quality impacts.
Comment: The Illinois EPA typically uses U.S. EPA’s definition of “significant air
quality impact” (from PSD guidance) in describing air quality impacts. The
established significant impact thresholds are expressed as micrograms per cubic meter
(ug/m
3
) and are usually in the range of 1% to 5% of an applicable NAAQS (
see
Illinois EPA Group Exhibit 2, Exhibit 10, Table 2). For example, the significant
impact threshold for NOx is 1 ug/m
3
while the NAAQS is 100 ug/m
3
for an annual
average. The significance thresholds are used as a trigger in the PSD air quality
analysis process to require more detailed analyses and are not intended as “not to be
exceeded” limitations. As presented by the Illinois EPA, the modeling analyses have
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5
shown that most peakers will not cause significant air quality impacts (i.e., their
maximum impacts will not exceed the PSD significant impact thresholds). In a few
cases, impacts have been shown to be “significant” but were still only a small
percentage of the applicable NAAQS, thus the reference to “small” impacts in the
Illinois EPA’s testimony.
5.
At the Board’s public hearing held on October 6, 2000, the Board requested data from
the continuous emissions monitoring system (CEMS) at the Elwood facility located in
Will County.
Comment: Exhibit 5 contains the CEMS data from the Elwood facility. Note that:
a. The data provided in Exhibit 5 is from the second quarter of 2000. Validated
third quarter data is not yet available.
b. Each bundle of information contains the same types of data, one bundle for
the CEMS for each of the four units located at Elwood (each unit has a
separate CEMS). The CEMS at Elwood measure only NOx emissions. The
monitors are operated in accordance with the Acid Rain regulations.
c. The data included on the bar charts each type of data recorded by the CEMS
for each day the unit operated. As the units did not operate every day during
the quarter, only those days on which they did operate show recorded data.
These charts provide the megawattage (“Gross Load”), the NOx rate in
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6
pounds/mmBtu, the total pounds of NOx emitted (“NOx Mass”), and the
unadjusted NOx concentrations in parts per million.
d. A table is also provided that includes numerical data for each unit’s daily
operation. This table provides the total number of hours per day that the unit
operated, the total heat input per day, the average NOx rate per day, the total
number of tons of NOx emitted per day, and the number of tons of carbon
dioxide emitted (a calculated number based upon oxygen content of the
exhaust),
1
and the total gross load in megawatts.
e. The second group of tables provides hourly data for the operating hours, the
total heat input for that hour, the NOx rate for that hour, the number of pounds
of NOx emitted during that hour, the tons of CO
2
emitted during that hour (a
calculation) and the gross load during that hour. The first day of operating in
April for Unit 4 was on the 4
th
. The facility operated for half an hour or less
during the hour between 7:00 and 8:00 a.m. The heat input during this time
was a little over 544 mmBtu. Its NOx rate during that half hour was 0.112
ppm. It emitted about 60 pounds of NOx. It produced 40 megawatts of
electricity. The F Factor shown is a constant value specific to natural gas (the
fuel used at Elwood) that is used in the calculation of emission rates. During
the rest of the time on April 4 until the hour between 10:00 and 11:00 p.m.,
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7
the heat input steadied at around 1,750 lb/mmBtu/hr until shutdown.
Likewise, the NOx rate, the number of pounds of NOx emitted, and the gross
load all steadied until shutdown. Note that start-up and shutdown each took
less than an hour. For purposes of comparison, the NOx emission limits
applying to the turbines during normal operation are 0.061 pound/mmBtu and
108 pounds per hour, and the units are rated at 170 MW output a maximum
firing rate of 1763 mmBtu/hr (Low Heating Value) at 49° F.
f. The final piece of information here is a print-out of U.S. EPA’s “Emissions
Tracking System,” cumulative data through the second quarter of 2000. As
you can see, the Elwood Energy facility is the 8
th
facility listed on this page.
This data identifies the total operating hours for the year to the end of the 2
nd
quarter per unit, the cumulative annual heat input, the cumulative annual
emissions (the values provided are the default values for natural gas), the
average annual NOx emission rate in lb/mmBtu, the cumulative mass
emissions of CO
2
, and the percentage of time that the monitors were operating
(the Elwood monitors operated well within the expectations for CEMS under
40 CFR Part 75).
1
Emissions of carbon dioxide (CO
2
) are also identified on this exhibit. Electrical power plants in general are major
contributors to greenhouse gas emissions of CO
2
, and data on emissions of CO
2
is collected by the U.S. EPA’s Acid
Rain Program as related to global warming.
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8
6.
During this proceeding, witnesses expressed concerns regarding the amount of
emissions that may occur from natural gas-fired peaking power plants during start-up.
Comment: General information and background on emissions from a turbine during
startup is contained in U.S. EPA’s Alternative Control Technology document (
see
Illinois EPA Group Exhibit 2, Exhibit 4). In Section 5.2 of this document, U.S. EPA
provides a description of how low-NOx combustors, with which new peaking
turbines are equipped, operate and how emissions of pollutants vary during startup.
This information generally describes the two different phenomena that are occurring
during the startup of the turbine. One phenomenon occurs for pollutants that are
incomplete combustion products, i.e., CO and VOM, while another is taking place for
NOx, which is a byproduct of high-temperature combustion. Upon startup of the
combustors, the concentration of NOx begins at an intermediate level associated with
“natural” combustion. The NOx concentration gradually increases as the rate of
firing is increased and combustion conditions improve to a level at which the
combustion process is sufficiently stable to begin low-NOx operation. At this point,
the concentration of NOx drops rapidly, as pre-mixing of fuel and air is initiated or
water begins to be injected into the combustors. The concentration of NOx then
remains relatively stable as the operation of the turbine increases to full load. In
contrast, during startup, the concentrations of incomplete combustion products start at
very high levels, but then rapidly decrease as the conditions for combustion
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9
(temperature and turbulence) stabilize as fuel firing rate is increased. The
concentrations gradually decrease further to normal levels as the combustion
conditions in the combustors continue to improve, with only a brief interruption, as
the concentrations temporarily jump when the combustors are shifted into low-NOx
operation.
In applying this theory to a particular turbine to develop a quantitative determination
of emissions during startup, one must consider a number of elements. These include
the variation of fuel firing rate and airflow during the startup, the overall duration of
the startup, the degree to which NOx is reduced by low-NOx operation of the
combustor, and the consequences of this degree of NOx reduction on combustion
conditions and emissions of incomplete combustion products. For purposes of
comparing turbines, it is also necessary to consider the safety factors included in
projections of emissions provided by equipment manufacturers.
The information provided in permit applications to date suggests that startup does not
have a significant effect on the overall NOx emissions of a turbine, when emissions
are evaluated in terms of pounds per hour. Although the concentrations of NOx are
somewhat higher during startup, this is balanced out by the reduced level of operation
during startup. Thus, NOx emissions during an hour with a startup are similar, or
only slightly higher than those during an hour of normal operation. This is confirmed
by NOx emission data collected by the NOx CEMS at the Elwood Energy facility. In
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10
particular, the CEMS data show a NOx emission rate in lb/mmBTU during a startup
that is about twice the normal rate.
2
The CEMS data shows that the peaking turbines
presently at Elwood Energy normally operate at about 0.05 to 0.055 lb NOx/mmBtu.
(The permit limit is 0.061 lb/mmBtu, based on an exhaust concentration of 15 ppm
NOx.) During startup, NOx emissions are in the range of 0.1 to 0.115 lb/mmBtu. Of
course, the average firing rate during a startup is about half of the turbines capacity.
This indicates that startup of these peaking turbines does not significantly change the
hourly NOx emissions of these turbines.
A different conclusion is reached for the new model of turbines and combustors that
are being added to Elwood. During normal operation, these new units are required to
comply with a lower emission rate than the existing units, i.e., 0.037 lb NOx/mmBtu.
