3EPA
United States
Environmental Protection
Agency
Office of Air and Radiation
Clean Air Markets Division
6204N
August, 2001
EPA-430-R-01-008
Acid Rain Program:
Annual Progress Report, 2000
Compliance and Emissions Trends
CLEANAIR
MARKET PROGRAMS
www.epa.gov/airmarkets
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Table of Contents
Page
Background 1
Multiple Benefits of Reducing Acid Rain 2
SO2 Program Compliance Results 5
• Deducting Allowances for Compliance 8
• Geographic Trends in Sulfur Dioxide Emissions 9
SO2 Allowance Market 11
NOX Program Compliance Results 13
• Geographic Trends in Nitrogen Oxide Emissions 17
SO2 and NOX Monitoring in 2000 19
Conclusion 21
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List of Exhibits
Page
1. Affected Sources under the Acid Rain Program 1
2. Sensitive Resources: Nitrogen-Saturated Forests, 4
Class I Areas, Acidic Surface Waters in Surveyed Regions
3. National SO2 Emissions Trend for All Acid Rain Program Affected Units 5
4. The SO2 Allowance Bank: Emissions and Allocations (1995-2000) 6
5. Origin of 2000 Allowable Emissions Level 7
6. SO2 Allowance Reconciliation Summary 8
7. Sulfur Dioxide Emissions from Power Generation: 9
State-level Bar Graph (1990, 1995-1999 Phase I Average, 2000)
8. Geographic and Temporal Trends in Sulfur Dioxide Emissions 10
from Power Generation (1990, 1995-1999 Phase I Average, 2000)
9. SO2 Allowance Price Indices 12
10. SO2 Allowances Transferred Under the Acid Rain Program 12
11. Phase IINOX Units by Boiler Type 14
12. Compliance Options Chosen in 2000 15
13. NOX Mass Emissions for Phase II Units 16
14. State-level Electrical Production (Heat Input): 1990, 1999, 2000 17
15. State-level Nitrogen Oxide Emissions from Power Generation: Bar Graphs 18
(1990, 1996-1999 Phase I Average, 2000)
16. Geographic and Temporal Trends in Nitrogen Oxide Emissions 19
from Power Generation (1990, 1996-1999 Phase I Average, 2000)
17. 2000 Relative Accuracy Test Audit (RATA) Results 20
18. 2000 Continuous Emissions Monitoring Systems (CEMS) Availability 20
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Acid Rain Program: Annual Progress Report, 2000
Page 1
BACKGROUND
The Acid Rain Program was established under Title IV of the 1990 Clean Air Act Amendments ("the
Act"). The program calls for major reductions of sulfur dioxide (SO2) and nitrogen oxides (NOX), the
pollutants that cause acid rain. Using a new, market-based approach to environmental protection, the
program sets a permanent cap on the total amount of SO2 that may be emitted by electric utilities
nationwide at about one half of the amount emitted in 1980, and allows flexibility for individual utility
combustion units to select their own methods of compliance. The program also sets NOX emission
limitations (in Ib/mmBtu) for certain electric utility boilers, representing about a 27 percent reduction
from 1990 levels. The Acid Rain Program is being implemented in two phases: Phase I ran from 1995
through 1999 for SO2 and from 1996 through 1999 for NOX; Phase II for both pollutants began in 2000
and involves over 2,000 units (Exhibit 1). In 2000, there were 2,262 units affected by the SO2
provisions of the Acid Rain Program, meaning they operated, submitted emissions data for SO2, and
were subject to annual reconciliation of allowable emissions with actual emissions. Additionally,
1,046 of these units were required to meet a NOX emissions limit under the Acid Rain Program
provisions.
Exhibit 1
Affected Sources under the Acid Rain Program
/ I I* •
-V
» Phase!
• Phase II
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Acid Rain Program: Annual Progress Report, 2000 Page 2
The SO2 component of the Acid Rain Program represents a dramatic departure from traditional
command and control regulatory methods that establish source-specific emissions limitations. Instead,
the program introduces a trading system for SO2 that facilitates lowest-cost emissions reductions and
an overall emissions cap that ensures the achievement and maintenance of the environmental goal. The
program features tradeable SO2 emissions allowances, where one allowance is a limited authorization
to emit one ton of SO2. Allowances may be bought, sold, or banked by utilities, brokers, or anyone else
interested in holding them. Existing utility units were allocated allowances for each future compliance
year and all participants of the program are obliged to surrender to EPA the number of allowances that
correspond to their annual SO2 emissions.
The NOX component of the Acid Rain Program uses a more traditional management approach, and
establishes an emission rate limit for certain types of coal-fired boilers. Flexibility is introduced to this
command and control measure, however, through compliance options such as emissions averaging,
whereby a utility can meet the standard emission limitations by averaging the emissions rates of two or
more boilers. This allows utilities to over-control at units where it is technically easier to control
emissions, thereby achieving emissions reductions at a lower cost. Additionally, certain Phase n units
elected to become subject to Phase I limits beginning in 1997. These early election units are not
subject to the more stringent Phase n limits until 2008.
At the end of each year, utilities must demonstrate compliance with the provisions of the Acid Rain
Program. For SO2, utilities are granted a 60-day grace period during which additional SO2 allowances
may be purchased, if necessary, to cover each unit's emissions for the year. At the end of the grace
period (the Allowance Transfer Deadline), the allowances a unit holds in its Allowance Tracking
System (ATS) account must equal or exceed the unit's annual SO2 emissions. Any remaining SO2
allowances may be sold or banked for use in future years. For the NOX portion of the program, utilities
must achieve an annual emission rate at or below mandated levels.
Multiple Benefits of Reducing Acid Rain
Acid deposition, or acid rain as it is commonly known, occurs when emissions of sulfur dioxide (SO2)
and oxides of nitrogen (NOX) react in the atmosphere (with water, oxygen, and oxidants) to form
various acidic compounds which then fall to earth in either wet form (rain, snow, and fog) or dry form
(gases and particles). Prevailing winds transport the compounds, sometimes hundreds of miles, across
state and national borders. SO2 and NOX gases and their particulate matter derivatives, sulfates and
nitrates, contribute to many negative environmental effects: air quality impairment and impacts to
public health, acidification of lakes and streams, damage to forest ecosystems, visibility degradation,
and acceleration of the decay of building materials, paints and cultural artifacts, including buildings,
statues, and sculptures.
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Acid Rain Program: Annual Progress Report, 2000
PageS
By reducing the pollutants that cause acid rain, significant environmental and health benefits are being
achieved.
:•>
1 m pro vt- air quality^
and public
acidified
lakes Mid streams
4
- Reduce damage to
forest a
* Protect historic
buildings and statues
from degradation
A,:
-
.
Exhibit 2 illustrates the geographic extent of multiple sensitive resources in the United States: nitrogen-
saturated forests (forests where excess nitrogen deposition has resulted in long-term changes in soil
chemistry, leading to nitrogen saturation; saturated, the soil can no longer retain nutrients, leaving
forests more vulnerable to the effects of air pollutants and other stresses); Class 1 areas (national parks,
forests and wilderness areas with stringent protection from visibility impairment); and acidic surface
waters in surveyed regions (lakes and streams with a poor capacity to neutralize acid deposition, i.e.,
with acid neutralizing capacity less than zero).
As illustrated, many of these sensitive resources affected by air pollution and acid deposition are found
in the same parts of the country: Northeast (Adirondacks), Mid-Atlantic (Mid-Appalachians),
Southeast (Great Smokies), Upper Midwest, and West (Cascades, Rocky Mountains, Colorado Front
Range), including mountain ranges in California (Klamath, San Bernardino and San Gabriel
mountains). The significant emission reductions occurring as a result of the Acid Rain Program are
expected to benefit many of these sensitive resources.
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Acid Rain Program: Annual Progress Report, 2000
Page 4
Exhibit 2
Sensitive Resources:
Nitrogen-Saturated Forests, Class I Areas,
Acidic Surface Waters in Surveyed Regions
Mountain* U/pr~r~
>" ColoradJ Front Rang*
San
Nitrogen Saturated Forests
Class I Areas (NFS, NFSh NFWS)
I I Acid-Sensitive Surface Waters
The Acid Rain Program's ultimate objective is to protect the environment and improve human health
by reducing both SO2 and NOx emissions. EPA believes these reductions will benefit the nation by:
Improving air quality and protecting public health
Restoring acidified lakes and streams so they can once again support fish and other aquatic life
Improving visibility, especially at scenic vistas in national parks
Reducing the damage to forests along the mountain ranges of the East coast
Protecting our historic buildings and monuments from degradation.
The first step in protecting the environment and human health from acid rain is reducing emissions.
The Acid Rain program is proving extremely effective in this regard. At the end of Phase I (1999), SO2
emissions from the 263 sources affected by Phase I were reduced 50 percent below 1990 levels; NOx
emissions were reduced about 32 percent below 1990 levels.
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Acid Rain Program: Annual Progress Report, 2000
Page 5
Starting in Phase n (2000), additional units are affected with more stringent SO2 emissions limitations
nationwide. NOx rates (i.e., the amount of NOx emitted per unit of coal used) were also reduced (to
between 0.40 and 0.86 Ibs/mmBtu, depending on the boiler type). In the first year of Phase II,
emissions continued to decline. In 2000, SO2 emissions from power generation were reduced by 1.25
million tons, and emissions of NOx were reduced by 380,000 tons, from the previous year.
SO2 PROGRAM COMPLIANCE RESULTS
All Title IV Units Reduce Overall Emissions by 29 Percent from 1990 Levels;
10 Percent from 1999 Levels
In the first year of Phase II, all Title IV sources achieved a total reduction in SO2 emissions of almost
29 percent, when compared to 1990 levels. Compared to 1999 levels, these units reduced their SO2
emissions by 10 percent or 1.25 million tons, while increasing their utilization by 2.7 percent. Exhibit 3
illustrates the trend in SO, emissions since 1980 for all affected units.
Exhibit 3
National SO2 Emissions Trend for All Acid Rain Program Affected Units
8
en
£
|
.1
20
18
w -
14 -
12
10
8
e
4 -
J
0
17.JO
16.09
15,73
Phase I Source*
Phase II Sources
All Affected Sources, 2000
11.87
12.51
• • • • • i
13.98
1J.1J
12,45
11.2(1
1980 1935
1990
1995 1996 1997 1999
1999 2000
: ADOVfitlKt* kWHtil fW 4111 lllttW I Mill III aTTtCt-Ml *
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Acid Rain Program: Annual Progress Report, 2000
Page 6
There were 2,262 operating units that underwent annual reconciliation for SO2 in 2000. (These units
are listed on our website at www.epa.gov/airmarkets/cmprpt/arpOO/index.html in Appendix A).
The allowances (i.e., authorizations to emit SO2) allocated in a particular year to each source are
determined by several provisions of the Act. For the year 2000, a total of 9.97 million allowances were
granted. However, as a result of sources emitting less than their allowance allocations during 1995
through 1999, 11.62 million allowances were saved (or banked). Coupled with the 9.97 million
allowances granted in 2000 by the Act, a total of 21.58 million allowances were available for use in
2000. Nevertheless, sources emitted only 11.2 million tons in 2000. However, this was 1.2 million
tons more than the allowances granted in 2000, so the bank declined by 1.2 million allowances.
(Exhibit 4). The bank is expected to decrease as sources use up these banked allowances to comply
with the more stringent Phase II requirements.
Exhibit 4
The SO2 Allowance Bank: Emissions and Allocations (1995-2000*)
15
-5
Al Nitwit ii m
missions
FA Ira
Reductions
Bank
C199S
K.7
3.4
11996
8.3
5.4
1199-
5.5
S
11998
1.7
9.6
• 1WW
J2000
-1.9
11.6
9.JI7
11.2
-123
10JS
*1!W 1CW; Pbatr [ wurct* only:
20WJ: lncliultt liodi Pliast I aid II MUITCI
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Acid Rain Program: Annual Progress Report, 2000
Page 7
Exhibit 5 explains in more detail the origin of the allowances available for use in the year 2000.
Exhibit 5
Origin of 2000 Allowable Emissions Level
Type of Allowance Allocation
Initial Allocation
Early Reduction Credits
Allowances for Substitution Units
Allowance Auctions
Opt-in Allowances
Small Diesel Allowances
TOTAL 2000 ALLOCATION
BANKED ALLOWANCES
Conservation and Renewable
Energy Allowances
TOTAL 2000 ALLOWABLE
Number of
Allowances
9,166,614'
416,989
10,636
250,000
97,824
24,468
9,966,531
11,607,955
9,054
21,583,540
Explanation of Allowance Allocation Type
Initial Allocation is the number of allowances granted to units
based on the product of their historic utilization and emissions
rates (performance standards) specified in the Clean Air Act
and other provisions of the Act.
Early Reduction Credit allowances were given to eligible Phase
II units for voluntary emissions reductions made between
January 1, 1995 and January 1, 2000.
A lawsuit settlement allowed for a small amount of allowances
to be allocated for Substitution Units in 2000 instead of an
earlier year during Phase I.
Allowance Auctions provide allowances to the market that were
set aside in a Special Allowance Reserve when the initial
allowance allocation was made.
Opt-in Allowances are provided to units entering the program
voluntarily. There were 1 1 opt-in units in 2000.
Small Diesel Allowances were allocated annually to small
diesel refineries that produced and desulfurized diesel fuel
during the previous year. These allowances were earned in
1999, which was the last year of the small diesel program.
Banked Allowances are those held over from 1995 through
1999 which can be used for compliance in 2000 or any future
year.
These allowances come from a special reserve set aside when
the initial allowance allocation was made. They are awarded to
utilities that undertake efficiency and renewable energy
measures. These are year 1999 allowances that were allocated
in year 2000.
1 The total year 2000 initial allocation was 9,191,897. A total of 25,283 allowances were surrendered by units that
exceeded their 1999 Phase I Extension projected emissions limit, and were subject to Phase I substitution unit provisions.
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Acid Rain Program: Annual Progress Report, 2000 Page 8
Deducting Allowances for Compliance
The total number of allowances deducted in 2000 was 11,202,053. Because a few sources did not hold
enough allowances in their allowance tracking system unit accounts to cover their emissions for the
2000 compliance year, 54 year 2001 allowances were taken as "offsets"and included in the total. In
addition to the offsets, the operators of these six units were assessed automatic monetary penalties
totaling $144,828.J Exhibit 6 displays these allowance deductions, as well as the remaining bank of
1995 through 2000 allowances.
Exhibit 6
SO2 Allowance Reconciliation Summary
Total Allowances Held in Accounts as of 3/1/2001 (1995 through 2000 Vintages)1
Unit Accounts
General Accounts2
Allowances Deducted for Emissions (1995 through 2000)
2001 Penalty Allowances Deducted
Banked Allowances
Unit Accounts
General Accounts2
21,583,540
15,753,910
5,829,630
11,201,999
54
10,381,541
4,551,911
5,829,630
1 The number of allowances held in the Allowance Tracking System (ATS) accounts equals the number of 2000 allowances
allocated (see Exhibit 5) plus the number of banked allowances. March 1, 2001 represents the Allowance Transfer
Deadline, the point in time at which unit accounts are frozen and after which no transfers of 1995 through 2000 allowances
will be recorded. The freeze on these accounts is removed when annual reconciliation is complete.
2 General accounts can be established in the ATS by any utility, individual or other organization.
At an individual unit, the number of allowances surrendered was equal to the number of tons emitted at
the unit, except where the unit shared a common stack with other units. For the purposes of
surrendering allowances for emissions at a common stack, the utility was allowed to choose the
proportion of allowances deducted from each unit sharing the stack, as long as enough allowances were
surrendered to cover the total number of tons emitted. If no apportionment was made, EPA deducted
allowances equally among the units sharing the stack to cover total emissions reported by the stack.
1A source that does not hold enough allowances in its unit account to cover its annual SO2 emissions has "excess
emissions" and must pay a $2000 per ton automatic penalty. The $2000 penalty is adjusted annually for inflation, so the
year 2000 penalty was $2,682. Total year 2000 monetary penalty = 54 tons of excess emissions x $2,682 per ton =
$144,828.
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Acid Rain Program: Annual Progress Report, 2000
Page 9
Appendix A reflects the deductions for emissions at each unit after the common stack apportionment
was made. Units sharing a common stack are listed directly under the entry for their common stack.
Geographic Trends in Sulfur Dioxide Emissions
Total sulfur dioxide emissions from power generation have decreased significantly from 1990 levels,
and continue to decline in 2000, the first year of Phase II. Exhibit 7 displays state-level bar graphs
illustrating SO2 emission trends from power generation before the Acid Rain Program (1990), during
Phase I (1995-1999 average), and in Phase II (2000).
Exhibit 7
Sulfur Dioxide Emissions from Power Generation:
State-level Bar Graph (1990,1995-1999 Phase I Average, 2000)
ftate Level £03 Emissions
\****
199S 1999 Phase I (SO?) Average
| Ctate* with lower SOl
(MTU Iff* level! fcVd Hie 1995-1PTT Pliase 1
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Acid Rain Program: Annual Progress Report, 2000
Page 10
Several geographic trends are shown:
The bar graphs illustrate that total SO2 emissions, as well as the greatest reductions, are
largely taking place in the Midwest;
The states colored yellow represent states with lower SO2 emissions in Phase II (2000),
as compared to both 1990 levels and the 1995-1999 Phase I average. Unlike the SO2
emission reductions achieved during Phase I which occurred predominantly in the
Eastern U.S. (since Phase I affected the larger, higher emitting utilities in the Eastern
half of the country), these Phase n reductions are geographically more widespread,
occurring in a larger number of Western states.
Exhibit 8
Geographic and Temporal Trends in Sulfur Dioxide Emissions from Power Generation
(1990,1995-1999 Phase I Average, 2000)
Phase I Average
State LevelUtUtty *OiXmtnluii
(thouand tool)
Ixn tlinn )»«
)•*-•«•
12M-1M*
Exhibit 8 illustrates the geographic and temporal trends in state-level sulfur dioxide emissions from
power generation before the Acid Rain Program (1990), during Phase I (1995-1999 average), and in
Phase II (2000).
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Acid Rain Program: Annual Progress Report, 2000 Page 11
In 2000, Title IV sources achieved a 29 percent reduction from 1990 SO2 levels nationwide. As
illustrated in Exhibit 8, although most SO2 emissions occur in the Midwestern U.S., it is important to
note that over time, this same region has also seen the most significant decrease in SO2 emissions in the
country. The highest SO2 emitting states in 1990 (Ohio, Indiana, and Pennsylvania), have achieved an
average reduction of almost 40 percent in 2000 (45 percent, 42 percent, and 23 percent, respectively),
as compared to 1990 levels. Other states in the region are showing similar trends: Illinois (52 percent),
Kentucky (35 percent), Missouri (71 percent), Tennessee (47 percent) and West Virginia (39 percent),
have achieved an average reduction of almost 50 percent since 1990.
SO, ALLOWANCE MARKET
The flexibility provided by the Acid Rain Program enable the 2,262 units subject to the SO2
requirements in 2000 to pursue a variety of compliance options to meet their SO2 reduction obligations,
including scrubber installation, fuel switching, energy efficiency and allowance trading. The presence
of the allowance market has given some sources the incentive to reduce their SO2 emissions below the
level of their allowance allocation in order to bank their allowances for use in future years. Other
sources have been able to postpone and possibly avoid expenditures for control by acquiring
allowances from sources that controlled below their allowance allocation level. The flexibility in
compliance options is possible because of the accountability provided through strict monitoring
requirements for all affected units that ensure one allowance is equivalent to one ton of SO2. The
program's flexibility significantly reduced the cost of achieving these emissions reductions as
compared to the cost of a technological mandate.
The marginal cost of reducing a ton of SO2 from the utility sector should be reflected in the price of an
allowance. The cost of reductions continues to be lower than anticipated when the Clean Air Act
Amendments were enacted, and the price of allowances reflects this. The cost of compliance was
initially estimated at $400-1000/ton, however during 2000, SO2 allowances ranged in price from
$130/ton to $155/ton. At the time of the allowance auction, allowances were approximately $135/ton.
The price rose through June, peaking at $155/ton. During the second half of 2000, prices dropped
down to $130/ton but showed signs of a rebound at the very end of the year. Some market observers
believe lower than expected allowances prices during the first several years of the program were due
primarily to lower than expected compliance costs and larger than expected emissions reductions,
which have increased the supply of allowances and put downward pressure on prices. Additionally,
Phase IFs more stringent limits most likely fueled the end-of-year price increases as sources realized
they would have to withdraw from the bank to comply. Exhibit 9 displays the price trend since mid-
1994, based on monthly price reports from Cantor Fitzgerald Environmental Brokerage Services, and a
market survey conducted by Fieldston Publications.
The level of activity in the allowance market created under the Acid Rain Program increased in 2000
compared to earlier years, with the increase in the number of sources required to comply with Phase U
of the program.
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Acid Rain Program: Annual Progress Report, 2000
Page 12
Exhibit 9
SCK Allowance Price Indices
•Fieldston Publications Price Index —Cantor Fitzgerald Market Price Index
250
o> o> o>
CO OJ CO
O) O) O) O) O) O) O) O) O O
oacooacooacooacocNico
Month/Year
In 2000, 4,690 allowance transfers were recorded in the Allowance Tracking System, the accounting
system developed to track holdings of allowances, moving about 30 million allowances. Of the
allowances transferred, 12.7 million, or 42 percent, were transferred in economically significant
transactions, i.e. between unrelated parties. Exhibit 10 shows the volume of SO2 allowances traded
under the Acid Rain Program since official recordation of trades began in 1994. The majority of the
allowances transferred in economically significant transactions were acquired by utilities. Trades
between unaffiliated utilities accounted for approximately 7 million allowances.
Exhibit 10
SO2 Allowances Transferred Under the Acid Rain Program
1994 1995 1996 1997 1998 1999 2000
• Between Economically Related Organizations
• Between Economically Unrelated Organizations
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Acid Rain Program: Annual Progress Report, 2000 Page 13
All transactions, along with data on account balances and ownership, are posted on the Clean Air
Markets Division's Internet site (www.epa.gov/airmarkets) on a daily basis in order to better inform
trading participants. Also available are cumulative market statistics and analysis.
NOX PROGRAM COMPLIANCE RESULTS
Instead of using allowance trading to facilitate emissions reductions, the Title IV NOX program
establishes standard emission limitations for certain affected units. Title IV of the 1990 Clean Air Act
Amendments required EPA to establish NOX annual average emission limits (in pounds of NOX per
million British thermal units of fuel consumed (Ib/mmBtu)) for coal-fired electric utility units. The
NOX program was implemented in two phases.
In April 1995, EPA published regulations which established NOX emission limits beginning on January
1, 1996 for Group 1 boilers that were also part of the Phase I SO2 program (Group 1 boilers are dry
bottom, wall-fired boilers and tangentially-fired boilers). From 1996 through 1999, Phase I dry bottom
wall-fired boilers were subject to a NOX emission limit of 0.50 Ib/mmBtu and Phase I tangentially-fired
boilers were subject to a NOX emission limit of 0.45 Ib/mmBtu annually.
In addition, the April 1995 regulations allowed Phase II Group 1 units to use an "early election"
compliance option. Under this regulatory provision, Phase U Group 1 NOX affected units meet the
higher Phase I limits for their boiler type from 1997 through 2007. In return for meeting this limit
three years earlier than they would be required to meet the Phase II limit, early election units do not
become subject to the more stringent Phase U limits until 2008. If a utility fails to meet this annual
limit for the boiler during any year, the unit is subject to the more stringent Phase II limit for Group 1
boilers beginning in 2000, or the year following the exceedance, whichever is later.
In December 1996, EPA established the NOX emission limits for Phase U Group 1 boilers and for
Group 2 boilers (cell burner, cyclone, wet bottom, and vertically-fired boilers) that apply beginning on
January 1, 2000. As a result of the April 1995 and December 1996 regulations, NOX reductions were
projected to be approximately 400,000 tons per year in 1996 through 1999 (Phase I), and 2 million tons
per year in 2000 and subsequent years (Phase U) below what the emissions would have been without
the Acid Rain Program.
There were 1,046 units subject to NOX emissions limitations in 2000. Exhibit 11 shows the number of
NOX affected units by boiler type.
For each NOX affected unit, a utility can comply with the applicable standard emission limitation, or
may participate in two additional compliance options which add flexibility to the rate-based
compliance requirements:
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Acid Rain Program: Annual Progress Report, 2000
Page 14
\ Emissions Averaging. A utility can meet the standard emission limitation by averaging the
heat-input weighted annual emission rates of two or more units.
! Alternative Emission Limitation (AEL). A utility can petition for a less stringent alternative
emission limitation if it uses the properly installed and operated NOX emissions reduction
technology prescribed for that boiler, but cannot meet its standard limit. EPA determines
whether an AEL is warranted based on analyses of emissions data and information about the
NOX control equipment.
Exhibit 12 summarizes the compliance options chosen by NOX affected units for 2000. Averaging was
the most widely chosen compliance option, with 53 averaging plans involving 645 units in 2000. See
Appendix B-2 for a list of averaging plans and results in 2000.
For 2000, 1,045 NOX units met the required emission limit through compliance with either the standard
emission limitation (including units that early elected), emissions averaging, or an alternative emission
limitation. (See Appendix B-l: Compliance Results for NOX Affected Units. For a more detailed
description of EPA's methodology for determining unit compliance with NOX limits, see Appendix B-
3: Description of NOX Compliance Assessment Methodology.)
Exhibit 11
Phase II NOX Units by Boiler Type
Boiler Type
Phase I Group 1 Tangentially-fired
Phase I Group 1 Dry Bottom Wall-fired
Phase n Group 1 Tangentially-fired
Phase n Group 1 Dry Bottom Wall-fired
Cell Burners
Cyclones> 155 MW
Wet Bottom > 65 MW
Vertically-fired
Standard
Emission
Limit
0.45
0.50
0.40
0.46
0.68
0.86
0.84
0.80
Total
Number
of Units
135
130
304
312
37
56
31
41
1,046
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Acid Rain Program: Annual Progress Report, 2000
Page 15
Only one unit failed to meet its emissions limit in 2000. This unit had NOX excess emissions of 58
tons and was assessed a monetary penalty of $155,556 (58 tons x $2,682 per ton penalty).
Exhibit 12
Compliance Options Chosen in 2000
Compliance Option
Standard Emission Limitation
Early Election
Emissions Averaging
Alternative Emission Limitation
TOTAL
Number of Units
133
274
645
27
1,079J
1 The numbers of units do not add to 1,046 because 29 units must meet both early election
and emissions averaging limits, and 4 units must meet both AEL and emissions averaging limits.
NOX Mass Emissions Reductions Exceed Goal by One Million Tons:
Phase II Units Reduced Overall NOx Emissions by 23 Percent from 1990 Levels;
7 Percent from 1999 Levels
Total NOX emissions from all Title IV affected units were three million tons below what they would
have been without the Acid Rain Program in 2000, easily surpassing the goal of a two million ton
reduction. Exhibit 13 illustrates the change in NOX mass emissions since 1990 for all affected units.
For the 2,262 Phase II units, total NOX mass emissions in 2000 were 1.55 million tons or 23.3 percent
lower than in 1990, and 0.38 million tons or 6.9 percent lower than in 1999.
These reductions have been achieved while electrical production, as measured by heat input, has
increased 30 percent since 1990 and 2.7 percent compared to 1999. As illustrated in Exhibit 14, many
states with increasing electrical production have also decreased total NOX emissions in 2000, as
compared to 1990 levels. Without further reductions in emissions rates, though, NOX emissions would
be expected to rise with increased utilization.
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Acid Rain Program: Annual Progress Report, 2000
Page 16
Exhibit 13
NOX Mass Emissions for Phase II Units
D Phase II Units Not Affected for NOi
• Phase II NOi Affected Units (1,046 )
"' Projected NQx Without Title IV
"*"?!
5,11
Mmsm
1990 1985 1996 1997 1998 1989 2000
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Acid Rain Program: Annual Progress Report, 2000
Page 17
Exhibit 14
State-level Electrical Production (Heat Input): 1990,1999, 2000
State Level Heat Input
Iff*
States with Increasing electrical production
and decreasing MOx in 2.OOO, HE compared to If fO.
Geographic Trends in Nitrogen Oxide Emissions
Total nitrogen oxide emissions from Title IV sources have decreased 23 percent since 1990. Exhibit
15 displays state-level bar graphs illustrating NOX emission trends from power generation before the
Acid Rain Program (1990), during Phase I (1996-1999 average), and in Phase II (2000).
Several geographic trends are shown:
The bar graphs illustrate that in the first year of Phase II, many states have reduced NOX
emissions from 1990 levels, with the greatest reduction occurring in the Eastern United States;
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Acid Rain Program: Annual Progress Report, 2000
Page 18
Exhibit 15
State-level Nitrogen Oxide Emissions from Power Generation: Bar Graphs
(1990,1996-1999 Phase I Average, 2000)
State Level NOx Emission*
|ltt«
Phase I (NOx) Average
Stain with lower NO* in
at«oup*red to both Iff* levels
the
Phase I Average
The states colored yellow represent states with lower NOX emissions in Phase n (2000), as
compared to both 1990 levels and the 1996-1999 Phase I average. Like SO2, during Phase I, the
majority of NOX reductions occurred predominantly in the Eastern U.S. However, the Phase II
reductions are geographically more extensive, occurring in a larger number of Western states.
As illustrated in Exhibit 16, in 1990, the greatest NOX emissions occurred in the Midwestern, Mid-
Atlantic and Southern regions of the U.S. In 2000, many of these states have significantly reduced
emissions from 1990 levels. The highest emitting states in 1990 (Ohio, Texas, and Pennsylvania),
have achieved an average reduction of about 32 percent (30 percent, 16 percent, and 51 percent,
respectively) in 2000. Other states in the region are showing similar trends: Indiana (21 percent),
Kentucky (29 percent), Tennessee (34 percent) and West Virginia (23 percent), have achieved an
average reduction of 27 percent since 1990.
-------
Acid Rain Program: Annual Progress Report, 2000
Page 19
Exhibit 16
Geographic and Temporal Trends in Nitrogen Oxide Emissions from Power Generation
(1990,1996-1999 Phase I Average, 2000)
Iff **Ift9 Miaae t Average
****
Uldlily NO« Knixxioni
nad te«O
L***lh#rt I**
***- 3**
SO, AND NOY MONITORING IN 2000
In order to verify the reductions of SO2 and NOX emissions mandated under the Act and to support the
SO2 allowance trading program, a fundamental objective of the Acid Rain Program is to ensure
accurate accounting of all pollutant emissions from all affected boilers and turbines. To implement
this objective, concentrations and mass emissions of SO2 and NOX from each affected unit are
measured and recorded using Continuous Emissions Monitoring Systems (CEMS) (or an approved
alternate measurement method) certified by EPA to meet the high accuracy standards of the Acid Rain
Program.
SO2 mass emissions are determined using CEMS to measure SO2 concentration and stack flow rate.
NOX emission rates, on the other hand, are determined with NOX and diluent gas (CO2 or O2)
concentration monitors. These monitors are required to meet strict initial and on-going performance
standards to demonstrate the accuracy, precision, and timeliness of their measurement capability.
-------
Acid Rain Program: Annual Progress Report, 2000
Page 20
One measure of the accuracy of a CEMS is the relative accuracy test audit (RATA), which is required
for initial certification of a CEMS and for on-going quality assurance. The RATA ensures that the
installed monitor measures the "true" value of the pollutant by comparing the monitor to a reference
method which simultaneously measures the stack gas pollutant. Thus, the lower the relative accuracy
resulting from the test audit, the more accurate the monitor. All monitoring systems must meet a
certain relative accuracy standard in order to be qualified to report emissions to the Acid Rain
Program. Because the RATA determines relative accuracy as an absolute value, it does not detect
whether the difference between the reference method values and the readings from the CEMS being
tested is due to random error or to systematic bias. Therefore, an additional test, the bias test, is
required to ensure that emissions are not underestimated. This test determines if the CEMS is
systematically biased low compared to the reference method and if so, a bias adjustment factor is
calculated and applied to all reported data from that monitoring system to ensure there is no systematic
underreporting. Exhibit 17 highlights the relative accuracy results achieved by Acid Rain CEMS in
2000.
Exhibit 17
2000 Relative Accuracy Test Audit (RATA) Results
Mean Relative Accuracy
Median Relative Accuracy
Percent Meeting Relative Accuracy
Standard
SO2 Concentration
3.65%
2.84%
96.6%
Volumetric Flow
Rate
3.30%
2.69%
98.6%
NOX Rate
4.22%
3.36%
94.9%
Another metric used to determine the effectiveness of a CEMS is the percentage of hours that a monitoring
system is operating properly and meeting all performance standards and therefore, able to record and report
an emissions value. This metric is defined as the percent monitor availability (PMA). Exhibit 18 shows
the monitor availabilities reported in 2000 and indicates that the CEMS used to determine SO2 mass
emissions and NOX emission rates are well maintained and fulfilling the high performance standards
required by the Acid Rain Program.
Exhibit 18
2000 CEMS Availability
Parameter
SO2
Flow
NOX
Median % Availability at End of 2000
Coal-Fired Units
99.5
99.6
99.2
Oil and Gas Units
98.7
99.2
98.2
-------
Acid Rain Program: Annual Progress Report, 2000
Page 21
CONCLUSION
Both SO2 and NOX emissions declined in the first year of Phase II of the Acid
Rain Program. Phase n sources continue to close in on the 10 million ton
reduction of SO2 emissions and exceeded the goal of a two million ton
reduction of NOX emissions by a sizeable margin.
In 2000, SO2 emissions fell, however the use of allowances saved by sources
from emitting less than required in Phase I resulted in SO2 emissions higher
than the year 2000 allowance allocations. This was both expected and allowed,
due to the substantial early reductions achieved in Phase I. EPA expects Phase n sources to continue to
use up the bank of allowances over the next several years, and to achieve the goal of an annual 10 million
ton reduction from 1980 levels by 2010.
NOX emissions in 2000 were an impressive three million tons below what emissions would have been
without the Acid Rain Program. Furthermore, the implementation of regional NOX cap-and-trade
programs (i.e., the NOX Budget Program in the Ozone Transport Region and the NOX SIP Call2) are
changing expectations concerning future emissions levels. EPA's expectation had been that over time,
NOX emissions would gradually rise due to increasing electricity production. However, because of the
eastern regional cap, it now appears that nationwide NOX emissions may decline over the next several
years as the NOX SIP call is implemented, and then remain stable or rise more slowly as energy demand
continues to grow and new sources continue to be built.
For additional detailed emissions data see http://www.epa.gov/airmarkets/emissions/scoreOO/index.html
For more information on these regional NOx reduction programs, visit http://www.epa.gov/airmarkets.