(This limit is equivalent to 9 ppm NOx.) Assuming that the emissions of NOx from
these turbines during startup itself are unchanged from the startup emissions for the
older turbines, the emissions during an hour when one of these new turbines startup
could be about 25 percent higher than the emissions during a normal hour of
operation. If the turbines typically operate five hours at a stretch, however, the
consideration of startup would still only increase overall NOx emissions from the
turbine by about five percent. Nevertheless, as combustors become more effective in
2
During the September 14, 2000 site visit to Peoples Energy’s Elwood facility, representatives of the facility stated
that start-up for its natural gas-fired peaker turbines takes about 20 minutes.
This filing submitted on recycled paper.
11
lowering NOx emissions during normal operations, the startup emissions will likely
become higher in comparison.
7.
During this proceeding, a witness suggested that the NOx waiver applies to the
Metro-East nonattainment area as well as the Chicago nonattainment area.
Comment: U.S. EPA never granted Illinois’ request for a NOx waiver for Metro-East
ozone nonattainment area, and nonattainment New Source Review for VOM and
NOx applies to the new electric generating units (EGUs) locating in that area. The
major source threshold for purposes of New Source Review is 100 tons per year in
the Metro-East nonattainment area, as opposed to 25 tons per year in the Chicago
ozone nonattainment area, because Metro-East is a moderate ozone nonattainment
area.
8.
During this proceeding, a witness referred to the findings and recommendations of the
Ozone Transport Assessment Group (“OTAG”), referring to regions and subregions
as used in the context of OTAG. This witness suggested that the regions and
subregions of OTAG might be comprised of Illinois or even the Lake Michigan
nonattainment area.
Comment: The OTAG region was comprised of 37 jurisdictions from North Dakota
to Texas and east to the Atlantic Coast. At one point, OTAG modeled the effect on
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12
regional ozone levels of control strategies applied in subregions. Each of these
subregions was made up of a number of states. The regions and subregions did not
refer to single nonattainment areas or portions of nonattainment areas or even
individual states. It is important to keep in mind that OTAG’s major finding was that
NOx is a regional problem and that regional reductions of NOx, meaning reductions
in the NOx SIP call area, are necessary to generally reduce transported ozone and
ozone precursors. The findings of OTAG addressed the benefits of reducing NOx as
a regional, transport problem rather than as a local problem within nonattainment
areas such as the Chicago ozone nonattainment area.
9.
During this proceeding, a witness suggested that the OTAG process refuted the
validity of NOx disbenefit.
Comment: OTAG recognized NOx disbenefit as a local issue. OTAG also
recognized that local control measures, meaning those control strategies unique to a
given state or nonattainment area, might be necessary in addition to the regional NOx
reductions it recommended to U.S. EPA. These local measures would likely be
strategies to reduce emissions of VOCs, but they might be measures to reduce NOx
emissions in addition to or other than those identified to U.S. EPA; however, OTAG
made no findings or recommendations with regard to the benefits of local NOx
reductions.
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13
10.
Several witnesses suggested that the NOx SIP call supported the need for NOx
reductions within the Chicago ozone nonattainment area as part of the State’s
attainment demonstration.
Comment: The purpose of the NOx SIP call is to address ozone transport. Consistent
with OTAG’s findings, U.S. EPA issued the NOx SIP call to require reductions in
regional NOx in order to reduce the transport of ozone and ozone precursors. These
regional reductions of NOx are intended to enable Illinois and the other Lake
Michigan states to demonstrate attainment with the 1-hour ozone standard in the Lake
Michigan area, in conjunction with any local control measures that might be
necessary or appropriate. Without regional reductions of NOx, Illinois would have to
implement extreme levels of reductions of VOCs in the nonattainment areas. If the
regional reductions in NOx do not actually provide attainment as our modeling
predicts or if there is significant importation of NOx allowances under the national
trading program such that NOx emissions in the State continue to interfere with
attainment, then the Illinois EPA will have to impose additional emissions limitations
as appropriate. In any event, it is important to keep in mind that the NOx SIP call
addresses NOx as a regional issue involving a large sector of the eastern portion of
the United States.
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14
Respectfully submitted,
ILLINOIS ENVIRONMENTAL PROTECTION AGENCY
____________________________
Scott O. Phillips
Deputy Counsel
Division of Legal Counsel
1021 North Grand Avenue, East
P.O. Box 19276
Springfield, Illinois 62794-9276
217/782-5544
217/782-9143 (TDD)
Dated: November 6, 2000
This filing submitted on recycled paper.
CERTIFICATE OF SERVICE
I, the undersigned attorney at law, hereby certify that on November 6, 2000, I served true
and correct copies of ADDITIONAL COMMENTS, submitted on recycled paper, by placing
true and correct copies thereof in properly sealed and addressed envelopes and by sending said
sealed envelopes via overnight express delivery, upon the following named persons:
Dorothy M. Gunn, Clerk
Amy L. Jackson, Hearing Officer
Illinois Pollution Control Board
Illinois Pollution Control Board
James R. Thompson Center
600 South Second Street
100 West Randolph Street
Suite 402
Suite 11-500
Springfield, IL 62704
Chicago, IL 60601
ILLINOIS ENVIRONMENTAL PROTECTION AGENCY
____________________________
Scott O. Phillips
Deputy Counsel
Division of Legal Counsel
1021 North Grand Avenue, East
P.O. Box 19276
Springfield, Illinois 62794-9276
217/782-5544
217/782-9143 (TDD)
EXHIBIT 1
2
NATURAL GAS FIRED TURBINE ELECTRIC POWER PLANT PROJECTS
Status as of November 2, 2000
PROJECTS AT NEW PLANT SITES
Type of Turbine
Project
ID No./Application No.
(Rated Power – MW e)
Rec’d/Issued Dates
Simple Cycle
(Peaking)
Comb. Cycle
(Base Load)
Backup
Fuel
Status
LS Power
LS Power – Nelson Project
Nelson, Lee County
103814AAC 98080039
R 8/11/98
I 1/28/00
Units may first
be operated as
peaking units
4 @ 250
w/SCR
oil
Permitted
(being built)
LS Power
Kendall Energy
Minooka, Kendall County
093808AAD 98110017
R 11/5/98
I 6/2/99
Units may first
be operated as
peaking units
4 @ 250
w/SCR
_
Permitted
Illinois Power
Tilton Plant
Tilton, Vermilion County
183090AAE 98110018
R 11/5/98
I 1/99
4 @ 44
w/WI
_
Permitted
(operating)
089425AAC 98120016
R 12/4/98
I 2/4/99
2 @ 121 w/DLN
1 @ 35 w/WI
_
Permitted
Dynegy
(operating)
Rocky Road Power
East Dundee, Kane County
99050098
R 5/99
I 10/27/99
1 @ 121
w/DLN
_
Permitted
(operating)
171851AAA 98120050
R 12/6/98
I 3/24/99
2 @ 30
2 @ 22.5 w/WI
oil
Permitted
Soyland Power
(operating)
Soyland - Alsey Plant
Alsey, Scott County
99120026
R 12/9/99
I 7/7/00
1 @ 25
oil
Permitted
197811AAH 99020021
R 2/3/99
I 9/28/99
8 @ 83
w/DLN
_
Permitted
Enron
(operating)
Des Plaines Green Land Dev.
Manhattan, Will County
99020021
R 4/3/00
1 @ 167
_
Final Rev.
(major mod.)
Enron
Kendall New Century Dev.
Plano/Yorkville, Kendall Cty
093801AAN 99020032
R 2/3/99
I 1/14/00
8 @ 83
w/DLN
_
Permitted
Union Electric
Kinmundy Plant
Kinmundy, Marion County
121803AAA 99020027
R 2/4/99
I 6/28/99
2 @ 135
w/DLN
oil
Permitted
(being built)
Union Electric
Gibson City Plant
Gibson City, Ford County
053803AAL
99020071
R 2/19/99
I 6/16/99
2 @ 135
w/DLN
oil
Permitted
(operating)
Mid America
Cordova Energy
Cordova, Rock Island County
161807AAN 99020097
R 2/26/99
I 9/2/99
2 @ 250
w/SCR
_
Permitted
(being built)
Reliant Energy
McHenry County Plant
Woodstock, McHenry County
111805AAP 99050089
R 5/26/99
1 12/9/99
3 @ 170
w/DLN
_
Permitted
Spectrum Energy
Central Illinois Power
St. Elmo, Fayette County
051808AAK 99060052
R 6/16/99
I 9/8/99
1 @ 45
_
Permitted
(being built)
Duke Energy
Lee Generating Station
South Dixon, Lee County
103817AAH 99090029
R 9/13/99
I 3/31/00
8 @ 83
w/DLN
_
Permitted
145842AAA 99090035
R 9/13/99
I 11/10/99
4 @ 48.5
w/WI
_
Permitted
Ameren
(operating)
Pinckneyville Power Plant
Pinckneyville, Perry County
00090076
R 9/28/00
4 @ 48
w/DLN
_
In review
(minor mod.)
3
ABB Energy Ventures
Grande Prairie Energy
Bartlett, DuPage County
043412AAH 99090051
R 9/16/99
I* 9/5/00
2 @ 279
w/SCR
oil
Permitted
Reliant Energy
Williamson Energy Center
Crab Orchard, Williamson Cty
199856AAK 99090084
R 9/30/99
I 12/20/99
8 @ 41
w/WI
_
Permitted
Reliant Energy
Shelby Energy Center
Sigel, Shelby County
173801AAA 99090085
R 9/30/99
I 2/23/00
8 @ 41
w/WI
_
Permitted
(operating)
Spectrum Energy
Central Illinois Power
St. Peter, Fayette County
051030AAD 99100013
R 10/4/99
I 2/1/00
1 @ 45
_
Permitted
Constellation Power
Holland Energy LLC
Beecher City, Shelby County
173807AAG 99100022
R 10/7/99
I 4/6/00
2 @ 168
w/SCR
oil
Permitted
(being built)
Peoples Energy
Calumet Power LLC
Chicago, Cook County
031600GGV 99100023
R 10/7/99
I 12/13/99
2 @ 133
w/WI
_
Permitted
Reliant Energy
Reliant DuPage County LP
Aurora, DuPage County
043407AAF 99110018
R 11/3/99
I 5/10/00
6 @ 45 w/WI
4 @ 170 w/DLN
_
Permitted
(being built)
Skygen Services
Zion Energy Center
Zion, Lake County
097200ABB 99110042
R 11/12/99
5 @ 160
w/DLN
oil
Final
Review
(major)
Coastal Power
Fox River Peaking Station
Big Rock, Kane County
089802AAF 99110073
R 11/19/99
3 @ 115
w/DLN
_
Final
Review
Indeck
Indeck Rockford
Rockford, Winnebago County
201030BCG 99110088
R 11/24/99
I 2/16/00
2 @ 150
w/DLN
_
Permitted
(operating)
Calumet Energy LLC
Calumet Energy Team
Chicago, Cook County
031600GHA 99110107
R 11/24/99
I 5/18/00
2 @152.5
w/DLN
oil
Permitted
(being built)
Standard Energy Ventures
Standard Energy
West Chicago, DuPage Cty
043090ADB 99120001
R 12/01/99
800 MW w/SCN
(Specific turbines
yet to be selected)
(Combined cycle
turbines may be
chosen in place of
simple cycle units)
_
In review
(major
source)
Constellation
University Park Energy LLC
University Park, Will County
197899AAB 99120020
R 12/06/99
I 5/1/00
6 @ 25 + 25
w/WI
_
Permitted
(being built)
Midwest Generation
West Tech Turbines
Chicago, Cook County
031600GHS 00020062
R 12/14/99
I 4/7/00
5 @ 22
(temporary)
_
Permitted
(operating)
Power Energy Partners
Crete Energy Park
Crete, Will County
197030AAO 99120056
R 12/20/99
3 @ 131
w/WI
_
In review
(minor
source)
Carlton
North Shore Power Plant
Zion, Lake County
097810AAC 99120057
R 12/21/99
3 @ 169 w/DLN
or
6 @ 80 w/DLN
_
Final
Review
(minor)
Kinder Morgan
Aux Sable Power Plant
Morris, Grundy County
063800AAP 00030031
R 3/6/00
4 @ 44
w/WI
_
In review
(minor
source)
Entergy Power
Clay County Power, LLC
Flora, Clay County
025804AAC 00030053
R 3/16/00
4 @ 73
2 @ 148
both w/DLN
_
Permitted
Duke Energy
Duke Energy Kankakee
Kankakee, Kankakee County
091806AAM 00040067
R 4/10/00
2 @ 310 MW
_
Final Rev.
(major
source)
Duke Energy
Duke Energy Cook County
Chicago Heights, Cook Cty
031801AAI
00040068
R 4/24/00
2 @ 310 MW
_
In review
(major
source)
4
Rolls-Royce Power Ventures
Lockport Power Generation
Lockport, Will County
197810ABS 00050010
R 5/1/00
10/27/00
6 @ 49 w/DLN
_
Permitted
Spectrum Energy
Logan County Power
New Holland, Logan County
107815AAC 00050025
R 5/5/00
I 9/12/00
3 @ 45 w/WI
_
Permitted
Aquila Energy
MEP Flora Power
Flora, Clay County
025803AAD 00050050
R 5/8/00
4 @ 94.5
w/DLN
_
In review
(minor
source)
Indeck
Indeck-Bourbonnais
Bourbonnais, Kankakee Cty
091015AAD 00060010
R 6/6/00
4 @ 170.8
w/DLN
_
In review
(minor
source)
EnerStar
Montana Station
Newman, Douglas County
041806AAC 00060075
R 6/22/00
2 @ 161 w/DLN
1 @ 38 w/DLN
In review
(minor
source)
PPL Global
University Park Power Plant
University Park, Will County
197899AAC 00080078
R 8/17/00
12 @ 44.2
w/WI & SCR
_
In review
(minor
source)
Entergy
Franklin County Power
Kegley, Franklin County
055803AAB 00080055
R 8/22/00
2 @ 147.8
4 @ 72.9
both w/DLN
_
In review
(minor
source)
Gen Power
Gen Power – West Frankfort
West Frankfort, Franklin Cty
055807AAD 00090005
R 9/1/00
4 @ 80
w/DLN
_
In review
(minor
source)
MEP Investments
Washington County
Posen, Washington County
189802AAA 00090081
R 9/28/00
6 @ 94.5
w/DLN
_
In review
(minor
source)
MEP Investments
Piatt County
Deland/Lodge, Piatt County
147803AAC 00090082
R 9/28/00
6 @ 94.5
w/DLN
_
In review
(minor
source)
Ameren Energy
Elgin Energy Center
Elgin, Cook County
031438ABC 00100065
R 10/26/00
4 @ 113
w/DLN
_
In review
(minor
source)
Notes: DLN = Dry Low NOx Burners
SCR = Selective Catalytic Reduction
WI = Water Injection Burners
SCN = SCONOX
TM
SCR = Selective Catalytic Reduction
R = Received
I = Issued
I* = Issued. Permit becomes effective 30 days following issuance
5
PROJECTS AT EXISTING INDUSTRIAL AND UTILITY PLANTS
Type of Turbine
Project
ID No./Application No.