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
PLANT NAME
Barry
Barry
Barry
Barry
Barry
Barry
Barry
Barry
Charles R Lowman
Charles R Lowman
Charles R Lowman
Chickasaw
Colbert
Colbert
Colbert
Colbert
Colbert
Colbert
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
Gadsden
Gadsden
General Electric Company
Gorgas
Gorgas
Gorgas
Gorgas
Gorgas
Gorgas
Gorgas
Greene County
Greene County
Greene County
Greene County
Greene County
Greene County
Greene County
Greene County
Greene County
PLANT
CODE
3
3
3
3
3
3
3
3
56
56
56
5
47
47
47
47
47
47
26
26
26
26
26
26
26
7
7
7698
8
8
8
8
8
8
8
10
10
10
10
10
10
10
10
10
STACK/UNIT ID*
CSOAAN (1 , 2, 3)
1
2
3
4
5
6A
6B
1
2
3
110
CSCO14(1,2, 3, 4)
1
2
3
4
5
CSOCAN (1 , 2)
1
2
CSOCBN (3, 4)
3
4
5
1
2
CC1
5
CSODAN (6, 7)
6
7
8
9
10
1
2
CT2
CT3
CT4
CT5
CT6
CT7
CT8
2000
ALLOWANCES
ALLOCATED
3,882
4,292
8,811
10,051
24,836
0
0
1,853
7,026
5,895
111
5,854
6,602
6,641
6,646
16,033
7,805
7,996
7,896
8,313
25,805
1,957
2,024
0
1,756
3,036
3,139
4,759
4,747
22,443
8,488
7,923
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
6,490
6,854
10,205
15,429
26,644
10
10
7,502
7,061
7,296
111
19,006
28,600
29,814
31 ,580
53,216
26,699
31 ,283
25,750
37,572
82,427
5,385
6,055
10
1,756
12,026
10,082
10,571
9,166
34,062
24,800
25,109
100
100
100
100
100
100
100
ALLOWANCES
DEDUCTED
6,065
6,406
9,537
14,420
24,901
1
2
3,174
6,400
6,635
0
6,291
6,405
6,379
6,661
44,455
18,188
18,685
20,170
17,904
42,910
5,033
4,705
2
0
11,146
9,422
9,879
8,638
31,830
23,619
23,914
41
30
42
50
30
48
21
ALLOWANCES
CARRIED OVER
TO 2001
425
448
668
1,009
1,743
9
8
4,328
661
661
111
12,715
22,195
23,435
24,919
8,761
8,511
12,598
5,580
19,668
39,517
352
1,350
8
1,756
880
660
692
528
2,232
1,181
1,195
59
70
58
50
70
52
79
A, 1
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AZ
AZ
AZ
PLANT NAME
Greene County
Greene County
James H Miller Jr
James H Miller Jr
James H Miller Jr
James H Miller Jr
Mclntosh
Mclntosh
Mclntosh
Mcwilliams
Washington County Cogen (Olin)
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Carl Bailey
Cecil Lynch
Cecil Lynch
Cecil Lynch
Flint Creek
Hamilton Moses
Hamilton Moses
Harvey Couch
Harvey Couch
Independence
Independence
Lake Catherine
Lake Catherine
Lake Catherine
Lake Catherine
Mcclellan
Robert E Ritchie
Robert E Ritchie
Thomas Fitzhugh
White Bluff
White Bluff
Agua Fria
Agua Fria
Agua Fria
PLANT
CODE
10
10
6002
6002
6002
6002
7063
7063
7063
533
7697
50
50
50
50
50
50
50
50
50
202
167
167
167
6138
168
168
169
169
6641
6641
170
170
170
170
203
173
173
201
6009
6009
141
141
141
STACK/UNIT ID*
CT9
CT10
1
2
3
4
"1
**2
**3
**4
CC1
2000
ALLOWANCES
ALLOCATED
0
0
14,217
17,769
17,422
8,049
938
0
0
0
0
CSWC16(1,2, 3, 4, 5, 6)
1
2
3
4
5
6
7
8
01
1
2
3
1
1
2
1
2
1
2
1
2
3
4
01
1
2
1
1
2
1
2
3
3,340
3,212
3,356
3,454
3,565
3,279
7,805
7,460
10
0
0
3
15,192
0
0
7
112
18,155
18,401
0
0
8
156
15
53
2,148
1
20,940
23,900
54
65
77
HELD IN
ACCOUNTS AS
OF 3/1/2001
100
100
17,558
17,769
17,422
18,134
503
5
5
5
10
5,340
6,212
5,856
4,954
5,065
6,779
11,005
12,460
310
0
1
2
15,192
2
2
2
3
14,574
17,844
2
2
4
6
2,115
6
2,153
601
22,378
20,640
54
65
77
ALLOWANCES
DEDUCTED
47
49
16,409
16,375
15,460
16,948
0
0
1
1
3
4,647
5,854
5,278
4,137
4,810
6,576
10,390
1 1 ,054
263
0
0
0
12,863
0
0
0
1
10,609
1 1 ,252
0
0
1
4
1,641
2
5
145
19,679
18,593
18
22
33
ALLOWANCES
CARRIED OVER
TO 2001
53
51
1,149
1,394
1,962
1,186
503
5
4
4
7
693
358
578
817
255
203
615
1,406
47
0
1
2
2,329
2
2
2
2
3,965
6,592
2
2
3
2
474
4
2,148
456
2,699
2,047
36
43
44
A, 2
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
PLANT NAME
Apache Station
Apache Station
Apache Station
Cholla
Cholla
Cholla
Cholla
Cholla
Coronado
Coronado
De Moss Petrie
Gila Bend
Gila Bend
Gila Bend
Gila Bend
Irvington
Irvington
Irvington
Irvington
Kyrene
Kyrene
Navajo
Navajo
Navajo
Ocotillo
Ocotillo
Saguaro
Saguaro
Springerville
Springerville
Springerville
West Phoenix
West Phoenix
Yuma Axis
AES Alamitos, LLC
AES Alamitos, LLC
AES Alamitos, LLC
AES Alamitos, LLC
AES Alamitos, LLC
AES Alamitos, LLC
AES Huntington Beach, LLC
AES Huntington Beach, LLC
AES Huntington Beach, LLC
AES Huntington Beach, LLC
PLANT
CODE
160
160
160
113
113
113
113
113
6177
6177
124
923
923
923
923
126
126
126
126
147
147
4941
4941
4941
116
116
118
118
8223
8223
8223
117
117
120
315
315
315
315
315
315
335
335
335
335
STACK/UNIT ID*
1
2
3
1
2
3
4
**5
U1B
U2B
4
**GT1
**GT2
"GTS
**GT4
1
2
3
4
K-1
K-2
1
2
3
1
2
1
2
1
2
3
4
6
1
1
2
3
4
5
6
1
2
3
4
2000
ALLOWANCES
ALLOCATED
331
1,609
3,011
2,223
5,443
5,147
8,334
0
5,733
5,903
0
0
0
0
0
16
28
0
2,854
7
18
26,220
24,262
25,042
56
132
204
25
6,566
5,756
0
11
22
42
2,775
105
290
819
4,227
1,484
1,325
1,134
161
176
HELD IN
ACCOUNTS AS
OF 3/1/2001
11
3,417
3,223
945
1,528
9,355
8,334
0
10,052
9,409
0
0
0
0
0
2
3
5
3,816
46
46
3,458
3,451
3,451
7
5
161
3
10,051
1 1 ,048
0
0
0
42
51
1
3
13
76
23
26
21
0
0
ALLOWANCES
DEDUCTED
1
3,411
3,157
859
1,389
8,378
7,270
0
10,051
9,409
0
0
0
0
0
1
1
1
3,415
45
46
1,206
1,687
1,944
5
1
144
1
9,036
10,013
0
0
0
12
0
1
3
4
6
5
2
3
0
0
ALLOWANCES
CARRIED OVER
TO 2001
10
6
66
86
139
977
1,064
0
1
0
0
0
0
0
0
1
2
4
401
1
0
2,252
1,764
1,507
2
4
17
2
1,015
1,035
0
0
0
30
51
0
0
9
70
18
24
18
0
0
A, 3
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
PLANT NAME
AES Redondo Beach, LLC
AES Redondo Beach, LLC
AES Redondo Beach, LLC
AES Redondo Beach, LLC
AES Redondo Beach, LLC
AES Redondo Beach, LLC
AES Redondo Beach, LLC
AES Redondo Beach, LLC
AES Redondo Beach, LLC
AES Redondo Beach, LLC
AES Redondo Beach, LLC
Almond Power Plant
Alta (Cool Water)
Alta (Cool Water)
Alta (Cool Water)
Alta (Cool Water)
Alta (Cool Water)
Alta (Cool Water)
Anaheim Combustion Turbine
Avon
Avon
Avon
Broadway
Broadway
Broadway
Cabrillo Power 1 LLC (Encina)
Cabrillo Power 1 LLC (Encina)
Cabrillo Power 1 LLC (Encina)
Cabrillo Power 1 LLC (Encina)
Cabrillo Power 1 LLC (Encina)
Cabrillo Power 1 LLC (Encina)
Carson Cogeneration
Carson Cogeneration
Contra Costa
Contra Costa
Contra Costa
Contra Costa
Contra Costa
Contra Costa
Contra Costa
Contra Costa
Contra Costa
Contra Costa
Duke Energy Morro Bay LLC
PLANT
CODE
356
356
356
356
356
356
356
356
356
356
356
7315
329
329
329
329
329
329
7693
216
216
216
420
420
420
302
302
302
302
302
302
7527
7527
228
228
228
228
228
228
228
228
228
228
259
STACK/UNIT ID*
5
6
7
8
11
12
13
14
15
16
17
1
1
2
31
32
41
42
1
1
2
3
B1
B2
B3
CS0001 (1 , 2, 3, 4, 5)
1
2
3
4
5
1
2
1
2
3
4
5
6
7
8
9
10
1
2000
ALLOWANCES
ALLOCATED
80
105
554
597
36
0
0
0
0
0
0
0
10
6
0
0
0
0
0
17
0
0
127
164
74
491
1,131
737
1,946
2,495
0
0
125
2
0
0
0
0
28
53
356
4,286
1,561
HELD IN
ACCOUNTS AS
OF 3/1/2001
2
2
11
13
0
0
0
0
0
0
0
20
2
2
2
2
4
4
0
0
0
0
27
27
26
0
0
0
1
160
15
5
0
0
0
0
0
0
0
0
30
4
12
ALLOWANCES
DEDUCTED
1
1
5
3
0
0
0
0
0
0
0
1
1
1
1
1
2
2
0
0
0
0
0
0
2
0
0
0
0
61
1
0
0
0
0
0
0
0
0
0
4
4
2
ALLOWANCES
CARRIED OVER
TO 2001
1
1
6
10
0
0
0
0
0
0
0
19
1
1
1
1
2
2
0
0
0
0
27
27
24
0
0
0
1
99
14
5
0
0
0
0
0
0
0
0
26
0
10
A, 4
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
PLANT NAME
Duke Energy Morro Bay LLC
Duke Energy Morro Bay LLC
Duke Energy Morro Bay LLC
Duke Energy South Bay LLC
Duke Energy South Bay LLC
Duke Energy South Bay LLC
Duke Energy South Bay LLC
El Centra
El Centra
El Centra
El Segundo
El Segundo
El Segundo
El Segundo
Glenarm
Glenarm
Grayson
Grayson
Harbor Gen Station
Harbor Gen Station
Harbor Gen Station
Harbor Gen Station
Harbor Gen Station
Harbor Gen Station
Harbor Gen Station
Haynes Gen Station
Haynes Gen Station
Haynes Gen Station
Haynes Gen Station
Haynes Gen Station
Haynes Gen Station
Humboldt Bay
Humboldt Bay
Hunters Point
Hunters Point
Hunters Point
Hunters Point
Hunters Point
Kern
Kern
Kern
Kern
Magnolia
Martinez
PLANT
CODE
259
259
259
310
310
310
310
389
389
389
330
330
330
330
422
422
377
377
399
399
399
399
399
399
399
400
400
400
400
400
400
246
246
247
247
247
247
247
251
251
251
251
375
256
STACK/UNIT ID*
2
3
4
1
2
3
4
3
4
2-2
1
2
3
4
16
17
4
5
1
2
3
4
5
**10A
**10B
1
2
3
4
5
6
1
2
3
4
5
6
7
1
2
3
4
M4
1
2000
ALLOWANCES
ALLOCATED
139
3,822
3,053
2,492
1,775
2,177
603
614
586
0
440
90
182
370
0
0
102
36
68
121
94
104
171
699
699
681
338
1,244
1,002
1,401
1,527
358
24
76
5
74
1
192
3
0
13
0
37
1
HELD IN
ACCOUNTS AS
OF 3/1/2001
18
11
26
68
64
16
59
514
586
100
12
2
4
7
0
0
102
36
0
0
0
0
0
6
0
131
338
1,244
1,002
1,401
1,527
302
300
2
2
2
2
35
0
0
0
0
0
0
ALLOWANCES
DEDUCTED
3
5
5
5
2
8
5
1
3
1
1
1
1
1
0
0
1
0
0
0
0
0
0
1
1
3
2
1
1
3
1
1
102
0
0
0
0
1
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2001
15
6
21
63
62
8
54
513
583
99
11
1
3
6
0
0
101
36
0
0
0
0
0
5
-1
128
336
1,243
1,001
1,398
1,526
301
198
2
2
2
2
34
0
0
0
0
0
0
A, 5
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
PLANT NAME
Martinez
Martinez
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Mountain Vista (Etiwanda)
Mountain Vista (Etiwanda)
Mountain Vista (Etiwanda)
Mountain Vista (Etiwanda)
Mountainview (San Bernadino)
Mountainview (San Bernadino)
NCPA Combustion Turbine Project #2
Ocean Vista (Mandalay)
Ocean Vista (Mandalay)
Oleum
Oleum
Oleum
Oleum
Oleum
Oleum
Olive
Olive
Ormond Beach
Ormond Beach
Pittsburg
Pittsburg
Pittsburg
Pittsburg
Pittsburg
Pittsburg
Pittsburg
Potrero
Riverside Canal (Highgrove)
Riverside Canal (Highgrove)
Riverside Canal (Highgrove)
Riverside Canal (Highgrove)
Sacramento Power Authority Cogen
PLANT
CODE
256
256
260
260
260
260
260
260
260
260
260
260
331
331
331
331
358
358
7449
345
345
263
263
263
263
263
263
6013
6013
350
350
271
271
271
271
271
271
271
273
334
334
334
334
7552
STACK/UNIT ID*
2
3
1
2
3
4
5
6
7
8
6-1
7-1
1
2
3
4
1
2
NA1
1
2
1
2
3
4
5
6
01
02
1
2
1
2
3
4
5
6
7
3-1
1
2
3
4
1
2000
ALLOWANCES
ALLOCATED
1
1
122
0
0
0
0
0
79
466
8,924
976
117
29
1,372
261
118
17
0
1,379
1,291
146
138
244
102
174
204
133
25
4,520
4,586
1,641
1,350
1,586
1,581
285
3,754
740
321
4
1
1
3
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
0
1
0
0
0
0
0
0
4
40
31
3
2
19
6
3
0
25
24
21
0
0
4
0
2
2
15
0
77
81
1
2
1
2
12
4
30
25
4
1
2
3
10
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
0
0
9
14
1
1
3
4
0
0
1
4
4
0
0
0
0
0
0
0
0
4
8
1
1
1
1
4
3
10
3
0
0
0
0
3
ALLOWANCES
CARRIED OVER
TO 2001
0
0
1
0
0
0
0
0
0
4
31
17
2
1
16
2
3
0
24
20
17
0
0
4
0
2
2
15
0
73
73
0
1
0
1
8
1
20
22
4
1
2
3
7
A, 6
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
PLANT NAME
SCACogen II
SCACogen II
Scattergood Gen Sta
Scattergood Gen Sta
Scattergood Gen Sta
Silver Gate
Silver Gate
Silver Gate
Silver Gate
Silver Gate
Silver Gate
Valley Gen Station
Valley Gen Station
Valley Gen Station
Valley Gen Station
Woodland Generation Station
Arapahoe
Arapahoe
Arapahoe
Arapahoe
Arapahoe
Arapahoe Combustion Turbines
Arapahoe Combustion Turbines
Brush 4
Brush 4
Cameo
Cherokee
Cherokee
Cherokee
Cherokee
Comanche
Comanche
Craig
Craig
Craig
Fort St. Vrain
Fort St. Vrain
Hayden
Hayden
Manchief Electric Gen Station
Manchief Electric Gen Station
Martin Drake
Martin Drake
Martin Drake
PLANT
CODE
7551
7551
404
404
404
309
309
309
309
309
309
408
408
408
408
7266
465
465
465
465
465
55200
55200
55209
55209
468
469
469
469
469
470
470
6021
6021
6021
6112
6112
525
525
55127
55127
492
492
492
STACK/UNIT ID*
1A
1B
1
2
3
1
2
3
4
5
6
1
2
3
4
1
CS1 (1 , 2)
1
2
3
4
CT5
CT6
GT4
GTS
2
1
2
3
4
1
2
C1
C2
C3
2
3
H1
H2
CT1
CT2
5
6
7
2000
ALLOWANCES
ALLOCATED
0
0
752
658
262
0
0
0
0
0
0
122
141
389
351
0
221
247
181
1,927
0
0
0
0
904
2,138
2,838
3,761
7,535
7,698
6,914
8,218
7,845
2,602
0
0
6,063
9,230
0
0
1,149
2,030
3,219
HELD IN
ACCOUNTS AS
OF 3/1/2001
5
5
418
658
262
0
0
0
0
0
0
631
141
389
351
20
904
598
1,084
1,816
0
0
0
0
2,295
2,631
4,571
5,053
6,965
5,980
8,415
6,812
6,994
2,602
5
5
2,096
2,895
1
1
1,399
2,380
4,894
ALLOWANCES
DEDUCTED
1
1
1
11
4
0
0
0
0
0
0
0
0
0
0
1
840
583
1,079
1,665
0
0
0
0
2,288
2,622
4,561
5,013
6,949
5,956
8,405
4,204
4,059
1,802
3
4
695
1,603
0
0
1,344
2,330
4,643
ALLOWANCES
CARRIED OVER
TO 2001
4
4
417
647
258
0
0
0
0
0
0
631
141
389
351
19
64
15
5
151
0
0
0
0
7
9
10
40
16
24
10
2,608
2,935
800
2
1
1,401
1,292
1
1
55
50
251
A, 7
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
PLANT NAME
Nucla
Pawnee
Pawnee
Rawhide
Ray D Nixon
Ray D Nixon
Ray D Nixon
Valmont
Valmont
Valmont
Valmont
Valmont Combustion Turbine
Zuni
Zuni
Zuni
Bridgeport Energy
Bridgeport Energy
Bridgeport Harbor
Bridgeport Harbor
Bridgeport Harbor
Devon
Devon
Devon
Devon
Devon
Devon
Devon
Devon
Devon
Devon
Devon
Devon
Devon
English
English
Mid-Conn/S. Meadow
Middletown
Middletown
Middletown
Middletown
Montville
Montville
New Haven Harbor
Norwalk Harbor
PLANT
CODE
527
6248
6248
6761
8219
8219
8219
477
477
477
477
55207
478
478
478
55042
55042
568
568
568
544
544
544
544
544
544
544
544
544
544
544
544
544
569
569
563
562
562
562
562
546
546
6156
548
STACK/UNIT ID*
1
1
"2
101
1
2
3
5
14
21
24
CT7
1
2
3
BE1
BE2
BHB1
BHB2
BHB3
3
6
CS0001 (7, 8)
7
8
11
12
13
14
4A
4B
5A
5B
EB13
EB14
15
1
2
3
4
5
6
NHB1
CS0001 (1 , 2)
2000
ALLOWANCES
ALLOCATED
1,122
14,443
0
1,800
4,477
0
0
3,137
4
20
0
0
340
0
5
0
0
2,079
4,727
11,481
980
898
2,808
3,003
0
0
0
0
170
171
155
155
114
157
0
461
1,328
3,339
2,390
1,208
5,675
13,070
HELD IN
ACCOUNTS AS
OF 3/1/2001
1,522
14,745
0
1,160
5,500
1
1
4,716
0
0
0
0
3
2
3
10
10
1
530
9,226
940
863
2,699
2,886
0
1
1
0
164
164
149
149
114
157
0
442
996
3,209
2,576
1,311
5,304
9,292
ALLOWANCES
DEDUCTED
1,273
14,678
0
849
5,220
0
0
4,506
0
0
0
0
1
0
0
2
2
0
474
8,747
0
0
1,141
1,434
0
1
1
0
0
0
0
0
0
0
0
0
628
1,197
2,572
1,293
3,412
9,256
ALLOWANCES
CARRIED OVER
TO 2001
249
67
0
311
280
1
1
210
0
0
0
0
2
2
3
8
8
1
56
479
940
863
1,558
1,452
0
0
0
0
164
164
149
149
114
157
0
442
368
2,012
4
18
1,892
36
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CT
CT
DC
DC
DE
DE
DE
DE
DE
DE
DE
DE
DE
DE
DE
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
PLANT NAME
Norwalk Harbor
Norwalk Harbor
Banning
Banning
Delaware City Refinery (Motiva)
Edge Moor
Edge Moor
Edge Moor
Hay Road
Indian River
Indian River
Indian River
Indian River
McKee Run
Van Sant
Anclote
Anclote
Arvah B Hopkins
Arvah B Hopkins
Auburndale Power Partners, LP
Avon Park
Big Bend
Big Bend
Big Bend
Big Bend
Big Bend
Big Bend
C D Mcintosh Jr
C D Mcintosh Jr
C D Mcintosh Jr
C D Mcintosh Jr
Cane Island
Cane Island
Cape Canaveral
Cape Canaveral
Combined Cycle 1
Crist
Crist
Crist
Crist
Crist
Crist
Crist
Crist
PLANT
CODE
548
548
603
603
52193
593
593
593
7153
594
594
594
594
599
7318
8048
8048
688
688
54658
624
645
645
645
645
645
645
676
676
676
676
7238
7238
609
609
7254
641
641
641
641
641
641
641
641
STACK/UNIT ID*
1
2
15
16
DCPP4
3
4
5
**3
1
2
3
4
3
"11
1
2
1
2
1
2
XS12(BB01,BB02)
BB01
BB02
XS23 (BB03, BB04)
BB03
BB04
1
2
3
5
2
**1
PCC1
PCC2
32432
CS001 (1 , 2, 3)
1
2
3
4
5
6
7
2000
ALLOWANCES
ALLOCATED
5,141
5,458
517
856
0
3,558
6,295
6,463
158
2,998
3,182
5,441
13,414
2,585
138
13,890
13,895
81
5,524
0
495
12,136
12,200
1 1 ,448
8,783
907
1,029
9,931
0
0
0
4,225
4,963
60
35
3
4
2,468
2,431
8,399
12,526
HELD IN
ACCOUNTS AS
OF 3/1/2001
4,941
5,245
517
856
1,300
19,678
6,295
6,463
158
5,998
6,132
7,870
8,914
1,085
138
16,000
12,500
101
5,504
2
0
25,931
7,799
13,501
4,997
1,131
1,029
9,931
2
26
10
7,812
5,814
60
35
3
4
36,724
33,047
37,497
53,830
ALLOWANCES
DEDUCTED
3,379
3,380
391
567
1,198
3,290
5,985
1,698
1
5,679
5,741
7,409
8,399
563
5
14,657
11,425
85
778
2
0
24,545
6,782
12,808
3,962
1,114
140
8,423
0
2
0
7,419
5,521
1
1
0
0
3,651
5,949
13,679
29,803
ALLOWANCES
CARRIED OVER
TO 2001
1,562
1,865
126
289
102
16,388
310
4,765
157
319
391
461
515
522
133
1,343
1,075
16
4,726
0
0
1,386
1,017
693
1,035
17
889
1,508
2
24
10
393
293
59
34
3
4
33,073
27,098
23,818
24,027
A, 9
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
PLANT NAME
Crystal River
Crystal River
Crystal River
Crystal River
Cutler
Cutler
Debary
Debary
Debary
Debary
Deerhaven
Deerhaven
Deerhaven
Deerhaven
F J Gannon
F J Gannon
F J Gannon
F J Gannon
F J Gannon
F J Gannon
Fort Myers
Fort Myers
Fort Myers
Fort Myers
G E Turner
G E Turner
G E Turner
Hardee Power Station
Henry D King
Henry D King
Higgins
Higgins
Higgins
Hines Facility
Hines Facility
Hookers Point
Hookers Point
Hookers Point
Hookers Point
Hookers Point
Hookers Point
Hookers Point
Hookers Point
Indian River
PLANT
CODE
628
628
628
628
610
610
6046
6046
6046
6046
663
663
663
663
646
646
646
646
646
646
612
612
612
612
629
629
629
50949
658
658
630
630
630
7302
7302
647
647
647
647
647
647
647
647
55318
STACK/UNIT ID*
1
2
4
5
PCU5
PCU6
"7
"8
"9
"10
B1
B2
CT3
**NA2
GB01
GB02
GB03
GB04
GB05
GB06
PFM1
PFM2
FMCT2A
FMCT2B
2
3
4
CT2B
7
8
1
2
3
1A
1B
2000
ALLOWANCES
ALLOCATED
12,429
14,295
23,659
25,257
0
0
705
705
705
705
98
8,271
0
0
3,843
4,426
5,666
6,225
6,539
10,084
3,189
9,460
0
0
543
718
611
0
63
26
423
475
969
0
0
CS001 (HB01.HB02, HB05)
HB01
HB02
CS002 (HB03, HB04)
HB03
HB04
HB05
HB06
CS1 (1 , 2)
177
207
469
701
1,253
478
HELD IN
ACCOUNTS AS
OF 3/1/2001
19,500
20,000
27,500
30,000
5
5
55
60
45
135
502
7,918
3
0
7,843
6,426
7,666
8,125
11,539
10,084
4,373
15,233
4
4
0
0
0
50
63
26
0
0
0
8
8
177
207
408
401
553
478
ALLOWANCES
DEDUCTED
18,362
18,982
26,301
28,566
1
1
49
51
39
112
500
7,915
1
0
6,898
5,906
7,349
7,831
10,776
9,310
4,153
14,465
0
0
0
0
0
6
0
0
0
0
0
3
3
0
207
203
273
336
300
ALLOWANCES
CARRIED OVER
TO 2001
1,138
1,018
1,199
1,434
4
4
6
9
6
23
2
3
2
0
945
520
317
294
763
774
220
768
4
4
0
0
0
44
63
26
0
0
0
5
5
177
0
205
128
217
178
A, 10
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
PLANT NAME
Indian River
Indian River
Indian River
Indian River
Indian River
Intercession City
Intercession City
Intercession City
Intercession City
Intercession City
J D Kennedy
J D Kennedy
J D Kennedy
J D Kennedy
J R Kelly
Lansing Smith
Lansing Smith
Larsen Memorial
Larsen Memorial
Larsen Memorial
Lauderdale
Lauderdale
Lauderdale
Lauderdale
Lauderdale
Lauderdale
Manatee
Manatee
Martin
Martin
Martin
Martin
Martin
Martin
Mulberry Cogeneration Facility
Northside
Northside
Northside
Orange Cogeneration Facility
Orange Cogeneration Facility
Orlando CoGen
P L Bartow
P L Bartow
P L Bartow
PLANT
CODE
55318
55318
55318
683
683
8049
8049
8049
8049
8049
666
666
666
666
664
643
643
675
675
675
613
613
613
613
613
613
6042
6042
6043
6043
6043
6043
6043
6043
54426
667
667
667
54365
54365
54466
634
634
634
STACK/UNIT ID*
1
2
3
**C
"D
"7
"8
"9
"10
"11
7
8
9
10
JRK8
1
2
7
"8
"9
4GT1
4GT2
5GT1
5GT2
PFL4
PFL5
PMT1
PMT2
PMR1
PMR2
HRSG3A
HRSG3B
HRSG4A
HRSG4B
1
1
2
3
1
2
1
1
2
3
2000
ALLOWANCES
ALLOCATED
1,192
1,569
3,647
0
639
705
705
705
705
0
0
196
553
1,976
58
6,478
7,603
307
665
0
948
948
948
948
0
0
13,777
12,701
5,094
6,041
1,275
1,275
1,275
1,275
0
6,224
6,268
11,126
0
0
0
2,806
2,962
5,430
HELD IN
ACCOUNTS AS
OF 3/1/2001
403
2,166
3,728
1
6
35
35
25
30
125
20
0
0
20
29
12,673
13,614
558
188
0
8
8
8
8
0
0
14,654
15,790
8,779
7,942
8
8
8
9
4
10,356
0
10,889
2
2
4
6,000
6,000
1 1 ,000
ALLOWANCES
DEDUCTED
398
2,161
3,723
0
2
23
22
12
18
99
7
0
0
2
29
9,200
11,527
552
2
0
4
4
4
4
0
0
13,915
14,995
8,336
7,542
4
4
4
4
1
7,286
0
8,014
0
0
2
5,110
5,230
9,951
ALLOWANCES
CARRIED OVER
TO 2001
5
5
5
1
4
12
13
13
12
26
13
0
0
18
0
3,473
2,087
6
186
0
4
4
4
4
0
0
739
795
443
400
4
4
4
5
3
3,070
0
2,875
2
2
2
890
770
1,049
A, 11
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
PLANT NAME
Polk
Polk
Polk
Polk
Port Everglades
Port Everglades
Port Everglades
Port Everglades
Putnam
Putnam
Putnam
Putnam
Riviera
Riviera
Riviera
S O Purdom
S O Purdom
Sanford
Sanford
Sanford
Scholz
Scholz
Seminole
Seminole
Southside
Southside
Southside
Southside
Southside
St Johns River Power
St Johns River Power
Stanton Energy
Stanton Energy
Stock Island
Suwannee River
Suwannee River
Suwannee River
Tiger Bay
Tom G Smith
Tom G Smith
Turkey Point
Turkey Point
University of Florida
Vero Beach Municipal
PLANT
CODE
7242
7242
7242
7242
617
617
617
617
6246
6246
6246
6246
619
619
619
689
689
620
620
620
642
642
136
136
668
668
668
668
668
207
207
564
564
6584
638
638
638
7699
673
673
621
621
7345
693
STACK/UNIT ID*
**1
"2
"3
**4
PPE1
PPE2
PPE3
PPE4
HRSG11
HRSG12
HRSG21
HRSG22
PRV2
PRV3
PRV4
7
8
PSN3
PSN4
PSN5
1
2
1
2
1
2
3
4
5
1
2
1
2
1
1
2
3
1
S-3
S-4
PTP1
PTP2
1
3
2000
ALLOWANCES
ALLOCATED
0
0
0
0
2,340
2,414
5,882
5,964
1,644
1,644
1,568
1,568
94
3,574
3,546
443
0
1,085
8,615
3,222
1,959
2,051
18,388
18,388
930
963
227
616
1,811
11,586
11,374
11,294
0
2,572
254
253
649
0
9
80
5,870
5,913
0
315
HELD IN
ACCOUNTS AS
OF 3/1/2001
1,011
550
0
0
3,102
4,066
7,785
7,107
6
7
6
7
0
7,934
9,697
433
10
2,278
8,682
8,852
27,638
26,431
18,388
18,388
0
0
0
1,416
2,082
14,472
13,420
6,910
3,253
1
1,600
1,500
1,700
8
89
0
5,803
5,858
5
315
ALLOWANCES
DEDUCTED
918
409
0
0
2,946
3,861
7,392
6,748
2
2
1
2
0
7,542
9,228
96
1
2,166
8,245
8,421
1,601
1,417
14,832
17,909
0
0
0
958
1,278
11,019
10,295
6,570
3,099
0
1,353
1,271
1,492
3
62
0
5,510
5,561
1
2
ALLOWANCES
CARRIED OVER
TO 2001
93
141
0
0
156
205
393
359
4
5
5
5
0
392
469
337
9
112
437
431
26,037
25,014
3,556
479
0
0
0
458
804
3,453
3,125
340
154
1
247
229
208
5
27
0
293
297
4
313
A, 12
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
FL
FL
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
PLANT NAME
Vero Beach Municipal
Vero Beach Municipal
Arkw right
Arkwright
Arkwright
Arkwright
Arkwright
Atkinson
Atkinson
Atkinson
Atkinson
Atkinson
Baconton
Baconton
Baconton
Baconton
Bo wen
Bo wen
Bo wen
Bo wen
Doyle Generating Facility
Doyle Generating Facility
Doyle Generating Facility
Doyle Generating Facility
Doyle Generating Facility
Hammond
Hammond
Hammond
Hammond
Hammond
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Hartwell Energy Facility
Hartwell Energy Facility
Jack Mcdonough
Jack Mcdonough
Jack Mcdonough
Jackson County Combustion Turbine
Jackson County Combustion Turbine
Jackson County Combustion Turbine
PLANT
CODE
693
693
699
699
699
699
699
700
700
700
700
700
55304
55304
55304
55304
703
703
703
703
55244
55244
55244
55244
55244
708
708
708
708
708
709
709
709
709
709
709
70454
70454
710
710
710
7765
7765
7765
STACK/UNIT ID*
4
"5
CS001 (1,2,3,4)
1
2
3
4
A2
A3
A4
A1A
A1B
CT1
CT4
CT5
CT6
1BLR
2BLR
3BLR
4BLR
CTG-1
CTG-2
CTG-3
CTG-4
CTG-5
CS001 (1,2,3)
1
2
3
4
CS001 (1 , 2)
1
2
CS002 (3, 4)
3
4
MAG1
MAG2
CS001 (MB1 , MB2)
MB1
MB2
1
2
3
2000
ALLOWANCES
ALLOCATED
107
317
1,449
1,470
1,539
1,255
4
6
5
2
2
0
0
0
0
23,617
24,288
30,942
30,934
0
0
0
0
0
3,786
3,975
3,842
16,232
9,859
11,661
16,044
15,921
0
0
8,584
8,885
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
107
317
5,811
5,242
10,423
7,785
4
6
5
2
2
3
3
3
3
46,592
35,414
117,749
98,345
1
1
1
1
1
19,834
21 ,306
20,272
101,111
33,349
52,722
46,490
45,176
2
4
45,622
48,61 1
5
5
5
ALLOWANCES
DEDUCTED
5
1
1,236
1,237
1,237
1,237
0
0
0
0
0
0
0
0
0
28,958
35,098
41 ,479
49,839
0
0
0
0
0
3,847
3,847
3,847
16,742
11,601
11,601
23,182
23,182
1
3
14,121
14,121
0
1
1
ALLOWANCES
CARRIED OVER
TO 2001
102
316
4,575
4,005
9,186
6,548
4
6
5
2
2
3
3
3
3
17,634
316
76,270
48,506
1
1
1
1
1
15,987
17,459
16,425
84,369
21,748
41,121
23,308
21,994
1
1
31 ,501
34,490
5
4
4
A, 13
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
PLANT NAME
Jackson County Combustion Turbine
Jackson County Combustion Turbine
Jackson County Combustion Turbine
Jackson County Combustion Turbine
Jackson County Combustion Turbine
Kraft
Kraft
Kraft
Kraft
Kraft
Mclntosh
Mclntosh
Mclntosh
Mclntosh
Mclntosh
Mclntosh
Mclntosh
Mclntosh
Mclntosh
Mcmanus
Mcmanus
Mcmanus
Mid-Georgia Cogeneration
Mid-Georgia Cogeneration
Mitchell
Monroe Power Plant
Riverside
Robins
Robins
Scherer
Scherer
Scherer
Scherer
Sewell Creek Energy (Smarr 2)
Sewell Creek Energy (Smarr 2)
Sewell Creek Energy (Smarr 2)
Sewell Creek Energy (Smarr 2)
Smarr Energy Facility
Smarr Energy Facility
Sowega Power Project
Sowega Power Project
Wansley
Wansley
West Georgia Generating Co, LP
PLANT
CODE
7765
7765
7765
7765
7765
733
733
733
733
733
6124
6124
6124
6124
6124
6124
6124
6124
6124
715
715
715
55040
55040
727
7764
734
7348
7348
6257
6257
6257
6257
7813
7813
7813
7813
7829
7829
7768
7768
6052
6052
55267
STACK/UNIT ID*
4
5
6
7
8
CS001 (1,2,3,4)
1
2
3
4
1
CT1
CT2
CT3
CT4
CT5
CT6
CT7
CT8
CS001 (1,2)
1
2
1
2
3
1
12
CT1
CT2
1
2
3
4
1
2
3
4
1
2
CT2
CT3
1
2
1
2000
ALLOWANCES
ALLOCATED
0
0
0
0
0
1,530
1,510
2,964
436
5,556
0
0
0
0
0
0
0
0
844
1,279
0
0
5,463
0
5
0
0
21 ,083
21 ,232
21 ,266
21 ,242
0
0
0
0
0
0
0
0
30,517
28,211
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
5
5
5
5
5
3,936
3,513
5,591
4
14,001
54
54
54
54
54
54
54
54
2,678
2,661
25
25
35,688
10
5
30
20
53,599
44,705
15,767
22,412
5
5
5
5
5
5
0
0
108,924
102,622
12
ALLOWANCES
DEDUCTED
1
1
1
0
1
2,238
1,791
4,417
0
7,830
10
9
5
6
8
7
7
6
2,678
2,660
20
19
4,929
5
0
29
17
27,591
25,697
15,594
22,404
0
0
0
0
0
0
0
0
37,070
32,148
9
ALLOWANCES
CARRIED OVER
TO 2001
4
4
4
5
4
1,698
1,722
1,174
4
6,171
44
45
49
48
46
47
47
48
0
1
5
6
30,759
5
5
1
3
26,008
19,008
173
8
5
5
5
5
5
5
0
0
71,854
70,474
3
A, 14
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
PLANT NAME
West Georgia Generating Co, LP
West Georgia Generating Co, LP
West Georgia Generating Co, LP
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Ames
Ames
Burlington (IA)
Council Bluffs
Council Bluffs
Council Bluffs
Des Moines
Des Moines
Des Moines
Dubuque
Dubuque
Dubuque
Earl F Wisdom
Fair Station
George Neal North
George Neal North
George Neal North
George Neal South
Grinnell
Lansing
Lansing
Lansing
Lansing
Lansing
Lime Creek
Lime Creek
Louisa
Maynard Station
Milton L Kapp
Muscatine
Muscatine
Na 1 - 7230
PLANT
CODE
55267
55267
55267
728
728
728
728
728
728
728
728
728
1122
1122
1104
1082
1082
1082
1083
1083
1083
1046
1046
1046
1217
1218
1091
1091
1091
7343
7137
1047
1047
1047
1047
1047
7155
7155
6664
1096
1048
1167
1167
7230
STACK/UNIT ID*
2
3
4
Y1BR
CS001 (Y2BR, Y3BR)
Y2BR
Y3BR
CS002 (Y4BR, Y5BR)
Y4BR
Y5BR
Y6BR
Y7BR
7
8
1
1
2
3
10
11
**5
1
5
6
1
2
1
2
3
4
"2
CS1 (1 , 2)
1
2
3
4
**1
"2
101
1
2
8
9
**2
2000
ALLOWANCES
ALLOCATED
0
0
0
3,107
3,036
2,998
3,843
4,056
10,678
10,502
403
1,834
4,499
1,110
1,651
15,956
163
244
0
1,120
305
0
379
5,575
2,310
9,082
12,296
15,144
189
0
0
478
4,629
255
255
15,593
31
5,795
1,362
2,027
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
3
12
7
35,148
20,222
19,832
25,223
27,381
77,524
61,863
403
1,316
22,314
1,310
1,951
18,153
1
2
0
2,199
1,454
2
1,229
6,315
3,864
6,482
1 1 ,396
15,940
0
35
295
948
5,712
255
255
15,181
0
38,797
2,990
2,027
0
ALLOWANCES
DEDUCTED
1
9
5
301
3,342
3,343
4,145
4,145
16,277
13,551
317
656
6,374
1,221
1,898
17,718
0
0
0
2,189
1,444
1
1,192
6,216
3,431
6,187
1 1 ,071
14,973
0
27
283
933
5,701
12
11
14,779
0
4,922
2,511
646
0
ALLOWANCES
CARRIED OVER
TO 2001
2
3
2
34,847
16,880
16,489
21 ,078
23,236
61 ,247
48,312
86
660
15,940
89
53
435
1
2
0
10
10
1
37
99
433
295
325
967
0
8
12
15
11
243
244
402
0
33,875
479
1,381
0
A, 15
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
ID
ID
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
PLANT NAME
Ottumwa
Pella
Pella
Pella
Pella
Pleasant Hill Energy Center
Prairie Creek
Prairie Creek
Riverside
Sixth Street
Sixth Street
Sixth Street
Sixth Street
Sixth Street
Streeter Station
Sutherland
Sutherland
Sutherland
Rathdrum Combustion Turbine Project
Rathdrum Combustion Turbine Project
Baldwin
Baldwin
Baldwin
Coffeen
Coffee n
Coffeen
Collins
Collins
Collins
Collins
Collins
Collins
Collins
Crawford
Crawford
Dallman
Dallman
Dallman
Dallman
Duck Creek
E D Edwards
E D Edwards
E D Edwards
Elwood Energy Facility
PLANT
CODE
6254
1175
1175
1175
1175
7145
1073
1073
1081
1058
1058
1058
1058
1058
1131
1077
1077
1077
7456
7456
889
889
889
861
861
861
6025
6025
6025
6025
6025
6025
6025
867
867
963
963
963
963
6016
856
856
856
55199
STACK/UNIT ID*
1
CS67 (6, 7)
6
7
8
3
3
4
9
1
2
3
4
5
7
1
2
3
1
2
1
2
3
CS0001 (01 , 02)
01
02
031230(1,2,3)
1
2
3
CS0405 (4, 5)
4
5
7
8
033132(31,32)
31
32
33
1
1
2
3
1
2000
ALLOWANCES
ALLOCATED
19,095
757
978
68
0
725
3,434
1,745
814
177
154
77
308
554
199
376
2,191
0
0
18,116
19,154
18,350
5,085
15,381
1,327
1,133
2,001
1,633
1,810
7,236
9,850
1,385
1,568
5,199
11,201
2,899
6,916
9,125
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
19,095
757
978
68
31
1,000
21 ,429
3,198
7
322
309
309
1,008
754
899
696
3,191
2
2
8,440
5,533
24,015
15,183
25,056
579
579
578
519
518
4,291
5,641
11,242
11,899
1,757
1 1 ,201
16,766
18,066
23,935
25
ALLOWANCES
DEDUCTED
18,415
269
269
0
2
987
3,079
2,507
0
313
296
229
991
524
893
667
3,113
1
1
8,240
5,333
23,026
14,588
24,501
278
279
279
218
219
3,991
5,341
10,308
10,728
1,391
11,115
16,435
16,964
23,410
0
ALLOWANCES
CARRIED OVER
TO 2001
680
488
709
68
29
13
18,350
691
7
9
13
80
17
230
6
29
78
1
1
200
200
989
595
555
301
300
299
301
299
300
300
934
1,171
366
86
331
1,102
525
25
A, 16
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
PLANT NAME
Elwood Energy Facility
Elwood Energy Facility
Elwood Energy Facility
Fisk
Freedom Power Project
Gibson City Power Plant
Gibson City Power Plant
Grand Tower
Grand Tower
Grand Tower
Havana
Havana
Havana
Havana
Havana
Havana
Havana
Havana
Havana
Hennepin
Hennepin
Hennepin
Hutsonville
Hutsonville
Indeck-Rockford Energy Center
Indeck-Rockford Energy Center
Interstate
Joliet 29
Joliet 29
Joliet 29
Joliet 29
Joliet 29
Joliet 29
Joliet 9
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Kincaid
PLANT
CODE
55199
55199
55199
886
7842
55201
55201
862
862
862
891
891
891
891
891
891
891
891
891
892
892
892
863
863
55238
55238
7425
384
384
384
384
384
384
874
887
887
887
887
887
887
887
887
887
876
STACK/UNIT ID*
2
3
4
19
CT1
GCTG1
GCTG2
07
08
09
1
2
3
4
5
6
7
8
9
CSS (1 , 2)
1
2
05
06
0001
0002
1
CS7172(71,72)
71
72
CS8182(81,82)
81
82
5
CS1 (1,2)
1
2
CS2 (3, 4)
3
4
CSS (5, 6)
5
6
CS0102(1,2)
2000
ALLOWANCES
ALLOCATED
0
0
0
10,032
0
0
0
248
235
2,547
35
45
35
35
35
35
35
35
8,805
2,018
7,940
2,591
3,238
0
0
0
7,580
6,177
7,296
7,558
8,676
5,288
4,523
5,153
4,773
4,795
4,460
HELD IN
ACCOUNTS AS
OF 3/1/2001
25
25
25
5,148
0
5
5
3,483
3,279
8,621
82
76
66
95
71
16
35
25
11,518
1,404
5,030
6,913
8,163
25
25
5
4,580
4,634
5,296
5,559
4,508
46,424
36,807
45,063
40,253
37,849
33,623
ALLOWANCES
DEDUCTED
0
0
0
4,848
0
0
1
3,017
2,802
7,955
68
67
55
87
61
7
28
18
10,586
1,204
4,528
6,301
7,527
0
0
1
4,334
4,335
5,258
5,259
4,309
6,540
1,229
5,017
2,359
5,313
2,980
ALLOWANCES
CARRIED OVER
TO 2001
25
25
25
300
0
5
4
466
477
666
14
9
11
8
10
9
7
7
932
200
502
612
636
25
25
4
246
299
38
300
199
39,884
35,578
40,046
37,894
32,536
30,643
A, 17
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
PLANT NAME
Kincaid
Kincaid
Lakeside
Lakeside
Lakeside
Lincoln Generating Facility LLC
Lincoln Generating Facility LLC
Lincoln Generating Facility LLC
Lincoln Generating Facility LLC
Lincoln Generating Facility LLC
Lincoln Generating Facility LLC
Lincoln Generating Facility LLC
Lincoln Generating Facility LLC
Marion
Marion
Marion
Marion
Marion
MEPI GT Facility
MEPI GT Facility
MEPI GT Facility
MEPI GT Facility
MEPI GT Facility
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Newton
Newton
Pinckneyville Power Plant
Pinckneyville Power Plant
Pinckneyville Power Plant
Pinckneyville Power Plant
Powerton
Powerton
Powerton
Powerton
Powerton
R S Wallace
R S Wallace
Rocky Road Power, LLC
PLANT
CODE
876
876
964
964
964
55222
55222
55222
55222
55222
55222
55222
55222
976
976
976
976
976
7858
7858
7858
7858
7858
864
864
864
864
864
864
864
6017
6017
55202
55202
55202
55202
879
879
879
879
879
859
859
55109
STACK/UNIT ID*
1
2
CS0078 (7, 8)
7
8
CTG-1
CTG-2
CTG-3
CTG-4
CTG-5
CTG-6
CTG-7
CTG-8
CS0001 (1 , 2)
1
2
3
4
1
2
3
4
5
2000
ALLOWANCES
ALLOCATED
13,596
14,982
2,554
1,446
0
0
0
0
0
0
0
0
2,080
2,130
2,310
6,841
0
0
0
0
0
CS0001 (01 , 02, 03, 04)
01
02
03
04
05
06
1
2
CT01
CT02
CT03
CT04
298
322
280
255
5,991
46
16,185
13,932
0
0
0
0
CS0506 (51 , 52, 61 , 62)
51
52
61
62
9
10
T1
10,704
10,574
10,516
10,599
901
2,432
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
8,512
9,987
2,537
1,437
2
2
2
2
2
2
2
2
5,480
3,951
7,310
1 1 ,570
5
5
5
5
5
2,682
3,130
2,942
3,571
12,382
679
8,065
9,056
0
0
0
0
5,993
5,993
5,993
5,822
0
0
0
ALLOWANCES
DEDUCTED
8,487
9,962
2,131
1,198
0
0
0
0
0
0
0
0
3,032
3,032
4,417
3,151
0
0
0
0
0
2,230
2,470
2,426
3,100
1 1 ,959
327
7,371
8,587
0
0
0
0
5,693
5,693
5,693
5,693
0
0
0
ALLOWANCES
CARRIED OVER
TO 2001
25
25
406
239
2
2
2
2
2
2
2
2
2,448
919
2,893
8,419
5
5
5
5
5
452
660
516
471
423
352
694
469
0
0
0
0
300
300
300
129
0
0
0
A, 18
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IN
IN
IN
IN
IN
IN
PLANT NAME
Rocky Road Power, LLC
Rocky Road Power, LLC
Rocky Road Power, LLC
Shelby Energy Center
Shelby Energy Center
Shelby Energy Center
Shelby Energy Center
Shelby Energy Center
Shelby Energy Center
Shelby Energy Center
Tilton
Tilton
Tilton
Tilton
Venice
Venice
Venice
Venice
Venice
Venice
Venice
Venice
Vermilion
Vermilion
Vermilion
Waukegan
Waukegan
Waukegan
Will County
Will County
Will County
Will County
Wood River
Wood River
Wood River
Wood River
Wood River
Wood River
A B Brown
A B Brown
A B Brown
Anderson
Anderson
Bailly
PLANT
CODE
55109
55109
55109
55237
55237
55237
55237
55237
55237
55237
7760
7760
7760
7760
913
913
913
913
913
913
913
913
897
897
897
883
883
883
884
884
884
884
898
898
898
898
898
898
6137
6137
6137
7336
7336
995
STACK/UNIT ID*
T2
T3
T4
2000
ALLOWANCES
ALLOCATED
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
0
0
CP1 (SCE1, SCE2, SCE3, SCE4, SCE5, SCE6)
SCE1
SCE2
SCE3
SCE4
SCE5
SCE6
1
2
3
4
1
2
3
4
5
6
7
8
CSS (1 , 2)
1
2
7
8
17
1
2
3
4
CS1 (1,2,3)
1
2
3
4
5
1
2
3
ACT1
ACT2
XS12(7, 8)
0
0
0
0
0
0
0
0
0
0
5
2
17
14
10
10
2
2
2,835
3,831
8,214
7,840
3,104
5,322
4,850
6,995
13,804
3
3
3
2,259
9,481
5,358
4,530
639
0
0
0
0
0
0
0
0
0
0
0
0
5
2
7
4
10
10
12
12
6,167
7,712
7,161
8,881
2,328
2,492
2,648
5,247
6,781
6
3
3
3,077
11,543
5,358
4,530
639
5
5
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
1
2
3
5,720
7,281
6,886
8,544
2,220
2,309
2,348
5,092
6,481
0
0
0
2,894
10,675
4,589
2,274
1
2
1
ALLOWANCES
CARRIED OVER
TO 2001
0
0
0
0
0
0
0
0
0
0
0
0
0
5
2
7
4
9
9
10
9
447
431
275
337
108
183
300
155
300
6
3
3
183
868
769
2,256
638
3
4
A, 19
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
PLANT NAME
Bailly
Bailly
Breed
Cayuga
Cayuga
Cayuga
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Dean H Mitchell
Dean H Mitchell
Dean H Mitchell
Dean H Mitchell
Dean H Mitchell
Dean H Mitchell
Edwardsport
Edwardsport
Edwardsport
Edwardsport
Elmer W Stout
Elmer W Stout
Elmer W Stout
Elmer W Stout
Elmer W Stout
Elmer W Stout
Elmer W Stout
Elmer W Stout
Elmer W Stout
Elmer W Stout
Elmer W Stout
Elmer W Stout
Elmer W Stout
Elmer W Stout
Elmer W Stout
F B Culley
F B Culley
F B Culley
F B Culley
Frank E Ratts
PLANT
CODE
995
995
984
1001
1001
1001
983
983
983
983
983
983
983
983
996
996
996
996
996
996
1004
1004
1004
1004
990
990
990
990
990
990
990
990
990
990
990
990
990
990
990
1012
1012
1012
1012
1043
STACK/UNIT ID*
7
8
1
1
2
4
CS001 (1, 2, 3)
1
2
3
CS002 (4, 5, 6)
4
5
6
CS45 (4, 5)
4
5
CS611 (6,11)
6
11
6-1
7-1
7-2
8-1
1
2
3
4
5
6
7
8
9
10
50
60
70
GT4
GTS
1
XS23 (2, 3)
2
3
1SG1
2000
ALLOWANCES
ALLOCATED
4,812
6,871
7,977
14,390
14,715
0
8,465
8,324
8,573
8,434
8,132
8,560
3,116
3,018
2,970
2,658
0
347
354
375
0
0
0
0
0
0
0
0
1
2
1,674
2,058
10,180
0
0
827
1,759
7,318
3,593
HELD IN
ACCOUNTS AS
OF 3/1/2001
3,133
9,585
17,889
38,812
34,313
15
7,754
7,754
7,754
7,473
7,473
7,473
889
2,072
2,009
2,358
29
4,281
4,005
3,475
0
0
0
0
0
0
0
0
51
52
8,040
7,849
25,679
50
50
2,227
9,872
36,724
11,715
ALLOWANCES
DEDUCTED
2,787
2,358
0
34,978
30,755
1
7,253
7,254
7,254
6,973
6,972
6,972
760
1,698
1,961
1,946
12
3,961
3,674
3,147
0
0
0
0
0
0
0
0
3
2
7,778
7,610
24,906
6
6
2,147
9,590
0
11,195
ALLOWANCES
CARRIED OVER
TO 2001
346
7,227
17,889
3,834
3,558
14
501
500
500
500
501
501
129
374
48
412
17
320
331
328
0
0
0
0
0
0
0
0
48
50
262
239
773
44
44
80
282
36,724
520
A, 20
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
PLANT NAME
Frank E Ratts
Georgetown
Georgetown
Georgetown
Gibson
Gibson
Gibson
Gibson
Gibson
Gibson
Gibson
H T Pritchard
H T Pritchard
H T Pritchard
H T Pritchard
H T Pritchard
H T Pritchard
H T Pritchard
H T Pritchard
Merom
Merom
Michigan City
Michigan City
Michigan City
Michigan City
Mirant State Line Energy, LLC (IN)
Mirant State Line Energy, LLC (IN)
Na 1 - 7221
Na 1 - 7221
Na 1 - 7221
Na 1 - 7228
Na 1 - 7228
Noblesville
Noblesville
Noblesville
Perry K Steam Plant
Petersburg
Petersburg
Petersburg
Petersburg
R Gallagher
R Gallagher
R Gallagher
R Gallagher
PLANT
CODE
1043
7759
7759
7759
6113
6113
6113
6113
6113
6113
6113
991
991
991
991
991
991
991
991
6213
6213
997
997
997
997
981
981
7221
7221
7221
7228
7228
1007
1007
1007
992
994
994
994
994
1008
1008
1008
1008
STACK/UNIT ID*
2SG1
GT1
GT2
GTS
CS0003 (1 , 2)
1
2
XS34 (3, 4)
3
4
5
1
2
CS592 (3, 4)
3
4
CS596 (5, 6)
5
6
1SG1
2SG1
4
5
6
12
3
4
**1
**3
**4
"2
**3
1
2
3
11
1
2
3
4
CS0001 (1 , 2)
1
2
CS0002 (3, 4)
2000
ALLOWANCES
ALLOCATED
3,660
0
0
0
17,420
17,683
17,714
17,389
18,187
0
1
240
533
596
2,488
14,925
14,823
909
1,010
1,019
10,052
4,726
6,924
0
0
0
0
0
66
54
40
432
7,088
13,965
16,886
16,155
2,909
3,138
HELD IN
ACCOUNTS AS
OF 3/1/2001
13,534
0
0
0
72,443
66,582
67,512
183,311
26,576
31
141
3,457
3,883
3,728
7,200
8,325
9,817
0
0
0
24,694
3,920
5,124
0
0
0
0
0
2,357
2,332
2,292
32
1,719
3,240
20,939
17,485
16,857
15,880
ALLOWANCES
DEDUCTED
11,855
0
0
0
50,620
44,026
28,075
28,075
20,708
4
8
3,346
3,713
3,612
6,980
7,535
9,285
0
0
0
1 1 ,298
3,895
5,099
0
0
0
0
0
2,312
2,298
2,264
18
1,638
3,121
20,321
16,975
15,379
14,686
ALLOWANCES
CARRIED OVER
TO 2001
1,679
0
0
0
21 ,823
22,556
39,437
155,236
5,868
27
133
111
170
116
220
790
532
0
0
0
13,396
25
25
0
0
0
0
0
45
34
28
14
81
119
618
510
1,478
1,194
A, 21
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
KS
KS
KS
KS
KS
PLANT NAME
R Gallagher
R Gallagher
R M Schahfer
R M Schahfer
R M Schahfer
R M Schahfer
Richmond (IN)
Richmond (IN)
Rockport
Rockport
Rockport
Tanners Creek
Tanners Creek
Tanners Creek
Tanners Creek
Tanners Creek
Vermillion Generating Station
Vermillion Generating Station
Vermillion Generating Station
Vermillion Generating Station
Vermillion Generating Station
Vermillion Generating Station
Vermillion Generating Station
Vermillion Generating Station
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Warrick
Warrick
Warrick
Warrick
Warrick
Whitewater Valley
Whitewater Valley
Whitewater Valley
Arthur Mullergren
Cimarron River
Coffeyville
East12ThSt
Garden City
PLANT
CODE
1008
1008
6085
6085
6085
6085
7335
7335
6166
6166
6166
988
988
988
988
988
55111
55111
55111
55111
55111
55111
55111
55111
1010
1010
1010
1010
1010
1010
1010
6705
6705
6705
6705
6705
1040
1040
1040
1235
1230
1271
7013
1336
STACK/UNIT ID*
3
4
14
15
17
18
RCT1
RCT2
CS012(MB1,MB2)
MB1
MB2
CS013(U1,U2, U3)
U1
U2
U3
U4
1
2
3
4
5
6
7
8
1
CS0005 (2, 3, 4, 5, 6)
2
3
4
5
6
1
2
3
4
XS123(1,2, 3)
CS12(1,2)
1
2
3
1
4
4
S-2
2000
ALLOWANCES
ALLOCATED
2,815
2,933
10,357
10,693
5,224
5,189
0
0
33,003
33,003
2,776
2,798
4,080
10,705
0
0
0
0
0
0
0
0
1,723
1,392
1,616
1,532
1,582
5,295
30,372
30,732
27,668
10,509
2,237
6,695
1
12
11
10
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
16,425
15,511
1 1 ,403
13,370
6,185
4,939
19
5
42,462
33,003
4,945
5,234
6,854
118,159
4
4
4
4
4
4
4
4
17,223
7,151
12,078
6,723
9,662
30,947
20,606
29,037
19,201
32,487
2,237
9,895
1
12
11
10
10
ALLOWANCES
DEDUCTED
14,902
14,041
11,319
13,281
5,629
4,706
2
2
32,940
30,449
4,800
5,081
6,653
50,912
0
0
0
0
0
0
0
0
657
6,534
7,574
6,091
8,859
28,756
20,583
20,069
19,140
31,595
2,226
9,847
1
1
0
0
1
ALLOWANCES
CARRIED OVER
TO 2001
1,523
1,470
84
89
556
233
17
3
9,522
2,554
145
153
201
67,247
4
4
4
4
4
4
4
4
16,566
617
4,504
632
803
2,191
23
8,968
61
892
11
48
0
11
11
10
9
A, 22
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KY
KY
KY
KY
PLANT NAME
Gordon Evans
Gordon Evans
Gordon Evans
Gordon Evans
Holcomb
Hutchinson
Hutchinson
Hutchinson
Hutchinson
Hutchinson
Jeffrey Energy Centr
Jeffrey Energy Centr
Jeffrey Energy Centr
Judson Large
Kaw
Kaw
Kaw
La Cygne
La Cygne
Lawrence
Lawrence
Lawrence
Lawrence
Mcpherson 2
McPherson 3
Murray Gill
Murray Gill
Murray Gill
Murray Gill
Nearman Creek
Neosho
Quindaro
Quindaro
Ripley
Ripley
Riverton
Riverton
Tecumseh
Tecumseh
Wamego
Big Sandy
Big Sandy
Big Sandy
Cane Run
PLANT
CODE
1240
1240
1240
1240
108
1248
1248
1248
1248
1248
6068
6068
6068
1233
1294
1294
1294
1241
1241
1250
1250
1250
1250
1305
7515
1242
1242
1242
1242
6064
1243
1295
1295
1244
1244
1239
1239
1252
1252
1328
1353
1353
1353
1363
STACK/UNIT ID*
1
2
E1CT
E2CT
SGU1
CP001 (1,2,3)
1
2
3
4
1
2
3
4
1
2
3
1
2
2
3
4
5
1
1
1
2
3
4
N1
7
1
2
"2
"3
39
40
9
10
7
CS012(BSU1, BSU2)
BSU1
BSU2
3
2000
ALLOWANCES
ALLOCATED
64
25
0
0
4,011
0
0
0
18
17,113
18,087
20,635
39
787
619
516
17,946
15,061
2
2,148
1,819
5,377
1
0
1
5
50
62
6,930
13
2,032
2,079
0
0
1,039
1,764
2,256
3,916
0
6,430
19,718
39
HELD IN
ACCOUNTS AS
OF 3/1/2001
244
418
10
10
2,501
0
0
0
1,098
18,774
20,383
21 ,235
39
2
0
2
1 1 ,431
21,161
2
2,148
539
1,677
76
40
1
5
430
1,262
8,987
33
2,032
7,486
0
0
2,539
1,264
2,036
3,916
0
20,271
47,91 1
0
ALLOWANCES
DEDUCTED
229
378
4
2
2,094
0
0
0
997
18,184
19,771
20,540
2
0
0
0
9,698
20,983
0
1,480
219
1,262
7
1
0
0
388
1,162
7,596
16
1,031
2,139
0
0
1,798
892
1,785
3,624
0
13,980
37,830
0
ALLOWANCES
CARRIED OVER
TO 2001
15
40
6
8
407
0
0
0
101
590
612
695
37
2
0
2
1,733
178
2
668
320
415
69
39
1
5
42
100
1,391
17
1,001
5,347
0
0
741
372
251
292
0
6,291
10,081
0
A, 23
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
PLANT NAME
Cane Run
Cane Run
Cane Run
Cane Run
Cane Run
Coleman
Coleman
Coleman
Cooper
Cooper
Cooper
D B Wilson
Dale
Dale
Dale
E W Brown
E W Brown
E W Brown
E W Brown
E W Brown
E W Brown
E W Brown
E W Brown
E W Brown
E W Brown
East Bend
Elmer Smith
Elmer Smith
Elmer Smith
Ghent
Ghent
Ghent
Ghent
Ghent
Green River
Green River
Green River
Green River
Green River
Green River
H L Spurlock
H L Spurlock
Henderson 1
Hmp&L Station 2
PLANT
CODE
1363
1363
1363
1363
1363
1381
1381
1381
1384
1384
1384
6823
1385
1385
1385
1355
1355
1355
1355
1355
1355
1355
1355
1355
1355
6018
1374
1374
1374
1356
1356
1356
1356
1356
1357
1357
1357
1357
1357
1357
6041
6041
1372
1382
STACK/UNIT ID*
4
5
6
"12
"13
C1
C2
C3
CS1 (1,2)
1
2
W1
CS2 (3, 4)
3
4
1
CS003 (2, 3)
2
3
6
7
8
9
10
11
2
XS12(1,2)
1
2
1
2
CS002 (3, 4)
3
4
XS123(1,2, 3)
1
2
3
4
5
1
2
6
H1
2000
ALLOWANCES
ALLOCATED
4,522
4,341
5,500
0
0
4,854
5,536
5,324
3,210
6,608
12,465
1,984
1,847
3,066
5,807
1 1 ,254
0
0
0
0
0
0
18,322
2,805
6,213
12,252
12,737
13,960
13,717
130
851
744
2,826
3,372
9,824
16,591
810
5,758
HELD IN
ACCOUNTS AS
OF 3/1/2001
6,958
5,341
6,103
0
0
16,210
15,268
16,266
9,124
20,595
10,965
3,184
3,247
18,432
28,632
71 ,257
100
100
100
100
100
100
25,898
8,330
18,464
103,708
17,737
19,960
19,717
130
851
744
12,826
14,229
40,954
25,618
810
11,746
ALLOWANCES
DEDUCTED
6,245
5,329
5,865
0
0
15,485
14,362
15,350
5,974
12,128
10,109
3,143
3,143
7,867
10,855
31 ,638
10
10
0
0
0
0
14,850
2,057
4,799
4,109
17,240
18,815
19,022
125
174
223
9,987
12,851
16,300
22,352
698
2,794
ALLOWANCES
CARRIED OVER
TO 2001
713
12
238
0
0
725
906
916
3,150
8,467
856
41
104
10,565
17,777
39,619
90
90
100
100
100
100
1 1 ,048
6,273
13,665
99,599
497
1,145
695
5
677
521
2,839
1,378
24,654
3,266
112
8,952
A, 24
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
LA
LA
LA
LA
LA
LA
LA
LA
PLANT NAME
Hmp&L Station 2
J K Smith
J K Smith
J K Smith
Mill Creek
Mill Creek
Mill Creek
Mill Creek
Na 1 - 7220
Na 1 - 7220
Na 1 - 7220
Paradise
Paradise
Paradise
Pineville
R D Green
R D Green
Robert Reid
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Trimble County
Tyrone
Tyrone
Tyrone
Tyrone
Tyrone
A B Paterson
A B Paterson
Arsenal Hill
Big Cajun 1
Big Cajun 1
Big Cajun 2
Big Cajun 2
Big Cajun 2
PLANT
CODE
1382
54
54
54
1364
1364
1364
1364
7220
7220
7220
1378
1378
1378
1360
6639
6639
1383
1379
1379
1379
1379
1379
1379
1379
1379
1379
1379
1379
1379
6071
1361
1361
1361
1361
1361
1407
1407
1416
1464
1464
6055
6055
6055
STACK/UNIT ID*
H2
SCT1
SCT2
SCT3
1
2
3
4
**3
**4
"5
1
2
3
3
G1
G2
R1
CSSH15(1,2, 3, 4, 5)
1
2
3
4
5
2000
ALLOWANCES
ALLOCATED
5,936
0
0
0
8,082
8,142
10,982
13,622
0
0
0
10,821
12,304
25,513
914
5,294
6,378
942
3,644
3,673
3,708
3,594
3,826
CSSH60 (6, 7, 8, 9, 10)
6
7
8
9
10
1
1
2
3
4
5
3
4
5A
1B1
1B2
2B1
2B2
2B3
3,712
3,640
3,571
3,666
4,895
9,634
0
0
0
0
1,713
7
8
30
27
27
14,868
14,640
14,657
HELD IN
ACCOUNTS AS
OF 3/1/2001
9,289
10
10
10
8,082
10,142
9,982
8,622
0
0
0
20,321
24,804
183,941
2,914
2,617
2,616
8,942
4,144
4,173
4,708
4,094
4,326
3,712
4,640
4,571
4,166
4,992
9,969
0
0
0
0
3,713
2
2
30
27
27
16,079
17,036
17,304
ALLOWANCES
DEDUCTED
3,108
0
1
0
7,677
9,841
8,806
8,179
0
0
0
17,733
24,387
102,920
1,449
1,838
1,544
7,439
3,495
3,324
4,022
3,678
3,895
2,604
3,794
3,877
3,405
1,993
7,583
0
0
0
0
2,607
0
0
1
1
4
16,069
17,026
17,289
ALLOWANCES
CARRIED OVER
TO 2001
6,181
10
9
10
405
301
1,176
443
0
0
0
2,588
417
81 ,021
1,465
779
1,072
1,503
649
849
686
416
431
1,108
846
694
761
2,999
2,386
0
0
0
0
1,106
2
2
29
26
23
10
10
15
A, 25
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
PLANT NAME
Calcasieu Power, LLC
D G Hunter
D G Hunter
Doc Bonin
Doc Bonin
Doc Bonin
Dolet Hills
Evangeline (Coughlin)
Evangeline (Coughlin)
Evangeline (Coughlin)
Evangeline (Coughlin)
Evangeline (Coughlin)
Houma
Houma
Lieberman
Lieberman
Little Gypsy
Little Gypsy
Little Gypsy
Louisiana 1
Louisiana 1
Louisiana 1
Louisiana 1
Louisiana 1
Louisiana 2
Louisiana 2
Louisiana 2
Michoud
Michoud
Michoud
Monroe
Monroe
Morgan City
Natchitoches
Ninemile Point
Ninemile Point
Ninemile Point
Ninemile Point
Ninemile Point
Opelousas
R S Nelson
R S Nelson
R S Nelson
Rodemacher
PLANT
CODE
55165
6558
6558
1443
1443
1443
51
1396
1396
1396
1396
1396
1439
1439
1417
1417
1402
1402
1402
1391
1391
1391
1391
1391
1392
1392
1392
1409
1409
1409
1448
1448
1449
1450
1403
1403
1403
1403
1403
1454
1393
1393
1393
6190
STACK/UNIT ID*
GTG1
3
4
1
2
3
1
6
7
6-1
7-1
7-2
15
16
3
4
1
2
3
1A
2A
3A
4A
5A
10
11
12
1
2
3
11
12
4
10
1
2
3
4
5
10
3
4
6
1
2000
ALLOWANCES
ALLOCATED
0
0
32
12
24
45
20,501
46
128
0
0
0
10
14
86
72
245
378
543
116
2
2
0
0
0
0
0
71
106
491
13
45
5
0
62
112
96
691
930
1
39
123
19,569
3,249
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
0
32
12
24
45
20,501
0
0
46
64
64
10
14
111
47
245
378
543
6
7
7
36
33
2
2
2
3
5
2,321
13
45
5
1
62
112
96
691
930
1
4
8
20,834
3,249
ALLOWANCES
DEDUCTED
0
0
15
1
1
1
19,518
0
0
2
1
1
0
0
102
4
1
13
5
3
2
2
18
19
0
0
0
1
3
2,252
0
0
0
0
1
2
1
163
11
0
2
7
20,422
136
ALLOWANCES
CARRIED OVER
TO 2001
0
0
17
11
23
44
983
0
0
44
63
63
10
14
9
43
244
365
538
3
5
5
18
14
2
2
2
2
2
69
13
45
5
1
61
110
95
528
919
1
2
1
412
3,113
A, 26
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
PLANT NAME
Rodemacher
Ruston
Ruston
Sterlington
Sterlington
Sterlington
Teche
Teche
Waterford 1 & 2
Waterford 1 & 2
Willow Glen
Willow Glen
Willow Glen
Willow Glen
Willow Glen
Berkshire Power
Brayton Point
Brayton Point
Brayton Point
Brayton Point
Canal
Canal
Cannon Street
Cleary Flood
Cleary Flood
Dighton
Kendall Square
Kendall Square
Kendall Square
Kendall Square
Millennium Power Partners, L.P.
Mount Tom
Mystic
Mystic
Mystic
Mystic
New Boston
New Boston
Salem Harbor
Salem Harbor
Salem Harbor
Salem Harbor
Somerset
Somerset
PLANT
CODE
6190
1458
1458
1404
1404
1404
1400
1400
8056
8056
1394
1394
1394
1394
1394
55041
1619
1619
1619
1619
1599
1599
1616
1682
1682
55026
1595
1595
1595
1595
55079
1606
1588
1588
1588
1588
1589
1589
1626
1626
1626
1626
1613
1613
STACK/UNIT ID*
2
2
3
10
7C
7AB
2
3
1
2
1
2
3
4
5
1
1
2
3
4
1
2
3
8
9
1
CS12(1,2)
1
2
3
1
1
4
5
6
7
1
2
1
2
3
4
1
2
2000
ALLOWANCES
ALLOCATED
18,909
4
5
174
0
72
27
446
4,554
3,535
99
26
93
291
458
0
8,481
8,911
18,625
12,139
13,235
17,999
374
143
2,679
0
199
208
421
0
6,347
2,607
3,092
3,076
17,244
6,158
6,324
3,339
3,408
5,461
12,571
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
18,909
4
5
174
15
57
27
446
4,554
3,535
4
6
8
11
746
10
10,873
10,532
22,505
4,959
13,235
12,999
374
158
2,664
34
199
208
421
5
12,440
1,607
2,092
2,076
7,604
58
64
3,753
4,072
5,885
7,834
0
0
ALLOWANCES
DEDUCTED
14,703
0
0
2
5
2
1
58
1,183
627
1
3
3
6
707
3
9,370
9,070
21,427
4,719
12,472
1 1 ,376
0
137
142
2
45
46
94
0
7,373
1,103
1,116
1,016
6,149
1
1
3,576
3,877
5,603
7,458
0
0
ALLOWANCES
CARRIED OVER
TO 2001
4,206
4
5
172
10
55
26
388
3,371
2,908
3
3
5
5
39
7
1,503
1,462
1,078
240
763
1,623
374
21
2,522
32
154
162
327
5
5,067
504
976
1,060
1,455
57
63
177
195
282
376
0
0
A, 27
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MA
MA
MA
MA
MA
MA
MA
MA
MA
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
PLANT NAME
Somerset
Somerset
Somerset
Somerset
Somerset
Somerset
West Springfield
West Springfield
West Springfield
Brandon Shores
Brandon Shores
C P Crane
C P Crane
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Dickerson
Dickerson
Dickerson
Dickerson
Dickerson
Dickerson
Dickerson
Dickerson
Dickerson
Easton 2
Easton 2
Easton 2
Gould Street
Herbert A Wagner
Herbert A Wagner
Herbert A Wagner
Herbert A Wagner
Morgantown
Morgantown
Nanticoke
Panda Brandywine
Panda Brandywine
PLANT
CODE
1613
1613
1613
1613
1613
1613
1642
1642
1642
602
602
1552
1552
1571
1571
1571
1571
1571
1571
1571
1571
1571
1572
1572
1572
1572
1572
1572
1572
1572
1572
4257
4257
4257
1553
1554
1554
1554
1554
1573
1573
4207
54832
54832
STACK/UNIT ID*
3
4
5
6
7
8
1
2
3
1
2
1
2
CSE12(1,2)
1
2
3
4
"GTS
**GT4
"GTS
"GT6
XS123(1,2, 3)
1
2
3
CW1
GT2
GTS
HCT3
HCT4
"25
"26
"27
3
1
2
3
4
1
2
"ST1
1
2
2000
ALLOWANCES
ALLOCATED
0
0
0
0
2,765
3,985
378
356
3,012
18,510
7,795
4,349
4,043
9,202
10,219
12,610
3,557
707
707
894
894
5,848
5,500
5,846
0
1,082
1,082
0
0
0
0
0
821
1,291
1,299
8,381
1,520
16,932
16,189
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
0
0
0
1,715
5,035
352
331
2,803
32,099
27,834
24,129
16,705
19,202
17,219
12,503
2,600
707
707
894
894
8,848
13,500
10,846
0
1,082
1,082
0
0
0
0
0
814
1,418
7,316
17,858
2,800
43,263
43,189
0
1
1
ALLOWANCES
DEDUCTED
0
0
0
0
0
5,023
0
0
840
28,465
21 ,235
15,633
15,044
17,258
15,343
1,643
1,215
5
5
17
4
8,145
11,763
9,305
0
0
2
0
0
0
0
0
582
813
5,610
14,939
2,240
37,896
37,722
0
1
1
ALLOWANCES
CARRIED OVER
TO 2001
0
0
0
0
1,715
12
352
331
1,963
3,634
6,599
8,496
1,661
1,944
1,876
10,860
1,385
702
702
877
890
703
1,737
1,541
0
1,082
1,080
0
0
0
0
0
232
605
1,706
2,919
560
5,367
5,467
0
0
0
A, 28
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
PLANT NAME
Ferryman
Ferryman
Ferryman
Ferryman
R P Smith
R P Smith
Riverside
Riverside
Riverside
Riverside
Riverside
Vienna
Westport
Westport
Androscoggin Cogeneration Center
Androscoggin Cogeneration Center
Androscoggin Cogeneration Center
Graham Station
Maine Independence Station
Maine Independence Station
Mason Steam
Mason Steam
Mason Steam
Rumford Power Associates
William F Wyman
William F Wyman
William F Wyman
William F Wyman
48th Street Peaking Station
48th Street Peaking Station
48th Street Peaking Station
B C Cobb
B C Cobb
B C Cobb
B C Cobb
B C Cobb
Belle River
Belle River
Belle River
Belle River
Belle River
Conners Creek
Conners Creek
Conners Creek
PLANT
CODE
1556
1556
1556
1556
1570
1570
1559
1559
1559
1559
1559
1564
1560
1560
55031
55031
55031
1470
55068
55068
1496
1496
1496
55100
1507
1507
1507
1507
7258
7258
7258
1695
1695
1695
1695
1695
6034
6034
6034
6034
6034
1726
1726
1726
STACK/UNIT ID*
"51
"52
"61
"62
9
11
1
2
3
4
5
8
3
4
CT01
CT02
CT03
5
1
2
3
4
5
1
1
2
3
4
9
"7
"8
1
2
3
4
5
1
2
CTG121
CTG122
CTG131
15
16
17
2000
ALLOWANCES
ALLOCATED
0
0
0
0
634
2,314
189
171
354
455
294
3,645
186
258
0
0
0
344
0
0
2
1
1
0
1,159
1,161
2,946
6,274
0
298
298
1,142
1,229
1,223
4,573
4,695
18,505
18,769
0
0
0
4,285
4,279
4,034
HELD IN
ACCOUNTS AS
OF 3/1/2001
2,401
0
0
0
722
4,117
0
0
0
4
0
3,645
0
0
2
2
2
3
10
10
8
7
9
33
1,159
1,161
5,018
6,274
10
88
98
63,186
2,022
1,223
9,950
9,349
18,505
18,769
5
5
5
171
981
4,034
ALLOWANCES
DEDUCTED
134
0
0
0
482
4,017
0
0
0
0
0
3,312
0
0
2
2
0
0
2
2
4
4
5
1
894
876
4,124
4,678
0
5
1
0
0
0
8,291
7,790
15,178
14,179
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2001
2,267
0
0
0
240
100
0
0
0
4
0
333
0
0
0
0
2
3
8
8
4
3
4
32
265
285
894
1,596
10
83
97
63,186
2,022
1,223
1,659
1,559
3,327
4,590
5
5
5
171
981
4,034
A, 29
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
PLANT NAME
Conners Creek
Dan E Karn
Dan E Karn
Dan E Karn
Dan E Karn
Dan E Karn
Dearborn Industrial Generation
Delray
Delray
Delray
Delray
Delray
Delray
Delray
Delray
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Endicott Generating
Erickson
Greenwood
Greenwood
Greenwood
Greenwood
Harbor Beach
J B Sims
J C Weadock
J C Weadock
J C Weadock
J H Campbell
J H Campbell
J H Campbell
J H Campbell
J R Whiting
J R Whiting
J R Whiting
James De Young
Kalamazoo River Generating Station
Livingston Generating Station
Livingston Generating Station
Livingston Generating Station
PLANT
CODE
1726
1702
1702
1702
1702
1702
55088
1728
1728
1728
1728
1728
1728
1728
1728
1831
1831
1831
1831
1831
1831
4259
1832
6035
6035
6035
6035
1731
1825
1720
1720
1720
1710
1710
1710
1710
1723
1723
1723
1830
55101
55102
55102
55102
STACK/UNIT ID*
18
1
2
CS0009 (3, 4)
3
4
GTP1
7
8
9
10
11
12
CTG111
CTG121
1
2
3
4
5
6
1
1
1
CTG111
CTG112
CTG121
1
3
CS0009 (7, 8)
7
8
CS0009 (1 , 2)
1
2
3
1
2
3
5
1
1
2
3
2000
ALLOWANCES
ALLOCATED
3,353
8,388
8,567
1,020
948
0
0
12
0
14
0
14
0
0
1,298
1,354
1,327
2,223
2,666
2,343
1,810
6,646
539
0
0
0
3,520
1,484
4,745
4,691
8,098
9,685
27,805
3,412
3,842
4,919
1,048
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
3,353
12,737
13,097
3,912
3,468
0
0
12
0
14
0
14
5
5
1,298
1,354
1,327
2,223
2,666
2,343
1,810
6,646
1,696
5
5
5
3,520
1,484
5,885
5,653
15,521
16,986
23,949
3,797
4,253
5,413
1,448
0
0
0
0
ALLOWANCES
DEDUCTED
0
8,614
8,914
3,259
2,890
0
0
0
0
0
0
0
0
0
779
727
576
1,775
1,833
988
755
6,504
1,157
0
0
0
2,246
626
4,904
4,711
9,218
10,822
20,722
3,348
2,859
4,169
1,438
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2001
3,353
4,123
4,183
653
578
0
0
12
0
14
0
14
5
5
519
627
751
448
833
1,355
1,055
142
539
5
5
5
1,274
858
981
942
6,303
6,164
3,227
449
1,394
1,244
10
0
0
0
0
A, 30
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
PLANT NAME
Livingston Generating Station
Marysville
Marysville
Marysville
Marysville
Marysville
Marysville
Michigan Power Limited Partnership
Mistersky
Mistersky
Mistersky
Monroe
Monroe
Monroe
Monroe
Monroe
Monroe
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
River Rouge
River Rouge
River Rouge
Shiras
St Clair
St Clair
St Clair
St Clair
St Clair
St Clair
St Clair
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Wyandotte
PLANT
CODE
55102
1732
1732
1732
1732
1732
1732
54915
1822
1822
1822
1733
1733
1733
1733
1733
1733
1769
1769
1769
1769
1769
1769
1769
1769
1769
1740
1740
1740
1843
1743
1743
1743
1743
1743
1743
1743
1745
1745
1745
1745
1745
1745
1866
STACK/UNIT ID*
4
CS0001 (9, 10)
9
10
030002(11,12)
11
12
1
5
6
7
030012(1,2)
1
2
CS0034 (3, 4)
3
4
CS4 (1 , 2, 3, 4)
2
3
4
5
6
7
8
9
1
2
3
3
1
2
3
4
5
6
7
2000
ALLOWANCES
ALLOCATED
0
1,637
1,261
1,315
1,061
0
257
437
485
23,669
24,307
22,771
24,617
637
1,907
1,677
2,934
2,941
2,216
2,192
2,346
79
6,323
9,103
500
3,666
3,543
3,525
3,396
0
7,342
13,459
CS0006(16, 17, 18, 19)
16
17
18
19
9A
5
3,292
767
3,563
698
14,507
960
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
1,637
1,261
1,315
1,061
4
257
437
485
32,630
44,013
49,164
45,334
637
2,711
2,549
4,619
4,086
1,770
2,302
2,138
4
6,323
9,103
500
5,756
5,567
4,473
5,596
0
7,452
21,912
3,357
3,222
3,563
2,875
15,684
151
ALLOWANCES
DEDUCTED
0
313
452
315
394
3
1
3
2
28,549
29,706
26,393
22,894
318
2,510
2,361
4,199
3,714
1,708
2,091
1,943
0
5,939
6,549
356
5,756
5,138
4,473
5,596
0
7,452
21,912
3,357
3,222
2,620
2,875
15,684
0
ALLOWANCES
CARRIED OVER
TO 2001
0
1,324
809
1,000
667
1
256
434
483
4,081
14,307
22,771
22,440
319
201
188
420
372
62
211
195
4
384
2,554
144
0
429
0
0
0
0
0
0
0
943
0
0
151
A, 31
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
Ml
Ml
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MO
MO
MO
MO
PLANT NAME
Wyandotte
Wyandotte
Allen S King
Black Dog
Black Dog
Black Dog
Black Dog
Black Dog
Clay Boswell
Clay Boswell
Clay Boswell
Clay Boswell
Clay Boswell
Cottage Grove
Fox Lake
High Bridge
High Bridge
High Bridge
High Bridge
High Bridge
Hoot Lake
Hoot Lake
Hutchinson Utils Comm - Plant 2
M L Hibbard
M L Hibbard
M L Hibbard
Minnesota Valley
Northeast Station
Riverside
Riverside
Riverside
Riverside
Sherburne County
Sherburne County
Sherburne County
Sherburne County
Silver Lake
Syl Laskin
Syl Laskin
Syl Laskin
Asbury
Blue Valley
Chamois
Columbia
PLANT
CODE
1866
1866
1915
1904
1904
1904
1904
1904
1893
1893
1893
1893
1893
55010
1888
1912
1912
1912
1912
1912
1943
1943
6358
1897
1897
1897
1918
1961
1927
1927
1927
1927
6090
6090
6090
6090
2008
1891
1891
1891
2076
2132
2169
2123
STACK/UNIT ID*
7
8
1
CS1 (1 , 2, 3, 4)
1
2
3
4
CS0003 (1 , 2, 3)
1
2
3
4
01
3
CS0001 (3, 4, 5, 6)
3
4
5
6
2
3
1
CS0001 (3, 4)
3
4
4
NEPP
XS67 (6, 7)
6
7
8
CS1 (1,2)
1
2
3
4
CS0001 (1 , 2)
1
2
1
3
2
CSS (6, 7)
2000
ALLOWANCES
ALLOCATED
953
0
15,628
1,914
3,683
2,275
4,056
1,827
1,800
9,866
10,324
0
2,069
2,118
1,458
2,194
1,852
1,242
1,978
0
987
1,094
938
1,052
3,076
1,339
5,068
13,091
13,184
12,956
3,133
1,692
1,649
6,975
4,670
5,457
HELD IN
ACCOUNTS AS
OF 3/1/2001
1,525
237
30,399
1,914
3,683
2,275
4,056
1,827
1,800
8,753
3,311
5
2,069
5,314
3,059
3,062
9,546
1,850
1,978
1
55
55
938
4,006
2,797
1,339
1 1 ,645
14,679
14,833
12,979
3,132
808
807
42,870
4,670
2,701
ALLOWANCES
DEDUCTED
1,523
237
27,251
10
11
1,070
2,352
1,827
1,800
8,748
2,774
4
1
254
273
1,092
1,840
1,201
1,438
0
54
54
2
1,906
1,105
1,105
10,585
6,396
5,277
1 1 ,090
2,028
754
754
3,735
3,903
2,654
ALLOWANCES
CARRIED OVER
TO 2001
2
0
3,148
1,904
3,672
1,205
1,704
0
0
5
537
1
2,068
5,060
2,786
1,970
7,706
649
540
1
1
1
936
2,100
1,692
234
1,060
8,283
9,556
1,889
1,104
54
53
39,135
767
47
A, 32
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
PLANT NAME
Columbia
Columbia
Columbia
Combustion Turbine 1
Combustion Turbine 1
Combustion Turbine 1
Combustion Turbine 1
Combustion Turbine 2
Combustion Turbine 3
Essex Power Plant
Hawthorn
Hawthorn
Hawthorn
Hawthorn
Hawthorn
latan
latan
James River
James River
James River
James River
Jim Hill
Labadie
Labadie
Labadie
Labadie
Lake Road
Meramec
Meramec
Meramec
Meramec
Montrose
Montrose
Montrose
Montrose
Na 1 - 7223
Na 1 - 7223
Na 1 - 7223
Na 1 - 7226
New Madrid
New Madrid
Nodaway Power Plant
Nodaway Power Plant
Rg1 &2
PLANT
CODE
2123
2123
2123
7160
7160
7160
7160
7161
7162
7749
2079
2079
2079
2079
2079
6065
6065
2161
2161
2161
2161
2073
2103
2103
2103
2103
2098
2104
2104
2104
2104
2080
2080
2080
2080
7223
7223
7223
7226
2167
2167
7754
7754
212
STACK/UNIT ID*
6
7
8
**1
**NA4
**NA5
**NA6
**2
**3
1
5
6
7
8
9
1
**2
3
4
5
**GT2
"1
1
2
3
4
6
1
2
3
4
1
CS023 (2, 3)
2
3
**1
"2
"3
"1
1
2
1
2
**1
2000
ALLOWANCES
ALLOCATED
903
3,631
125
0
0
0
0
0
0
0
12,773
0
0
0
0
16,208
0
3,327
5,975
2,133
604
0
17,553
16,363
17,487
15,584
605
2,745
2,778
6,058
7,175
3,189
3,535
4,349
0
0
0
0
12,178
14,009
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
903
3,220
125
0
0
0
0
0
0
50
33,639
5
5
5
5
16,208
0
1,863
2,277
4,045
4
0
12,413
16,233
17,347
15,460
2,840
2,736
4,251
6,049
12,154
4,990