(Rated Power – MW e)
Rec’d/Issued Dates
Simple Cycle
(Peaking)
Comb. Cycle
(Base Load)
Backup
Fuel
Status
4 @ 170
w/DLN
ethane
Permitted
197808AAG 98060091
(operating)
R 6/98
I 12/98
10 @ 250
w/SCR
ethane
Permitted
197035AAG 00010076
R 1/27/00
I 10/17/00
2 @ 172
w/DLN
Permitted
Peoples Gas
Elwood Energy Center I/II/III
McDonnell Energy Center
Elwood, Will County
(McDowell Synthetic Natural
Gas Plant)
197035AAH 00010077
R 1/27/00
I 10/17/00
3 @ 172
w/DLN
Permitted
Houston Industries
Cardinal Energy
Roxana, Madison County
(Shell - Wood River Refinery)
119090AAH 98090064
R 9/21/98
I 7/14/99
3 @ 211
w/SCR
fuel gas
Permitted
Ameren
Grand Tower Station
Grand Tower, Jackson Cty
(Grand Tower Power Plant)
077806AAA 99080101
R 8/30/99
I 2/25/00
2 @ 300
w/DLN &
future SCR
_
Permitted
(being built)
Electric Energy
Midwest Electric Power
Joppa, Massac County
(Joppa Power Plant)
127899AAA 99100060
R 10/18/99
I 3/29/00
3 @ 72 w/WI
2 @ 51 w/WI
_
Permitted
(operating)
CILCO
Medina Cogeneration Plant
Mossville, Peoria County
(Caterpillar Engine Plant)
143810AAG 99100102
R 10/29/99
I 5/30/00
3 @ 14.2
w/DLN
_
Permitted
Dominion Energy
Lincoln Generation
Kincaid, Christian County
(Kincaid Power Plant)
021814AAG 00020011
R 2/3/00
4 @ 172
w/DLN
_
In review
(major
modification)
Midwest Generation EME
Waukegan Peaking Facility
Waukegan, Lake County
(Waukegan Power Plant)
097190AAC 00050071
R 5/22/00
2 @ 145.8
w/DLN
_
In review
(minor
source)
Southern Illinois Power Coop
Marion
Marion, Williamson County
(SIPCO Power Plant)
199856AAC 00070028
R 7/12/00
2 @ 83 w/DLN
oil
In review
(netting)
6
WITHDRAWN APPLICATIONS AND EXPIRED PERMITS
Type of Turbine
Project
ID No./Application No.
(Rated Power – MW e)
Action Dates
Simple Cycle
(Peaking)
Comb. Cycle
(Base Load)
Backup
Fuel
Status
Indeck
Indeck – Pleasant Valley
Woodstock, McHenry County
111805AAO 98100061
R 10/19/98
I 1/28/99
Rev 3/4/99
Exp 3/4/00
2 @ 150
w/DLN
_
Permit
Expired
KN Power
Lake County Plant
Island Lake, Lake County
097454AAB 98120032
R 12/11/98
WD 2/00
6 @ 62.5
w/DLN
1 @ 135
w/DLN
oil
Application
Withdrawn
Constellation
West Chicago Energy LLC
West Chicago, DuPage Cty
043090ADC 99120014
R 12/06/99 WD 5/15/00
6 @ 25 + 25
w/WI
_
Application
Withdrawn
Unicom (Com Ed)
North Chicago Power
North Chicago, Lake County
097125ABT 99100028
R 10/8/99
I 2/24/00
WD 8/24/00
1 @ 37.8 w/DLN
1 @ 39.8 w/WI
_
Permit
Withdrawn
Indeck
Indeck-Chicago Heights
Chicago Heights, Cook Cty
031045ANT 00080004
R 8/3/00
WD 9/13/00
3 @ 69 w/DLN
_
Application
Withdrawn
Indeck
Indeck – Libertyville
Libertyville, Lake County
097090ACD 98120030
R 2/14/00 WD 10/3/00
2 @ 150
w/DLN
_
Application
Withdrawn
Indeck
Indeck – Holiday Hills
Holiday Hills, McHenry Cty
111032AAA 99080066
R 8/20/99 WD 10/3/00
2 @ 150
w/DLN
_
Application
Withdrawn
7
NEW COAL-FIRED BOILER POWER PLANTS
Project
ID No./Application No.
Action Dates
Type of Boiler
Emission
Controls
Rated
Output
(MW e)
Status
Enviropower
Enviropower
Benton, Franklin County
055802AAG 00080042
R 8/16/00
Fluidized bed
(Coal/coal
waste)
Baghouse
250 ea.
Major
(Under
review)
COAL-FIRED BOILER PROJECTS
AT EXISTING UTILITY POWER PLANTS
Project
ID No./Application No.
Action Dates
Type of Boiler
Emission
Controls
Rated
Output
(MW e)
Status
Southern Illinois Power Coop
Marion
Marion, Williamson County
(SIPCO Power Plant)
199856AAC 00070028
R 7/12/00
Fluidized Bed
(coal/tire-
derived fuel)
Baghouse
120
In review
(Netting, with
existing units)
EXHIBIT 2
Table: List of Existing and New Simple Cycle, and New Combined Cycle Units
Combined Cycle Units are Highlighted
F:utility\peakersEGU\sheet 2\10-31-2000\v gupta
S.
ID #
Company Name
Street Address
Location
County
EGU Site
Ozone
Permit
No.
Existing/ Attainment
Permit
Type
New
Yes/No
Number
C/O
12
3
4
5
678910
1 021814AAG Dom. Energy-Lincoln Generation Route 104
Kincaid
Christian
Existing
Yes
00020011
C
2 025803AAD Aquila Energy/MEP Flora Power
Route 2, Box 89a
Harter/Flora
Clay
New
Yes
00050050
C
3 025804AAC Entergy Power-Flora Peaking Stn To Be Determined
Flora
Clay
New
Yes
00030053
C
4 025804AAC Entergy Power-Flora Peaking Stn To Be Determined
Flora
Clay
New
Yes
00030053
C
5 031600AMI Midwest Generation
1111 W Cermak Rd
Chicago
Cook
Existing
No
95090081
Title V
6 031600GGV People's Energy/Calumet Power 3200 E 98th St
Chicago
Cook
New
No
99100023
C
7 031600GHA Calumet Energy Team LLC
10301 S Doty Ave
Chicago
Cook
New
No
99110107
C
8 031801AAI Duke Energy Chicago Hts
1600 Feet West Of Cottage Grove
Chicago
Rd Hts
Cook
New
No
00040068
C
9 041806AAC Ener Star- Montana Stn
Rural
Newman
Douglas
New
Yes
00060075
C
10 041806AAC Ener Star- Montana Stn
Rural
Newman
Douglas
New
Yes
00060075
C
11 043090ADB Standard Energy Venture, LLC
McChesney Rd and Fabyan PkwyW.Chicago
Du Page
New
No
99120001
C
12 043407AAF Reliant Energy/Reliant DuPage Cty Eola
LP Rd @ Ferry Rd
Aurora
Du Page
New
No
99110018
C
13 043407AAF Reliant Energy/Reliant DuPage Cty Eola
LP Rd @ Ferry Rd
Aurora
Du Page
New
No
99110018
C
14 043412AAH Grand Prairie Energy, LLC/ABB
Old Bartlett Quarry
Bartlett
Du Page
New
No
99090051
C
15 051030AAD Spectrum Energy/C.I. C.S.Power 1 mile NE of city of St. Peters St. Peters
Fayette
New
Yes
99100013
C
16 051808AAK Cent.Ill. S C Pow./ Spectrum
State Route 4
St. Elmo
Fayette
New
Yes
99060052
C
17 053803AAL Ameren CIPS
545 N Jordan Dr
Gibson City
Ford
New
Yes
99020071
C
18 055803AAB Entergy -Franklin County Pwr
2429 Eaton Road
Thompsonville Franklin
New
Yes
00080055
C
19 055803AAB Entergy -Franklin County Pwr
2429 Eaton Road
Thompsonville Franklin
New
Yes
00080055
C
20 055807AAD Gen Power
Woods Road
W.Frankfort
Franklin
New
Yes
00090005
C
21 063800AAP Kinder Morgan-Aux Sable Power PltEast Route 6
Morris
Grundy
New
No
00030031
C
22 077806AAA Ameren CIPs
1820 Power Plant Rd.
Grand Tower Jackson
Existing
Yes
99080101
C
23 089425AAC DMG (Dynegy/Rocky Road)
1221 Power Dr
E.Dundee
Kane
New
No
98120016
C
24 089425AAC DMG (Dynegy/Rocky Road)
1221 Power Dr
E.Dundee
Kane
New
No
98120016
C
25 089425AAC DMG (Dynegy/Rocky Road)
1221 Power Dr
E.Dundee
Kane
New
No
99050098
C
26 089802AAF Fox River Pkng Stn/Coastal Power Lasher
Co.