5,724
8,498
0
0
0
0
8,425
8,243
50
50
0
ALLOWANCES
DEDUCTED
237
406
0
0
0
0
0
0
0
0
0
1
0
0
0
13,430
0
1,503
1,538
3,472
0
0
8,278
9,949
1 1 ,450
9,616
1,760
1,358
1,249
5,142
10,181
3,023
2,695
3,799
0
0
0
0
8,324
8,127
0
0
0
ALLOWANCES
CARRIED OVER
TO 2001
666
2,814
125
0
0
0
0
0
0
50
33,639
4
5
5
5
2,778
0
360
739
573
4
0
4,135
6,284
5,897
5,844
1,080
1,378
3,002
907
1,973
1,967
3,029
4,699
0
0
0
0
101
116
50
50
0
A, 33
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
PLANT NAME
Rg1 &2
Rush Island
Rush Island
Sibley
Sibley
Sibley
Sibley
Sikeston
Sioux
Sioux
Southwest
St. Francis
State Line (MO)
State Line (MO)
Thomas Hill
Thomas Hill
Thomas Hill
Batesville Generation Facility
Batesville Generation Facility
Batesville Generation Facility
Baxter Wilson
Baxter Wilson
Caledonia Power I, LLC
Caledonia Power I, LLC
Caledonia Power I, LLC
Caledonia Power I, LLC
Caledonia Power I, LLC
Caledonia Power I, LLC
Chevron Cogenerating Station
Daniel Electric Generating Plant
Daniel Electric Generating Plant
Delta
Delta
Gerald Andrus
Jack Watson
Jack Watson
Jack Watson
Jack Watson
Jack Watson
Moselle
Moselle
Moselle
Moselle
Moselle
PLANT
CODE
212
6155
6155
2094
2094
2094
2094
6768
2107
2107
6195
7604
7296
7296
2168
2168
2168
55063
55063
55063
2050
2050
2783
2783
2783
2783
2783
2783
2047
6073
6073
2051
2051
8054
2049
2049
2049
2049
2049
2070
2070
2070
2070
2070
STACK/UNIT ID*
**2
1
2
CS0001 (1 , 2, 3)
1
2
3
1
1
2
1
1
1
2-2
MB1
MB2
MBS
1
2
3
1
2
AA-001
AA-002
AA-003
AA-004
AA-005
AA-006
5
1
2
1
2
1
1
2
3
4
5
1
2
3
**4
**5
2000
ALLOWANCES
ALLOCATED
0
14,960
15,652
519
638
7,634
6,791
10,823
9,492
4,184
0
0
0
4,421
7,432
18,257
0
0
0
360
3,564
0
0
0
0
0
0
0
1 1 ,228
14,277
26
50
3,282
172
180
273
7,525
15,415
35
76
42
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
17,327
18,230
2,190
3,727
13,767
7,063
23,737
23,417
4,376
50
30
110
2,985
4,088
11,492
2
2
2
60
10,151
1
1
1
1
1
1
25
16,056
14,690
6
5
33,390
172
180
273
26,555
39,813
35
66
42
10
0
ALLOWANCES
DEDUCTED
0
13,643
13,257
1,588
1,588
12,703
6,523
20,017
16,522
2,737
1
2
1
2,948
4,028
11,337
1
1
1
53
9,951
0
0
0
0
0
0
9
13,948
13,060
1
1
31,740
2
1
1
16,152
36,751
2
1
2
0
0
ALLOWANCES
CARRIED OVER
TO 2001
0
3,684
4,973
602
2,139
1,064
540
3,720
6,895
1,639
49
28
109
37
60
155
1
1
1
7
200
1
1
1
1
1
1
16
2,108
1,630
5
4
1,650
170
179
272
10,403
3,062
33
65
40
10
0
A, 34
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MT
MT
MT
MT
MT
MT
MT
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
PLANT NAME
Moselle
Moselle
Natchez
New Albany Power 1, LLC
New Albany Power 1, LLC
New Albany Power 1, LLC
New Albany Power 1, LLC
New Albany Power 1, LLC
New Albany Power 1, LLC
R D Morrow
R D Morrow
Rex Brown
Rex Brown
Rex Brown
Rex Brown
Sweatt
Sweatt
Sweatt
Wright
Colstrip
Colstrip
Colstrip
Colstrip
Frank Bird
J E Corette
Lewis & Clark
Asheville
Asheville
Asheville
Asheville
Belews Creek
Belews Creek
Buck
Buck
Buck
Buck
Buck
Cape Fear
Cape Fear
Cape Fear
Cape Fear
Cliffside
Cliffside
Cliffside
PLANT
CODE
2070
2070
2052
13213
13213
13213
13213
13213
13213
6061
6061
2053
2053
2053
2053
2048
2048
2048
2063
6076
6076
6076
6076
2184
2187
6089
2706
2706
2706
2706
8042
8042
2720
2720
2720
2720
2720
2708
2708
2708
2708
2721
2721
2721
STACK/UNIT ID*
**6
"7
1
AA-001
AA-002
AA-003
AA-004
AA-005
AA-006
1
2
3
4
1A
1B
CS01 (1 , 2)
1
2
W4
1
2
3
4
1
2
B1
1
2
3
4
1
2
5
6
7
8
9
3
4
5
6
1
2
3
2000
ALLOWANCES
ALLOCATED
0
0
2
0
0
0
0
0
0
4,800
5,254
41
159
6
6
78
86
0
7,859
7,870
4,405
2,917
0
5,062
1,444
6,622
5,261
0
0
134,376
131,213
1,709
1,208
1,831
6,407
7,354
599
599
3,382
3,913
1,612
1,625
2,486
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
0
2
1
1
1
1
1
1
6,414
8,197
2
3
1
1
78
86
0
5,208
5,624
2,933
2,329
0
3,614
1,444
10,893
9,475
10
10
27,108
52,453
828
837
922
3,572
5,093
0
0
5,955
6,897
1,313
1,346
2,080
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
0
4,138
4,095
1
1
0
0
0
1
0
5,059
5,559
2,859
2,315
0
3,315
1,141
10,793
9,375
8
5
24,643
47,686
759
761
838
3,247
4,640
0
0
5,854
6,797
1,194
1,224
1,891
ALLOWANCES
CARRIED OVER
TO 2001
0
0
2
1
1
1
1
1
1
2,276
4,102
1
2
1
1
78
85
0
149
65
74
14
0
299
303
100
100
2
5
2,465
4,767
69
76
84
325
453
0
0
101
100
119
122
189
A, 35
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
PLANT NAME
Cliffside
Cliffside
Dan River
Dan River
Dan River
G G Allen
G G Allen
G G Allen
G G Allen
G G Allen
L V Sutton
L V Sutton
L V Sutton
L V Sutton
Lee
Lee
Lee
Lee
Lee
Lee
Lee
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Marshall
Marshall
Marshall
Marshall
Mayo
Mayo
Mayo
PLANT
CODE
2721
2721
2723
2723
2723
2718
2718
2718
2718
2718
2713
2713
2713
2713
2709
2709
2709
2709
2709
2709
2709
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
2727
2727
2727
2727
6250
6250
6250
STACK/UNIT ID*
4
5
1
2
3
1
2
3
4
5
CS0002 (1 , 2)
1
2
3
1
2
3
10
11
12
13
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
1
2
3
4
CS0005(1A, 1B)
1A
1B
2000
ALLOWANCES
ALLOCATED
2,555
33,588
3,749
4,665
7,467
1 1 ,374
1 1 ,552
23,354
21 ,382
22,823
2,051
2,270
8,298
2,226
2,277
7,132
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
24,31 1
26,809
43,969
44,018
12,785
12,785
HELD IN
ACCOUNTS AS
OF 3/1/2001
973
26,323
1,448
1,578
3,393
6,018
4,768
10,045
10,266
6,368
3,807
3,807
15,236
3,519
3,426
10,195
10
10
10
10
6
4
4
4
4
4
4
4
6
5
5
5
4
5
4
4
17,054
15,631
26,260
27,772
14,857
14,857
ALLOWANCES
DEDUCTED
884
23,946
1,316
1,433
3,084
5,471
4,334
9,132
9,333
5,789
3,706
3,707
15,135
3,418
3,326
10,094
4
4
4
3
3
2
2
2
2
2
2
2
3
2
2
2
2
2
2
2
15,503
14,303
23,872
25,363
14,756
14,756
ALLOWANCES
CARRIED OVER
TO 2001
89
2,377
132
145
309
547
434
913
933
579
101
100
101
101
100
101
6
6
6
7
3
2
2
2
2
2
2
2
3
3
3
3
2
3
2
2
1,551
1,328
2,388
2,409
101
101
A, 36
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
PLANT NAME
Riverbend
Riverbend
Riverbend
Riverbend
Rockingham Power, LLC
Rockingham Power, LLC
Rockingham Power, LLC
Rockingham Power, LLC
Rockingham Power, LLC
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
W H Weatherspoon
W H Weatherspoon
W H Weatherspoon
W H Weatherspoon
Antelope Valley
Antelope Valley
Coal Creek
Coal Creek
Coyote
Leland Olds
Leland Olds
Milton R Young
Milton R Young
R M Heskett
Stanton
Stanton
Bluffs
C W Burdick
Canaday
Gerald Gentleman Sta
Gerald Gentleman Sta
Gerald Whelan Energy Center
Harold Kramer
Harold Kramer
Harold Kramer
Harold Kramer
Lon Wright
PLANT
CODE
2732
2732
2732
2732
55116
55116
55116
55116
55116
2712
2712
2712
2712
2712
2712
2712
2712
2716
2716
2716
2716
6469
6469
6030
6030
8222
2817
2817
2823
2823
2790
2824
2824
2276
2241
2226
6077
6077
60
2269
2269
2269
2269
2240
STACK/UNIT ID*
7
8
9
10
CT1
CT2
CT3
CT4
CT5
1
2
CS0003 (3A, 3B)
3A
3B
CS0004 (4A, 4B)
4A
4B
CS0001 (1 , 2)
1
2
3
B1
B2
1
2
B1
1
2
B1
B2
B2
1
10
4
B-3
1
1
2
1
1
2
3
4
8
2000
ALLOWANCES
ALLOCATED
3,754
3,759
5,071
5,406
0
0
0
0
0
1 1 ,088
19,642
9,096
9,096
10,407
10,407
1,122
1,125
1,626
1 1 ,947
11,131
23,310
21,187
16,182
9,105
26,401
12,951
15,885
3,202
7,447
1,334
18
0
627
10,805
17,572
2,335
38
40
1,052
2,079
2,044
HELD IN
ACCOUNTS AS
OF 3/1/2001
3,574
3,411
6,263
5,959
5
5
4
4
5
16,158
30,386
15,458
15,458
10,029
10,029
2,097
2,097
2,732
11,947
11,131
14,410
17,587
16,117
17,605
32,901
25,512
23,291
3,162
1 1 ,847
1,334
18
10
627
10,714
17,302
2,335
38
40
1,052
2,079
2,044
ALLOWANCES
DEDUCTED
3,250
3,101
5,693
5,418
3
4
2
3
4
16,058
30,286
15,357
15,357
9,927
9,928
1,997
1,997
2,632
6,640
6,407
14,332
12,817
14,521
16,864
28,587
18,095
21,134
1,778
7,660
973
0
1
81
9,604
12,988
2,164
0
0
0
0
841
ALLOWANCES
CARRIED OVER
TO 2001
324
310
570
541
2
1
2
1
1
100
100
101
101
102
101
100
100
100
5,307
4,724
78
4,770
1,596
741
4,314
7,417
2,157
1,384
4,187
361
18
9
546
1,110
4,314
171
38
40
1,052
2,079
1,203
A, 37
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NH
NH
NH
NH
NH
NH
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
PLANT NAME
Na1 -7019
Nebraska City
North Omaha
North Omaha
North Omaha
North Omaha
North Omaha
North Omaha
Platte
Rokeby
Sarpy County Station
Sarpy County Station
Sarpy County Station
Sarpy County Station
Sarpy County Station
Sheldon
Sheldon
Merrimack
Merrimack
Newington
Schiller
Schiller
Schiller
B L England
B L England
B L England
Bergen
Bergen
Bergen
Bergen
Bergen
Bergen
Burlington (NJ)
Burlington (NJ)
Burlington (NJ)
Burlington (NJ)
Burlington (NJ)
Burlington (NJ)
Burlington (NJ)
Burlington (NJ)
Burlington (NJ)
Butler
Deepwater
Deepwater
PLANT
CODE
7019
6096
2291
2291
2291
2291
2291
2291
59
6373
2292
2292
2292
2292
2292
2277
2277
2364
2364
8002
2367
2367
2367
2378
2378
2378
2398
2398
2398
2398
2398
2398
2399
2399
2399
2399
2399
2399
2399
2399
2399
7152
2384
2384
STACK/UNIT ID*
**NA1
1
CSOOOA (1 , 2, 3)
1
2
3
4
5
1
2
CT3
CT4A
CT4B
CT5A
CT5B
1
2
1
2
1
4
5
6
1
2
3
1
2
1101
1201
1301
1401
7
101
102
103
104
121
122
123
124
"1
1
3
2000
ALLOWANCES
ALLOCATED
0
13,194
2,388
3,287
3,208
3,849
4,647
2,927
0
0
0
0
0
0
2,168
2,280
4,288
9,242
12,103
1,514
1,457
1,643
3,811
4,931
2,420
1,978
2,044
0
0
0
0
561
0
0
0
0
0
0
0
0
0
1,164
11
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
15,234
2,388
3,287
3,208
3,849
4,647
2,917
20
0
0
0
0
0
2,190
2,308
14,634
27,596
25,764
2,162
2,072
2,143
14,775
1,535
1,170
6,500
0
4
3
3
2
0
2
2
2
2
8
12
17
12
0
14
11
ALLOWANCES
DEDUCTED
0
15,227
2,045
2,046
2,046
2,873
3,631
2,497
0
0
0
0
0
0
2,106
2,084
14,113
26,426
4,967
2,030
1,997
1,794
13,606
1,084
817
0
0
3
2
2
1
0
1
1
0
1
5
1
13
8
0
0
0
ALLOWANCES
CARRIED OVER
TO 2001
0
7
343
1,241
1,162
976
1,016
420
20
0
0
0
0
0
84
224
521
1,170
20,797
132
75
349
1,169
451
353
6,500
0
1
1
1
1
0
1
1
2
1
3
11
4
4
0
14
11
A, 38
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
PLANT NAME
Deepwater
Deepwater
Deepwater
Deepwater
Deepwater
Gilbert
Gilbert
Gilbert
Gilbert
Gilbert
Gilbert
Gilbert
Gilbert
Hudson
Hudson
Kearny
Kearny
Linden
Linden
Linden
Linden
Linden
Linden
Linden
Linden
Linden
Mercer
Mercer
Na1 -7139
Na2-7140
Na3-7141
Na3-7141
Na4-7142
Na5-7217
Na6-7218
Pedricktown Cogen
Pedricktown Cogen
Sayreville
Sayreville
Sayreville
Sayreville
Sayreville
Sayreville
Sewaren
PLANT
CODE
2384
2384
2384
2384
2384
2393
2393
2393
2393
2393
2393
2393
2393
2403
2403
2404
2404
2406
2406
2406
2406
2406
2406
2406
2406
2406
2408
2408
7139
7140
7141
7141
7142
7217
7218
10099
10099
2390
2390
2390
2390
2390
2390
2411
STACK/UNIT ID*
4
5
6
8
9
1
2
3
9
04
05
06
07
1
2
7
8
2
4
5
6
7
8
11
12
13
1
2
**1
"1
"1
**2
**1
"1
"1
001001
005004
2
3
5
6
07
08
1
2000
ALLOWANCES
ALLOCATED
59
5
59
2,744
1,814
60
37
700
0
600
596
593
605
1,197
15,972
145
153
644
423
0
0
0
0
968
665
877
7,683
7,439
0
0
0
0
0
0
0
0
0
2
2
41
39
766
892
117
HELD IN
ACCOUNTS AS
OF 3/1/2001
59
5
59
3,894
1,814
60
37
700
4
596
596
593
605
119
23,134
145
314
644
0
11
7
45
2
968
665
246
8,448
8,375
0
0
0
0
0
0
0
5
2
2
2
41
39
766
892
117
ALLOWANCES
DEDUCTED
0
0
0
3,190
0
0
0
0
2
3
3
3
3
115
23,119
120
284
298
0
10
5
32
1
157
0
179
8,441
8,370
0
0
0
0
0
0
0
5
0
0
0
0
0
0
0
53
ALLOWANCES
CARRIED OVER
TO 2001
59
5
59
704
1,814
60
37
700
2
593
593
590
602
4
15
25
30
346
0
1
2
13
1
811
665
67
7
5
0
0
0
0
0
0
0
0
2
2
2
41
39
766
892
64
A, 39
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NJ
NJ
NJ
NJ
NJ
NJ
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
PLANT NAME
Sewaren
Sewaren
Sewaren
Sewaren
Sherman Avenue
Werner
Cunningham
Cunningham
Cunningham
Cunningham
Four Corners
Four Corners
Four Corners
Four Corners
Four Corners
Maddox
Milagro
Milagro
North Lovington
Person
Person
Person Generating Project
Prewitt Escalante Generating Static
Reeves
Reeves
Reeves
Rio Grande
Rio Grande
Rio Grande
San Juan
San Juan
San Juan
San Juan
Clark
Clark
Clark
El Dorado Energy
El Dorado Energy
El Dorado Energy
Fort Churchill
Fort Churchill
Harry Allen
Harry Allen
Harry Allen
PLANT
CODE
2411
2411
2411
2411
7288
2385
2454
2454
2454
2454
2442
2442
2442
2442
2442
2446
54814
54814
2473
2448
2448
55039
87
2450
2450
2450
2444
2444
2444
2451
2451
2451
2451
2322
2322
2322
55077
55077
55077
2330
2330
7082
7082
7082
STACK/UNIT ID*
2
3
4
5
1
4
121B
122B
123T
124T
1
2
3
4
5
051 B
1
2
S2
3
4
GT-1
1
1
2
3
6
7
8
1
2
3
4
1
2
3
CP1 (EDE1, EDE2)
EDE1
EDE2
1
2
"5
"6
**3
2000
ALLOWANCES
ALLOCATED
340
254
574
0
0
194
42
269
0
0
3,593
3,589
4,478
12,507
13,275
170
0
0
0
0
0
0
1,874
4
7
104
3
1
80
7,941
5,922
13,878
13,047
20
273
18
0
0
371
577
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
40
254
574
0
100
194
42
265
2
2
3,980
3,989
4,550
14,515
18,211
170
1
1
0
0
0
5
1,874
4
7
104
3
1
80
6,629
5,752
13,878
13,047
20
151
18
3
3
371
577
0
0
1
ALLOWANCES
DEDUCTED
25
38
45
0
1
0
1
3
0
0
3,618
3,629
4,140
1 1 ,935
15,011
2
0
0
0
0
0
2
1,385
0
0
0
1
1
2
5,543
5,579
9,117
8,647
1
1
1
2
2
27
100
0
0
0
ALLOWANCES
CARRIED OVER
TO 2001
15
216
529
0
99
194
41
262
2
2
362
360
410
2,580
3,200
168
1
1
0
0
0
3
489
4
7
104
2
0
78
1,086
173
4,761
4,400
19
150
17
1
1
344
477
0
0
1
A, 40
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
PLANT NAME
Harry Allen
Harry Allen
Mohave
Mohave
North Valmy
North Valmy
Reid Gardner
Reid Gardner
Reid Gardner
Reid Gardner
Sunrise
Tracy
Tracy
Tracy
Tracy
Tracy
Tracy
59Th Street
74Th Street
74Th Street
74Th Street
74Th Street
AES Cayuga, L.L.C.(Milliken)
AESCayuga, LLC.(Milliken)
AES Cayuga, LLC.(Milliken)
AES Greenidge LLC
AES Greenidge LLC
AES Greenidge LLC
AES Greenidge LLC
AES Hickling L.L.C.
AES Hickling L.L.C.
AES Hickling L.L.C.
AES Hickling L.L.C.
AES Hickling L.L.C.
AES Hickling L.L.C.
AES Jennison, L.L.C.
AES Jennison, L.L.C.
AES Jennison, L.L.C.
AES Jennison, L.L.C.
AES Jennison, L.L.C.
AES Jennison, L.L.C.
AES Somerset L.L.C.
AES Westover
AES Westover
PLANT
CODE
7082
7082
2341
2341
8224
8224
2324
2324
2324
2324
2326
2336
2336
2336
2336
2336
2336
2503
2504
2504
2504
2504
2535
2535
2535
2527
2527
2527
2527
2529
2529
2529
2529
2529
2529
2531
2531
2531
2531
2531
2531
6082
2526
2526
STACK/UNIT ID*
**GT1
**GT2
1
2
1
2
1
2
3
4
1
1
2
3
4
5
6
110
2000
ALLOWANCES
ALLOCATED
0
0
26,660
26,556
6,960
4,262
2,173
2,202
2,125
2,814
50
15
46
314
0
0
0
64
CS0002(120, 121,122)
120
121
122
XS12(1,2)
1
2
CSG003 (4, 5)
4
5
6
CSH001 (1 , 2)
1
2
CSH002 (3, 4)
3
4
CSJ001 (1 , 2)
1
2
CSJ002 (3, 4)
3
4
1
CSW003(11,12)
11
447
449
447
4,928
5,215
982
980
3,185
725
725
895
933
650
676
724
724
13,889
792
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
0
26,660
26,556
6,315
2,916
1,273
1,402
1,325
1,114
50
27
46
295
2
3
2
0
447
449
447
6,406
6,296
7,018
58
12,819
235
725
550
933
750
676
1,088
725
8,770
5,944
ALLOWANCES
DEDUCTED
0
0
20,300
22,450
5,673
1,567
714
769
729
765
22
27
39
11
1
1
2
0
416
417
417
4,805
4,207
7,018
57
12,818
235
725
550
933
750
676
1,088
725
8,296
5,944
ALLOWANCES
CARRIED OVER
TO 2001
0
0
6,360
4,106
642
1,349
559
633
596
349
28
0
7
284
1
2
0
0
31
32
30
1,601
2,089
0
1
1
0
0
0
0
0
0
0
0
474
0
A, 41
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
PLANT NAME
AES Westover
AES Westover
Albany
Albany
Albany
Albany
Allegany Station #133
Arthur Kill
Arthur Kill
Arthur Kill
Astoria
Astoria
Astoria
Astoria
Astoria
Bowline Point
Bowline Point
Brooklyn Navy Yard Cogeneration Fac
Brooklyn Navy Yard Cogeneration Fac
Carthage Energy, LLC
CH Resources - Niagara Falls
CH Resources - Syracuse
Charles Poletti
Dunkirk
Dunkirk
Dunkirk
Dunkirk
Dunkirk
Dynegy Danskammer, LLC
Dynegy Danskammer, LLC
Dynegy Danskammer, LLC
Dynegy Danskammer, LLC
Dynegy Roseton, LLC
Dynegy Roseton, LLC
E F Barrett
E F Barrett
East River
East River
East River
Far Rockaway
Glenwood
Glenwood
Huntley Power
Huntley Power
PLANT
CODE
2526
2526
2539
2539
2539
2539
10619
2490
2490
2490
8906
8906
8906
8906
8906
2625
2625
54914
54914
10620
50202
10621
2491
2554
2554
2554
2554
2554
2480
2480
2480
2480
8006
8006
2511
2511
2493
2493
2493
2513
2514
2514
2549
2549
STACK/UNIT ID*
12
13
1
2
3
4
00001
CS0002 (20, 30)
20
30
10
20
30
40
50
1
2
1
2
1
1
1
001
1
2
CS0003 (3, 4)
3
4
1
2
3
4
1
2
10
20
50
60
70
40
40
50
2000
ALLOWANCES
ALLOCATED
780
3,288
1,801
1,556
1,593
1,687
0
1,478
2,367
1,216
1,554
3,024
2,376
2,700
4,240
4,241
0
0
0
0
0
6,438
2,843
3,229
5,292
5,906
948
920
3,129
6,030
15,584
14,912
2,372
2,337
1,396
1,430
1,033
469
939
903
CS0002 (63, 64, 65, 66)
63
2,657
HELD IN
ACCOUNTS AS
OF 3/1/2001
688
10,860
932
1,151
843
1,568
1
600
401
0
0
475
409
219
900
581
0
0
2
1,190
10
6,238
1 1 ,001
1 1 ,633
15,527
17,597
156
200
3,614
8,475
14,966
14,294
2,372
2,337
0
1,430
1,033
469
939
903
3,790
ALLOWANCES
DEDUCTED
687
10,859
929
960
841
994
0
3
4
0
0
464
399
214
895
575
12
6
2
1,105
7
2,337
11,001
11,652
15,527
16,528
151
195
3,609
8,470
7,408
9,256
133
370
0
259
276
1
1
1
3,790
ALLOWANCES
CARRIED OVER
TO 2001
1
1
3
191
2
574
1
597
397
0
0
11
10
5
5
6
-12
-6
0
85
3
3,901
0
-19
0
1,069
5
5
5
5
7,558
5,038
2,239
1,967
0
1,171
757
468
938
902
0
A, 42
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
PLANT NAME
Huntley Power
Huntley Power
Huntley Power
Huntley Power
Huntley Power
Huntley Power
Lovett
Lovett
Lovett
Northport
Northport
Northport
Northport
Oswego
Oswego
Oswego
Oswego
Oswego
Oswego
Port Jefferson
Port Jefferson
Port Jefferson
Port Jefferson
Ravenswood
Ravenswood
Ravenswood
Richard M Flynn
Rochester 3, Beebee Station
Rochester 3, Beebee Station
Rochester 3, Beebee Station
Rochester 3, Beebee Station
Rochester 3, Beebee Station
Rochester 3, Beebee Station
Rochester 3, Beebee Station
Rochester 7, Russell Station
Rochester 7, Russell Station
Rochester 7, Russell Station
Rochester 7, Russell Station
Rochester 7, Russell Station
Rochester 7, Russell Station
S A Carlson
S A Carlson
S A Carlson
S A Carlson
PLANT
CODE
2549
2549
2549
2549
2549
2549
2629
2629
2629
2516
2516
2516
2516
2594
2594
2594
2594
2594
2594
2517
2517
2517
2517
2500
2500
2500
7314
2640
2640
2640
2640
2640
2640
2640
2642
2642
2642
2642
2642
2642
2682
2682
2682
2682
STACK/UNIT ID*
64
65
66
CS0001 (67, 68)
67
68
3
4
5
1
2
3
4
1
2
3
4
5
6
1
2
3
4
10
20
30
001
1
2
3
4
7
8
12
CS1 (1,2)
1
2
CS2 (3, 4)
3
4
CS0001 (9, 12)
9
030002(10,11)
10
2000
ALLOWANCES
ALLOCATED
2,664
2,693
2,729
5,775
5,381
225
4,569
4,988
8,323
10,130
11,122
5,794
0
0
90
398
17,242
4,808
475
498
4,397
5,181
3,165
2,678
4,992
0
0
0
2
0
201
0
2,269
1,093
1,626
1,586
2,213
664
673
HELD IN
ACCOUNTS AS
OF 3/1/2001
8,397
5,592
3,651
16,004
15,971
225
5,019
4,888
23,048
12,096
30,518
18,539
0
0
0
0
1,492
4,767
475
498
12,300
19,002
401
901
2,702
200
0
0
0
0
0
0
0
5,632
5,609
7,375
7,335
664
673
ALLOWANCES
DEDUCTED
8,397
5,592
3,657
16,004
14,862
14
5,011
4,879
7,396
4,522
9,661
4,070
0
0
0
0
1,502
216
0
0
3,085
4,220
2
384
1,570
99
0
0
0
0
0
0
0
5,560
5,561
7,195
7,195
659
673
ALLOWANCES
CARRIED OVER
TO 2001
0
0
-6
0
1,109
211
8
9
15,652
7,574
20,857
14,469
0
0
0
0
-10
4,551
475
498
9,215
14,782
399
517
1,132
101
0
0
0
0
0
0
0
72
48
180
140
5
0
A, 43
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
PLANT NAME
S A Carlson
S A Carlson
South Glens Falls Energy, LLC
Waterside
Waterside
Waterside
Waterside
Waterside
Waterside
Waterside
Waterside
Waterside
Waterside
Acme
Acme
Acme
Acme
Acme
Acme
Acme
Acme
AMP-Ohio Bowling Green
AMP-Ohio Hamilton
Ashtabula
Ashtabula
Ashtabula
Ashtabula
Ashtabula
Ashtabula
Avon Lake
Avon Lake
Avon Lake
Avon Lake
Bay Shore
Bay Shore
Bay Shore
Bay Shore
Bay Shore
Cardinal
Cardinal
Cardinal
Conesville
Conesville
Conesville
PLANT
CODE
2682
2682
10618
2502
2502
2502
2502
2502
2502
2502
2502
2502
2502
2877
2877
2877
2877
2877
2877
2877
2877
7783
7782
2835
2835
2835
2835
2835
2835
2836
2836
2836
2836
2878
2878
2878
2878
2878
2828
2828
2828
2840
2840
2840
STACK/UNIT ID*
11
12
1
41
42
51
52
CS0002 (61 , 62)
61
62
CS0003 (80, 90)
80
90
9
11
13
14
15
16
91
92
P001
P001
7
CS1 (8,9, 10, 11)
8
9
10
11
9
10
11
12
XS14(1,2, 3, 4)
1
2
3
4
1
2
3
CS012(1,2)
1
2
2000
ALLOWANCES
ALLOCATED
424
1,276
0
252
247
416
417
431
507
1,128
1,234
1
7
1,846
2,519
3,365
2,421
2,012
1,800
0
0
7,220
2,337
1,990
1,795
1,890
2,567
2,254
5,025
15,199
4,719
4,495
4,277
7,038
14,778
16,526
17,301
1,814
2,110
HELD IN
ACCOUNTS AS
OF 3/1/2001
847
1,053
3
0
0
0
0
431
507
1,128
1,234
0
0
0
0
0
0
0
0
1
1
4,403
800
0
2,141
1,519
0
2,800
0
20,000
796
2,488
2,229
3,885
71 ,986
47,289
23,460
17,076
15,173
ALLOWANCES
DEDUCTED
847
912
2
0
0
0
0
3
3
2
3
0
0
0
0
0
0
0
0
0
0
3,647
737
0
2,044
1,433
0
2,724
0
19,372
761
2,392
2,139
3,770
69,884
26,698
22,772
16,578
14,730
ALLOWANCES
CARRIED OVER
TO 2001
0
141
1
0
0
0
0
428
504
1,126
1,231
0
0
0
0
0
0
0
0
1
1
756
63
0
97
86
0
76
0
628
35
96
90
115
2,102
20,591
688
498
443
A, 44
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
PLANT NAME
Conesville
Conesville
Conesville
Conesville
Conesville
Dover
Eastlake
Eastlake
Eastlake
Eastlake
Eastlake
Edgewater
Edgewater
Edgewater
Frank M Tait
Frank M Tait
Frank M Tait
Gen J M Gavin
Gen J M Gavin
Gorge
Gorge
Greenville Electric Gen Station
Greenville Electric Gen Station
Greenville Electric Gen Station
Greenville Electric Gen Station
Greenville Electric Gen Station
Greenville Electric Gen Station
Greenville Electric Gen Station
Greenville Electric Gen Station
Hamilton
J M Stuart
J M Stuart
J M Stuart
J M Stuart
Killen Station
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Lake Road
Lake Shore
Lake Shore
PLANT
CODE
2840
2840
2840
2840
2840
2914
2837
2837
2837
2837
2837
2857
2857
2857
2847
2847
2847
8102
8102
2858
2858
55228
55228
55228
55228
55228
55228
55228
55228
2917
2850
2850
2850
2850
6031
2876
2876
2876
2876
2876
2876
2908
2838
2838
STACK/UNIT ID*
3
4
CS056 (5, 6)
5
6
"6
1
2
3
4
5
11
12
13
1
2
3
1
2
25
26
G1CT1
G1CT2
G2CT1
G2CT2
G3CT1
G3CT2
G4CT1
G4CT2
9
1
2
3
4
2
CS001 (1 , 2, 3, 4, 5)
1
2
3
4
5
6
18
91
2000
ALLOWANCES
ALLOCATED
2,370
21,031
9,025
9,394
153
3,366
3,725
4,319
6,258
16,605
878
947
2,179
0
0
0
34,099
34,738
1,498
1,677
0
0
0
0
0
0
0
0
1,665
19,632
18,611
18,454
19,503
16,928
8,100
7,797
7,524
7,860
7,874
1,340
6,033
47
HELD IN
ACCOUNTS AS
OF 3/1/2001
16,843
77,478
7,483
6,947
0
4,953
5,338
7,025
8,946
37,017
0
0
113
4
4
4
12,763
12,697
0
0
0
0
0
0
0
0
0
0
1,665
45,673
38,922
39,008
40,571
24,937
25,736
25,736
25,736
25,736
25,736
1,340
1,302
0
ALLOWANCES
DEDUCTED
16,351
76,277
7,263
6,741
0
4,855
5,284
6,955
8,855
36,646
0
0
11
0
0
0
12,381
12,314
0
0
0
0
0
0
0
0
0
0
997
29,043
28,501
22,686
25,425
24,636
25,238
25,238
25,238
25,238
25,238
0
1,238
0
ALLOWANCES
CARRIED OVER
TO 2001
492
1,201
220
206
0
98
54
70
91
371
0
0
102
4
4
4
382
383
0
0
0
0
0
0
0
0
0
0
668
16,630
10,421
16,322
15,146
301
498
498
498
498
498
1,340
64
0
A, 45
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
PLANT NAME
Lake Shore
Lake Shore
Lake Shore
Madison Generating Station
Madison Generating Station
Madison Generating Station
Madison Generating Station
Madison Generating Station
Madison Generating Station
Madison Generating Station
Madison Generating Station
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Niles
Niles
Niles
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
Picway
Poston
Poston
Poston
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
PLANT
CODE
2838
2838
2838
55110
55110
55110
55110
55110
55110
55110
55110
2832
2832
2832
2832
2832
2832
2872
2872
2872
2872
2872
2872
2861
2861
2861
2848
2848
2848
2848
2848
2848
2848
2848
2848
2843
2844
2844
2844
2864
2864
2864
2864
2864
STACK/UNIT ID*
92
93
94
1
2
3
4
5
6
7
8
CS056 (5-1 , 5-2, 6)
6
7
8
5-1
5-2
CS0141, 2, 3, 4)
1
2
3
4
5
XS12(1,2)
1
2
CS0001 (H-1 , H-2)
H-1
H-2
CS0002 (H-3, H-4)
H-3
H-4
CS0003 (H-5, H-6)
H-5
H-6
9
1
2
3
2000
ALLOWANCES
ALLOCATED
84
65
107
0
0
0
0
0
0
0
0
4,908
16,607
18,233
144
144
6,414
6,108
6,018
5,080
17,450
2,995
3,924
1,736
1,671
1,603
1,623
1,630
1,660
2,128
787
731
957
CS0001 (1,2,3,4,5,6,7,8)
1
2
3
4
1,233
1,206
1,246
1,275
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
0
0
4
4
4
4
4
4
4
4
20,521
40,929
19,418
3,342
3,341
31,148
30,348
37,158
37,583
25,495
5,925
14,444
594
538
1,421
1,340
1,338
1,499
10,879
0
0
0
0
0
0
0
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
0
0
0
16,671
39,663
18,801
3,189
3,189
30,239
29,462
36,074
36,487
23,776
5,824
14,013
589
531
1,402
1,323
1,326
1,486
10,563
0
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2001
0
0
0
4
4
4
4
4
4
4
4
3,850
1,266
617
153
152
909
886
1,084
1,096
1,719
101
431
5
7
19
17
12
13
316
0
0
0
0
0
0
0
A, 46
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
PLANT NAME
R E Burger
R E Burger
R E Burger
R E Burger
Refuse & Coal
Refuse & Coal
Refuse & Coal
Refuse & Coal
Refuse & Coal
Refuse & Coal
Refuse & Coal
Refuse & Coal
Refuse & Coal
Richard Gorsuch
Richard Gorsuch
Richard Gorsuch
Richard Gorsuch
Richard Gorsuch
Tidd
Toronto
Toronto
Toronto
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
W H Zimmer
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Woodsdale
Woodsdale
Woodsdale
Woodsdale
Woodsdale
Woodsdale
PLANT
CODE
2864
2864
2864
2864
312
312
312
312
312
312
312
312
312
7253
7253
7253
7253
7253
2828
2867
2867
2867
2866
2866
2866
2866
2866
2866
2866
2866
2866
6019
2830
2830
2830
2830
2830
2830
7158
7158
7158
7158
7158
7158
STACK/UNIT ID*
5
6
7
8
CSSA12(001,002)
001
002
CSSA34 (003, 004)
003
004
CSSA56 (005, 006)
005
006
CS0001 (1 , 2, 3, 4)
1
2
3
4
"1
9
10
11
CS0001 (1 , 2)
1
2
CS0002 (3, 4)
3
4
5
6
7
1
1
2
3
4
5
6
**GT1
**GT2
"GTS
**GT4
"GTS
"GT6
2000
ALLOWANCES
ALLOCATED
1,327
1,325
4,648
5,361
426
381
402
438
375
366
6,152
5,064
6,880
1,404
714
1,873
3,343
3,612
6,239
5,472
6,238
5,529
10,422
19,953
18,639
16,154
1,834
1,859
2,530
3,262
3,858
9,925
294
294
294
294
294
294
HELD IN
ACCOUNTS AS
OF 3/1/2001
722
799
25,538
33,218
0
0
0
0
0
0
9,285
9,285
9,285
9,283
0
0
0
0
12,468
13,081
12,713
1 1 ,764
21 ,507
25,976
24,339
21 ,465
4,657
5,163
8,110
8,081
16,870
38,017
294
294
294
294
294
294
ALLOWANCES
DEDUCTED
709
756
25,275
20,504
0
0
0
0
0
0
8,428
8,428
8,428
8,428
0
0
0
0
12,342
12,950
12,576
11,656
21,291
25,713
24,092
19,411
4,437
4,941
7,753
7,722
16,139
30,442
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2001
13
43
263
12,714
0
0
0
0
0
0
857
857
857
855
0
0
0
0
126
131
137
108
216
263
247
2,054
220
222
357
359
731
7,575
294
294
294
294
294
294
A, 47
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
OH
OH
OH
OH
OH
OH
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
PLANT NAME
Woodsdale
Woodsdale
Woodsdale
Woodsdale
Woodsdale
Woodsdale
Anadarko
Arbuckle
Chouteau Power Plant
Chouteau Power Plant
Comanche
Comanche
Conoco
Conoco
Grda
Grda
Horseshoe Lake
Horseshoe Lake
Horseshoe Lake
Horseshoe Lake
Horseshoe Lake
Hugo
Mooreland
Mooreland
Mooreland
Muskogee
Muskogee
Muskogee
Muskogee
Mustang
Mustang
Mustang
Mustang
Na 1 - 5030
Na 1 - 5030
Na 1 - 5030
Northeastern
Northeastern
Northeastern
Northeastern
Northeastern
Ponca
Ponca
Riverside
PLANT
CODE
7158
7158
7158
7158
7158
7158
3006
2947
7757
7757
8059
8059
7185
7185
165
165
2951
2951
2951
2951
2951
6772
3008
3008
3008
2952
2952
2952
2952
2953
2953
2953
2953
5030
5030
5030
2963
2963
2963
2963
2963
762
762
4940
STACK/UNIT ID*
**GT7
"GTS
**GT9
"GT10
"GT11
"GT12
3
ARB
1
2
7251
7252
**1
"2
1
2
6
7
8
9
10
1
1
2
3
3
4
5
6
1
2
3
4
"1
"2
**3
3301
3302
CS1 00 (331 3, 3314)
3313
3314
2
3
1501
2000
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
45
0
0
333
2
222
222
14,642
8,396
173
231
313
0
0
11,877
0
44
7
141
9,311
8,277
14,425
32
26
1
163
0
0
0
1,742
5,935
13,833
14,884
0
0
519
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
0
0
0
0
0
1
45
76
75
323
12
222
222
15,633
7,405
173
231
253
30
30
9,377
1
42
7
141
9,811
1 1 ,277
10,925
32
26
1
163
0
0
0
1,742
5,935
13,833
14,884
0
0
489
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
1
0
2
3
6
12
15,516
4,877
3
4
1
0
0
7,379
0
1
1
1
9,359
10,327
9,731
0
0
1
2
0
0
0
1
4
8,842
8,843
0
0
286
ALLOWANCES
CARRIED OVER
TO 2001
0
0
0
0
0
0
1
45
75
75
321
9
216
210
117
2,528
170
227
252
30
30
1,998
1
41
6
140
452
950
1,194
32
26
0
161
0
0
0
1,741
5,931
4,991
6,041
0
0
203
A, 48
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OR
OR
OR
OR
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PLANT NAME
Riverside
Seminole
Seminole
Seminole
Sooner
Sooner
Southwestern
Southwestern
Southwestern
Southwestern
Southwestern
Tulsa
Tulsa
Tulsa
Tulsa
Boardman
Coyote Springs
Hermiston
Hermiston
Allegheny Energy Unit 1 and Unit 2
Allegheny Energy Unit 1 and Unit 2
Allegheny Energy Unit 8 and Unit 9
Allegheny Energy Unit 8 and Unit 9
Armstrong
Armstrong
Bruce Mansfield
Bruce Mansfield
Bruce Mansfield
Brunner Island
Brunner Island
Brunner Island
Brunner Island
Cheswick
Conemaugh
Conemaugh
Cromby
Cromby
Delaware
Delaware
Eddystone
Eddystone
Eddystone
Eddystone
Eddystone
PLANT
CODE
4940
2956
2956
2956
6095
6095
2964
2964
2964
2964
2964
2965
2965
2965
2965
6106
7350
54761
54761
55196
55196
55377
55377
3178
3178
6094
6094
6094
3140
3140
3140
3140
8226
3118
3118
3159
3159
3160
3160
3161
3161
3161
3161
3161
STACK/UNIT ID*
1502
1
2
3
1
2
2000
ALLOWANCES
ALLOCATED
285
412
453
494
10,471
9,979
CP001 (8002,8003,801 N.801 S)
8002
8003
801 N
801 S
15
164
3
0
CP001(1402,1403,1404)
1402
1403
1404
1SG
CTG1
1
2
1
2
8
9
1
2
1
2
3
CS102(1,2)
1
2
3
1
1
2
1
2
71
81
1
2
CS034 (3, 4)
3
4
98
4
58
13,377
0
0
0
0
0
0
0
6,215
6,654
12,717
14,069
14,473
1 1 ,972
13,414
23,209
16,891
25,938
28,752
2,203
2,110
743
537
2,845
3,005
1,895
2,011
HELD IN
ACCOUNTS AS
OF 3/1/2001
315
412
453
494
10,471
9,979
15
164
3
0
98
4
58
14,375
4
7
7
1
1
1
1
17,621
17,166
14,134
14,793
14,473
14,701
17,371
28,957
46,544
10,764
11,198
4,668
2,110
743
1,071
3,851
4,241
1,895
2,011
ALLOWANCES
DEDUCTED
304
4
4
5
8,944
8,923
0
28
0
0
1
0
0
14,374
4
4
4
0
0
0
0
17,421
16,966
8,549
8,380
12,133
14,679
17,307
28,91 1
44,908
3,119
3,988
3,971
955
189
220
2,915
3,668
1,252
1,202
ALLOWANCES
CARRIED OVER
TO 2001
11
408
449
489
1,527
1,056