and Dauberman
Big Rock
Kane
New
No
99110073
C
27 091015AAD Indeck-Bourbonnais Energy CenterEast of I57 on George Road Bourbonnais Kankakee
New
Yes
00060010
C
28 091806AAM Duke Energy
Township Rd 6000 N
Manteno
Kankakee
New
Yes
00040067
C
29 093801AAN Kendall New Cent. Dev./Enron
Corneils Rd Between Eldermaun and
Plano
Beeche
Kendall
New
Yes
99020032
C
30 093808AAD L S Power/Kendall Energy
County Line and Wildy Rds. Minooka
Kendall
New
No
98110017
C
31 097190AAC Midwest Generation
401 E Greenwood Ave
Waukegan
Lake
Existing
No
95090043
Title V
32 097190AAC Midwest Generation
401 E Greenwood Ave
Waukegan
Lake
Existing
No
00050071
C
33 097200ABB Skygen/Zion Energy Center LLC West Ninth St
Zion
Lake
New
No
99110042
C
34 097810AAC Carlton Inc./North Shore Power
N. Of 9th St, E Of Union Pacific ZionRR
Lake
New
No
99120057
C
35 103814AAC Lee Cty Gen. Facility/L S Power
Nelson Rd At I-88
Nelson
Lee
New
Yes
98080039
C
36 103817AAH Lee Generating Stn./Duke Energy Nachusa Rd
South Dixon
Lee
New
Yes
99090029
C
37 107815AAC Spectrum Energy-Logan County 1 1/2 Miles E Of New Holland Sheridan
Logan
New
Yes
00050025
C
38 111805AAP Reliant Energy
4500 S Route 47
Woodstock
McHenry
New
No
99050089
C
39 119090AAH Reliant Energy (Cardinal Energy) Madison St. East of Hwy 111 Roxana
Madison
New
No
98090064
C
40 119105AAA Ameren CIPS
701 Main & McKinley Bridge Venice
Madison
Existing
No
95090017
Title V
41 121803AAA Ameren Energy Gen. Company-Kinmundy2816 Kinoka Rd
Patoka
Marion
New
Yes
99020027
C
42 127899AAA Electric Energy/Midwest Elec. Power2100 Portland Rd
Joppa
Massac
Existing
Yes
99100060
C
43 127899AAA Electric Energy/Midwest Elec. Power2100 Portland Rd
Joppa
Massac
Existing
Yes
99100060
C
44 145842AAA Ameren Energy Gen. Company
4646 White Walnut Rd
Pinckneyville Perry
New
Yes
99090035
C
45 145842AAA Ameren Energy Gen. Company
4646 White Walnut Rd
Pinckneyville Perry
New
Yes
00090076
C
46 147803AAA MEP Investments-Deland
To Be Announced
Goose Creek Piatt
New
Yes
00090082
C
47 161807AAN Cordova Energy
SW Corner 192nd St.,and 250th
CordovaSt.
Rock Island
New
Yes
99020097
C
48 167822ABG CWLP
3620 Ridgely Rd
Springfield
Sangamon
New
Yes
94120058
O
49 171851AAA Soyland Power
1175 E Campbell Rd
Alsey
Scott
New
Yes
98120050
C
50 171851AAA Soyland Power
1175 E Campbell Rd
Alsey
Scott
New
Yes
98120050
C
51 173801AAA Shelby Enrgy Cntr/ Reliant Energy Us 45 @ County Rd 35
Sigel
Shelby
New
Yes
99090085
C
52 173807AAG Holland Energy, LLC
RR2, County Line Rd.
Holland
Shelby
New
Yes
99100022
C
53 183090AAE DMG/Tilton Energy Center
80 W First St
Tilton
Vermilion
New
Yes
98110018
O
54 189802AAA MEP Investments-Posen
To Be Announced
Bolo
Washington
New
Yes
00090081
C
55 197030AAO Power Energy Partners/Crete Energy
Burville
Park Road Access
Crete
Will
New
No
99120056
C
56 197035AAG Elwood Energy/Peoples Gas
20900 West Noel Road
Elwood
Will
New
No
00010076
C
57 197035AAH Elwood Energy/Peoples Gas
20900 West Noel Road
Elwood
Will
New
No
00010077
C
58 197808AAG Elwood Energy Center,LLC
21100 W Noel Rd
Elwood
Will
New
No
98060091
C
59 197808AAG Elwood Energy Center,LLC
21100 W Noel Rd
Elwood
Will
New
No
98060091
C
60 197810ABS Rolls-Royce/Lockport Pwr Gen.
East Of I and M Canal
Lockport
Will
New
No
00050010
C
61 197811AAH Desplaines Greenland/Enron
27155 S Kankakee St
Manhattan
Will
New
No
99020021
C
62 197811AAH Desplaines Greenland/Enron
27155 S Kankakee St
Manhattan
Will
New
No
99020021
C
63 197899AAB Univ. Park Energy/ Constellation Po.
SW Intersection Of Central Ave and Univ.
Dralle
Park
Rd
Will
New
No
99120020
C
64 197899AAC Univ. Park Power (PPL Global)
Dralle Road
Univ. Park
Will
New
No
00080078
C
65 199856AAC Southern Ill. Power Coop.
11543 Lake Of Egypt Rd
Marion
Williamson Existing
Yes
00070029
C
66 199856AAK Reliant Energy/ Williamson Enrgy CntrHwy 13 Near Hwy 166
Crab Orchard Williamson
New
Yes
99090084
C
67 201030BCG Indeck-Rockford
136 Harrison Ave
Rockford
Winnebago
New
Yes
99110088
C
Total
Abbreviations: DLN=Dry Low NOx burner, WI= Water Injection, SCR=Selective Catalytic Reduction, SCN= Sconox, CT=Combution Turbine, SCT= Simple Combustion Turbine, CCT= Combined Cycle Turbine,
HRSG= Heat Recovery Steam Generator, EGU= Electric Generating Unit, C= Construction, O=Operating, MW=Megawatt, NG=Natural Gas, F.Oil=Fuel Oil, tpy=tons/year, JP-4=Jet Fuel, D.B.=Duct Burner, G=Gas, O=Oil
*SCT or CCT . The company has not made the final decision
** Currently many new EGUs are operating under the construction permit, and they are planning to apply for Title V permit. Title V permit has been applied for existing Waukegan and Fisk peakers
*** Combined Cycle may be chosen in place of single cycle turbines
*¹ DLN when n.gas used, WI when oil is fired, HRSG s controlled by SCR
*³ 99 ppm NOx is approximately equal to 0.397 lb/mmBtu for gas turbines burning natural gas as per ACT for Turbines
*² 40 CFR75 monitoring required if 3-year annual average capacity factor exceeds 10% and, if oil is also fired, and average annual heat input from oil exceeds 15%.
Date
Date
Oper. Permit
Turbine
No. of
Alternative
Existing
Turbine
MW
Turbine
Applic.