15
136
3
0
97
4
58
1
0
3
3
1
1
1
1
200
200
5,585
6,413
2,340
22
64
46
1,636
7,645
7,210
697
1,155
554
851
936
573
643
809
A, 49
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PLANT NAME
Elrama
Elrama
Elrama
Elrama
Elrama
F R Phillips
F R Phillips
F R Phillips
F R Phillips
F R Phillips
F R Phillips
F R Phillips
Front Street
Front Street
Front Street
Front Street
Grays Ferry Cogen
Hatfields Ferry
Hatfields Ferry
Hatfields Ferry
Hatfields Ferry
Holtwood
Homer City
Homer City
Homer City
Hunlock Power
Keystone
Keystone
Martins Creek
Martins Creek
Martins Creek
Martins Creek
Martins Creek
Mitchell
Mitchell
Mitchell
Mitchell
Montour
Montour
New Castle
New Castle
New Castle
New Castle
New Castle
PLANT
CODE
3098
3098
3098
3098
3098
3099
3099
3099
3099
3099
3099
3099
3121
3121
3121
3121
54785
3179
3179
3179
3179
3145
3122
3122
3122
3176
3136
3136
3148
3148
3148
3148
3148
3181
3181
3181
3181
3149
3149
3138
3138
3138
3138
3138
STACK/UNIT ID*
CS001 (1 , 2, 3, 4)
1
2
3
4
2000
ALLOWANCES
ALLOCATED
1,650
1,616
1,568
2,580
CS001 (1,2,3,4,5,6)
1
2
3
4
5
6
7
8
9
10
2
XS123(1,2, 3)
1
2
3
17
1
2
3
6
1
2
CS102(1,2)
1
2
3
4
1
2
3
33
1
2
1
2
3
4
5
663
504
1,165
1,112
1,131
2,022
294
294
1,176
1,176
0
16,313
16,094
17,365
3,571
17,759
16,314
27,629
2,257
28,219
30,045
5,457
5,528
13,183
12,127
0
1
0
5,495
24,191
24,680
1,292
1,439
2,843
2,817
4,514
HELD IN
ACCOUNTS AS
OF 3/1/2001
910
700
555
2,580
0
0
0
0
0
0
0
0
0
0
9
56,715
56,690
54,090
1
61 ,674
51 ,007
28,362
3,578
77,886
76,366
9,919
10,630
4,180
2,792
37
50
44
1,356
58,361
49,795
0
0
7,871
8,294
9,335
ALLOWANCES
DEDUCTED
889
683
543
2,519
0
0
0
0
0
0
0
0
0
0
9
56,115
56,090
53,490
0
52,865
50,539
27,865
3,576
77,479
76,01 1
8,822
9,953
4,168
2,757
17
30
24
1,256
58,244
49,723
0
0
7,612
8,018
9,029
ALLOWANCES
CARRIED OVER
TO 2001
21
17
12
61
0
0
0
0
0
0
0
0
0
0
0
600
600
600
1
8,809
468
497
2
407
355
1,097
677
12
35
20
20
20
100
117
72
0
0
259
276
306
A, 50
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
Rl
Rl
Rl
Rl
Rl
PLANT NAME
Portland
Portland
Portland
Richmond
Richmond
Schuylkill
Seward
Seward
Seward
Seward
Shawville
Shawville
Shawville
Shawville
Shawville
Southwark
Southwark
Southwark
Southwark
Springdale
Springdale
Sunbury
Sunbury
Sunbury
Sunbury
Sunbury
Sunbury
Sunbury
Sunbury
Titus
Titus
Titus
Warren
Warren
Warren
Warren
Warren
Westwood
Williamsburg
Manchester Street
Manchester Street
Manchester Street
Manchester Street
Manchester Street
PLANT
CODE
3113
3113
3113
3168
3168
3169
3130
3130
3130
3130
3131
3131
3131
3131
3131
3170
3170
3170
3170
3182
3182
3152
3152
3152
3152
3152
3152
3152
3152
3115
3115
3115
3132
3132
3132
3132
3132
50611
3135
3236
3236
3236
3236
3236
STACK/UNIT ID*
1
2
5
63
64
1
CS2(12, 14,15)
12
14
15
1
2
CS1 (3, 4)
3
4
11
12
21
22
77
88
3
4
CS1 (1A, 1B)
1A
1B
CS2 (2A, 2B)
2A
2B
1
2
3
CSS (1 , 2, 3, 4)
1
2
3
4
031
11
6
7
9
10
11
2000
ALLOWANCES
ALLOCATED
2,560
4,413
0
0
0
572
1,096
1,096
5,002
4,430
4,456
6,111
6,070
0
0
0
0
0
0
4,029
5,250
1,818
1,817
1,818
1,818
2,150
2,272
2,195
720
720
740
740
0
935
693
458
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
9,056
11,265
2
0
0
572
1,096
1,217
8,593
9,478
10,956
12,806
15,033
0
0
0
0
0
0
16,527
9,654
3,718
3,582
2,818
3,018
5,459
4,858
4,991
525
584
876
935
350
935
0
0
7
7
7
ALLOWANCES
DEDUCTED
9,036
11,260
1
0
0
128
1,093
1,212
8,588
9,473
10,951
12,801
15,028
0
0
0
0
0
0
8,005
7,806
3,436
3,382
2,708
2,735
5,454
4,853
4,986
502
579
873
930
293
0
0
0
2
2
2
ALLOWANCES
CARRIED OVER
TO 2001
20
5
1
0
0
444
3
5
5
5
5
5
5
0
0
0
0
0
0
8,522
1,848
282
200
110
283
5
5
5
23
5
3
5
57
935
0
0
5
5
5
A, 51
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
Rl
Rl
Rl
Rl
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
PLANT NAME
Manchester Street
South Street
South Street
Tiverton
Broad River Energy Center (1)
Broad River Energy Center (1)
Broad River Energy Center (1)
Canadys Steam
Canadys Steam
Canadys Steam
Cherokee County Cogen
Cope Station
Cross
Cross
Darlington County
Darlington County
Dolphus M Grainger
Dolphus M Grainger
H B Robinson
Hagood
Hagood
Hagood
Hagood
Jefferies
Jefferies
Jefferies
Jefferies
Mcmeekin
Mcmeekin
Na1 -7106
Urquhart
Urquhart
Urquhart
Urquhart
WSLee
WSLee
WSLee
Wateree
Wateree
Williams
Winyah
Winyah
Winyah
Winyah
PLANT
CODE
3236
3238
3238
55048
55166
55166
55166
3280
3280
3280
55043
7210
130
130
3250
3250
3317
3317
3251
3285
3285
3285
3285
3319
3319
3319
3319
3287
3287
7106
3295
3295
3295
3295
3264
3264
3264
3297
3297
3298
6249
6249
6249
6249
STACK/UNIT ID*
12
121
122
1
CT-1
CT-2
CT-3
CAN1
CAN2
CANS
CCCP1
COP1
1
2
12
13
1
2
1
HAG1
HAG2
HAGS
HAG4
1
2
3
4
MCM1
MCM2
**GT1
URQ1
URQ2
URQ3
URQ4
1
2
3
WAT1
WAT2
WIL1
1
2
3
4
2000
ALLOWANCES
ALLOCATED
512
1,086
946
0
0
0
0
3,248
2,979
4,223
0
2,616
5,603
8,941
0
0
3,114
277
3,815
3
451
787
948
0
1
3,886
3,743
4,080
4,038
0
2,195
1,927
2,914
0
3,381
3,727
6,800
9,717
9,270
15,821
7,574
6,234
3,610
3,427
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
0
0
33
6
4
3
10,432
9,976
12,324
4
4,884
4,175
10,109
10
10
4,820
4,054
7,995
0
0
0
982
656
692
10,622
10,991
21 ,805
13,915
0
7,249
6,957
10,285
3
2,582
2,995
5,631
19,225
27,923
24,517
21,442
9,818
4,998
4,008
ALLOWANCES
DEDUCTED
0
0
0
1
1
2
1
5,085
5,727
7,855
1
2,012
2,725
9,728
6
6
4,581
3,963
7,894
0
0
0
34
314
367
9,698
8,955
6,776
7,380
0
3,852
4,092
6,043
3
2,347
2,721
5,203
16,126
15,058
24,205
19,646
9,235
4,737
3,924
ALLOWANCES
CARRIED OVER
TO 2001
0
0
0
32
5
2
2
5,347
4,249
4,469
3
2,872
1,450
381
4
4
239
91
101
0
0
0
948
342
325
924
2,036
15,029
6,535
0
3,397
2,865
4,242
0
235
274
428
3,099
12,865
312
1,796
583
261
84
A, 52
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
SD
SD
SD
SD
SD
SD
SD
SD
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
PLANT NAME
Angus Anson
Angus Anson
Big Stone
Huron
Huron
Pathfinder
Pathfinder
Pathfinder
Allen
Allen
Allen
Brownsville Power 1, LLC
Brownsville Power 1, LLC
Brownsville Power 1, LLC
Brownsville Power 1, LLC
Bull Run
Cumberland
Cumberland
DuPont Johnsonville
DuPont Johnsonville
DuPont Johnsonville
DuPont Johnsonville
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gleason Generating Facility LLC
Gleason Generating Facility LLC
Gleason Generating Facility LLC
John Sevier
John Sevier
John Sevier
John Sevier
John Sevier
John Sevier
Johnsonville
Johnsonville
Johnsonville
PLANT
CODE
7237
7237
6098
3344
3344
3334
3334
3334
3393
3393
3393
2387
2387
2387
2387
3396
3399
3399
880001
880001
880001
880001
3403
3403
3403
3403
3403
3403
3403
3403
3403
3403
55251
55251
55251
3405
3405
3405
3405
3405
3405
3406
3406
3406
STACK/UNIT ID*
2
3
1
**2A
**2B
11
12
13
1
2
3
AA-001
AA-002
AA-003
AA-004
1
1
2
JVD1
JVD2
JVD3
JVD4
CSGA12(1,2)
1
2
CSGA34 (3, 4)
3
4
GCT5
GCT6
GCT7
GCT8
CTG-1
CTG-2
CTG-3
CSJS12(1,2)
1
2
CSJS34 (3, 4)
3
4
2000
ALLOWANCES
ALLOCATED
851
1,020
13,715
80
103
11
2
2
6,608
7,231
6,756
0
0
0
0
25,047
37,386
40,896
1,778
1,778
1,777
1,777
7,605
7,464
8,635
9,168
0
0
0
0
0
0
0
6,361
6,358
6,519
6,669
CSJO10(1,2, 3, 4, 5, 6, 7, 8, 9, 10)
1
2
3,358
3,465
HELD IN
ACCOUNTS AS
OF 3/1/2001
851
1,020
13,780
5
3
11
2
2
27,049
22,894
23,901
1
1
1
1
39,513
123,716
150,697
0
0
0
0
18,339
18,864
21 ,881
26,361
500
500
500
500
2
2
2
16,361
16,858
14,019
15,669
13,610
13,874
ALLOWANCES
DEDUCTED
3
2
13,528
0
0
0
0
0
6,462
7,536
4,864
0
0
0
0
36,669
8,995
10,861
0
0
0
0
17,181
17,070
19,860
24,189
3
2
3
2
0
0
0
14,071
14,253
12,886
14,690
11,992
12,044
ALLOWANCES
CARRIED OVER
TO 2001
848
1,018
252
5
3
11
2
2
20,587
15,358
19,037
1
1
1
1
2,844
114,721
139,836
0
0
0
0
1,158
1,794
2,021
2,172
497
498
497
498
2
2
2
2,290
2,605
1,133
979
1,618
1,830
A, 53
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Watts Bar
Watts Bar
Watts Bar
Watts Bar
Barney M. Davis
Barney M. Davis
Bay Port
Bay Port
Bay Port
Bay Port
Big Brown
Big Brown
Blackhawk Station
Blackhawk Station
Bosque County Power Plant
Bosque County Power Plant
Bryan
C E Newman
Cedar Bayou
Cedar Bayou
Cedar Bayou
PLANT
CODE
3406
3406
3406
3406
3406
3406
3406
3406
3406
3406
3406
3406
3407
3407
3407
3407
3407
3407
3407
3407
3407
3407
3407
3419
3419
3419
3419
4939
4939
10298
10298
10298
10298
3497
3497
55064
55064
55172
55172
3561
3574
3460
3460
3460
STACK/UNIT ID*
3
4
5
6
7
8
9
10
JCT17
JCT18
JCT19
JCT20
CSKI15(1,2, 3, 4, 5)
1
2
3
4
5
CSKI69 (6, 7, 8, 9)
6
7
8
9
A
B
C
D
1
2
CG801
CG802
CG803
CG804
1
2
001
002
GT-1
GT-2
6
BW5
CBY1
CBY2
CBY3
2000
ALLOWANCES
ALLOCATED
3,628
3,443
3,553
3,404
3,871
3,753
3,052
3,256
0
0
0
0
4,152
3,992
4,751
5,041
6,194
6,347
6,189
5,784
6,405
0
0
0
0
496
398
0
0
0
0
20,985
19,878
0
0
0
0
19
3
814
921
725
HELD IN
ACCOUNTS AS
OF 3/1/2001
13,340
13,307
11,650
12,806
14,212
15,128
14,422
14,079
500
500
500
500
10,652
10,492
1 1 ,751
9,541
12,694
12,347
12,189
14,284
14,405
0
0
0
0
456
438
0
0
0
0
42,985
44,093
5
5
5
5
19
3
814
921
725
ALLOWANCES
DEDUCTED
11,608
11,774
10,460
10,987
12,436
13,250
11,758
12,114
1
1
1
1
9,225
9,399
10,086
8,226
11,498
11,426
10,895
13,325
12,872
0
0
0
0
149
426
0
0
0
0
42,401
43,590
3
3
1
0
2
2
102
194
63
ALLOWANCES
CARRIED OVER
TO 2001
1,732
1,533
1,190
1,819
1,776
1,878
2,664
1,965
499
499
499
499
1,427
1,093
1,665
1,315
1,196
921
1,294
959
1,533
0
0
0
0
307
12
0
0
0
0
584
503
2
2
4
5
17
1
712
727
662
A, 54
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Cleburne Cogeneration Facility
Cleburne Cogeneration Facility
Coleto Creek
Coleto Creek
Collin
Concho
Dallas
Dallas
Dansby
Decker Creek
Decker Creek
Decordova
Deepwater
Deepwater
Deepwater
Deepwater
Deepwater
Deepwater
Deepwater
Deepwater
Deepwater
Denver City
E S Joslin
Eagle Mountain
Eagle Mountain
Eagle Mountain
Forest Grove
Fort Phantom
Fort Phantom
Frontera Power Facility
Frontera Power Facility
Generic Stat
Generic Stat
Gibbons Creek
Graham
Graham
Greens Bayou
Greens Bayou
Greens Bayou
Greens Bayou
Greens Bayou
Gregory Power Facility
Gregory Power Facility
Handley
PLANT
CODE
54817
54817
6178
6178
3500
3518
3451
3451
6243
3548
3548
8063
3461
3461
3461
3461
3461
3461
3461
3461
3461
3480
3436
3489
3489
3489
6148
4938
4938
55098
55098
7235
7235
6136
3490
3490
3464
3464
3464
3464
3464
55086
55086
3491
STACK/UNIT ID*
EAST
WEST
1
**2
1
7
3
9
1
1
2
1
DWP1
DWP2
DWP3
DWP4
DWP5
DWP6
DWP7
DWP8
DWP9
6
1
1
2
3
"1
1
2
1
2
**1
**2
1
1
2
GBY1
GBY2
GBY3
GBY4
GBY5
101
102
2
2000
ALLOWANCES
ALLOCATED
0
0
14,721
0
92
11
27
26
94
128
195
1,018
0
0
0
0
0
0
0
0
28
0
260
52
140
100
0
126
187
0
0
0
0
14,414
235
496
1
2
15
19
352
0
0
21
HELD IN
ACCOUNTS AS
OF 3/1/2001
5
0
14,741
0
62
11
0
0
94
128
195
218
0
0
0
0
0
0
0
0
28
0
260
52
90
60
0
136
177
8
8
0
0
12,567
135
446
1
2
15
19
352
5
5
21
ALLOWANCES
DEDUCTED
4
0
14,721
0
5
0
0
0
6
10
22
69
0
0
0
0
0
0
0
0
1
0
52
1
23
2
0
125
56
2
2
0
0
11,639
57
377
0
0
0
0
13
2
2
1
ALLOWANCES
CARRIED OVER
TO 2001
1
0
20
0
57
11
0
0
88
118
173
149
0
0
0
0
0
0
0
0
27
0
208
51
67
58
0
11
121
6
6
0
0
928
78
69
1
2
15
19
339
3
3
20
A, 55
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Handley
Handley
Handley
Handley
Handley
Harrington Station
Harrington Station
Harrington Station
Hidalgo Energy Facility
Hidalgo Energy Facility
Hiram Clarke
Hiram Clarke
Hiram Clarke
Hiram Clarke
Holly Ave
Holly Ave
Holly Street
Holly Street
Holly Street
Holly Street
J K Spruce
J K Spruce
J L Bates
J L Bates
J T Deely
J T Deely
J T Deely
J. Robert Massengale Generating
Jones Station
Jones Station
Knox Lee
Knox Lee
Knox Lee
Knox Lee
La Raima
Lake Creek
Lake Creek
Lake Hubbard
Lake Hubbard
Lamar Power (Paris Generating Stati
Lamar Power (Paris Generating Stati
Laredo
Laredo
Laredo
PLANT
CODE
3491
3491
3491
3491
3491
6193
6193
6193
7762
7762
3465
3465
3465
3465
3602
3602
3549
3549
3549
3549
7097
7097
3438
3438
6181
6181
6181
3604
3482
3482
3476
3476
3476
3476
3442
3502
3502
3452
3452
55097
55097
3439
3439
3439
STACK/UNIT ID*
3
4
5
1A
1B
061 B
062B
063B
HRSG1
HRSG2
HOC1
HOC2
HOC3
HOC4
1
2
1
2
3
4
**1
"2
1
2
CS012(1,2)
1
2
GT1
151B
152B
2
3
4
5
7
1
2
1
2
1
2
1
2
3
2000
ALLOWANCES
ALLOCATED
423
118
136
7
0
8,234
8,721
9,269
0
0
0
0
3
2
59
71
49
31
68
43
6,692
0
48
124
13,136
13,705
0
125
93
0
5
29
251
178
39
191
170
604
0
0
15
14
85
HELD IN
ACCOUNTS AS
OF 3/1/2001
73
468
106
7
0
9,018
8,621
8,585
2
2
0
0
3
2
59
71
49
31
68
43
6,692
0
48
124
13,136
13,705
0
124
93
5
5
24
251
178
39
91
120
204
2
2
15
14
85
ALLOWANCES
DEDUCTED
4
102
34
0
0
8,818
8,303
8,361
1
1
0
0
0
0
1
1
0
0
2
2
3,642
0
28
25
9,802
9,803
0
4
27
0
0
0
145
99
1
7
31
52
2
0
1
1
6
ALLOWANCES
CARRIED OVER
TO 2001
69
366
72
7
0
200
318
224
1
1
0
0
3
2
58
70
49
31
66
41
3,050
0
20
99
3,334
3,902
0
120
66
5
5
24
106
79
38
84
89
152
0
2
14
13
79
A, 56
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Leon Creek
Leon Creek
Lewis Creek
Lewis Creek
Limestone
Limestone
Lon C Hill
Lon C Hill
Lon C Hill
Lon C Hill
Lone Star
Malakoff
Martin Lake
Martin Lake
Martin Lake
Midlothian Energy
Midlothian Energy
Mission Road
Monticello
Monticello
Monticello
Moore County Station
Morgan Creek
Morgan Creek
Morgan Creek
Morgan Creek
Mountain Creek
Mountain Creek
Mountain Creek
Mountain Creek
Mountain Creek
Mountain Creek
Mustang Station
Mustang Station
Na1 -7219
Na1 -7219
Na 2 - 4274
Neches
Neches
Neches
Neches
Newgulf
Newman
Newman
PLANT
CODE
3609
3609
3457
3457
298
298
3440
3440
3440
3440
3477
370
6146
6146
6146
55091
55091
3610
6147
6147
6147
3483
3492
3492
3492
3492
3453
3453
3453
3453
3453
3453
55065
55065
7219
7219
4274
3458
3458
3458
3458
50137
3456
3456
STACK/UNIT ID*
3
4
1
2
LIM1
LIM2
1
2
3
4
1
**1
1
2
3
STK1
STK2
3
1
2
3
3
3
4
5
6
2
6
7
8
3A
3B
1
2
"1
**2
**NA1
11
13
15
18
1
1
2
2000
ALLOWANCES
ALLOCATED
2
10
317
271
23,787
14,158
9
10
179
197
0
1,539
33,231
32,266
33,436
0
0
3
23,641
22,938
35,232
0
8
72
154
836
4
63
62
527
11
2
0
0
0
0
0
0
0
0
0
0
14
29
HELD IN
ACCOUNTS AS
OF 3/1/2001
2
10
7
7
21,787
16,158
9
10
179
197
0
1,539
26,631
31 ,266
30,436
1
1
3
38,641
34,246
18,272
1
8
72
154
136
4
63
212
102
11
2
5
5
0
0
0
0
0
0
0
4
14
29
ALLOWANCES
DEDUCTED
0
0
5
5
16,862
15,209
0
1
3
46
0
0
16,490
21,172
20,396
1
1
0
37,587
33,186
17,572
0
0
1
44
8
0
25
175
5
0
0
3
3
0
0
0
0
0
0
0
0
1
1
ALLOWANCES
CARRIED OVER
TO 2001
2
10
2
2
4,925
949
9
9
176
151
0
1,539
10,141
10,094
10,040
0
0
3
1,054
1,060
700
1
8
71
110
128
4
38
37
97
11
2
2
2
0
0
0
0
0
0
0
4
13
28
A, 57
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Newman
Newman
Newman
Nichols Station
Nichols Station
Nichols Station
North Lake
North Lake
North Lake
North Main
North Texas
Nueces Bay
Nueces Bay
Nueces Bay
O W Sommers
O W Sommers
Oak Creek
Oklaunion
P H Robinson
P H Robinson
P H Robinson
P H Robinson
Paint Creek
Paint Creek
Paint Creek
Paint Creek
Parkdale
Parkdale
Parkdale
Pasadena Power Plant
Pasadena Power Plant
Pasadena Power Plant
Permian Basin
Permian Basin
Pirkey
Plant X
Plant X
Plant X
Plant X
Port Neches
Powerlane Plant
Powerlane Plant
RW Miller
RW Miller
PLANT
CODE
3456
3456
3456
3484
3484
3484
3454
3454
3454
3493
3627
3441
3441
3441
3611
3611
3523
127
3466
3466
3466
3466
3524
3524
3524
3524
3455
3455
3455
55047
55047
55047
3494
3494
7902
3485
3485
3485
3485
54748
4195
4195
3628
3628
STACK/UNIT ID*
3
**4
"5
141B
142B
143B
1
2
3
4
3
5
6
7
1
2
1
1
PHR1
PHR2
PHR3
PHR4
1
2
3
4
1
2
3
CG-1
CG-2
CG-3
5
6
1
111B
112B
113B
114B
GT1
2
3
1
2
2000
ALLOWANCES
ALLOCATED
88
99
0
77
86
50
131
150
294
42
13
1
140
496
478
188
106
7,859
645
494
685
796
11
11
28
105
34
62
61
0
0
0
103
804
20,532
0
2
89
0
0
459
37
55
98
HELD IN
ACCOUNTS AS
OF 3/1/2001
7
49
50
77
86
50
131
100
164
42
1
1
140
476
472
188
106
7,859
645
494
685
796
21
41
28
125
34
62
61
7
1
1
53
254
20,532
1
2
76
12
0
459
37
1
2
ALLOWANCES
DEDUCTED
1
2
2
1
1
2
36
16
34
1
1
0
8
177
6
4
2
5,602
6
7
7
8
13
29
8
113
1
1
1
4
1
1
1
118
18,828
0
0
1
8
0
0
0
1
2
ALLOWANCES
CARRIED OVER
TO 2001
6
47
48
76
85
48
95
84
130
41
0
1
132
299
466
184
104
2,257
639
487
678
788
8
12
20
12
33
61
60
3
0
0
52
136
1,704
1
2
75
4
0
459
37
0
0
A, 58
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
RW Miller
RW Miller
RW Miller
Ray Olinger
Ray Olinger
Ray Olinger
Rio Pecos
Rio Pecos
River Crest
Sabine
Sabine
Sabine
Sabine
Sabine
Sabine Cogeneration Facility
Sabine Cogeneration Facility
Sam Bertron
Sam Bertron
Sam Bertron
Sam Bertron
Sam Seymour
Sam Seymour
Sam Seymour
San Angelo
San Jacinto Steam Electric Station
San Jacinto Steam Electric Station
San Miguel
Sandow
Seaholm
Silas Ray
Sim Gideon
Sim Gideon
Sim Gideon
Spencer
Spencer
Stryker Creek
Stryker Creek
Sweeny Cogeneration Facility
Sweeny Cogeneration Facility
Sweeny Cogeneration Facility
T C Ferguson
T H Wharton
T H Wharton
Tenaska Frontier Generating Station
PLANT
CODE
3628
3628
3628
3576
3576
3576
3526
3526
3503
3459
3459
3459
3459
3459
55104
55104
3468
3468
3468
3468
6179
6179
6179
3527
7325
7325
6183
6648
3550
3559
3601
3601
3601
4266
4266
3504
3504
55015
55015
55015
4937
3469
3469
55062
STACK/UNIT ID*
3
**4
"5
BW2
BW3
CE1
5
6
1
1
2
3
4
5
SAB-1
SAB-2
SRB1
SRB2
SRB3
SRB4
1
2
3
2
SJS1
SJS2
SM-1
4
9
9
1
2
3
4
5
1
2
1
2
3
1
THW1
THW2
1
2000
ALLOWANCES
ALLOCATED
218
851
851
60
79
42
64
179
61
152
164
576
504
323
0
0
57
18
120
79
15,910
17,396
10,494
161
0
0
17,216
25,698
4
0
47
56
277
19
23
170
525
0
0
0
253
7
97
0
HELD IN
ACCOUNTS AS
OF 3/1/2001
3
1
1
60
79
42
44
139
61
7
9
11
9
13
1
1
57
18
100
79
14,982
16,072
1,746
161
10
10
17,216
25,698
4
5
47
56
277
19
23
120
425
36
12
12
253
7
97
2
ALLOWANCES
DEDUCTED
3
1
1
5
2
1
2
2
1
4
3
6
6
8
1
1
1
1
2
2
14,150
14,743
1,736
4
3
3
12,223
19,546
0
0
1
1
4
0
1
38
182
3
3
3
5
0
2
2
ALLOWANCES
CARRIED OVER
TO 2001
0
0
0
55
77
41
42
137
60
3
6
5
3
5
0
0
56
17
98
77
832
1,329
10
157
7
7
4,993
6,152
4
5
46
55
273
19
22
82
243
33
9
9
248
7
95
0
A, 59
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Tenaska Frontier Generating Station
Tenaska Frontier Generating Station
TNP One
TNP One
Tolk Station
Tolk Station
Tradinghouse
Tradinghouse
Trinidad
Trinidad
Trinidad
Twin Oak
Twin Oak
V H Braunig
V H Braunig
V H Braunig
V H Braunig
V H Braunig
V H Braunig
Valley (Texas Utilities)
Valley (Texas Utilities)
Valley (Texas Utilities)
Victoria
Victoria
Victoria
Victoria
W a Parish
W a Parish
W a Parish
W a Parish
W a Parish
W a Parish
W a Parish
W a Parish
W B Tuttle
W B Tuttle
W B Tuttle
W B Tuttle
Webster
Webster
Webster
Welsh
Welsh
Welsh
PLANT
CODE
55062
55062
7030
7030
6194
6194
3506
3506
3507
3507
3507
6180
6180
3612
3612
3612
3612
3612
3612
3508
3508
3508
3443
3443
3443
3443
3470
3470
3470
3470
3470
3470
3470
3470
3613
3613
3613
3613
3471
3471
3471
6139
6139
6139
STACK/UNIT ID*
2
3
U1
U2
171B
172B
1
2
7
8
9
1
2
1
2
3
CP01 (CT01.CT02)
CT01
CT02
1
2
3
5
6
7
8
WAP1
WAP2
WAP3
WAP4
WAP5
WAP6
WAP7
WAP8
1
2
3
4
WEB1
WEB2
WEBS
1
2
3
2000
ALLOWANCES
ALLOCATED
0
0
2,123
3,500
14,781
14,444
593
995
6
1
135
8,015
1,540
78
121
416
0
0
77
518
124
6
8
110
238
57
56
245
558
22,878
20,761
15,142
7,287
2
19
11
48
14
17
343
13,329
12,846
15,220
HELD IN
ACCOUNTS AS
OF 3/1/2001
2
2
2,624
2,999
14,293
14,932
193
395
6
1
85
0
0
78
121
416
3
3
77
168
124
6
8
110
238
57
56
245
558
21 ,378
19,261
19,500
5,929
2
19
11
48
14
17
343
14,029
12,846
14,520
ALLOWANCES
DEDUCTED
2
2
2,350
2,695
13,536
14,665
5
96
0
0
1
0
0
6
1
4
2
2
11
39
2
0
0
19
32
1
1
3
4
16,206
14,894
18,500
4,933
0
0
0
0
0
0
2
14,024
12,599
12,843
ALLOWANCES
CARRIED OVER
TO 2001
0
0
274
304
757
267
188
299
6
1
84
0
0
72
120
412
1
1
66
129
122
6
8
91
206
56
55
242
554
5,172
4,367
1,000
996
2
19
11
48
14
17
341
5
247
1,677
A, 60
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
PLANT NAME
Wilkes
Wilkes
Wilkes
Bonanza
Carbon
Carbon
Gadsby
Gadsby
Gadsby
Hale
Hunter (Emery)
Hunter (Emery)
Hunter (Emery)
Huntington
Huntington
Intermountain
Intermountain
Bellemeade
Bellemeade
Bremo
Bremo
Chesapeake
Chesapeake
Chesapeake
Chesapeake
Chesterfield
Chesterfield
Chesterfield
Chesterfield
Chesterfield
Chesterfield
Clinch River
Clinch River
Clinch River
Clinch River
Clover
Clover
Commonwealth Chesapeake Pwr Station
Commonwealth Chesapeake Pwr Station
Commonwealth Chesapeake Pwr Station
East Chandler
Glen Lyn
Glen Lyn
Glen Lyn
PLANT
CODE
3478
3478
3478
7790
3644
3644
3648
3648
3648
3652
6165
6165
6165
8069
8069
6481
6481
50966
50966
3796
3796
3803
3803
3803
3803
3797
3797
3797
3797
3797
3797
3775
3775
3775
3775
7213
7213
55381
55381
55381
7186
3776
3776
3776
STACK/UNIT ID*
1
2
3
1-1
1
2
1
2
3
1
1
2
3
1
2
1SGA
2SGA
1
2
3
4
1
2
3
4
3
4
5
6
**8A
**8B
CS012(1,2)
1
2
3
1
2
CT-001
CT-002
CT-003
**2
6
51
52
2000
ALLOWANCES
ALLOCATED
30
118
129
10,785
1,913
2,499
24
1,690
2,265
1
7,454
7,960
1 1 ,254
7,925
9,753
2,875
2,895
0
0
2,029
5,160
2,117
2,210
4,560
5,872
2,561
4,670
9,166
17,139
1,387
0
5,348
6,113
5,651
2,938
2,938
0
0
0
0
5,535
1,152
1,113
HELD IN
ACCOUNTS AS
OF 3/1/2001
30
118
129
1,824
1,560
3,094
2
2
2
0
2,512
2,599
1,075
1,853
1 1 ,339
2,875
2,895
25
25
6,029
11,160
10,117
8,210
12,560
15,872
9,561
10,670
19,166
42,139
1,387
0
8,514
8,733
9,590
1,900
1,900
10
10
10
0
9,827
2,458
2,803
ALLOWANCES
DEDUCTED
16
3
3
1,038
1,535
3,069
1
1
1
0
2,156
1,764
1,050
1,798
11,314
1,855
1,619
7
7
3,859
7,678
5,367
5,005
8,274
10,663
5,510
6,751
18,068
37,145
45
0
8,264
8,477
9,309
867
1,059
1
1
1
0
9,539
2,386
2,721
ALLOWANCES
CARRIED OVER
TO 2001
14
115
126
786
25
25
1
1
1
0
356
835
25
55
25
1,020
1,276
18
18
2,170
3,482
4,750
3,205
4,286
5,209
4,051
3,919
1,098
4,994
1,342
0
250
256
281
1,033
841
9
9
9
0
288
72
82
A, 61
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VT
WA
WA
WA
WA
WA
WA
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
PLANT NAME
Possum Point
Possum Point
Possum Point
Possum Point
Possum Point
Potomac River
Potomac River
Potomac River
Potomac River
Potomac River
Remington Combustion Turbine
Remington Combustion Turbine
Remington Combustion Turbine
Remington Combustion Turbine
Yorktown
Yorktown
Yorktown
Yorktown
J C Mcneil
Centralia
Centralia
River Road
Shuffleton
Shuffleton
Shuffleton
Alma
Alma
Alma
Alma
Alma
Alma
Bay Front
Bay Front
Bay Front
Bay Front
Bay Front
Blount Street
Blount Street
Blount Street
Blount Street
Blount Street
Blount Street
Blount Street
Columbia
PLANT
CODE
3804
3804
3804
3804
3804
3788
3788
3788
3788
3788
7839
7839
7839
7839
3809
3809
3809
3809
589
3845
3845
7605
3858
3858
3858
4140
4140
4140
4140
4140
4140
3982
3982
3982
3982
3982
3992
3992
3992
3992
3992
3992
3992
8023
STACK/UNIT ID*
1
2
3
4
5
1
2
3
4
5
1
2
3
4
CSO (1 , 2)
1
2
3
1
BW21
BW22
1
1
2
3
2000
ALLOWANCES
ALLOCATED
0
0
2,647
6,725
4,336
2,334
2,309
2,756
3,037
2,913
0
0
0
0
4,671
4,674
6,305
104
19,076
20,337
0
0
0
0
CS1 (B1 , B2, B3, B4, B5)
B1
B2
B3
B4
B5
1
2
3
4
5
3
5
6
7
8
9
11
1
537
518
455
1,193
1,906
1,046
529
0
33
281
6
7
7
1,476
1,130
1,183
1
15,484
HELD IN
ACCOUNTS AS
OF 3/1/2001
0
10
10,647
18,725
4,336
2,334
2,309
3,756
4,037
3,913
25
25
25
25
14,671
17,014
10,305
104
43,453
50,749
12
0
0
0
872
898
716
8,578
18,401
761
529
0
33
566
6
7
7
1,708
2,366
8,584
6
16,216
ALLOWANCES
DEDUCTED
0
5
6,045
12,149
2,371
1,997
2,093
3,251
3,352
3,255
1
0
1
2
9,408
11,612
7,688
9
41 ,824
41 ,776
4
0
0
0
236
187
226
1,182
1,614
131
143
0
0
512
1
0
0
1,485
2,057
3,380
1
15,055
ALLOWANCES
CARRIED OVER
TO 2001
0
5
4,602
6,576
1,965
337
216
505
685
658
24
25
24
23
5,263
5,402
2,617
95
1,629
8,973
8
0
0
0
636
711
490
7,396
16,787
630
386
0
33
54
5
7
7
223
309
5,204
5
1,161
A, 62
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
PLANT NAME
Columbia
Combustion Turbine
Commerce
Concord
Concord
Concord
Concord
DePere Energy Center
Edgewater
Edgewater
Edgewater
Genoa
Germantown Power Plant
J P Madgett
Manitowoc
Manitowoc
Manitowoc
Manitowoc
Na 1 - 7205
Na 1 - 7205
Na 1 - 7205
Na3
Na4
Neenah Power Plant
Neenah Power Plant
Nelson Dewey
Nelson Dewey
Nelson Dewey
North Oak Creek
North Oak Creek
North Oak Creek
North Oak Creek
Paris
Paris
Paris
Paris
Pleasant Prairie
Pleasant Prairie
Pleasant Prairie
Port Washington
Port Washington
Port Washington
Port Washington
Port Washington
PLANT
CODE
8023
7157
4036
7159
7159
7159
7159
55029
4050
4050
4050
4143
6253
4271
4125
4125
4125
4125
7205
7205
7205
7251
7252
55135
55135
4054
4054
4054
4039
4039
4039
4039
7270
7270
7270
7270
6170
6170
6170
4040
4040
4040
4040
4040
STACK/UNIT ID*
2
"2
25
**1
**2
"3
**4
B01
3
4
5
1
**5
B1
CS0020 (6, 7, 8)
6
7
8
"1
**2
**3
"1
"1
CT01
CT02
CS1 (1,2)
1
2
1
2
3
4
**1
"2
"3
**4
CS1 (1 , 2)
1
2
CS7 (1 , 2, 3)
1
2
3
4
2000
ALLOWANCES
ALLOCATED
8,758
0
4
126
126
126
126
0
1,237
10,396
1 1 ,459
8,019
0
7,436
672
814
238
0
0
0
0
0
0
0
2,524
2,808
2,119
2,081
2,130
2,482
124
124
124
124
1 1 ,802
16,680
529
1,031
858
804
HELD IN
ACCOUNTS AS
OF 3/1/2001
15,037
0
4
13
10
10
10
1
18,025
37,370
10,664
22,247
10
14,988
3,172
814
238
0
0
0
0
0
3
7
8,177
10,739
18
18
18
20
10
10
10
20
17,566
20,121
4,771
4,592
4,756
4,223
ALLOWANCES
DEDUCTED
13,270
0
0
1
2
1
1
1
1,809
7,153
8,744
8,165
4
5,376
1,817
814
238
0
0
0
0
0
1
3
7,484
6,787
0
0
0
0
1
2
1
1
17,129
17,130
4,277
4,278
4,278
3,839
ALLOWANCES
CARRIED OVER
TO 2001
1,767
0
4
12
8
9
9
0
16,216
30,217
1,920
14,082
6
9,612
1,355
0
0
0
0
0
0
0
2
4
693
3,952
18
18
18
20
9
8
9
19
437
2,991
494
314
478
384
A, 63
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
wv
wv
wv
wv
wv
wv
wv
wv
PLANT NAME
Port Washington
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Rock River
Rock River
South Fond Du Lac
South Fond Du Lac
South Fond Du Lac
South Fond Du Lac
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
Stoneman
Stoneman
Stoneman
Valley (WEPCO)
Valley (WEPCO)
Valley (WEPCO)
Valley (WEPCO)
Valley (WEPCO)
Valley (WEPCO)
West Marinette
West Marinette
Weston
Weston
Weston
Whitewater
Albright
Albright
Albright
Fort Martin
Fort Martin
Harrison
Harrison
Harrison
PLANT
CODE
4040
4072
4072
4072
4072
4072
4072
4072
4072
4057
4057
7203
7203
7203
7203
4041
4041
4041
4041
4041
4041
4146
4146
4146
4042
4042
4042
4042
4042
4042
4076
4076
4078
4078
4078
55011
3942
3942
3942
3943
3943
3944
3944
3944
STACK/UNIT ID*
5
CS34 (3, 4)
3
4
CS56 (5, 6)
5
6
7
8
1
2
**CT1
**CT2
**CT3
**CT4
CSS (5, 6)
5
6
CS4 (7, 8)
7
8
CS12(B1, B2)
B1
B2
CS1 (1,2)
1
2
CS2 (3, 4)
3
4
"33
"34
1
2
3
01
1
2
3
1
2
XS123(1,2, 3)
1
2
2000
ALLOWANCES
ALLOCATED
1,061
140
208
764
885
2,280
3,153
1,560
1,482
639
39
39
0
3,885
4,861
6,504
6,392
177
223
1,805
1,824
1,954
1,900
765
0
1,396
3,547
9,704
0
1,974
2,054
4,598
17,935
17,767
20,966
19,902
HELD IN
ACCOUNTS AS
OF 3/1/2001
9
220
470
902
1,370
1,800
2,100
18,938
14,414
639
39
39
0
7,399
9,047
5,661
5,275
427
456
3,330
3,289
4,461
4,579
765
5
1,300
2,300
9,550
5
5,180
5,255
12,740
42,603
48,452
2,429
2,667
ALLOWANCES
DEDUCTED
0
200
430
818
1,250
1,676
1,940
8
17
0
0
0
0
6,725
8,223
4,969
4,970
407
448
3,008
3,008
4,108
4,108
1
0
1,220
2,120
8,358
3
5,080
5,155
12,540
42,103
47,952
2,110
2,110
ALLOWANCES
CARRIED OVER
TO 2001
9
20
40
84
120
124
160
18,930
14,397
639
39
39
0
674
824
692
305
20
8
322
281
353
471
764
5
80
180
1,192
2
100
100
200
500
500
319
557
A, 64
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
WV
wv
WV
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
WY
WY
WY
WY
WY
WY
WY
WY
WY
PLANT NAME
Harrison
John E Amos
John E Amos
John E Amos
John E Amos
Kammer
Kammer
Kammer
Kammer
Kanawha River
Kanawha River
Kanawha River
Mitchell
Mitchell
Mitchell
Mountaineer (1301)
Mt Storm
Mt Storm
Mt Storm
Mt Storm
North Branch Power Station
North Branch Power Station
North Branch Power Station
Phil Sporn
Phil Sporn
Phil Sporn
Phil Sporn
Phil Sporn
Phil Sporn
Pleasants
Pleasants
Rivesville
Rivesville
Willow Island
Willow Island
Dave Johnston
Dave Johnston
Dave Johnston
Dave Johnston
Jim Bridger
Jim Bridger
Jim Bridger
Jim Bridger
Laramie River
PLANT
CODE
3944
3935
3935
3935
3935
3947
3947
3947
3947
3936
3936
3936
3948
3948
3948
6264
3954
3954
3954
3954
7537
7537
7537
3938
3938
3938
3938
3938
3938
6004
6004
3945
3945
3946
3946
4158
4158
4158
4158
8066
8066
8066
8066
6204
STACK/UNIT ID*
3
CS012(1,2)
1
2
3
03013(1,2,3)
1
2
3
03012(1,2)
1
2
03012(1,2)
1
2
1
030 (1 , 2)
1
2
3
CS1 (1A, 1B)
1A
1B
2000
ALLOWANCES
ALLOCATED
17,898
22,589
25,899
41,512
8,082
8,390
7,499
4,462
4,291
18,963
19,622
35,223
18,855
17,688
18,296
0
0
03014(11,21,31,41)
11
21
31
41
51
1
2
7
8
1
2
BW41
BW42
BW43
BW44
BW71
BW72
BW73
BW74
1
3,130
2,965
3,313
3,053
10,617
17,603
20,194
1,237
2,529
1,496
4,684
4,706
4,572
8,830
6,804
20,913
20,470
19,590
4,065
5,113
HELD IN
ACCOUNTS AS
OF 3/1/2001
2,435
31,739
25,455
39,237
16,393
14,282
13,530
8,545
7,459
31,210
24,397
39,513
72,083
59,979
8,471
500
500
8,672
8,084
8,116
9,428
21 ,348
23,557
17,905
1,665
4,406
5,627
13,016
3,749
3,718
6,484
5,710
6,843
5,711
5,167
3,270
4,534
ALLOWANCES
DEDUCTED
2,110
30,807
24,704
35,595
15,914
13,863
13,134
7,933
6,852
30,295
23,681
38,350
53,900
56,054
3,118
259
255
8,436
7,873
7,886
9,179
20,792
23,357
17,705
1,565
4,306
5,527
12,816
3,724
3,693
6,284
5,685
6,818
5,686
4,985
3,245
3,264
ALLOWANCES
CARRIED OVER
TO 2001
325
932
751
3,642
479
419
396
612
607
915
716
1,163
18,183
3,925
5,353
241
245
236
211
230
249
556
200
200
100
100
100
200
25
25
200
25
25
25
182
25
1,270
A, 65
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 S02 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
WY
WY
WY
WY
WY
WY
WY
WY
PLANT NAME
Laramie River
Laramie River
Naughton
Naughton
Naughton
Neil Simpson II
Neil Simpson II
Wyodak
PLANT
CODE
6204
6204
4162
4162
4162
7504
7504
6101
STACK/UNIT ID*
2
3
1
2
3
001
CT1
BW91
2000
ALLOWANCES
ALLOCATED
4,303
3,823
5,203
6,743
5,216
0
0
18,317
HELD IN
ACCOUNTS AS
OF 3/1/2001
4,303
4,402
7,295
9,321
4,992
750
4
6,618
ALLOWANCES
DEDUCTED
3,752
4,402
7,270
9,296
4,967
662
1
6,566
* CS stands for Common Stack, which includes emissions from more than one unit. XS stands for Complex Stack, which includes emissions from one or more
Common Stacks and/or Multiple Stacks (MS).