Permit
Expiration** Permit Action
Unit
Identical
Turbine
Turbine
Turbine
Under
NOx
Capacity/ Heat Input
Rec'd
Issued
Date
Status
Type
Turbines ManufacturerModel No. Proposal Subpart W
Control
Turbine
mmBtu/hr
11
12
13
14
15
16
17
18
19
20
21
22
23
2/3/00
Add. Info Ltr 3/6/00
SCT
4
GE
7FA Frame
No
DLN
172
1972
5/8/2000
Review Pending
SCT
6
GE
7EA Frame
No
DLN
94.5
1001.7
3/16/2000
Public Notice
SCT
4
GE
7EA Frame
No
DLN
73
1024
3/16/2000
Public Notice
SCT
2
GE
7FA Frame
No
DLN
148
1747
9/7/1995
Review Pending
SCT
8
WorthingtonGG4
Yes
None
33
558
10/7/1999 3/24/2000
Permitted
SCT
2
ABB
11N2
No
WI
133
1500
11/24/1999 5/19/2000
Permitted
SCT
2
ABB
11N2
No
DLN or WI
152.5
1604
4/24/2000
Review Pending
CCT
2
GE
7FA Frame
No
SCR
310
4232
6/22/2000
Review Pending
SCT
2
GE
7FA Frame
No
DLN
161
1640
6/22/2000
Review Pending
SCT
1
GE
7FA Frame
No
DLN
40
400
12/1/1999
Draft Permit
SCT***
16
Pratt & WhittneyFT8 "Twin Packs"Aero
NoSCN ?? (DLN??)/WI(o)50
554.8
10/29/1999 5/9/2000
Permitted
SCT
4
GE
7FA Frame
No
DLN
170
1885
10/29/1999 5/9/2000
Permitted
SCT
6
GE (Stewart & LM6000
Stevenson)
PC
No
WI
45
444
9/16/1999
9/5/2000
Permitted
CCT
2
NoDLN(g), WI(o), SCR (HRSG)
250
1868
10/4/1999
2/1/2000
Permitted
SCT
1
GE
LM6000 Aero
No
WI
45
420
6/16/1999
9/7/1999
Permitted
SCT
1
GE
LM6000 Aero
No
WI
45
420
2/19/1999 6/16/1999
Permitted
SCT
2
Westinghouse501D5A
No
DLN
135
1457
8/22/2000
Review Pending
SCT
2
GE
7FA Frame
No
DLN
147.8
1747
8/22/2000
Review Pending
SCT
4
GE
7EA Frame
No
DLN
72.9
787.6
9/1/2000
Review Pending
SCT
4
GE
7EA Frame
No
3/6/2000
Draft Permit
SCT
4
GE
LM6000 Aero
No
WI
44
403
8/30/1999 2/25/2000
Permitted
CCT
2
Westinghouse501F
Yes CT (SCR), SCR(HRSG)300
2050
12/4/1998
6/5/2000
Permitted
SCT
1
GE
LM5000
No
WI
35
367
12/4/1998
6/5/2000
Permitted
SCT
2
Westinghouse501DA
No
DLN
121
1439
5/28/1999 10/27/1999
Permitted
SCT
1
Westinghouse501D5A
No
DLN
121
1439
11/19/1999
Final Review
SCT
3
ABB
11N2 Frame
No
DLN
115
1362
6/6/2000
No Action
SCT
4
GE
7FA Frame
No
DLN
170.8
1540
4/10/2000
Public Notice
CCT
2
GE
7FA Frame
No
SCR
310
4232
2/3/1999
1/14/2000
Permitted
SCT
8
GE
7EA Frame
No
DLN
83
1002
11/5/1998
6/2/1999
Permitted
CCT/SCT*
4
GE or Equivalent7241
No CT(DLN), SCR (HRSG)*¹
250
2166
9/7/1995
Consoldation
SCT
4
WorthingtonGG4
Yes
None
33
558
5/22/2000
Review Pending
SCT
2
GE
7FA Frame
No
DLN
145.8
1951
11/12/1999
Final Review
SCT
5
GE
7FA Frame
No
DLN/WI
160
1719
12/21/1999
Final Review
SCT
3
GE/ABB
7FA/11N2
Frame
6 GE Type
EA each 80
MW
No
DLN
187
1746
8/11/1998 1/28/2000
Permitted
CCT/SCT*
4
GE or EquivalentTBD
NoDLN(g)/WI(o),HRSG(SCR)*¹
250
2516
9/13/1999 3/31/2000
Permitted
SCT
8
GE
7EA Frame
No
DLN
83
978
5/5/2000
9/12/2000
Permitted
SCT
6
GE
LM6000 Aero
No
WI
45
420
5/26/1999 12/9/1999
Permitted
SCT
3
GE
7FA Frame
No
DLN
170
1874
9/21/1998 7/14/1999
Permitted
CCT
3
GE/Westinghouse7FA/501D
No DLN, SCR (CT, HRSG)211
1916
Permitted
SCT
1
WestinghouseW-301G
Yes
None
37
372
2/4/1999
6/28/1999
Permitted
SCT
2
Westinghouse501D5A
No
DLN(g),WI(o)
135
1457
6/23/2000 7/25/2000
Permitted
SCT
3
GE
Frame 7B
No
WI
72
743
6/23/2000 7/25/2000
Permitted
SCT
2
GE
Frame 7B
No
WI
51
9/13/1999 11/9/1999
Permitted
SCT
8
GE/Stewart LM6000
& StevensonAero
No
WI
48.5
444
9/28/2000
Review Pending
SCT
4
GE
PG6581
No
DLN
48
553
9/28/2000
Review Pending
6
GE
7EA Frame
No
DLN
94.5
2/26/1999
9/2/1999
Permitted
CCT
2
No DLN (g), SCR (HRSG) 250
1974
3/14/1997 3/21/1997 3/14/2002
Permitted
SCT
1
Westinghouse501D5A
No
WI
100
1370
12/6/1998 3/24/1999
Permitted
SCT
2
Westinghouse251AA Frame
No
DLN
30
375
12/9/1999
7/2/2000
Permitted
SCT
1
Westinghouse251AA Frame
No
WI
25
341
9/30/1999 2/23/2000
Permitted
SCT
8
GE
LM6000 Aero
No
WI
41
444
10/7/1999
4/5/2000
Permitted
CCT
2
NoDLN(g),WI(o),SCR(HRSG)168
1762
10/22/1999 6/1/2000 4/1/2002
Permitted
SCT
4
GE
LM6000 Aero
No
WI
44
410
9/28/2000
Review Pending
SCT
6
GE
7EA Frame
No
DLN
94.5
12/20/1999
Draft Permit
SCT
3
ABB
11N2 FrameEquivalent to GE11N2
No
DLN or WI
131
1624
1/27/2000 10/17/2000
Permitted
SCT
2
GE
7FA Frame
No
DLN
172
1763
1/27/2000 10/17/2000
Permitted
SCT
3
GE
7FA Frame
No
DLN
172
1763
2/18/1999 10/17/2000
Permitted
SCT
4
GE
7FA Frame
No
DLN
170
1763
4/2/1999
10/17/2000
Permitted
CCT
10
GE
7FA Frame
No
DLN,SCR
250
1763
5/1/2000
10/27/2000
Permitted
SCT
6
RR
Trent(p) Aero
No
DLN
62
492
2/3/1999
9/28/1999
Permitted
SCT
8
GE
7EA Frame
No
DLN
83
1002
4/3/2000
Final Revision
SCT
1
GE
7FA Frame
No
DLN
167
2750 ??