ALLOWANCES
CARRIED OVER
TO 2001
551
0
25
25
25
88
3
52
A, 66
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
Plant Name
Barry
Barry
Barry
Barry
Barry
Charles R Lowman
Charles R Lowman
Charles R Lowman
Colbert
Colbert
Colbert
Colbert
Colbert
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
Gadsden
Gadsden
Gorgas
Gorgas
Gorgas
Operating Utility
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Electric Coop.
Alabama Electric Coop.
Alabama Electric Coop.
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
ORIS
Code
3
3
3
3
3
56
56
56
47
47
47
47
47
26
26
26
26
26
7
7
8
8
8
Standard
Compliance Emission
Boiler Approach Limit
1
2
3
4
5
1
2
3
1
2
3
4
5
1
2
3
4
5
1
2
6
7
8
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.46
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.46
0.46
0.40
Actual
Emission
Rate
0.53
0.53
0.53
0.35
0.35
0.38
0.48
0.47
0.41
0.41
0.41
0.41
0.42
0.46
0.46
0.45
0.45
0.41
0.58
0.63
0.83
0.83
0.58
Avg. Plan,
AEL, or
Early
Election
Limit
0.46
0.46
0.46
0.46
0.46
0.50
0.50
0.57
0.57
0.57
0.57
0.57
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
Actual
Avg. Plan
Rate
0.43
0.43
0.43
0.43
0.43
0.54
0.54
0.54
0.54
0.54
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
1990
Emission
Rate
0.54
0.54
0.54
0.65
0.68
0.69
0.62
0.66
0.80
0.67
0.83
0.86
0.78
0.90
0.78
0.80
0.80
0.78
0.51
0.56
0.83
0.83
0.55
Change
from 1990
to 2000
-2%
-2%
-2%
-46%
-49%
-45%
-23%
-29%
-49%
-39%
-51%
-52%
-46%
-49%
-41%
-44%
-44%
-47%
14%
13%
0%
0%
5%
B-l, 1
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AR
AR
AR
AR
AR
AZ
AZ
AZ
Plant Name
Gorgas
Gorgas
Greene County
Greene County
James H Miller Jr
James H Miller Jr
James H Miller Jr
James H Miller Jr
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Flint Creek
Independence
Independence
White Bluff
White Bluff
Apache Station
Apache Station
Cholla
Operating Utility
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Alabama Power Co.
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
American Electric Power Service
Entergy Arkansas, Inc.
Entergy Arkansas, Inc.
Entergy Arkansas, Inc.
Entergy Arkansas, Inc.
Arizona Electric Power Coop., Inc.
Arizona Electric Power Coop., Inc.
Arizona Public Service Co.
ORIS
Code
8
8
10
10
6002
6002
6002
6002
50
50
50
50
50
50
50
50
6138
6641
6641
6009
6009
160
160
113
Boiler
9
10
1
2
1
2
3
4
1
2
3
4
5
6
7
8
1
1
2
1
2
2
3
1
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Standard
Emission
Limit
0.40
0.40
0.68
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.40
0.40
0.46
0.40
0.40
0.40
0.40
0.46
0.46
0.40
Actual
Emission
Rate
0.36
0.43
0.59
0.41
0.25
0.26
0.32
0.34
0.72
0.72
0.72
0.72
0.72
0.72
0.38
0.42
0.28
0.25
0.26
0.43
0.33
0.48
0.43
0.40
Avg. Plan,
AEL, or
Early
Election
Limit
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.50
0.45
0.45
0.45
0.45
0.50
0.50
0.45
Actual
Avg. Plan
Rate
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
1990
Emission
Rate
0.57
0.73
0.92
0.82
0.73
0.54
0.44
0.58
0.76
0.76
0.76
0.76
0.76
0.76
0.78
0.63
0.31
0.34
0.35
0.29
0.34
0.58
0.58
0.46
Change
from 1990
to 2000
-37%
-41%
-36%
-50%
-66%
-52%
-27%
-41%
-5%
-5%
-5%
-5%
-5%
-5%
-51%
-33%
-10%
-26%
-26%
48%
-3%
-17%
-26%
-13%
B-l, 2
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
Plant Name
Cholla
Cholla
Cholla
Coronado
Coronado
Irvington
Navajo
Navajo
Navajo
Springerville
Springerville
Arapahoe
Arapahoe
Arapahoe
Arapahoe
Cameo
Cherokee
Cherokee
Cherokee
Cherokee
Comanche
Comanche
Craig
Craig
Operating Utility
Arizona Public Service Co.
Arizona Public Service Co.
Arizona Public Service Co.
Salt River Proj . Ag. I & P Dis
Salt River Proj . Ag. I & P Dis
Tucson Electric Power Co.
Salt River Proj . Ag. I & P Dis
Salt River Proj . Ag. I & P Dis
Salt River Proj . Ag. I & P Dis
Tucson Electric Power Co.
Tucson Electric Power Co.
Public Service Company of CO
Public Service Company of CO
Public Service Company of CO
Public Service Company of CO
Public Service Company of CO
Public Service Company of CO
Public Service Company of CO
Public Service Company of Colorado
Public Service Company of Colorado
Public Service Company of Colorado
Public Service Company of Colorado
Tri-State G&T Association, Inc.
Tri-State G&T Association, Inc.
ORIS
Code
113
113
113
6177
6177
126
4941
4941
4941
8223
8223
465
465
465
465
468
469
469
469
469
470
470
6021
6021
Boiler
2
3
4
U1B
U2B
4
1
2
3
1
2
1
2
3
4
2
1
2
3
4
1
2
Cl
C2
Standard
Compliance Emission
Approach Limit
Early Election
Early Election
Early Election
Early Election
Early Election
Standard Limitation
Early Election
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
0.40
0.40
0.40
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.40
0.80
0.80
0.80
0.80
0.46
0.80
0.80
0.46
0.40
0.40
0.46
0.46
0.46
Actual
Emission
Rate
0.37
0.32
0.28
0.42
0.40
0.42
0.41
0.35
0.37
0.39
0.38
0.71
0.71
0.66
0.26
0.41
0.34
0.80
0.38
0.34
0.24
0.32
0.36
0.42
Avg. Plan,
AEL, or
Early
Election
Limit
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.80
0.80
0.80
0.80
0.80
0.80
0.50
0.45
0.45
0.50
0.50
0.50
Actual 1990
Avg. Plan Emission
Rate Rate
0.42
0.36
0.38
0.51
0.51
0.71
0.41
0.41
0.37
0.34
0.33
0.49 1.14
0.49 1.14
0.49 1.12
0.49 1.10
0.96
0.60 1.38
0.60 1.67
0.73
0.51
0.24
0.31
0.39
0.40
Change
from 1990
to 2000
-12%
-11%
-26%
-18%
-22%
-41%
0%
-15%
0%
15%
15%
-38%
-38%
-41%
-76%
-57%
-75%
-52%
-48%
-33%
0%
3%
-8%
5%
B-l, 3
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CT
DE
DE
DE
DE
DE
DE
FL
FL
FL
FL
FL
FL
FL
Plant Name
Craig
Hayden
Hayden
Martin Drake
Martin Drake
Martin Drake
Pawnee
Rawhide
Ray D Nixon
Valmont
Bridgeport Harbor
Edge Moor
Edge Moor
Indian River
Indian River
Indian River
Indian River
Big Bend
Big Bend
Big Bend
Big Bend
C D Mclntosh Jr
Crist
Crist
Operating Utility
Tri-State G&T Association, Inc.
Public Service Company of CO
Public Service Company of CO
Colorado Springs Utilities
Colorado Springs Utilities
Colorado Springs Utilities
Public Service Company of Colorado
Platte River Power Authority
Colorado Springs Utilities
Public Service Company of Colorado
The United Illuminating Co.
Conectiv Delmarva Generation, Inc.
Conectiv Delmarva Generation, Inc.
Delmarva Power & Light Co.
Delmarva Power & Light Co.
Delmarva Power & Light Co.
Delmarva Power & Light Co.
Tampa Electric Co.
Tampa Electric Co.
Tampa Electric Co.
Tampa Electric Co.
City of Lakeland, Dept. of Ele
Gulf Power Co.
Gulf Power Co.
ORIS
Code
6021
525
525
492
492
492
6248
6761
8219
477
568
593
593
594
594
594
594
645
645
645
645
676
641
641
Boiler
C3
HI
H2
5
6
7
1
101
1
5
BHB3
3
4
1
2
3
4
BB01
BB02
BB03
BB04
3
4
5
Standard
Compliance Emission
Approach Limit
Early Election
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Averaging Plan
0.46
0.46
0.40
0.46
0.46
0.46
0.46
0.40
0.46
0.40
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.84
0.84
0.84
0.45
0.46
0.45
0.45
Actual
Emission
Rate
0.36
0.40
0.36
0.42
0.39
0.39
0.21
0.29
0.39
0.26
0.25
0.39
0.22
0.40
0.36
0.31
0.32
0.74
0.74
0.61
0.44
0.48
0.39
0.39
Avg. Plan,
AEL, or
Early
Election
Limit
0.50
0.46
0.46
0.46
0.50
0.45
0.50
0.45
0.45
0.75
0.75
0.75
0.75
0.50
0.46
0.46
Actual 1990
Avg. Plan Emission
Rate Rate
0.28
0.89
0.45
0.39 1.09
0.39 0.83
0.39 0.93
0.62
0.43
0.54
0.17
0.56
0.74
0.55
0.81
0.81
0.97
0.57
0.65 1.24
0.65 1.26
0.65 0.64
0.65 0.46
0.46
0.43 0.43
0.43 0.49
Change
from 1990
to 2000
29%
-55%
-20%
-61%
-53%
-58%
-66%
-33%
-28%
53%
-55%
-47%
-60%
-51%
-56%
-68%
-44%
-40%
-41%
-5%
-4%
4%
-9%
-20%
B-l, 4
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
GA
GA
GA
GA
Plant Name
Crist
Crist
Crystal River
Crystal River
Crystal River
Crystal River
Deerhaven
F J Gannon
F J Gannon
F J Gannon
F J Gannon
Lansing Smith
Lansing Smith
Scholz
Scholz
Seminole
Seminole
St Johns River Power
St Johns River Power
Stanton Energy
Arkwright
Arkwright
Arkwright
Arkwright
Operating Utility
Gulf Power Co.
Gulf Power Co.
Florida Power Corp.
Florida Power Corp.
Florida Power Corp.
Florida Power Corp.
Gainesville Regional Utilities
Tampa Electric Co.
Tampa Electric Co.
Tampa Electric Co.
Tampa Electric Co.
Gulf Power Co.
Gulf Power Co.
Gulf Power Co.
Gulf Power Co.
Seminole Electric Coop.
Seminole Electric Coop.
Jacksonville Electric Authority
Jacksonville Electric Authority
Orlando Utilities Comm.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
ORIS
Code
641
641
628
628
628
628
663
646
646
646
646
643
643
642
642
136
136
207
207
564
699
699
699
699
Boiler
6
7
1
2
4
5
B2
GB03
GB04
GB05
GB06
1
2
1
2
1
2
1
2
1
1
2
3
4
Standard
Compliance Emission
Approach Limit
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.50
0.50
0.40
0.40
0.46
0.46
0.46
0.86
0.86
0.84
0.84
0.40
0.40
0.50
0.50
0.46
0.46
0.46
0.46
0.46
0.45
0.45
0.50
0.50
Actual
Emission
Rate
0.47
0.47
0.37
0.44
0.48
0.48
0.48
0.78
0.76
0.66
0.79
0.51
0.38
0.59
0.63
0.45
0.39
0.47
0.47
0.43
0.76
0.76
0.76
0.76
Avg. Plan,
AEL, or
Early
Election
Limit
0.46
0.46
0.45
0.50
0.50
0.50
0.75
0.75
0.75
0.75
0.46
0.46
0.46
0.46
0.50
0.50
0.50
0.50
0.46
0.46
0.46
0.46
Actual
Avg. Plan
Rate
0.43
0.43
0.65
0.65
0.65
0.65
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
1990
Emission
Rate
1.04
1.16
0.79
0.38
0.50
0.47
0.53
1.52
1.48
1.26
1.61
0.71
0.63
0.69
0.80
0.43
0.36
0.50
0.59
0.43
0.90
0.90
0.90
0.90
Change
from 1990
to 2000
-55%
-59%
-53%
16%
-4%
2%
-9%
-49%
-49%
-48%
-51%
-28%
-40%
-14%
-21%
5%
8%
-6%
-20%
0%
-16%
-16%
-16%
-16%
B-l, 5
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
Plant Name
Bowen
Bowen
Bowen
Bowen
Hammond
Hammond
Hammond
Hammond
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Jack McDonough
Jack McDonough
Kraft
Kraft
Kraft
Mclntosh
Mitchell
Scherer
Scherer
Scherer
Scherer
Wansley
Operating Utility
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Savannah Electric & Power Co.
Savannah Electric & Power Co.
Savannah Electric & Power Co.
Savannah Electric & Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Oglethorpe Power Co.
ORIS
Code
703
703
703
703
708
708
708
708
709
709
709
709
710
710
733
733
733
6124
727
6257
6257
6257
6257
6052
Boiler
1BLR
2BLR
3BLR
4BLR
1
2
3
4
1
2
3
4
MB1
MB2
1
2
3
1
3
1
2
3
4
1
Compliance
Approach
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
; Plan/EE
;Plan
Standard
Emission
Limit
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.50
0.68
0.50
0.68
0.68
0.45
0.45
0.45
0.45
0.45
0.50
0.45
0.40
0.40
0.45
0.40
0.45
Avg. Plan,
AEL, or
Actual Early Actual
Emission Election Avg. Plan
Rate Limit Rate
0.41
0.41
0.42
0.42
0.87
0.87
0.87
0.45
0.86
0.77
0.89
0.89
0.33
0.33
0.48
0.48
0.48
0.72
0.60
0.41
0.38
0.25
0.27
0.39
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46/0.45
0.46
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
1990
Emission
Rate
0.67
0.65
0.56
0.58
0.84
0.84
0.84
1.20
1.18
0.99
1.04
1.04
0.66
0.60
0.40
0.40
0.40
0.83
0.61
0.52
0.35
0.20
0.21
0.73
Change
from 1990
to 2000
-39%
-37%
-25%
-28%
4%
4%
4%
-63%
-27%
-22%
-14%
-14%
-50%
-45%
20%
20%
20%
-13%
-2%
-21%
9%
25%
29%
-47%
B-l, 6
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
GA
GA
GA
GA
GA
GA
GA
GA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
Plant Name
Wansley
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Ames
Ames
Burlington
Council Bluffs
Council Bluffs
Council Bluffs
Dubuque
Dubuque
Earl F Wisdom
Fair Station
George Neal North
George Neal North
George Neal South
Lansing
Lansing
Lansing
Operating Utility
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
Georgia Power Co.
City of Ames
City of Ames
IES Utilities, Inc.
MidAmerican Energy Co.
MidAmerican Energy Co.
Atlantic Municipal Utilities
Interstate Power Co.
Interstate Power Co.
Com Belt Power Coop.
Eastern Iowa Light and Power C
MidAmerican Energy Co.
MidAmerican Energy Co.
MidAmerican Energy Co.
Interstate Power Co.
Interstate Power Co.
Interstate Power Co.
ORIS
Code
6052
728
728
728
728
728
728
728
1122
1122
1104
1082
1082
1082
1046
1046
1217
1218
1091
1091
7343
1047
1047
1047
Boiler
2
Y1BR
Y2BR
Y3BR
Y4BR
Y5BR
Y6BR
Y7BR
7
8
1
1
2
3
1
5
1
2
2
3
4
1
2
3
Standard
Compliance Emission
Approach Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Averaging Plan
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
AEL Final
Standard Limitation
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.40
0.46
0.45
0.46
0.40
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
Actual
Emission
Rate
0.40
0.42
0.42
0.42
0.36
0.36
0.28
0.28
0.38
0.43
0.19
0.45
0.38
0.45
0.68
0.98
0.56
0.39
0.38
0.46
0.34
0.62
0.62
0.85
Avg. Plan,
AEL, or
Early
Election
Limit
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.45
0.50
0.46
0.50
0.45
0.50
0.46
0.46
0.59
0.50
0.50
0.50
0.46
0.46
0.46
Actual
Avg. Plan
Rate
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.36
0.36
0.36
0.36
0.36
0.36
1990
Emission
Rate
0.67
0.56
0.62
0.62
0.56
0.65
0.67
0.61
0.60
0.55
0.63
0.56
0.33
0.37
0.69
0.80
1.11
0.97
1.06
0.39
0.64
0.80
0.80
1.03
Change
from 1990
to 2000
-40%
-25%
-32%
-32%
-36%
-45%
-58%
-54%
-37%
-22%
-70%
-20%
15%
22%
-1%
23%
-50%
-60%
-64%
18%
-47%
-23%
-23%
-17%
B-l, 7
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
Plant Name
Lansing
Louisa
Milton L Kapp
Muscatine
Ottumwa
Prairie Creek
Prairie Creek
Riverside
Sixth Street
Sixth Street
Sixth Street
Sixth Street
Sutherland
Sutherland
Baldwin
Baldwin
Baldwin
Coffeen
Coffeen
Crawford
Crawford
Dallman
Duck Creek
E D Edwards
Operating Utility
Interstate Power Co.
MidAmerican Energy Co.
Interstate Power Co.
City of Muscatine
IES Utilities, Inc.
IES Utilities, Inc.
IES Utilities, Inc.
MidAmerican Energy Co.
IES Utilities, Inc.
IES Utilities, Inc.
IES Utilities, Inc.
IES Utilities, Inc.
IES Utilities, Inc.
IES Utilities, Inc.
Dynegy Midwest Generation, Inc.
Dynegy Midwest Generation, Inc.
Dynegy Midwest Generation, Inc.
Ameren Energy Generating Co.
Ameren Energy Generating Co.
Midwest Generation EME, LLC
Midwest Generation EME, LLC
City of Springfield, Illinois
Central Illinois Light Co.
Central Illinois Light Co.
ORIS
Code
1047
6664
1048
1167
6254
1073
1073
1081
1058
1058
1058
1058
1077
1077
889
889
889
861
861
867
867
963
6016
856
Standard
Compliance Emission
Boiler Approach Limit
4
101
2
9
1
3
4
9
2
3
4
5
1
2
1
2
3
01
02
7
8
33
1
1
Early Election
Early Election
Averaging Plan
Standard Limitation
Early Election
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan/EE
Early Election
AEL Final
Standard Limitation
0.46
0.46
0.45
0.40
0.40
0.46
0.50
0.45
0.46
0.46
0.46
0.46
0.46
0.46
0.86
0.86
0.45
0.86
0.86
0.40
0.40
0.40
0.46
0.46
Avg. Plan,
AEL, or
Actual Early Actual 1990 Change
Emission Election Avg. Plan Emission from 1990
Rate Limit Rate Rate to 2000
0.41
0.28
0.19
0.27
0.33
0.40
0.32
0.34
0.33
0.38
0.45
0.75
0.72
0.56
0.66
0.70
0.21
1.05
1.05
0.30
0.38
0.40
0.54
0.46
0.50
0.50
0.46
0.45
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.59
0.59
0.59
0.59
0.59
0.59/0.45
0.59/0.45
0.45
0.58
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.48
0.48
0.48
0.55
0.55
0.48
0.48
0.50
0.25
0.80
0.35
0.69
0.83
1.05
0.82
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.48
0.48
1.70
1.47
0.67
1.23
1.23
0.33
0.48
0.55
0.90
0.98
-18%
12%
-76%
-23%
-52%
-52%
-70%
-59%
50%
17%
-61%
-52%
-69%
-15%
-15%
-9%
-21%
-27%
-40%
-53%
B-l, 8
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
Plant Name
E D Edwards
E D Edwards
Fisk
Grand Tower
Grand Tower
Grand Tower
Havana
Hennepin
Hennepin
Hutsonville
Hutsonville
Joliet 29
Joliet 29
Joliet 29
Joliet 29
Joliet 9
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Kincaid
Kincaid
Operating Utility
Central Illinois Light Co.
Central Illinois Light Co.
Midwest Generation EME, LLC
Ameren Energy Generating Co.
Ameren Energy Generating Co.
Ameren Energy Generating Co.
Dynegy Midwest Generation, Inc.
Dynegy Midwest Generation, Inc.
Dynegy Midwest Generation, Inc.
Ameren Energy Generating Co.
Ameren Energy Generating Co.
Midwest Generation EME, LLC
Midwest Generation EME, LLC
Midwest Generation EME, LLC
Midwest Generation EME, LLC
Midwest Generation EME, LLC
Electric Energy Inc.
Electric Energy Inc.
Electric Energy Inc.
Electric Energy Inc.
Electric Energy Inc.
Electric Energy Inc.
Dominion Energy Services Co.
Dominion Energy Services Co.
ORIS
Code
856
856
886
862
862
862
891
892
892
863
863
384
384
384
384
874
887
887
887
887
887
887
876
876
Standard
Compliance Emission
Boiler Approach Limit
2
3
19
07
08
09
9
1
2
05
06
71
72
81
82
5
1
2
3
4
5
6
1
2
AEL Final
AEL Final
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
0.46
0.46
0.40
0.50
0.50
0.50
0.46
0.40
0.45
0.45
0.45
0.40
0.40
0.40
0.40
0.86
0.45
0.45
0.45
0.45
0.45
0.45
0.86
0.86
Avg. Plan,
AEL, or
Actual Early Actual
Emission Election Avg. Plan
Rate Limit Rate
0.44
0.51
0.37
0.75
0.75
0.71
0.43
0.37
0.37
0.55
0.52
0.18
0.18
0.38
0.38
0.68
0.20
0.20
0.19
0.19
0.19
0.19
0.75
0.75
0.53
0.59/0.45
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.48
0.55
0.55
0.55
0.48
0.48
0.48
0.55
0.55
0.48
0.48
0.48
0.48
0.48
1990
Emission
Rate
1.00
1.25
0.39
0.78
0.96
0.64
0.46
0.57
0.59
0.70
0.67
0.32
0.32
0.46
0.46
0.91
0.56
0.56
0.56
0.56
0.56
0.56
1.47
1.47
Change
from 1990
to 2000
-56%
-59%
-5%
-4%
-22%
11%
-7%
-35%
-37%
-21%
-22%
-44%
-44%
-17%
-17%
-25%
-64%
-64%
-66%
-66%
-66%
-66%
-49%
-49%
B-l, 9
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IN
IN
Plant Name
Marion
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Newton
Newton
Powerton
Powerton
Powerton
Powerton
Vermilion
Vermilion
Waukegan
Waukegan
Will County
Will County
Will County
Will County
Wood River
Wood River
A B Brown
A B Brown
Operating Utility
Southern Illinois Power Coop.
Ameren Energy Generating Co.
Ameren Energy Generating Co.
Ameren Energy Generating Co.
Ameren Energy Generating Co.
Ameren Energy Generating Co.
Ameren Energy Generating Co.
Ameren Energy Generating Co.
Midwest Generation EME, LLC
Midwest Generation EME, LLC
Midwest Generation EME, LLC
Midwest Generation EME, LLC
Dynegy Midwest Generation, Inc.
Dynegy Midwest Generation, Inc.
Midwest Generation EME, LLC
Midwest Generation EME, LLC
Midwest Generation EME, LLC
Midwest Generation EME, LLC
Midwest Generation EME, LLC
Midwest Generation EME, LLC
Dynegy Midwest Generation, Inc.
Dynegy Midwest Generation, Inc.
Southern Indiana Gas & Electric Co.
Southern Indiana Gas & Electric Co.
ORIS
Code
976
864
864
864
864
864
6017
6017
879
879
879
879
897
897
883
883
884
884
884
884
898
898
6137
6137
Standard
Compliance Emission
Boiler Approach Limit
4
01
02
03
04
05
1
2
51
52
61
62
1
2
7
8
1
2
3
4
4
5
1
2
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan/EE
Early Election
Averaging Plan
Averaging Plan
Early Election
Early Election
0.86
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.86
0.86
0.86
0.86
0.45
0.45
0.40
0.40
0.86
0.86
0.40
0.40
0.40
0.40
0.46
0.46
Avg. Plan,
AEL, or
Actual Early Actual
Emission Election Avg. Plan
Rate Limit Rate
0.85
0.50
0.50
0.50
0.50
0.52
0.17
0.22
0.77
0.77
0.77
0.77
0.46
0.46
0.26
0.15
0.84
0.85
0.33
0.18
0.70
0.55
0.40
0.45
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59/0.45
0.59/0.45
0.59
0.59
0.59/0.45
0.45
0.59
0.59
0.50
0.50
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
1990
Emission
Rate
1.15
0.50
0.50
0.50
0.50
0.67
0.47
0.39
0.92
0.92
0.92
0.92
0.94
0.74
0.26
0.41
0.89
0.87
0.39
0.31
0.70
0.61
0.61
0.39
Change
from 1990
to 2000
-26%
0%
0%
0%
0%
-22%
-64%
-44%
-16%
-16%
-16%
-16%
-51%
-38%
0%
-63%
-6%
-2%
-15%
-42%
0%
-10%
-34%
15%
B-l, 10
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
Plant Name
Bailly
Bailly
Cayuga
Cayuga
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Dean H Mitchell
Dean H Mitchell
Dean H Mitchell
Dean H Mitchell
Edwardsport
Edwardsport
Edwardsport
Elmer W Stout
Elmer W Stout
Elmer W Stout
F B Culley
F B Culley
F B Culley
Frank E Ratts
Operating Utility
Northern Indiana Public Service Co.
Northern Indiana Public Service Co.
PSI Energy, Inc.
PSI Energy, Inc.
Indiana-Kentucky Electric Corp.
Indiana-Kentucky Electric Corp.
Indiana-Kentucky Electric Corp.
Indiana-Kentucky Electric Corp.
Indiana-Kentucky Electric Corp.
Indiana-Kentucky Electric Corp.
Northern Indiana Public Service Co.
Northern Indiana Public Service Co.
Northern Indiana Public Service Co.
Northern Indiana Public Service Co.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
Indianapolis Power & Light Co.
Indianapolis Power & Light Co.
Indianapolis Power & Light Co.
Southern Indiana Gas & Elec Co.
Southern Indiana Gas & Elec Co.
Southern Indiana Gas & Elec Co.
Hoosier Energy R E C Inc.
ORIS
Code
995
995
1001
1001
983
983
983
983
983
983
996
996
996
996
1004
1004
1004
990
990
990
1012
1012
1012
1043
Boiler
7
8
1
2
1
2
3
4
5
6
4
5
6
11
7-1
7-2
8-1
50
60
70
1
2
3
1SG1
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emission
Limit
0.86
0.86
0.45
0.45
0.84
0.84
0.84
0.84
0.84
0.84
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.45
0.45
0.45
0.46
0.50
0.50
0.50
Actual
Emission
Rate
1.29
1.29
0.32
0.30
0.75
0.75
0.75
0.73
0.73
0.73
0.29
0.29
0.26
0.26
0.72
0.67
0.67
0.37
0.36
0.32
0.72
0.46
0.46
0.50
Avg. Plan,
AEL, or
Early
Election
Limit
0.75
0.75
0.49
0.49
0.84
0.84
0.84
0.84
0.84
0.84
0.45
0.45
0.45
0.50
0.49
0.49
0.49
0.45
0.45
0.45
0.50
0.50
0.50
0.47
Actual
Avg. Plan
Rate
0.66
0.66
0.46
0.46
0.76
0.76
0.76
0.76
0.76
0.76
0.46
0.46
0.46
0.35
0.35
0.35
0.48
0.48
0.48
0.39
1990
Emission
Rate
1.51
1.51
0.42
0.47
1.68
1.68
1.68
1.88
1.88
1.88
0.43
0.43
0.58
0.58
0.77
0.98
0.76
0.63
0.65
0.71
0.79
1.05
1.23
1.08
Change
from 1990
to 2000
-15%
-15%
-24%
-36%
-55%
-55%
-55%
-61%
-61%
-61%
-33%
-33%
-55%
-55%
-6%
-32%
-12%
-41%
-45%
-55%
-9%
-56%
-63%
-54%
B-l, 11
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
Plant Name
Frank E Ratts
Gibson
Gibson
Gibson
Gibson
Gibson
H T Pritchard
H T Pritchard
H T Pritchard
H T Pritchard
Merom
Merom
Michigan City
Noblesville
Noblesville
Noblesville
Petersburg
Petersburg
Petersburg
Petersburg
R Gallagher
R Gallagher
R Gallagher
R Gallagher
Operating Utility
Hoosier Energy R E C Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
Indianapolis Power & Light Co.
Indianapolis Power & Light Co.
Indianapolis Power & Light Co.
Indianapolis Power & Light Co.
Hoosier Energy R E C Inc.
Hoosier Energy R E C Inc.
Northern Indiana Public Service Co.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
Indianapolis Power & Light Co.
Indianapolis Power & Light Co.
Indianapolis Power & Light Co.
Indianapolis Power & Light Co.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
ORIS
Code
1043
6113
6113
6113
6113
6113
991
991
991
991
6213
6213
997
1007
1007
1007
994
994
994
994
1008
1008
1008
1008
Boiler
2SG1
1
2
3
4
5
3
4
5
6
1SG1
2SG1
12
1
2
3
1
2
3
4
1
2
3
4
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emission
Limit
0.50
0.50
0.50
0.50
0.50
0.46
0.45
0.45
0.45
0.45
0.46
0.46
0.86
0.46
0.46
0.46
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.50
Avg. Plan,
AEL, or
Actual Early Actual
Emission Election Avg. Plan
Rate Limit Rate
0.47
0.45
0.45
0.46
0.43
0.42
0.68
0.68
0.41
0.41
0.39
0.36
0.51
0.93
0.89
0.93
0.29
0.32
0.36
0.32
0.44
0.44
0.41
0.41
0.47
0.49
0.49
0.49
0.49
0.49
0.45
0.45
0.45
0.45
0.47/0.50
0.47/0.50
0.75
0.49
0.49
0.49
0.45
0.45
0.45
0.45
0.49
0.49
0.49
0.49
0.39
0.46
0.46
0.46
0.46
0.46
0.35
0.35
0.35
0.35
0.39
0.39
0.66
0.46
0.46
0.46
0.35
0.35
0.35
0.35
0.46
0.46
0.46
0.46
1990
Emission
Rate
1.09
1.03
1.12
0.52
0.66
0.50
0.74
0.74
0.67
0.47
0.23
0.63
1.32
0.62
0.91
1.21
0.56
0.63
0.37
0.37
0.74
0.95
0.95
0.95
Change
from 1990
to 2000
-57%
-56%
-60%
-12%
-35%
-16%
-8%
-8%
-39%
-13%
70%
-43%
-61%
50%
-2%
-23%
-48%
-49%
-3%
-14%
-41%
-54%
-57%
-57%
B-l, 12
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
KS
KS
KS
Plant Name
R M Schahfer
R M Schahfer
R M Schahfer
R M Schahfer
Rockport
Rockport
State Line
State Line
Tanners Creek
Tanners Creek
Tanners Creek
Tanners Creek
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Warrick
Whitewater Valley
Whitewater Valley
Holcomb
Jeffrey Energy Centre
Jeffrey Energy Centre
Operating Utility
Northern Indiana Public Service Co.
Northern Indiana Public Service Co.
Northern Indiana Public Service Co.
Northern Indiana Public Service Co.
American Electric Power Genera
Passive Lessors
Mirant State Line Energy, LLC
Mirant State Line Energy, LLC
Indiana Michigan Power Co.
Indiana Michigan Power Co.
Indiana Michigan Power Co.
Indiana Michigan Power Co.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
AGC Div of Alcoa Pwr Gen, Inc.
City of Richmond, Indiana
City of Richmond, Indiana
Sunflower Electric Power Corp.
Western Resources, Inc.
Western Resources, Inc.
ORIS
Code
6085
6085
6085
6085
6166
6166
981
981
988
988
988
988
1010
1010
1010
1010
1010
1010
6705
1040
1040
108
6068
6068
Boiler
14
15
17
18
MB1
MB2
3
4
Ul
U2
U3
U4
1
2
3
4
5
6
4
1
2
SGU1
1
2
Standard
Compliance Emission
Approach Limit
Averaging Plan
Averaging Plan/EE
Early Election
Early Election
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Early Election
Standard Limitation
Averaging Plan
Averaging Plan
0.86
0.46
0.40
0.40
0.46
0.46
0.40
0.86
0.80
0.80
0.80
0.86
0.50
0.50
0.50
0.46
0.50
0.45
0.68
0.46
0.40
0.46
0.40
0.40
Avg. Plan,
AEL, or
Actual Early Actual 1990 Change
Emission Election Avg. Plan Emission from 1990
Rate Limit Rate Rate to 2000
0.57
0.26
0.36
0.35
0.40
0.40
0.21
0.83
0.70
0.70
0.70
1.50
0.14
0.51
0.64
0.61
0.63
0.36
0.45
0.44
0.44
0.27
0.39
0.36
0.75
0.75/0.50
0.45
0.45
0.61/0.50
0.61/0.50
0.68/0.45
0.68
0.61
0.61
0.61
0.61
0.49
0.49
0.49
0.49
0.49
0.49
0.50
0.45
0.40
0.40
0.66
0.66
0.56
0.56
0.58
0.58
0.56
0.56
0.56
0.56
0.46
0.46
0.46
0.46
0.46
0.46
0.36
0.36
1.33
0.42
0.46
0.44
0.32
0.32
0.32
0.75
1.14
1.14
1.14
1.91
0.95
0.95
0.92
Not Oper.
0.85
0.37
1.00
0.71
0.71
0.32
0.36
0.47
-57%
-38%
-22%
-20%
25%
25%
-34%
11%
-39%
-39%
-39%
-21%
-85%
-46%
-30%
-26%
-3%
-55%
-38%
-38%
-16%
8%
-23%
B-l, 13
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
Plant Name
Jeffrey Energy Centre
La Cygne
La Cygne
Lawrence
Lawrence
Lawrence
Nearman Creek
Quindaro
Quindaro
Riverton
Riverton
Tecumseh
Tecumseh
Big Sandy
Big Sandy
Cane Run
Cane Run
Cane Run
Coleman
Coleman
Coleman
Cooper
Cooper
D B Wilson
Operating Utility
Western Resources, Inc.