12/6/1999
5/1/2000
Permitted
Aero CT
6
Pratt & WhittneyFT8 "Twin Packs" Aero
No
WI
50
494
8/17/2000
Review Pending
SCT
12
GE
LM6000PC
No
WI+SCR
44.2
452
7/12/2000
Draft Permit
SCT
2
GE
PG7172 (EA)
No
DLN
83
1165
9/30/1999 12/20/1999
Permitted
SCT
8
GE
LM6000 Aero
No
WI
41
444
11/24/1999 2/16/2000
Permitted
SCT
2
SW
V84 Frame
No
DLN
150
1698.5
279
7948
77659.6
Abbreviations: DLN=Dry Low NOx burner, WI= Water Injection, SCR=Selective Catalytic Reduction, SCN= Sconox, CT=Combution Turbine, SCT= Simple Combustion Turbine, CCT= Combined Cycle Turbine,
HRSG= Heat Recovery Steam Generator, EGU= Electric Generating Unit, C= Construction, O=Operating, MW=Megawatt, NG=Natural Gas, F.Oil=Fuel Oil, tpy=tons/year, JP-4=Jet Fuel, D.B.=Duct Burner, G=Gas, O=Oil
** Currently many new EGUs are operating under the construction permit, and they are planning to apply for Title V permit. Title V permit has been applied for existing Waukegan and Fisk peakers
*³ 99 ppm NOx is approximately equal to 0.397 lb/mmBtu for gas turbines burning natural gas as per ACT for Turbines
Duct Burner
Load
F. Oil Limit
Nox Rate
NOx Rate NOx Emissions
H.Input
Type
per turbine All Turbines @Siteper turbine All Turbines
All Turbines @Site per
All Turbines
ppm
lb per mmBtuDuring Startup
mmBtu/hr Fuel Used
lb per hour
tpy
per hr
@Site/yr mmGal./Yr. turbine
@Site
lb/hr
24
25
26
27
28
29
30
31
32
33
34
35
36
N.Gas
Peaking
9
0.036
N.Gas
Peaking
60
245
8475
9-15
0.036-0.060
N.Gas
Peaking
55
212
9-15
0.036-0.060
N.Gas
Peaking
99
212
9
0.018
JP-4, N.G. Peaking
110(JP-4), 70 (g)0.44 (o) 0.28(g)
N.Gas OnlyPeaking
151.2
233
3.25
5002
25
0.1
N.Gas/Oil Peaking 170 (g) 317 (o)
240
1.6
4870
8
25-g/42-oil 0.10(g)-0.168(o)
N.Gas
Base
3.5
0.014
N.Gas
Peaking
9
0.036
N.Gas
Peaking
25
0.1
430??
N.Gas/Oil Base/Peaking54(g) 194(o)
732
2500(Total);500 (o)20000
12 (annual) 15 (hourly)
0.06 (g), 0.17 (o) 1.68 tpy Startup/shut down (all units total)
N.Gas OnlyPeaking
105
247
9878
9
0.036
N.Gas OnlyPeaking
41
247
9878
25
0.1
N.G./Oil
Base
24.5(g) 67.6 (o)
213
480(o)
4.5 (g), 10.5 (o)0.017 (g), 0.043 (o)
N.Gas OnlyPeaking
43
85.9
1700
4000
25
0.1
N.Gas OnlyPeaking
43
85.9
1580
4000
25
0.1
N.G./Oil
Peaking 136 (g) 242 (o)
245
37
25(G),42(O) 0.10(g)-0.168(o)
N. Gas
Peaking
250
9
0.036
N. Gas
Peaking
250
9
0.036
Peaking
N.Gas
Peaking
40
247.5
25
0.1
297(1)333(2) N. Gas OnlyBase
216.8(CT-1)
219.6(CT-2)
1911.5
40CFR60.44a(d)(1)
N. Gas OnlyPeaking
60
245
6600
25(G),42(O) 0.10(g)-0.168(o)
N. Gas OnlyPeaking
80
245
6600
25(G),42(O) 0.1 (G)
N. Gas OnlyPeaking
80
245
6600
25(G),42(O) 0.1 (G)
N.Gas
Peaking
25
0.1
N.Gas
Peaking
9
0.036
N.Gas
Base
31.6
3.5
0.014
NOx limit
N. Gas Limit, mmcf
Hrs of Operation Limit / yr
N. Gas
Peaking
60
426.4
3300
26400
9(yrly),12(monthly)15 0.037(annual),
(hrly)
0.048(monthly if operated >250 hours/month), 0.060 (hourly)
350
N. Gas OnlyBase/Peaking
188.7
(SCT) 36
(CCT)
99 (SCT),
630.7 (CCT)
1048 (SCT)
25 (SCT), 4.5 -G(SCR)0.0166(CCT), 0.0936 (SCT)
JP-4, N.G. Peaking
No Limit
110(JP-4) 70 (g)0.44 (o) 0.28(g)
N.Gas
Peaking
9
0.036
N.Gas/Oil (back-up)
Peaking
81(g) 321 (o)
697.5
2300(500-oil) 11500
9(yrly),12(monthly)15 (hrly)
0.058(hourly)
N.Gas
Peaking
100.9(7FA);
54.1(7EA)
245
8313, Alt. 6888
15
0.056
N.Gas/Oil Base/Peaking36(g) 139(o)
630.8
2000 as SCT2453
SCT-25(g),42(o),CCT-
(g) 96(o)
4.5(g)(SCR)
N.Gas/Oil Peaking
12
0.0545
N.Gas
Peaking
25
0.1
N.Gas
Peaking
105
248
14500
14500
9
0.036
489
N.Gas,
Refinery
Gas
Base
31.7(w/DB)
25.3(w/o
DB)
330.5
3.5 (8 hr) 4.5(1 hr) 0.013
Oil
Peaking
No Limit
No Limit
No Limit
No Limit
No Limit
110
0.44
N.G./Dis. OilPeaking 136(g) 242(o)
245
37
25(G),42(O) 0.1 (G)
N.Gas
Peaking
89.5
349.3
4032
40
0.16
N.Gas
Peaking
4032
N.Gas
Peaking
57
35
0.14
N.Gas
Peaking
N.Gas
Peaking
N.Gas
Base
35
306.6
4.5
0.019
N.G./#2 Oil Peaking
750
249
75(G),75(O)
0.3
N.Gas/Oil Peaking
About 175
0.7
N.Gas/Oil Peaking
148
0.59
N.Gas OnlyPeaking
40
198
4186
25
0.09
776
NG/Oil (CT), NG(D.B.)
Base
41.7
342
DB<1500, o<1000 4.5(hrly) 3.5(24 hr);16 (o)(hrly)0.02(g),0.04(o)
N.Gas OnlyPeaking
50
197
4250
25
0.1
N.Gas
Peaking
N.Gas
Peaking
125.47
245
6040
25
0.07
20% higher than normal emissions
N.Gas
Peaking
64.8
217.56
3200
9
0.037
N.Gas
Peaking
64.8
326.34
3200
9
0.037
N.G./EthanePeaking
108
1565.7
Peaking Use Only
15
0.061
??
N.G./EthaneBase
32.4
1565.7
6000
4.5
0.0184
N.Gas
Peaking
245
25
0.1
N.Gas
Peaking
419.4
3250
9(yrly),12(monthly)15 0.037(annual),
(hrly)
0.048(monthly if oper'd >250 hrs/m),0.060 (hourly)
N.Gas
Peaking
3250
N.Gas
Peaking
30
245
4443
25
0.1
N. Gas
Peaking
25 (WI) 5(WI+SCR)
0.1(scr) 0.02(WI+SCR)
N.Gas/Oil Peaking
15(g),42 (o) 0.06(g).17 (o)
N.Gas
Peaking
40
198
4186
25
0.1
N.Gas
Peaking
199
15
0.06
16311.6
Startup Acid Rain
NSPS MonitoringOther Monitoring
Review/
Time
Monitoring
40CFR60.334(a)
(daily, annual etc.)
Const./Oper.
min
40CFR75*²
and Others sections
/Recordkeeping
Applicable Rule Status
37
38
39
40
41
42
Major-PSD Under Review
NSPS
Under Review
NSPS
Under Review
NSPS
Under Review
None
Existing Peaker
If 3 yr. avg. C.F.>10%
fuel usage, water/fuel
fuel usage,Btu,
ratio,
NSPS
water usage,
Const.
oper. Pending
Hrs
If 3 yr. avg. C.F.>10%
fuel usage, water/fuel
fuel usage,Btu,
ratio,
NSPS
water usage,
Const.
oper. Initiated
Hrs
fuel use,Btu,N,
Major
reagent use,
Under
oper. Review
Hrs
NSPS
Under Review
NSPS
Under Review
1.68 tpy Startup/shut down (all Yesunits total)Yes
fuel usage,Btu,
PSD/BACT
water usage,
Under
oper. Review
Hrs
If 3 yr. avg. C.F.>10%
fuel usage, water/fuel
fuel usage,Btu,
ratio,
NSPS
oper. Hrs Const. Initiated
If 3 yr. avg. C.F.>10%
fuel usage, water/fuel
fuel usage,Btu,
ratio,
NSPS
water usage,
Const.
oper. Initiated
Hrs
Yes
fuel usage, water/fuel
PSD/BACT
ratio, Const.