Kansas City Power & Light Co.
Kansas City Power & Light Co.
Western Resources, Inc.
Western Resources, Inc.
Western Resources, Inc.
Board of Public Utilities, Kansas
K.C. Board of Public Utilities
K.C. Board of Public Utilities
Empire District Electric Co.
Empire District Electric Co.
Western Resources, Inc.
Western Resources, Inc.
Kentucky Power Co.
Kentucky Power Co.
Louisville Gas and Electric Co.
Louisville Gas and Electric Co.
Louisville Gas and Electric Co.
Big Rivers Electric Corp.
Big Rivers Electric Corp.
Big Rivers Electric Corp.
East Kentucky Power Coop. Inc.
East Kentucky Power Coop. Inc.
Big Rivers Electric Corp.
ORIS
Code
6068
1241
1241
1250
1250
1250
6064
1295
1295
1239
1239
1252
1252
1353
1353
1363
1363
1363
1381
1381
1381
1384
1384
6823
Boiler
3
1
2
3
4
5
Nl
1
2
39
40
9
10
BSU1
BSU2
4
5
6
Cl
C2
C3
1
2
Wl
Standard
Compliance Emission
Approach Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Standard Limitation
Standard Limitation
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
AEL Final
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Averaging Plan
0.40
0.86
0.50
0.40
0.40
0.40
0.46
0.86
0.50
0.46
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.40
0.50
0.50
0.50
0.50
0.50
0.46
Avg. Plan,
AEL, or
Actual Early Actual
Emission Election Avg. Plan
Rate Limit Rate
0.31
0.97
0.31
0.33
0.44
0.36
0.42
0.81
0.27
0.47
0.42
0.40
0.41
0.54
0.55
0.44
0.45
0.32
0.42
0.44
0.43
0.42
0.42
0.43
0.40
0.66
0.66
0.40
0.40
0.40
0.50
0.50
0.45
0.40
0.40
0.61
0.57
0.50
0.50
0.45
0.49
0.49
0.49
0.49/0.50
0.36
0.60
0.60
0.36
0.36
0.36
0.36
0.36
0.56
0.44
0.44
0.44
0.44
1990
Emission
Rate
0.46
1.09
0.29
0.45
0.51
0.34
0.46
0.97
0.64
0.83
0.55
0.42
0.44
1.33
1.33
0.84
1.15
1.02
1.41
1.29
1.14
0.90
0.90
0.56
Change
from 1990
to 2000
-33%
-11%
7%
-27%
-14%
6%
-9%
-16%
-58%
-43%
-24%
-5%
-7%
-59%
-59%
-48%
-61%
-69%
-70%
-66%
-62%
-53%
-53%
-23%
B-l, 14
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
Plant Name
Dale
Dale
E W Brown
E W Brown
E W Brown
East Bend
Elmer Smith
Ghent
Ghent
Ghent
Ghent
Green River
Green River
Green River
Green River
Green River
H L Spurlock
H L Spurlock
HMP&L Station 2
HMP&L Station 2
Mill Creek
Mill Creek
Mill Creek
Mill Creek
Operating Utility
East Kentucky Power Coop., Inc.
East Kentucky Power Coop., Inc.
Kentucky Utilities Co.
Kentucky Utilities Co.
Kentucky Utilities Co.
Cincinnati Gas & Electric Co.
City of Owensboro
Kentucky Utilities Co.
Kentucky Utilities Co.
Kentucky Utilities Co.
Kentucky Utilities Co.
Kentucky Utilities Co.
Kentucky Utilities Co.
Kentucky Utilities Co.
Kentucky Utilities Co.
Kentucky Utilities Co.
East Kentucky Power Coop. Inc.
East Kentucky Power Coop., Inc.
City of Henderson
City of Henderson
Louisville Gas and Electric Co.
Louisville Gas and Electric Co.
Louisville Gas and Electric Co.
Louisville Gas and Electric Co.
ORIS
Code
1385
1385
1355
1355
1355
6018
1374
1356
1356
1356
1356
1357
1357
1357
1357
1357
6041
6041
1382
1382
1364
1364
1364
1364
Standard
Compliance Emission
Boiler Approach Limit
3
4
1
2
3
2
2
1
2
3
4
1
2
3
4
5
1
2
HI
H2
1
2
3
4
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
0.46
0.46
0.50
0.45
0.45
0.50
0.45
0.45
0.40
0.46
0.46
0.46
0.46
0.46
0.46
0.50
0.50
0.40
0.50
0.50
0.40
0.40
0.46
0.46
Actual
Emission
Rate
0.36
0.36
0.51
0.38
0.38
0.37
0.39
0.42
0.35
0.33
0.33
0.69
0.69
0.69
0.75
0.39
0.42
0.40
0.46
0.48
0.30
0.34
0.40
0.43
Avg. Plan,
AEL, or
Early
Election
Limit
0.50
0.50
0.45
0.45
0.45
0.49
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.49
0.49
0.45
0.45
0.50
0.50
Actual
Avg. Plan
Rate
0.39
0.39
0.39
0.46
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.44
0.44
1990
Emission
Rate
0.73
0.73
1.00
0.59
0.57
0.31
0.86
0.56
0.54
0.55
0.55
0.65
0.65
0.65
0.99
0.84
0.90
0.47
1.34
1.34
0.76
0.79
0.62
0.57
Change
from 1990
to 2000
-51%
-51%
-49%
-36%
-33%
19%
-55%
-25%
-35%
-40%
-40%
6%
6%
6%
-24%
-54%
-53%
-15%
-66%
-64%
-61%
-57%
-35%
-25%
B-l, 15
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
LA
LA
LA
LA
LA
LA
Plant Name
Paradise
Paradise
Paradise
Pineville
R D Green
R D Green
Robert Reid
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Trimble County
Tyrone
Big Cajun 2
Big Cajun 2
Big Cajun 2
Dolet Hills
R S Nelson
Rodemacher
Operating Utility
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Kentucky Utilities Co.
Big Rivers Electric Corp.
Big Rivers Electric Corp.
Big Rivers Electric Corp.
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Louisville Gas and Electric Co.
Kentucky Utilities Co.
Louisiana Generating, LLC
Louisiana Generating, LLC
Louisiana Generating, LLC
CLECO Power, LLC
Entergy Gulf States, Inc.
CLECO Power, LLC
ORIS
Code
1378
1378
1378
1360
6639
6639
1383
1379
1379
1379
1379
1379
1379
1379
1379
1379
6071
1361
6055
6055
6055
51
1393
6190
Boiler
1
2
3
3
Gl
G2
Rl
1
2
3
4
5
6
7
8
9
1
5
2B1
2B2
2B3
1
6
2
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Standard
Emission
Limit
0.86
0.86
0.86
0.46
0.50
0.50
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.40
0.46
0.46
0.46
0.46
0.46
0.40
0.46
Actual
Emission
Rate
0.66
0.72
1.16
0.61
0.41
0.42
0.81
0.39
0.39
0.39
0.39
0.39
0.37
0.37
0.37
0.37
0.39
0.64
0.31
0.33
0.29
0.45
0.33
0.43
Avg. Plan,
AEL, or
Early
Election
Limit
0.57
0.57
0.57
0.45
0.49
0.49
0.49
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.50
Actual
Avg. Plan
Rate
0.54
0.54
0.54
0.39
0.44
0.44
0.44
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.39
1990
Emission
Rate
1.83
1.72
1.94
0.83
0.41
0.45
0.78
0.71
0.71
0.71
0.71
0.71
0.67
0.67
0.67
0.67
0.62
0.90
0.28
0.25
0.24
0.62
0.20
0.38
Change
from 1990
to 2000
-64%
-58%
-40%
-27%
0%
-7%
4%
-45%
-45%
-45%
-45%
-45%
-45%
-45%
-45%
-45%
-37%
-29%
11%
32%
21%
-27%
65%
13%
B-l, 16
-------
Appendix B-l: Compliance Results for All NOX Affected Units in
2000
2000
ST
MA
MA
MA
MA
MA
MA
MA
MA
MA
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
Plant Name
Brayton Point
Brayton Point
Brayton Point
Mount Tom
Salem Harbor
Salem Harbor
Salem Harbor
Somerset
Somerset
Brandon Shores
Brandon Shores
C P Crane
C P Crane
Chalk Point
Chalk Point
Dickerson
Dickerson
Dickerson
Herbert A Wagner
Herbert A Wagner
Morgantown
Morgantown
RP Smith
RP Smith
Operating Utility
USGen New England, Inc.
USGen New England, Inc.
USGen New England, Inc.
Holyoke Water Power Co.
USGen New England, Inc.
USGen New England, Inc.
USGen New England, Inc.
Somerset Operations Inc.
Somerset Operations Inc.
Constellation Pwr Source Gen
Constellation Pwr Source Gen
Constellation Pwr Source Gen
Constellation Pwr Source Gen
Southern Energy Mid Atlantic
Southern Energy Mid Atlantic
Southern Energy Mid Atlantic
Southern Energy Mid Atlantic
Southern Energy Mid Atlantic
Constellation Pwr Source Gen
Constellation Pwr Source Gen
Southern Energy Mid Atlantic
Southern Energy Mid Atlantic
Allegheny Energy Supply Co., LL
Allegheny Energy Supply Co., LL
ORIS
Code
1619
1619
1619
1606
1626
1626
1626
1613
1613
602
602
1552
1552
1571
1571
1572
1572
1572
1554
1554
1573
1573
1570
1570
Avg. Plan,
AEL, or
Standard Actual Early
Compliance Emission Emission Election
Boiler Approach Limit Rate Limit
1
2
3
1
1
2
3
7
8
1
2
1
2
1
2
1
2
3
2
3
1
2
9
11
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
AEL Final
AEL Final
AEL Final
AEL Final
AEL Final
Averaging Plan
Averaging Plan
AEL Final
AEL Final
Averaging Plan
Averaging Plan
0.40
0.40
0.46
0.46
0.46
0.46
0.46
0.40
0.40
0.46
0.46
0.86
0.86
0.50
0.50
0.40
0.40
0.40
0.46
0.68
0.45
0.45
0.50
0.45
0.30
0.29
0.41
0.36
0.31
0.31
0.31
Not Oper.
0.31
0.41
0.42
1.06
0.92
0.63
0.60
0.45
0.49
0.44
0.60
0.35
0.51
0.48
0.70
0.41
0.56
0.56
0.56
0.56
0.86
1.20
0.48
0.51
0.47
0.56
0.56
0.70
0.70
0.56
0.56
Actual 1990
Avg. Plan Emission
Rate Rate
0.70
0.70
1.43
1.00
1.10
1.10
1.10
1.00
0.67
0.51 0.47
0.51 0.45
0.51 1.27
0.51 1.46
1.35
1.35
0.65
0.65
0.65
0.51 0.83
0.51 1.11
0.95
0.95
0.50 0.87
0.50 0.78
Change
from 1990
to 2000
-57%
-59%
-71%
-64%
-72%
-72%
-72%
-54%
-13%
-7%
-17%
-37%
-53%
-56%
-31%
-25%
-32%
-28%
-68%
-46%
-49%
-20%
-47%
B-l, 17
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
Plant Name
B C Cobb
B C Cobb
B C Cobb
B C Cobb
B C Cobb
Belle River
Belle River
Dan E Karn
Dan E Karn
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Endicott Generating
Erickson
Harbor Beach
JB Sims
J C Weadock
J C Weadock
JH Campbell
J H Campbell
JH Campbell
Operating Utility
Consumers Energy Co.
Consumers Energy Co.
Consumers Energy Co.
Consumers Energy Co.
Consumers Energy Co.
Detroit Edison Co.
Detroit Edison Co.
Consumers Energy Co.
Consumers Energy Co.
Lansing Board of Water & Light
Lansing Board of Water & Light
Lansing Board of Water & Light
Lansing Board of Water & Light
Lansing Board of Water & Light
Lansing Board of Water & Light
Village of Clinton, Michigan
Lansing Board of Water & Light
Detroit Edison Co.
City of Grand Haven
Consumers Energy Co.
Consumers Energy Co.
Consumers Energy Co.
Consumers Energy Co.
Bay City Electric Light and Power
ORIS
Code
1695
1695
1695
1695
1695
6034
6034
1702
1702
1831
1831
1831
1831
1831
1831
4259
1832
1731
1825
1720
1720
1710
1710
1710
Standard
Compliance Emission
Boiler Approach Limit
1
2
3
4
5
1
2
1
2
1
2
3
4
5
6
1
1
1
3
7
8
1
2
3
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Early Election
Averaging Plan/EE
Averaging Plan/EE
AEL Final
Averaging Plan
Averaging Plan
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.40
0.46
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.40
0.40
0.45
0.68
0.46
Avg. Plan,
AEL, or
Actual Early Actual
Emission Election Avg. Plan
Rate Limit Rate
0.09
0.05
0.09
0.34
0.37
0.27
0.26
0.45
0.26
0.49
0.35
0.39
0.39
0.32
0.36
0.40
0.42
0.88
0.38
0.30
0.31
0.43
0.88
0.33
0.46/0.45
0.46/0.45
0.53
0.53
0.46
0.46
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.53
0.50
0.46/0.45
0.46/0.45
0.55
0.46
0.46
0.39
0.39
0.43
0.43
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.43
0.39
0.39
0.39
0.39
1990
Emission
Rate
1.10
1.10
1.10
0.38
0.36
0.26
0.16
0.64
0.91
0.77
0.57
0.44
0.62
0.63
0.70
0.58
0.93
0.90
0.51
0.44
0.44
0.69
1.00
0.69
Change
from 1990
to 2000
-92%
-95%
-92%
-11%
3%
4%
63%
-30%
-71%
-36%
-39%
-11%
-37%
-49%
-49%
-31%
-55%
-2%
-25%
-32%
-30%
-38%
-12%
-52%
B-l, 18
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
Plant Name
J R Whiting
J R Whiting
J R Whiting
James De Young
Marysville
Marysville
Marysville
Marysville
Monroe
Monroe
Monroe
Monroe
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
River Rouge
River Rouge
Shiras
St Clair
Operating Utility
Consumers Energy Co.
Consumers Energy Co.
Consumers Energy Co.
City of Holland
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Detroit Edison Co.
Detroit Edison Co.
Marquette Board of Light & Power
Detroit Edison Co.
ORIS
Code
1723
1723
1723
1830
1732
1732
1732
1732
1733
1733
1733
1733
1769
1769
1769
1769
1769
1769
1769
1769
1740
1740
1843
1743
Standard
Compliance Emission
Boiler Approach Limit
1
2
3
5
9
10
11
12
1
2
3
4
2
3
4
5
6
7
8
9
2
3
3
1
Averaging Plan/EE
Averaging Plan
Averaging Plan/EE
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
0.46
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.68
0.68
0.68
0.68
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.46
0.40
0.46
0.40
0.46
Avg. Plan,
AEL, or
Actual Early Actual 1990 Change
Emission Election Avg. Plan Emission from 1990
Rate Limit Rate Rate to 2000
0.27
0.34
0.32
0.42
0.34
0.34
0.35
0.35
0.53
0.53
0.53
0.53
0.64
0.64
0.64
0.82
0.86
0.48
0.49
0.48
0.39
0.42
0.18
0.68
0.46/0.50
0.46
0.46/0.50
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.47
0.47
0.47
0.47
0.47
0.50
0.50
0.50
0.53
0.53
0.53
0.39
0.39
0.39
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.41
0.41
0.41
0.41
0.41
0.43
0.43
0.43
0.82
0.96
1.04
0.99
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.86
0.86
0.78
0.78
0.75
0.75
0.75
0.91
0.88
0.49
0.53
0.66
0.44
0.83
0.22
0.54
-67%
-65%
-69%
-58%
-38%
-38%
-32%
-32%
-15%
-15%
-15%
-10%
-2%
-2%
-8%
-27%
-11%
-49%
-18%
26%
B-l, 19
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
Plant Name
St Clair
St Clair
St Clair
St Clair
St Clair
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Wyandotte
Allen S King
Black Dog
Black Dog
Black Dog
Clay Boswell
Clay Boswell
Clay Boswell
Clay Boswell
High Bridge
High Bridge
High Bridge
High Bridge
Hoot Lake
Operating Utility
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Detroit Edison Co.
Wyandotte Municipal Service Co.
NSP (d/b/a Xcel Energy)
NSP (d/b/a Xcel Energy)
NSP (d/b/a Xcel Energy)
NSP (d/b/a Xcel Energy)
Minnesota Power and Light Co.
Minnesota Power and Light Co.
Minnesota Power and Light Co.
Minnesota Power and Light Co.
NSP (d/b/a Xcel Energy)
NSP (d/b/a Xcel Energy)
NSP (d/b/a Xcel Energy)
NSP (d/b/a Xcel Energy)
Otter Tail Power Co.
ORIS
Code
1743
1743
1743
1743
1743
1745
1745
1745
1745
1745
1866
1915
1904
1904
1904
1893
1893
1893
1893
1912
1912
1912
1912
1943
Standard
Compliance Emission
Boiler Approach Limit
2
3
4
6
7
9A
16
17
18
19
7
1
1
3
4
1
2
3
4
3
4
5
6
2
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.46
0.86
0.40
0.46
0.46
0.46
0.46
0.40
0.46
0.50
0.50
0.50
0.50
0.40
Actual
Emission
Rate
0.31
0.68
0.71
0.22
0.42
0.32
0.42
0.42
0.42
0.42
0.50
0.71
0.76
0.76
0.76
0.43
0.43
0.38
0.28
0.58
0.58
0.58
0.58
0.44
Avg. Plan,
AEL, or
Early
Election
Limit
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.54
0.54
0.54
0.54
0.41
0.41
0.45
0.41
0.54
0.54
0.54
0.54
0.45
Actual
Avg. Plan
Rate
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.48
0.48
0.48
0.48
0.33
0.33
0.41
0.33
0.48
0.48
0.48
0.48
1990
Emission
Rate
0.58
0.63
0.57
0.39
0.31
0.33
0.47
0.47
0.47
0.47
0.69
1.22
0.75
0.95
0.95
0.42
0.42
0.42
0.38
0.48
0.48
0.48
0.48
0.58
Change
from 1990
to 2000
-47%
8%
25%
-44%
35%
-3%
-11%
-11%
-11%
-11%
-28%
-42%
1%
-20%
-20%
2%
2%
-10%
-26%
21%
21%
21%
21%
-24%
B-l, 20
-------
Appendix B-l: Compliance Results for All NOX Affected Units in
2000
2000
ST
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
Plant Name
Hoot Lake
Minnesota Valley
Northeast Station
Riverside
Riverside
Riverside
Sherburne County
Sherburne County
Sherburne County
Silver Lake
Syl Laskin
Syl Laskin
Asbury
Blue Valley
Hawthorn
latan
James River
James River
James River
Labadie
Labadie
Labadie
Labadie
Meramec
Operating Utility
Otter Tail Power Co.
NSP (d/b/a Xcel Energy)
City of Austin Utilities
NSP (d/b/a Xcel Energy)
NSP (d/b/a Xcel Energy)
NSP (d/b/a Xcel Energy)
NSP (d/b/a Xcel Energy)
NSP (d/b/a Xcel Energy)
NSP (d/b/a Xcel Energy)
Rochester Public Utilities
Minnesota Power and Light Co.
Minnesota Power and Light Co.
Empire District Electric Co.
City of Independence
Kansas City Power & Light Co.
Empire District Electric Co.
City of Springfield (MO)
City of Springfield (MO)
City of Springfield (MO)
Union Electric Co.
Union Electric Co.
Union Electric Co.
Union Electric Co.
Union Electric Co.
ORIS
Code
1943
1918
1961
1927
1927
1927
6090
6090
6090
2008
1891
1891
2076
2132
2079
6065
2161
2161
2161
2103
2103
2103
2103
2104
Boiler
3
4
NEPP
6
7
8
1
2
3
4
1
2
1
3
5
1
3
4
5
1
2
3
4
1
Avg. Plan,
AEL, or
Standard Actual Early
Compliance Emission Emission Election
Approach Limit Rate Limit
Standard Limitation
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.46
0.46
0.46
0.46
0.46
0.86
0.45
0.45
0.46
0.46
0.40
0.40
0.86
0.40
0.45
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.29
0.14
0.44
0.89
0.89
0.98
0.30
0.30
0.34
0.36
0.47
0.47
0.85
0.34
Not Oper.
0.29
0.53
0.54
0.62
0.11
0.12
0.12
0.12
0.38
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.41
0.41
0.50
0.50
0.50
0.52
0.52
0.52
0.52
0.52
Actual 1990 Change
Avg. Plan Emission from 1990
Rate Rate to 2000
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.33
0.33
0.45
0.45
0.45
0.29
0.29
0.29
0.29
0.29
0.67
0.52
0.78
Not Oper.
0.70
0.98
0.45
0.45
0.28
0.82
0.64
0.64
1.09
0.79
0.36
0.31
1.02
0.87
0.93
0.62
0.62
0.62
0.62
0.82
-57%
-73%
-44%
27%
0%
-33%
-33%
21%
-56%
-27%
-27%
-22%
-57%
-6%
-48%
-38%
-33%
-82%
-81%
-81%
-81%
-54%
B-l, 21
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MS
MS
MS
MS
MS
MS
Plant Name
Meramec
Meramec
Meramec
Montrose
Montrose
Montrose
New Madrid
New Madrid
Rush Island
Rush Island
Sibley
Sikeston
Sioux
Sioux
Southwest
Thomas Hill
Thomas Hill
Thomas Hill
Jack Watson
Jack Watson
R D Morrow
R D Morrow
Victor J Daniel Jr
Victor J Daniel Jr
Operating Utility
Union Electric Co.
Union Electric Co.
Union Electric Co.
Kansas City Power & Light Co.
Kansas City Power & Light Co.
Kansas City Power & Light Co.
City of New Madrid, Missouri
Associated Electric Coop. Inc.
Union Electric Co.
Union Electric Co.
Utilicorp United Inc.
City of Columbia, MO
Union Electric Co.
Union Electric Co.
City of Springfield (MO)
Associated Electric Coop. Inc.
Associated Electric Coop. Inc.
Associated Electric Coop. Inc.
Mississippi Power Co.
Mississippi Power Co.
South Mississippi Electric Power A
South Mississippi Electric Power A
Mississippi Power Co.
Mississippi Power Co.
ORIS
Code
2104
2104
2104
2080
2080
2080
2167
2167
6155
6155
2094
6768
2107
2107
6195
2168
2168
2168
2049
2049
6061
6061
6073
6073
Boiler
2
3
4
1
2
3
1
2
1
2
3
1
1
2
1
MB1
MB2
MB3
4
5
1
2
1
2
Standard
Compliance Emission
Approach Limit
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.45
0.50
0.50
0.45
0.45
0.45
0.86
0.86
0.45
0.45
0.86
0.46
0.86
0.86
0.50
0.86
0.86
0.50
0.50
0.50
0.50
0.50
0.45
0.45
Actual
Emission
Rate
0.29
0.75
0.30
0.30
0.36
0.36
1.23
0.52
0.14
0.13
0.74
0.23
1.33
0.47
0.31
0.99
1.01
0.33
0.53
0.71
0.45
0.47
0.31
0.29
Avg. Plan,
AEL, or
Early
Election
Limit
0.52
0.52
0.52
0.74
0.74
0.52
0.52
0.50
0.52
0.52
0.50
0.74
0.74
0.74
0.46
0.46
0.50
0.50
0.46
0.46
Actual
Avg. Plan
Rate
0.29
0.29
0.29
0.72
0.72
0.29
0.29
0.29
0.29
0.45
0.72
0.72
0.72
0.43
0.43
0.46
0.46
0.43
0.43
1990
Emission
Rate
0.63
0.96
1.17
0.32
0.34
0.34
1.47
1.32
0.63
0.63
1.37
0.51
1.07
1.21
0.47
0.90
0.90
0.31
1.10
1.22
0.42
0.43
0.27
0.28
Change
from 1990
to 2000
-54%
-22%
-74%
-6%
6%
6%
-16%
-61%
-78%
-79%
-46%
-55%
24%
-61%
-34%
10%
12%
6%
-52%
-42%
7%
9%
15%
4%
B-l, 22
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
MT
MT
MT
MT
MT
MT
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
Plant Name
Colstrip
Colstrip
Colstrip
Colstrip
J E Corette
Lewis & Clark
Asheville
Asheville
Belews Creek
Belews Creek
Buck
Buck
Buck
Buck
Buck
Cape Fear
Cape Fear
Cliffside
Cliffside
Cliffside
Cliffside
Cliffside
Dan River
Dan River
Operating Utility
P P & L Montana, LLC
P P & L Montana, LLC
P P & L Montana, LLC
Puget Sound Power & Light Co.
P P & L Montana, LLC
Montana-Dakota Utilities Co.
Carolina Power & Light Co.
Carolina Power & Light Co.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Carolina Power & Light Co.
Carolina Power & Light Co.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
ORIS
Code
6076
6076
6076
6076
2187
6089
2706
2706
8042
8042
2720
2720
2720
2720
2720
2708
2708
2721
2721
2721
2721
2721
2723
2723
Standard
Compliance Emission
Boiler Approach Limit
1
2
3
4
2
Bl
1
2
1
2
5
6
7
8
9
5
6
1
2
3
4
5
1
2
Early Election
Early Election
Early Election
Early Election
Standard Limitation
Early Election
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Early Election
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
0.40
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.68
0.68
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
Actual
Emission
Rate
0.35
0.42
0.40
0.41
0.24
0.40
0.46
0.36
0.60
0.55
0.41
0.42
0.44
0.43
0.44
0.46
0.59
0.38
0.40
0.39
0.42
0.44
0.41
0.43
Avg. Plan,
AEL, or
Early
Election
Limit
0.45
0.45
0.45
0.45
0.45
0.44
0.44
0.45
0.45
0.45
0.45
0.45
0.44
0.44
0.45
0.45
0.45
0.45
0.45
0.45
0.45
Actual 1990 Change
Avg. Plan Emission from 1990
Rate Rate to 2000
0.42
0.43
0.34
0.35
0.65
0.57
0.41 1.08
0.41 0.86
1.46
1.36
0.59
0.54
0.57
0.45
0.51
0.41 0.47
0.41 0.66
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.51
0.52
0.55
-17%
-2%
18%
17%
-63%
-30%
-57%
-58%
-59%
-60%
-31%
-22%
-23%
-4%
-14%
-2%
-11%
-14%
-21%
-22%
B-l, 23
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
Plant Name
Dan River
GG Allen
GG Allen
GG Allen
GG Allen
GG Allen
L V Sutton
L V Sutton
L V Sutton
Lee
Lee
Lee
Marshall
Marshall
Marshall
Marshall
Mayo
Mayo
Riverbend
Riverbend
Riverbend
Riverbend
Roxboro
Roxboro
Operating Utility
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Carolina Power & Light Co.
Carolina Power & Light Co.
Carolina Power & Light Co.
Carolina Power & Light Co.
Carolina Power & Light Co.
Carolina Power & Light Co.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Carolina Power & Light Co.
Carolina Power & Light Co.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
Carolina Power & Light Co.
Carolina Power & Light Co.
ORIS
Code
2723
2718
2718
2718
2718
2718
2713
2713
2713
2709
2709
2709
Tin
Tin
2727
2727
6250
6250
2732
2732
2732
2732
2712
2712
Compliance
Boiler Approach
3
1
2
3
4
5
1
2
3
1
2
3
1
2
3
4
1A
IB
7
8
9
10
1
2
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Standard
Emission
Limit
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.40
0.46
0.46
0.40
0.40
0.40
0.40
0.46
0.46
0.40
0.40
0.40
0.40
0.46
0.40
Actual
Emission
Rate
0.44
0.45
0.45
0.44
0.44
0.45
0.58
0.58
0.37
0.60
0.70
0.36
0.44
0.44
0.34
0.45
0.35
0.35
0.42
0.39
0.42
0.41
0.46
0.29
Avg. Plan,
AEL, or
Early
Election
Limit
0.45
0.45
0.45
0.45
0.45
0.45
0.44
0.44
0.44
0.44
0.44
0.44
0.45
0.45
0.45
0.45
0.44
0.44
0.45
0.45
0.45
0.45
0.44
0.44
Actual 1990 Change
Avg. Plan Emission from 1990
Rate Rate to 2000
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.56
0.65
0.61
0.64
0.68
0.68
0.63
0.63
1.19
0.82
0.73
0.90
0.48
0.61
0.52
0.70
0.64
Not Oper.
0.58
0.58
0.58
0.70
1.30
0.76
-21%
-31%
-26%
-31%
-35%
-34%
-8%
-8%
-69%
-27%
-4%
-60%
-8%
-28%
-35%
-36%
-45%
-28%
-33%
-28%
-41%
-65%
-62%
B-l, 24
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
NC
NC
NC
NC
NC
NC
NC
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
NE
NE
NE
NE
NE
NE
Plant Name
Roxboro
Roxboro
Roxboro
Roxboro
W H Weatherspoon
W H Weatherspoon
W H Weatherspoon
Antelope Valley
Antelope Valley
Coal Creek
Coal Creek
Coyote
Leland Olds
Leland Olds
Milton R Young
Milton R Young
Stanton
Stanton
Gerald Whelan Energy
Gerald Gentleman Station
Gerald Gentleman Station
Lon Wright
Nebraska City
North Omaha
Operating Utility
Carolina Power & Light Co.
Carolina Power & Light Co.
Carolina Power & Light Co.
Carolina Power & Light Co.
Carolina Power & Light Co.
Carolina Power & Light Co.
Carolina Power & Light Co.
Basin Electric Power Coop.
Basin Electric Power Coop.
Great River Energy
Great River Energy
Montana-Dakota Utilities Co.
Basin Electric Power Coop.
Basin Electric Power Coop.
Minnkota Power Coop., Inc.
Minnkota Power Coop., Inc.
Great River Energy
Great River Energy
City of Hastings
Nebraska Public Power District
Nebraska Public Power District
City of Fremont
Omaha Public Power District
Omaha Public Power District
ORIS
Code
2712
2712
2712
2712
2716
2716
2716
6469
6469
6030
6030
8222
2817
2817
2823
2823
2824
2824
60
6077
6077
2240
6096
2291
Standard
Compliance Emission
Boiler Approach Limit
3A
3B
4A
4B
1
2
3
Bl
B2
1
2
Bl
1
2
Bl
B2
1
10
1
1
2
8
1
1
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Standard Limitation
Standard Limitation
Standard Limitation
Early Election
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Early Election
Early Election
Early Election
Early Election
Standard Limitation
Early Election
Standard Limitation
0.46
0.46
0.46
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.40
0.86
0.46
0.86
0.86
0.86
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.40
Actual
Emission
Rate
0.38
0.38
0.39
0.39
0.70
0.70
0.42
0.38
0.33
0.21
0.22
0.74
0.25
0.60
0.80
0.84
0.41
0.37
0.29
0.43
0.32
0.18
0.41
0.29
Avg. Plan,
AEL, or
Early
Election
Limit
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.45
0.45
0.50
0.45
0.45
0.50
0.50
0.50
Actual 1990 Change
Avg. Plan Emission from 1990
Rate Rate to 2000
0.41 1.31
0.41 NotOper.
0.41 0.57
0.41 NotOper.
0.41 0.73
0.41 0.73
0.41 0.72
0.43
0.27
0.55
0.82
0.81
0.74
1.03
0.81
1.05
0.84
0.47
0.30
0.40
0.35
0.19
0.48
0.41
-71%
-32%
-4%
-4%
-42%
-12%
22%
-62%
-73%
-9%
-66%
-42%
-1%
-20%
-51%
-21%
-3%
7%
-9%
-5%
-15%
-29%
B-l, 25
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
NE
NE
NE
NE
NE
NH
NH
NH
NH
NJ
NJ
NJ
NJ
NJ
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
Plant Name
North Omaha
North Omaha
North Omaha
North Omaha
Platte
Merrimack
Schiller
Schiller
Schiller
B L England
Deepwater
Hudson
Mercer
Mercer
Escalante
Four Corners
Four Corners
Four Corners
Four Corners
Four Corners
San Juan
San Juan
San Juan
San Juan
Operating Utility
Omaha Public Power District
Omaha Public Power District
Omaha Public Power District
Omaha Public Power District
City of Grand Island
Vermont Electric Power
Public Service Co. of NH
Public Service Co. of NH
Public Service Co. of NH
Atlantic City Electric Co.
Atlantic City Electric Co.
PSEG Fossil LLC
PSEG Fossil LLC
PSEG Fossil LLC
Tri-State G&T Association, Inc.
Arizona Public Service Co.
Arizona Public Service Co.
Arizona Public Service Co.
Arizona Public Service Co.
Arizona Public Service Co.
Public Service Co. of NM
Public Service Co. of NM
Public Service Co. of NM
Public Service Co. of NM
ORIS
Code
2291
2291
2291
2291
59
2364
2367
2367
2367
2378
2384
2403
2408
2408
87
2442
2442
2442
2442
2442
2451
2451
2451
2451
Standard
Compliance Emission
Boiler Approach Limit
2
3
4
5
1
2
4
5
6
2
8
2
1
2
1
1
2
3
4
5
1
2
3
4
Standard Limitation
Standard Limitation
Early Election
Standard Limitation
Early Election
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.40
0.40
0.40
0.46
0.40
0.86
0.46
0.46
0.46
0.86
0.46
0.46
0.84
0.84
0.40
0.46
0.46
0.46
0.68
0.68
0.46
0.46
0.46
0.46
Actual
Emission
Rate
0.29
0.29
0.32
0.32
0.41
0.38
0.34
0.37
0.32
0.50
0.38
0.46
0.69
0.74
0.41
0.76
0.49
0.56
0.55
0.52
0.45
0.49
0.41
0.42
Avg. Plan,
AEL, or
Early
Election
Limit
0.45
0.45
0.64
0.64
0.64
0.45
0.61
0.61
0.61
0.61
0.61
0.46
0.46
0.46
0.46
Actual
Avg. Plan
Rate
0.58
0.58
0.58
0.55
0.55
0.55
0.55
0.55
0.44
0.44
0.44
0.44
1990
Emission
Rate
0.41
0.41
0.38
0.95
0.48
1.96
1.00
1.26
1.07
1.19
0.71
1.34
1.35
1.90
0.35
0.82
0.78
1.00
0.51
1.10
0.42
0.65
0.39
0.42
Change
from 1990
to 2000
-29%
-29%
-16%
-66%
-15%
-81%
-66%
-71%
-70%
-58%
-46%
-66%
-49%
-61%
17%
-7%
-37%
-44%
8%
-53%
7%
-25%
5%
0%
B-l, 26
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
NV
NV
NV
NV
NV
NV
NV
NV
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
Plant Name
Mohave
Mohave
North Valmy
North Valmy
Reid Gardner
Reid Gardner
Reid Gardner
Reid Gardner
AES Westover
AES Westover
AES Westover
C R Huntley
C R Huntley
C R Huntley
C R Huntley
C R Huntley
C R Huntley
Danskammer
Danskammer
Dunkirk
Dunkirk
Dunkirk
Dunkirk
Greenidge
Operating Utility
Nevada Power Co.
Southern California Edison Co.
Idaho Power Co.
Sierra Pacific Power Co.
Nevada Power Co.
Nevada Power Co.
Nevada Power Co.
Nevada Power Co.
NGE Generation, Inc.
NGE Generation, Inc.
NGE Generation, Inc.
Huntley Power Operations, Inc.
Huntley Power Operations, Inc.
Huntley Power Operations, Inc.
Huntley Power Operations, Inc.
Huntley Power Operatons, Inc.
Huntley Power Operatons, Inc.
Dynegy Northeast Generation
Dynegy Northeast Generation
Niagara Mohawk Power Corp.
Niagara Mohawk Power Corp.
Niagara Mohawk Power Corp.
Niagara Mohawk Power Corp.
AES Greenidge, LLC
ORIS
Code
2341
2341
8224
8224
2324
2324
2324
2324
2526
2526
2526
2549
2549
2549
2549
2549
2549
2480
2480
2554
2554
2554
2554
2527
Standard
Compliance Emission
Boiler Approach Limit
1
2
1
2
1
2
3
4
11
12
13
63
64
65
66
67
68
3
4
1
2
3
4
4
Early Election
Early Election
Early Election
Early Election
Standard Limitation
Standard Limitation
Standard Limitation
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Early Election
Early Election
Averaging Plan
Averaging Plan
Early Election
Early Election
Standard Limitation
Standard Limitation
Averaging Plan
0.40
0.40
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.40
0.84
0.84
0.84
0.84
0.40
0.40
0.40
0.40
0.40
0.40
0.45
0.45
0.46
Actual
Emission
Rate
0.42
0.40
0.35
0.38
0.41
0.43
0.43
0.28
0.59
0.59
0.44
0.74
0.74
0.74
0.74
0.37
0.37
0.43
0.38
0.36
0.35
0.35
0.35
0.70
Avg. Plan,
AEL, or
Early
Election
Limit
0.45
0.45
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.40
0.40
0.45
0.45
0.45
Actual 1990
Avg. Plan Emission
Rate Rate
0.38
0.46
0.51
0.40
1.12
1.13
0.53
0.38
0.35 0.62
0.35 0.62
0.35 0.68
0.91
0.91
0.91
0.91
0.64
0.64
0.40 0.54
0.40 0.62
0.48
0.48
0.48
0.48
0.35 0.69
Change
from 1990
to 2000
11%
-13%
-31%
-5%
-63%
-62%
-19%
-26%
-5%
-5%
-35%
-19%
-19%
-19%
-19%
-42%
-42%
-20%
-39%
-25%
-27%
-27%
-27%
1%
B-l, 27
-------
Appendix B-l: Compliance Results for All NOX Affected Units in
2000
2000
ST
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
OH
OH
OH
OH
OH
OH
OH
OH
Plant Name
Greenidge
Greenidge
Kintigh
Lovett
Lovett
Milliken
Milliken
Rochester 3
Rochester 7
Rochester 7
Rochester 7
Rochester 7
S A Carlson
S A Carlson
S A Carlson
S A Carlson
Acme
Acme
Acme
Acme
Acme
Ashtabula
Ashtabula
Ashtabula
Operating Utility
AES Greenidge, LLC
AES Greenidge, LLC
NGE Generation, Inc.
Southern Energy Lovett, LLC
Southern Energy Lovett, LLC
NGE Generation, Inc.
NGE Generation, Inc.
Rochester Gas & Electric Corp.
Rochester Gas & Electric Corp.
Rochester Gas & Electric Corp.
Rochester Gas & Electric Corp.
Rochester Gas & Electric Corp.
City of Jamestown
City of Jamestown
City of Jamestown
City of Jamestown
Toledo Edison Co.
Toledo Edison Co.
Toledo Edison Co.
Toledo Edison Co.
Toledo Edison Co.
Cleveland Electric Ilium Co.
Cleveland Electric Ilium Co.
Cleveland Electric Ilium Co.
ORIS
Code
2527
2527
6082
2629
2629
2535
2535
2640
2642
2642
2642
2642
2682
2682
2682
2682
2877
2877
2877
2877
2877
2835
2835
2835
Standard Actual
Compliance Emission Emission
Boiler Approach Limit Rate
5
6
1
4
5
1
2
12
1
2
3
4
9
10
11
12
14
15
16
91
92
7
8
9
Averaging Plan
Averaging Plan
Averaging Plan/EE
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Standard Limitation
0.46
0.45
0.46
0.46
0.46
0.45
0.45
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.80
0.80
0.80
0.80
0.80
0.45
0.46
0.46
0.70
0.35
0.31
0.35
0.36
0.31
0.31
Not Oper.
0.40
0.40
0.35
0.35
0.41
0.45
0.45
0.41
Not Oper.
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.36
0.52
Not Oper.
Avg. Plan,
AEL, or
Early Actual
Election Avg. Plan
Limit Rate
0.45 0.35
0.45 0.35
0.45/0.50 0.35
0.45 0.35
0.45 0.35
0.40 0.37
0.40 0.37
0.40 0.37
0.40 0.37
0.50
0.50
0.50
0.50
0.51 0.47
0.51 0.47
1990
Emission
Rate
0.69
0.55
0.62
0.57
0.59
0.66
0.59
0.77
0.62
0.65
0.44
0.59
0.90
0.90
1.05
0.83
1.34
1.34
1.34
1.34
1.34
0.61
0.51
0.51
Change
from 1990
to 2000
1%
-36%
-50%
-39%
-39%
-53%
-47%
-35%
-38%
-20%
-41%
-54%
-50%
-57%
-51%
-41%
2%
B-l, 28
-------
Appendix B-l: Compliance Results for All NOX Affected Units in
2000
2000
ST
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Plant Name
Ashtabula
Ashtabula
Avon Lake
Avon Lake
Avon Lake
Bay Shore
Bay Shore
Bay Shore
Bay Shore
Cardinal/Tidd
Cardinal/Tidd
Cardinal/Tidd
Conesville
Conesville
Conesville
Conesville
Eastlake
Eastlake
Eastlake
Eastlake
Eastlake
Edgewater
Edgewater
Edgewater
Operating Utility
Cleveland Electric Ilium Co.