SCR reagent,
Pendingfuel Btu
20 If 3 yr. avg. C.F.>10%
fuel usage, water/fuel
fuel usage,Btu,
ratio,
NSPS
water usage,
Const.
oper. Pending
Hrs
20 If 3 yr. avg. C.F.>10%
fuel usage, water/fuel
fuel usage,Btu,
ratio,
NSPS
water usage,
Const.
oper. Initiated
Hrs
If 3 yr. avg. C.F.>10%
fuel usage, water/fuel
fuel usage,Btu,
ratio,
NSPS
oper. Hrs Operating
NSPS
Under Review
NSPS
Under Review
PSD Minor Under Review
If 3 yr. avg. C.F.>10%
fuel usage, water/fuel
fuel usage,Btu,
ratio,
NSPS
water usage,
Under
oper. Review
Hrs
Yes
Yes
fuel use,Btu, reagent
NSPS use, oper.
Const.
HrsInitiated
If 3 yr. avg. C.F.>10%
fuel usage Fuel usage, operating
NSPS hours,
Operating
Fuel Btu
If 3 yr. avg. C.F.>10%
fuel usage Fuel usage, operating
NSPS hours,
Operating
Fuel Btu
20 If 3 yr. avg. C.F.>10%
fuel usage Fuel usage, operating
NSPS hours,
Operating
Fuel Btu
NSPS
Under Review
NSPS
Under Review
Yes
Yes
fuel use,Btu,N,
Major
reagent use,
Under
oper. Review
Hrs
0.037(annual), 0.048(monthly if operated
If 3 yr. >250
avg. hours/month),
C.F.>10%Yes
0.060
Fuel (hourly)
usage, operating
PSD/BACT
hours,
Const.
Fuel Btu
Pending
Yes
Yes
fuel use,Btu,N,
PSD/BACT
reagent use,
Const.
oper. Hrs
Pending
None
Existing Peaker
NSPS
Under Review
Yes
Fuel usage, operating
PSD/BACT/NSPS
hours,
Under
Fuel N,
Review
Btu
If 3 yr. avg. C.F.>10%
fuel usage, water/fuel
Fuel consumption,
ratio,
NSPSTotal hrs Under
of operation
Review
Yes
Yes
fuel use,Btu,N,
PSD/NSPS
reagent use,
Const.
oper. Hrs
Pending
PSD/BACT Const. Pending
Yes
Yes
NSPS
Const. Pending
Yes
Yes
Fuel usage PSD/BACT Const. Pending
Yes
Yes
fuel use,Btu,N,
PSD/BACT
reagent use,
Const.
oper. Hrs
Pending
No
No
None
Operating
Yes
Yes
fuel use,Btu,N,
NSPS
water/fuel, Const.
oper. Hrs
Initiated
Netted
Operating
Netted
Operating
NSPS
Operating
NSPS
Under Review
NSPS
Under Review
Yes
Yes
fuel use,Btu,N,
PSD/BACT
reagent use,
Const.
oper. Hrs
Pending
Yes
fuel usage,Btu,
NSPS
water usage,
Operating
oper. Hrs
old unit
Operating
old unit
Under Review
Yes
Yes
Fuel usage, operating
NSPS hours,
Operating
Fuel Btu
Yes
Yes
fuel use,Btu,N,
PSD/BACT
reagent use,
Const.
oper. Hrs
Initiated
NSPS
Operating
NSPS
Under Review
Explain if If >20
3 yr. min.avg. C.F.>10%
fuel usage, water/fuel
Fuel usage,
ratio,operating
NSPS hours,
Under
Fuel Btu
Review
Yes
Fuel usage Fuel usage, operating
Major-PSD
hours,
Const.
Fuel Btu
Pending
Yes
Fuel usage Fuel usage, operating
Major-PSD
hours,
Const.
Fuel Btu
Pending
Yes
Yes
fuel usage, Btu,
PSD/BACT
fuel N, oper.
Operating
Hrs
Yes
Yes
fuel use,Btu,N,
PSD/BACT
reagent use,
Const.
oper. Hrs
Pending
Yes
Yes
NSPS
Under Review
0.037(annual), 0.048(monthly if oper'd >250 hrs/m),0.060
Yes
(hourly)
Fuel usage, operating
PSD/BACT
hours,
Operating
Fuel Btu
Yes
Fuel usage, operating
PSD/BACT
hours,
Under
Fuel Btu
Review
Explanation
If 3 if yr. >20
avg.
minutesC.F.>10%
fuel usage, water/fuel
fuel usage,Btu,
ratio,
NSPS
water usage,
Const.
oper. Initiated
Hrs
NSPS
Under Review
Netting
Under Review
Yes
Yes
Fuel usage, operating
NSPS hours,
Const.
Fuel Btu
Pending
NSPS
Operating
EXHIBIT 3
This exhibit is a computer disk containing
the Microsoft Excel spreadsheet printed in
Exhibit 2.
EXHIBIT 4
Explanation of Certain Columns in Exhibit 1
Spreadsheet
Column 7:
Identifies whether the site is an existing site,
i.e.
, the site already
has electric generating units (EGUs) located there, or a new site,
i.e.
, the site has never been used for EGUs previously.
Column 10: Identifies the type of permit: construction (C), operating (O), or
Title V.
Column 13: Identifies the date that the operating permit for the facility expires.
In most cases, the new EGUs are still operating under their
construction permits, which they may do for a period of time.
Column 15: Identifies the type of turbine: simple cycle turbine (“SCT”) or
combined cycle turbine (“CCT”). Note that the rows addressing
combined cycle turbine facilities are highlighted to make them
easily distinguishable from the simple cycle facilities. The Agency
left the two types of turbine facilities intermixed on this table so
that the Board could see more easily where simple cycle turbines
and combined cycle turbines are intermingled at a single site.
Column 16: Identifies the number of identical turbines located at the site. In
some instances, a site will have a number of turbines that are not
identical or where the conditions or other specifics for the turbines
are different, in which case the Agency has provided more than
one row for that facility. And example is Rows 23 through 25,
where there are a total of four turbines, but they are three different
types of turbines, as indicated in Columns 17 and 18.
Column 21: Identifies the type of NOx control employed at the turbine: dry
low NOx burners (“DLN”), water injection (“WI”), or selective
catalytic reduction (“SCR”). Heat recovery steam generators
(“HRSG”) are found only on combined cycle units and are
sometimes referred to as the waste heat boilers.
Column 25: Identifies the types of fuel for which the unit(s) is/are permitted.
Where a second fuel is indicated, it is the back-up fuel. “JP-4”
refers to jet fuel.
Column 26: Identifies whether the unit is a peaking unit or will operate as more
than a peaking unit. Operating “more than a peaking unit” means
that the unit may be a baseload unit, expected to run almost
continuously, or a cyclic unit that will run for longer periods of
time than a peaker but not to full baseload timeframes. These last
two types are generally the combined cycle units, and the table
identifies them as “base.” In actuality, the Agency is not provided
the information as to whether the owner/operator considers the unit
a baseload unit or some other cyclic unit, other than any
information provided that limits hours of operation. The Agency
has just called them all “base” for simplicity’s sake.
Column 39: Identifies the type of monitoring required if Part 75 monitoring is
not required. In some cases, the construction permit is not
sufficiently developed to determine the appropriate type of
monitoring to be required.
EXHIBIT 5
Due to the size of this exhibit, it is not
provided in this Adobe Acrobat file.