Cleveland Electric Ilium Co.
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Toledo Edison Co.
Toledo Edison Co.
Toledo Edison Co.
Toledo Edison Co.
Ohio Power Co.
Buckeye Power, Inc.
Buckeye Power, Inc.
Columbus Southern Power Co.
Dayton Power & Light Co.
Columbus Southern Power Co.
Columbus Southern Power Co.
Cleveland Electric Ilium Co.
Cleveland Electric Ilium Co.
Cleveland Electric Ilium Co.
Cleveland Electric Ilium Co.
Cleveland Electric Ilium Co.
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
ORIS
Code
2835
2835
2836
2836
2836
2878
2878
2878
2878
2828
2828
2828
2840
2840
2840
2840
2837
2837
2837
2837
2837
2857
2857
2857
Avg. Plan,
AEL, or
Standard Actual Early
Compliance Emission Emission Election
Boiler Approach Limit Rate Limit
10
11
9
10
12
1
2
3
4
1
2
3
3
4
5
6
1
2
3
4
5
11
12
13
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.46
0.46
0.40
0.40
0.68
0.80
0.80
0.46
0.46
0.68
0.68
0.46
0.50
0.45
0.40
0.40
0.45
0.45
0.45
0.45
0.68
0.80
0.80
0.50
0.52
0.52
Not Oper.
0.39
0.80
Not Oper.
0.73
0.73
0.73
0.57
0.54
0.56
0.46
0.47
0.42
0.42
0.37
0.41
0.36
0.35
0.77
Not Oper.
Not Oper.
0.18
0.51
0.51
0.55
0.55
0.51
0.51
0.51
0.51
0.61
0.61
0.61
0.61
0.61
0.45
0.45
0.51
0.51
0.51
0.51
0.51
0.51
0.51
0.51
Actual
Avg. Plan
Rate
0.47
0.47
0.49
0.49
0.47
0.47
0.47
0.47
0.56
0.56
0.56
0.56
0.56
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
1990
Emission
Rate
0.51
0.51
0.63
0.58
0.96
1.08
1.08
1.08
1.08
0.90
1.02
0.74
0.93
0.55
0.44
0.44
0.49
0.68
0.54
0.51
0.67
1.16
1.16
1.16
Change
from 1990
to 2000
2%
2%
-33%
-17%
-32%
-32%
-32%
-37%
-47%
-24%
-51%
-15%
-5%
-5%
-24%
-40%
-33%
-31%
15%
-84%
B-l, 29
-------
Appendix B-l: Compliance Results for All NOX Affected Units in
2000
2000
ST
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Plant Name
Gen J M Gavin
Gen J M Gavin
Gorge
Gorge
Hamilton
J M Stuart
J M Stuart
J M Stuart
J M Stuart
Killen Station
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Lake Shore
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Muskingum River
Muskingum River
Muskingum River
Operating Utility
Ohio Power Co.
Ohio Power Co.
Ohio Edison Co.
Ohio Edison Co.
City of Hamilton
Dayton Power & Light Co.
Dayton Power & Light Co.
Cinergy
Dayton Power & Light Co.
Cincinnati Gas & Electric Co.
Ohio Valley Electric Corp.
Ohio Valley Electric Corp.
Ohio Valley Electric Corp.
Ohio Valley Electric Corp.
Ohio Valley Electric Corp.
Cleveland Electric Ilium Co.
Cincinnati Gas & Electric Co.
Cincinnati Gas & Electric Co.
Cincinnati Gas & Electric Co.
Cincinnati Gas & Electric Co.
Cincinnati Gas & Electric Co.
Ohio Power Co.
Ohio Power Co.
Ohio Power Co.
ORIS
Code
8102
8102
2858
2858
2917
2850
2850
2850
2850
6031
2876
2876
2876
2876
2876
2838
2832
2832
2832
2832
2832
2872
2872
2872
Avg. Plan,
AEL, or
Standard Actual Early
Compliance Emission Emission Election
Boiler Approach Limit Rate Limit
1
2
25
26
9
1
2
3
4
2
1
2
3
4
5
18
5-1
5-2
6
7
8
1
2
3
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.68
0.68
0.50
0.50
0.40
0.68
0.68
0.68
0.68
0.46
0.84
0.84
0.84
0.84
0.84
0.40
0.80
0.80
0.45
0.68
0.46
0.84
0.84
0.86
0.45
0.49
Not Oper.
Not Oper.
0.38
0.59
0.58
0.60
0.54
0.45
0.78
0.78
0.78
0.78
0.78
0.39
1.00
1.00
0.47
0.52
0.56
0.74
0.74
0.74
0.61
0.61
0.51
0.51
0.62
0.62
0.62
0.62
0.62
0.84
0.84
0.84
0.84
0.84
0.51
0.49
0.49
0.49
0.49
0.49
0.61
0.61
0.61
Actual
Avg. Plan
Rate
0.56
0.56
0.47
0.47
0.55
0.55
0.55
0.55
0.55
0.76
0.76
0.76
0.76
0.76
0.47
0.46
0.46
0.46
0.46
0.46
0.56
0.56
0.56
1990
Emission
Rate
1.16
1.16
1.16
1.16
0.60
1.11
1.05
0.95
1.16
0.51
1.34
1.34
1.34
1.34
1.34
0.67
0.71
0.71
0.73
1.07
0.62
1.09
1.09
1.09
Change
from 1990
to 2000
-61%
-58%
-37%
-47%
-45%
-37%
-53%
-12%
-42%
-42%
-42%
-42%
-42%
-42%
41%
41%
-36%
-51%
-10%
-32%
-32%
-32%
B-l, 30
-------
Appendix B-l: Compliance Results for All NOX Affected Units in
2000
2000
ST
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Plant Name
Muskingum River
Muskingum River
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
Picway
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
Richard Gorsuch
Richard Gorsuch
Richard Gorsuch
Richard Gorsuch
Toronto
Toronto
Toronto
Operating Utility
Ohio Power Co.
Ohio Power Co.
Dayton Power & Light Co.
Dayton Power & Light Co.
Dayton Power & Light Co.
Dayton Power & Light Co.
Dayton Power & Light Co.
Dayton Power & Light Co.
Columbus Southern Power Co.
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
American Municipal Power - OH
American Municipal Power - OH
American Municipal Power - OH
American Municipal Power - OH
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
ORIS
Code
2872
2872
2848
2848
2848
2848
2848
2848
2843
2864
2864
2864
2864
2864
2864
2864
2864
7253
7253
7253
7253
2867
2867
2867
Avg. Plan,
AEL, or
Standard Actual Early
Compliance Emission Emission Election
Boiler Approach Limit Rate Limit
4
5
H-l
H-2
H-3
H-4
H-5
H-6
9
1
2
3
4
5
6
7
8
1
2
3
4
9
10
11
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
0.86
0.68
0.40
0.40
0.40
0.40
0.40
0.40
0.50
0.84
0.84
0.84
0.84
0.84
0.84
0.50
0.50
0.46
0.46
0.46
0.46
0.84
0.50
0.50
0.74
0.65
0.56
0.56
0.58
0.58
0.58
0.58
0.43
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.89
0.87
0.67
0.64
0.38
0.38
0.38
0.38
Not Oper.
Not Oper.
Not Oper.
0.61
0.61
0.62
0.62
0.62
0.62
0.62
0.62
0.61
0.51
0.51
0.51
0.51
0.51
0.51
0.51
0.51
0.51
0.51
0.51
Actual 1990 Change
Avg. Plan Emission from 1990
Rate Rate to 2000
0.56
0.56
0.55
0.55
0.55
0.55
0.55
0.55
0.56
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
1.09
1.20
0.67
0.67
0.63
0.63
0.51
0.51
0.87
0.83
0.90
0.94
1.09
0.75
0.73
0.66
0.72
Not Oper.
Not Oper.
Not Oper.
Not Oper.
1.06
1.06
1.06
-32%
-46%
-16%
-16%
-8%
-8%
14%
14%
-51%
19%
19%
2%
-11%
B-l, 31
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
Plant Name
W H Sammis
W H Sammis
W H Sammis
W H Sammis
W H Sammis
W H Sammis
W H Sammis
W H Zimmer
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
GRDA
GRDA
Hugo
Muskogee
Muskogee
Muskogee
Northeastern
Northeastern
Sooner
Sooner
Operating Utility
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
Ohio Edison Co.
Cincinnati Gas & Electric Co.
Cincinnati Gas & Electric Co.
Cincinnati Gas & Electric Co.
Cincinnati Gas & Electric Co.
Cincinnati Gas & Electric Co.
Cincinnati Gas & Electric Co.
Cincinnati Gas & Electric Co.
Grand River Dam Authority
Grand River Dam Authority
Western Farmers Electric Coop.
Oklahoma Gas & Electric Co.
Oklahoma Gas & Electric Co.
Oklahoma Gas & Electric Co.
American Electric Power Service
American Electric Power Service
Oklahoma Gas & Electric Co.
Oklahoma Gas & Electric Co.
ORIS
Code
2866
2866
2866
2866
2866
2866
2866
6019
2830
2830
2830
2830
2830
2830
165
165
6772
2952
2952
2952
2963
2963
6095
6095
Boiler
1
2
3
4
5
6
7
1
1
2
3
4
5
6
1
2
1
4
5
6
3313
3314
1
2
Standard
Compliance Emission
Approach Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
0.46
0.46
0.46
0.46
0.50
0.50
0.68
0.46
0.40
0.40
0.46
0.40
0.45
0.45
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.40
0.40
0.40
Actual
Emission
Rate
0.44
0.45
1.03
0.62
0.47
0.40
0.36
0.46
0.67
0.65
1.00
0.63
0.44
0.33
0.43
0.27
0.22
0.38
0.32
0.42
0.36
0.36
0.37
0.35
Avg. Plan,
AEL, or
Early
Election
Limit
0.51
0.51
0.51
0.51
0.51
0.51
0.51
0.50
0.49
0.49
0.49
0.49
0.49
0.49
0.46
0.46
0.45
0.45
0.45
0.45
0.45
0.45
0.45
Actual 1990 Change
Avg. Plan Emission from 1990
Rate Rate to 2000
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.46
0.46
0.46
0.46
0.46
0.46
0.35
0.35
0.87
0.85
0.86
0.81
0.52
1.10
1.06
Not Oper.
0.58
0.65
1.21
0.51
0.72
0.71
0.41
0.27
0.27
0.44
0.41
0.44
0.53
0.53
0.33
0.42
-49%
-47%
20%
-23%
-10%
-64%
-66%
16%
0%
-17%
24%
-39%
-54%
5%
0%
-19%
-14%
-22%
-5%
-32%
-32%
12%
-17%
B-l, 32
-------
Appendix B-l: Compliance Results for All NOX Affected Units in
2000
2000
ST
OR
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
Plant Name
Boardman
Armstrong
Armstrong
Bruce Mansfield
Bruce Mansfield
Bruce Mansfield
Brunner Island
Brunner Island
Brunner Island
Cheswick
Conemaugh
Conemaugh
Cromby
Eddystone
Eddystone
Elrama
Elrama
Elrama
Elrama
FR Phillips
F R Phillips
FR Phillips
F R Phillips
FR Phillips
Operating Utility
Portland General Electric Co.
Allegheny Energy Supply Co., LL
Allegheny Energy Supply Co., LL
Pennsylvania Power Co.
Pennsylvania Power Co.
Pennsylvania Power Co.
PPL Brunner Island, LLC
PPL Brunner Island, LLC
PPL Brunner Island, LLC
Orion Power Midwest, LP
Reliant Energy NE Management C
Reliant Energy NE Management C
Exelon Generation Co.
Exelon Generation Co.
Exelon Generation Co.
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
ORIS
Code
6106
3178
3178
6094
6094
6094
3140
3140
3140
8226
3118
3118
3159
3161
3161
3098
3098
3098
3098
3099
3099
3099
3099
3099
Boiler
1SG
1
2
1
2
3
1
2
3
1
1
2
1
1
2
1
2
3
4
1
2
3
4
5
Standard Actual
Compliance Emission Emission
Approach Limit Rate
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Standard Limitation
Standard Limitation
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
0.46
0.50
0.50
0.50
0.50
0.46
0.45
0.45
0.45
0.45
0.45
0.45
0.46
0.40
0.40
0.80
0.80
0.80
0.46
0.80
0.80
0.80
0.80
0.80
0.41
0.37
0.37
0.36
0.34
0.38
0.38
0.38
0.36
0.36
0.34
0.34
0.36
0.29
0.27
0.48
0.48
0.48
0.48
Not Oper.
Not Oper.
Not Oper.
Not Oper.
Not Oper.
Avg. Plan,
AEL, or
Early Actual
Election Avg. Plan
Limit Rate
0.50
0.56
0.56
0.51
0.51
0.51/0.50
0.55
0.50
0.45
0.45
0.55
0.55
0.55
0.55
0.50
0.50
0.47
0.47
0.47
0.49
0.49
0.49
0.49
0.49
1990
Emission
Rate
0.40
0.90
1.04
0.98
1.13
0.57
0.65
0.71
0.83
0.71
0.65
0.71
0.60
0.42
0.50
0.80
0.80
0.80
0.85
0.85
0.85
0.85
0.85
0.85
Change
from 1990
to 2000
2%
-59%
-64%
-63%
-70%
-33%
-42%
-46%
-57%
-49%
-48%
-52%
-40%
-31%
-46%
-40%
-40%
-40%
-44%
B-l, 33
-------
Appendix B-l: Compliance Results for All NOX Affected Units in
2000
2000
ST
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
Plant Name
F R Phillips
Hatfield's Ferry
Hatfield's Ferry
Hatfield's Ferry
Homer City
Homer City
Homer City
Keystone
Keystone
Martins Creek
Martins Creek
Mitchell
Montour
Montour
New Castle
New Castle
New Castle
New Castle
New Castle
Portland
Portland
Seward
Seward
Seward
Operating Utility
Orion Power Midwest, LP
Allegheny Energy Supply Co., LL
Allegheny Energy Supply Co., LL
Allegheny Energy Supply Co., LL
EME Homer City Generation, LP
EME Homer City Generation, LP
EME Homer City Generation, LP
Reliant Energy NE Management C
Reliant Energy NE Management C
PPL Martins Creek, LLC
PPL Martins Creek, LLC
Allegheny Energy Supply Co., LL
PPL Montour, LLC
PPL Montour, LLC
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Reliant Energy Mid-Atl Pwr Hoi
Reliant Energy Mid-Atl Pwr Hoi
Reliant Energy Mid-Atl Pwr Hoi
Reliant Energy Mid-Atl Pwr Hoi
Reliant Energy Mid-Atl Pwr Hoi
ORIS
Code
3099
3179
3179
3179
3122
3122
3122
3136
3136
3148
3148
3181
3149
3149
3138
3138
3138
3138
3138
3113
3113
3130
3130
3130
Standard Actual
Compliance Emission Emission
Boiler Approach Limit Rate
6
1
2
3
1
2
3
1
2
1
2
33
1
2
1
2
3
4
5
1
2
12
14
15
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Standard Limitation
Standard Limitation
Averaging Plan
Early Election
Early Election
Standard Limitation
Standard Limitation
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.80
0.68
0.68
0.68
0.46
0.46
0.46
0.40
0.40
0.50
0.50
0.45
0.40
0.40
0.50
0.50
0.46
0.46
0.46
0.45
0.45
0.46
0.46
0.40
Not Oper.
0.46
0.46
0.46
0.41
0.44
0.44
0.32
0.33
0.44
0.44
0.37
0.42
0.32
Not Oper.
Not Oper.
0.33
0.36
0.39
0.25
0.30
0.45
0.45
0.45
Avg. Plan,
AEL, or
Early Actual
Election Avg. Plan
Limit Rate
0.56
0.56
0.56
0.50
0.50
0.50
0.45
0.45
0.56
0.45
0.45
0.55/0.50
0.55/0.50
0.55/0.50
0.44
0.44
0.44
0.44
0.44
0.50
0.50
0.50
0.50
0.49
0.49
0.49
0.35
0.35
0.35
0.35
0.35
1990
Emission
Rate
0.85
1.13
1.17
0.90
1.09
1.04
0.62
0.79
0.79
1.03
0.93
0.68
0.95
0.46
0.79
0.79
0.63
0.57
0.73
0.46
0.66
0.83
0.83
0.75
Change
from 1990
to 2000
-59%
-61%
-49%
-62%
-58%
-29%
-59%
-58%
-57%
-53%
-46%
-56%
-30%
-48%
-37%
-47%
-46%
-55%
-46%
-46%
-40%
B-l, 34
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST Plant Name
Operating Utility
ORIS
Code
Compliance
Boiler Approach
Standard
Emission
Limit
Actual
Emission
Rate
Avg. Plan,
AEL, or
Early
Election
Limit
Actual
Avg. Plan
Rate
1990
Emission
Rate
Change
from 1990
to 2000
PA Shawville
PA Shawville
PA Shawville
PA Shawville
PA Sunbury
PA Sunbury
PA Titus
PA Titus
PA Titus
PA Warren
PA Warren
PA Warren
PA Warren
SC Canadys Steam
SC Canadys Steam
SC Canadys Steam
SC Cope Station
SC Cross
SC Cross
SC Dolphus M Grainger
SC Dolphus M Grainger
SC H B Robinson
SC Jefferies
SC Jefferies
Reliant Energy Mid-Atl Pwr Hoi 3131 1
Reliant Energy Mid-Atl Pwr Hoi 3131 2
Reliant Energy Mid-Atl Pwr Hoi 3131 3
Reliant Energy Mid-Atl Pwr Hoi 3131 4
Sunbury Generation, LLC 3152 3
Sunbury Generation, LLC 3152 4
Reliant Energy Mid-Atlantic Pwr Holdings 3115 1
Reliant Energy Mid-Atlantic Pwr Holdings 3115 2
Reliant Energy Mid-Atlantic Pwr Holdings 3115 3
Reliant Energy Mid-Atl Pwr Holdings 3132 1
Reliant Energy Mid-Atl Pwr Holdings 3132 2
Reliant Energy Mid-Atl Pwr Holdings 3132 3
Reliant Energy Mid-Atl Pwr Holdings 3132 4
South Carolina Electric & Gas 3280 CAN1
South Carolina Electric & Gas 3280 CAN2
South Carolina Electric & Gas 3280 CAN3
South Carolina Electric & Gas 7210 COP 1
South Carolina Public Serv. Authority 130 1
South Carolina Public Service Authority 130 2
South Carolina Public Serv. Authority 3317 1
South Carolina Public Serv. Authority 3317 2
Carolina Power & Light Co. 3251 1
South Carolina Public Serv. Authority 3319 3
South Carolina Public Serv. Authority 3319 4
Standard Limitation 0.50 0.45 0.99 -55%
Standard Limitation 0.50 0.45 1.02 -56%
Standard Limitation 0.45 0.39 0.83 -53%
Standard Limitation 0.45 0.39 0.82 -52%
Standard Limitation 0.50 0.38 0.93 -59%
Standard Limitation 0.50 0.38 1.29 -71%
Early Election 0.40 0.32 0.45 0.73 -56%
Early Election 0.40 0.32 0.45 0.68 -53%
Early Election 0.40 0.33 0.45 0.77 -57%
Averaging Plan 0.46 0.52 0.44 0.35 0.63 -17%
Averaging Plan 0.46 0.52 0.44 0.35 0.63 -17%
Averaging Plan 0.46 0.52 0.44 0.35 0.63 -17%
Averaging Plan 0.46 0.52 0.44 0.35 0.63 -17%
Averaging Plan 0.40 0.40 0.41 0.35 0.45 -11%
Averaging Plan 0.40 0.41 0.41 0.35 0.60 -32%
Averaging Plan 0.46 0.38 0.41 0.35 1.00 -62%
Averaging Plan 0.40 0.26 0.41 0.35 NotOper.
Averaging Plan/EE 0.46 0.31 0.46/0.50 0.40 NotOper.
Early Election 0.40 0.39 0.45 0.46 -15%
Averaging Plan 0.46 0.48 0.46 0.40 0.90 -47%
Averaging Plan 0.46 0.90 0.46 0.40 1.07 -16%
Averaging Plan 0.40 0.76 0.44 0.41 0.63 21%
Averaging Plan 0.46 0.41 0.46 0.40 1.01 -59%
Averaging Plan 0.46 0.44 0.46 0.40 1.15 -62%
B-l, 35
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
SD
TN
TN
TN
TN
TN
TN
TN
TN
Plant Name
McMeekin
McMeekin
Urquhart
Urquhart
Urquhart
WSLee
WSLee
WSLee
Wateree
Wateree
Williams
Winyah
Winyah
Winyah
Winyah
Big Stone
Allen
Allen
Allen
Bull Run
Cumberland
Cumberland
Gallatin
Gallatin
Operating Utility
South Carolina Electric & Gas
South Carolina Electric & Gas
South Carolina Electric & Gas
South Carolina Electric & Gas
South Carolina Electric & Gas
Duke Energy Corp.
Duke Energy Corp.
Duke Energy Corp.
South Carolina Electric & Gas
South Carolina Electric & Gas
South Carolina Electric & Gas
South Carolina Public Serv. Au
South Carolina Public Serv. Au
South Carolina Public Serv. Au
South Carolina Public Serv. Au
Northwestern Public Service Co.
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
ORIS
Code
3287
3287
3295
3295
3295
3264
3264
3264
3297
3297
3298
6249
6249
6249
6249
6098
3393
3393
3393
3396
3399
3399
3403
3403
Boiler
MCM1
MCM2
URQ1
URQ2
URQ3
1
2
3
WAT1
WAT2
WIL1
1
2
3
4
1
1
2
3
1
1
2
1
2
Standard
Compliance Emission
Approach Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
AEL Final
AEL Final
AEL Final
Averaging Plan/AEL
AEL Final
AEL Final
AEL Final
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.40
0.46
0.46
0.46
0.46
0.86
0.86
0.86
0.86
0.40
0.68
0.68
0.45
0.45
Avg. Plan,
AEL, or
Actual Early Actual
Emission Election Avg. Plan
Rate Limit Rate
0.39
0.38
0.47
0.51
0.35
0.43
0.43
0.43
0.46
0.41
0.47
0.44
0.52
0.59
0.54
0.84
0.75
0.73
0.76
0.63
0.47
0.52
0.29
0.29
0.41
0.41
0.41
0.41
0.41
0.45
0.45
0.45
0.59
0.59
0.48
0.46/0.61
0.61
0.60
0.60
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.35
0.35
0.35
0.35
0.35
0.40
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
1990
Emission
Rate
0.61
0.59
0.69
0.64
0.51
0.64
0.61
0.50
1.30
1.47
0.87
1.03
0.65
0.63
0.50
1.29
1.95
1.91
1.87
0.67
1.57
1.33
0.59
0.63
Change
from 1990
to 2000
-36%
-36%
-32%
-20%
-31%
-33%
-30%
-14%
-65%
-72%
-46%
-57%
-20%
-6%
8%
-35%
-62%
-62%
-59%
-6%
-70%
-61%
-51%
-54%
B-l, 36
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
Plant Name
Gallatin
Gallatin
John Sevier
John Sevier
John Sevier
John Sevier
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Operating Utility
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
ORIS
Code
3403
3403
3405
3405
3405
3405
3406
3406
3406
3406
3406
3406
3406
3406
3406
3406
3407
3407
3407
3407
3407
3407
3407
3407
Boiler
3
4
1
2
3
4
1
2
3
4
5
6
7
8
9
10
1
2
3
4
5
6
7
8
Compliance
Approach
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emission
Limit
0.45
0.45
0.40
0.40
0.40
0.40
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.50
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
Actual
Emission
Rate
0.30
0.30
0.40
0.40
0.41
0.41
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.55
0.55
0.55
0.55
0.55
0.43
0.43
0.43
Avg. Plan,
AEL, or
Early
Election
Limit
0.57
0.57
0.45
0.45
0.45
0.45
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
0.57
Actual
Avg. Plan
Rate
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
0.54
1990
Emission
Rate
0.59
0.55
0.62
0.62
0.64
0.64
0.45
0.48
0.46
0.54
0.45
0.50
1.00
0.97
1.10
1.07
0.60
0.60
0.60
0.60
0.60
0.63
0.63
0.63
Change
from 1990
to 2000
-49%
-45%
-35%
-35%
-36%
-36%
7%
0%
4%
-11%
7%
-4%
-52%
-51%
-56%
-55%
-8%
-8%
-8%
-8%
-8%
-32%
-32%
-32%
B-l, 37
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
TN
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
Plant Name
Kingston
Big Brown
Big Brown
Coleto Creek
Gibbons Creek
Harrington Station
Harrington Station
Harrington Station
J T Deely
J T Deely
J K Spruce
Limestone
Limestone
Martin Lake
Martin Lake
Martin Lake
Monticello
Monticello
Monticello
Oklaunion
Pirkey
Sam Seymour
Sam Seymour
Sam Seymour
Operating Utility
Tennessee Valley Authority
TXU Electric Co.
TXU Electric Co.
American Electric Power Service
Texas Municipal Power Agency
Southwestern Public Service Co.
Southwestern Public Service Co.
Southwestern Public Service Co.
City of San Antonio
City of San Antonio
City of San Antonio
Houston Lighting & Power Co.
Houston Lighting & Power Co.
TXU Electric Co.
TXU Electric Co.
TXU Electric Co.
TXU Electric Co.
TXU Electric Co.
TXU Electric Co.
American Electric Power Service
American Electric Power Service
City of Austin, Texas
City of Austin, Texas
Lower Colorado River Authority
ORIS
Code
3407
3497
3497
6178
6136
6193
6193
6193
6181
6181
7097
298
298
6146
6146
6146
6147
6147
6147
127
7902
6179
6179
6179
Boiler
9
1
2
1
1
061B
062B
063B
1
2
**j
LIM1
LIM2
1
2
3
1
2
3
1
1
1
2
3
Compliance
Approach
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Standard
Emission
Limit
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.46
0.40
0.40
0.40
Actual
Emission
Rate
0.43
0.38
0.36
0.24
0.29
0.28
0.30
0.25
0.26
0.26
0.18
0.40
0.28
0.28
0.29
0.31
0.30
0.30
0.24
0.29
0.36
0.33
0.31
0.33
Avg. Plan,
AEL, or
Early
Election
Limit
0.57
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.45
0.45
0.45
Actual 1990 Change
Avg. Plan Emission from 1990
Rate Rate to 2000
0.54 0.63
0.40
0.34
0.38
0.47
0.27
0.36
0.36
0.31
0.31
Not Oper.
0.50
0.48
0.36
0.35
0.42
0.31
0.40
0.21
0.54
0.34
0.34
0.29
0.25
-32%
-5%
6%
-37%
-38%
4%
-17%
-31%
-16%
-16%
-20%
-42%
-22%
-17%
-26%
-3%
-25%
14%
-46%
6%
-3%
7%
32%
B-l, 38
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
VA
VA
VA
Plant Name
San Miguel
Sandow
Tolk Station
Tolk Station
W A Parish
W A Parish
W A Parish
W A Parish
Welsh
Welsh
Welsh
Bonanza
Carbon
Carbon
Hunter (Emery)
Hunter (Emery)
Hunter (Emery)
Huntington
Huntington
Intermountain
Intermountain
Bremo Bluff
Bremo Bluff
Chesapeake
Operating Utility
San Miguel Electric Coop.
TXU Electric Co.
Southwestern Public Service Co.
Southwestern Public Service Co.
Houston Lighting & Power Co.
Houston Lighting & Power Co.
Houston Lighting & Power Co.
Houston Lighting & Power Co.
American Electric Power Service
American Electric Power Service
American Electric Power Service
Deseret Generation & Transmission
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
Intermountain Power Service Co.
Intermountain Power Service Co.
Dominion Generation
Dominion Generation
Virginia Electric & Power Co.
ORIS
Code
6183
6648
6194
6194
3470
3470
3470
3470
6139
6139
6139
7790
3644
3644
6165
6165
6165
8069
8069
6481
6481
3796
3796
3803
Boiler
SM-1
4
171B
172B
WAP5
WAP6
WAP7
WAP8
1
2
3
1-1
1
2
1
2
3
1
2
1SGA
2SGA
3
4
1
Compliance
Approach
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Early Election
Averaging Plan
Early Election
Early Election
Averaging Plan
Averaging Plan
Early Election
Standard
Emission
Limit
0.46
0.40
0.40
0.40
0.46
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.40
Actual
Emission
Rate
0.40
0.33
0.30
0.30
0.34
0.20
0.14
0.30
0.29
0.33
0.36
0.34
0.42
0.44
0.44
0.42
0.41
0.43
0.42
0.42
0.41
0.75
0.41
0.41
Avg. Plan,
AEL, or
Early Actual
Election Avg. Plan
Limit Rate
0.50
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45 0.40
0.45
0.45 0.40
0.50
0.50
0.41 0.36
0.41 0.36
0.45
1990
Emission
Rate
0.41
0.43
0.38
0.24
0.47
0.53
0.35
0.31
0.27
0.36
0.37
0.42
0.50
0.58
0.50
0.55
0.34
0.52
0.43
0.45
0.38
0.78
0.93
0.42
Change
from 1990
to 2000
-2%
-23%
-21%
25%
-28%
-62%
-60%
-3%
7%
-8%
-3%
-19%
-16%
-24%
-12%
-24%
21%
-17%
-2%
-7%
8%
-4%
-56%
-2%
B-l, 39
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
Plant Name
Chesapeake
Chesapeake
Chesapeake
Chesterfield
Chesterfield
Chesterfield
Chesterfield
Clinch River
Clinch River
Clinch River
Clover
Clover
Glen Lyn
Glen Lyn
Glen Lyn
Possum Point
Possum Point
Potomac River
Potomac River
Potomac River
Potomac River
Potomac River
Yorktown
Yorktown
Operating Utility
Virginia Electric & Power Co.
Virginia Electric & Power Co.
Virginia Electric & Power Co.
Virginia Electric & Power Co.
Virginia Electric & Power Co.
Virginia Electric & Power Co.
Virginia Electric & Power Co.
Appalachian Power Co.
Appalachian Power Co.
Appalachian Power Co.
Virginia Electric & Power Co.
Virginia Electric & Power Co.
Appalachian Power Co.
Appalachian Power Co.
Appalachian Power Co.
Virginia Electric & Power Co.
Virginia Electric & Power Co.
Southern Energy Mid Atlantic
Southern Energy Mid Atlantic
Southern Energy Mid Atlantic
Southern Energy Mid Atlantic
Southern Energy Mid Atlantic
Virginia Electric & Power Co.
Virginia Electric & Power Co.
ORIS
Code
3803
3803
3803
3797
3797
3797
3797
3775
3775
3775
7213
7213
3776
3776
3776
3804
3804
3788
3788
3788
3788
3788
3809
3809
Compliance
Boiler Approach
2
3
4
3
4
5
6
1
2
3
1
2
6
51
52
3
4
1
2
3
4
5
1
2
Early Election
Averaging Plan
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan/EE
Early Election
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Standard
Emission
Limit
0.40
0.46
0.40
0.40
0.40
0.40
0.40
0.80
0.80
0.80
0.40
0.40
0.46
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
Avg. Plan,
AEL, or
Actual Early Actual 1990 Change
Emission Election Avg. Plan Emission from 1990
Rate Limit Rate Rate to 2000
0.41
0.42
0.43
0.42
0.42
0.36
0.37
0.64
0.64
0.59
0.29
0.30
0.62
0.40
0.43
0.43
0.36
0.43
0.42
0.41
0.44
0.42
0.45
0.40
0.45
0.41
0.45
0.45
0.45
0.41
0.41
0.61
0.61
0.61
0.41
0.41
0.61
0.61/0.45
0.61/0.45
0.45
0.41
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.36
0.36
0.36
0.56
0.56
0.56
0.36
0.36
0.56
0.56
0.56
0.36
0.48
1.07
0.54
0.52
0.49
0.62
0.73
1.34
1.34
1.42
Not Oper.
Not Oper.
0.76
0.46
Not Oper.
0.60
0.61
0.51
0.44
0.64
0.46
0.72
0.57
0.57
-15%
-61%
-20%
-19%
-14%
-42%
-49%
-52%
-52%
-58%
-18%
-13%
-28%
-41%
-16%
-5%
-36%
-4%
-42%
-21%
-30%
B-l, 40
-------
Appendix B-l: Compliance Results for All NOX Affected Units in
2000
2000
ST
WA
WA
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
Plant Name
Centralia
Centralia
Alma
Alma
Blount Street
Blount Street
Blount Street
Columbia
Columbia
Edgewater
Edgewater
Genoa
J P Madgett
Pleasant Prairie
Pleasant Prairie
Port Washington
Port Washington
Port Washington
Port Washington
Port Washington
Pulliam
Pulliam
Pulliam
Pulliam
Operating Utility
Transalta Centralia Generation
Transalta Centralia Generation
Dairyland Power Coop.
Dairyland Power Coop.
Madison Gas & Electric Co.
Madison Gas & Electric Co.
Madison Gas & Electric Co.
Wisconsin Power & Light Co.
Wisconsin Power & Light Co.
Wisconsin Power & Light Co.
Wisconsin Power & Light Co.
Dairyland Power Coop.
Dairyland Power Coop.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Public Service Corp.
Wisconsin Public Service Corp.
Wisconsin Public Service Corp.
Wisconsin Public Service Corp.
ORIS
Code
3845
3845
4140
4140
3992
3992
3992
8023
8023
4050
4050
4143
4271
6170
6170
4040
4040
4040
4040
4040
4072
4072
4072
4072
Boiler
BW21
BW22
B4
B5
7
8
9
1
2
4
5
1
Bl
1
2
1
2
3
4
5
3
4
5
6
Standard Actual
Compliance Emission Emission
Approach Limit Rate
Early Election
Early Election
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.40
0.40
0.50
0.50
0.68
0.46
0.46
0.40
0.40
0.86
0.46
0.45
0.50
0.46
0.46
0.50
0.50
0.50
0.50
0.50
0.46
0.46
0.46
0.46
0.40
0.40
0.63
0.63
0.62
0.37
0.41
0.37
0.34
1.06
0.21
0.37
0.39
0.42
0.42
0.31
0.31
0.31
0.30
Not Oper.
0.72
0.72
0.78
0.78
Avg. Plan,
AEL, or
Early Actual
Election Avg. Plan
Limit Rate
0.45
0.45
0.48
0.48
0.50
0.50
0.45
0.45
0.62
0.62/0.50
0.48
0.48
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.42
0.42
0.56
0.56
0.42
0.42
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
1990
Emission
Rate
0.40
0.45
0.85
0.85
0.89
0.71
0.61
0.46
0.49
1.17
0.21
0.75
0.30
0.45
0.45
0.32
0.32
0.32
0.37
0.37
0.76
0.76
0.94
0.94
Change
from 1990
to 2000
0%
-11%
-26%
-26%
-30%
-48%
-33%
-20%
-31%
-9%
0%
-51%
30%
-7%
-7%
-3%
-3%
-3%
-19%
-5%
-5%
-17%
-17%
B-l, 41
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
wv
wv
wv
wv
wv
wv
wv
wv
wv
Plant Name
Pulliam
Pulliam
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
Stoneman
Stoneman
Valley
Valley
Valley
Valley
Weston
Weston
Weston
Albright
Albright
Albright
Fort Martin
Fort Martin
Harrison
Harrison
Harrison
John E Amos
Operating Utility
Wisconsin Public Service Corp.
Wisconsin Public Service Corp.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Mid-American Power, LLC
Mid-American Power, LLC
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Public Service Corp.
Wisconsin Public Service Corp.
Wisconsin Public Service Corp.
Monongahela Power Co.
Monongahela Power Co.
Monongahela Power Co.
Monongahela Power Co.
Monongahela Power Co.
Monongahela Power Co.
Monongahela Power Co.
Monongahela Power Co.
Appalachian Power Co.
ORIS
Code
4072
4072
4041
4041
4041
4041
4146
4146
4042
4042
4042
4042
4078
4078
4078
3942
3942
3942
3943
3943
3944
3944
3944
3935
Standard
Compliance Emission
Boiler Approach Limit
7
8
5
6
7
8
Bl
B2
1
2
3
4
1
2
3
1
2
3
1
2
1
2
3
1
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/AEL
Averaging Plan
Averaging Plan
AEL Final
0.50
0.50
0.50
0.50
0.45
0.45
0.46
0.46
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.50
0.50
0.45
0.45
0.68
0.50
0.50
0.50
0.46
Avg. Plan,
AEL, or
Actual Early Actual
Emission Election Avg. Plan
Rate Limit Rate
0.45
0.32
0.23
0.23
0.39
0.39
0.39
0.39
0.46
0.46
0.47
0.47
0.83
0.38
0.22
0.66
0.66
0.38
0.40
0.98
0.46
0.46
0.46
0.55
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.56
0.56
0.56
0.56
0.56
0.56/0.70
0.56
0.56
0.59
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
1990
Emission
Rate
0.69
0.57
0.28
0.28
0.66
0.67
0.75
0.75
1.10
1.10
1.05
0.93
0.90
1.08
0.26
1.10
1.10
0.71
0.62
1.07
0.99
1.13
1.06
1.00
Change
from 1990
to 2000
-35%
-44%
-18%
-18%
-41%
-42%
-48%
-48%
-58%
-58%
-55%
-49%
-8%
-65%
-15%
-40%
-40%
-46%
-35%
-8%
-54%
-59%
-57%
-45%
B-l, 42
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
Plant Name
John E Amos
John E Amos
Kammer
Kammer
Kammer
Kanawha River
Kanawha River
Mitchell
Mitchell
Mountaineer (1301)
Mt Storm
Mt Storm
Mt Storm
Phil Sporn
Phil Sporn
Phil Sporn
Phil Sporn
Phil Sporn
Pleasants
Pleasants
Rivesville
Rivesville
Willow Island
Willow Island
Operating Utility
Appalachian Power Co.
Ohio Power Co.
Ohio Power Co.
Ohio Power Co.
Ohio Power Co.
Appalachian Power Co.
Appalachian Power Co.
Ohio Power Co.
Ohio Power Co.
Appalachian Power Co.
Virginia Electric & Power Co.
Virginia Electric & Power Co.
Virginia Electric & Power Co.
Central Operating Co.
Central Operating Co.
Central Operating Co.
Central Operating Co.
Central Operating Co.
Monongahela Power Co.
Monongahela Power Co.
Monongahela Power Co.
Monongahela Power Co.
Monongahela Power Co.
Monongahela Power Co.
ORIS
Code
3935
3935
3947
3947
3947
3936
3936
3948
3948
6264
3954
3954
3954
3938
3938
3938
3938
3938
6004
6004
3945
3945
3946
3946
Standard
Compliance Emission
Boiler Approach Limit
2
3
1
2
3
1
2
1
2
1
1
2
3
11
21
31
41
51
1
2
7
8
1
2
AEL Final
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/AEL
Averaging Plan/AEL
Averaging Plan/EE
AEL Final
AEL Final
AEL Final
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.46
0.68
0.86
0.86
0.86
0.80
0.80
0.50
0.50
0.46
0.45
0.45
0.45
0.80
0.80
0.80
0.80
0.46
0.50
0.50
0.80
0.80
0.80
0.86
Avg. Plan,
AEL, or
Actual Early Actual
Emission Election Avg. Plan
Rate Limit Rate
0.49
0.64
0.76
0.76
0.76
0.60
0.60
0.56
0.53
0.49
0.67
0.63
0.61
0.71
0.71
0.71
0.71
0.47
0.35
0.35
0.93
0.69
0.70
1.20
0.52
0.61
0.61
0.61
0.61
0.61
0.61/0.56
0.61/0.56
0.61/0.50
0.76
0.69
0.74
0.61
0.61
0.61
0.61
0.61
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.50
0.50
0.50
0.50
0.50
0.50
1990
Emission
Rate
1.00
1.05
1.21
1.21
1.21
1.23
1.23
0.77
0.77
0.47
0.88
0.76
1.27
1.21
1.21
1.21
1.21
0.90
0.52
0.35
0.86
0.77
0.88
1.26
Change
from 1990
to 2000
-51%
-39%
-37%
-37%
-37%
-51%
-51%
-27%
-31%
4%
-24%
-17%
-52%
-41%
-41%
-41%
-41%
-48%
-33%
0%
8%
-10%
-20%
-5%
B-l, 43
-------
Appendix B-l: Compliance Results for All NOX Affected Units in 2000
2000
ST
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
Plant Name
Dave Johnston
Dave Johnston
Dave Johnston
Dave Johnston
Jim Bridger
Jim Bridger
Jim Bridger
Jim Bridger
Laramie River
Laramie River
Laramie River
Naughton
Naughton
Naughton
Wyodak
Operating Utility
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
Basin Electric Power Coop.
Basin Electric Power Coop.
Basin Electric Power Coop.
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
ORIS
Code
4158
4158
4158
4158
8066
8066
8066
8066
6204
6204
6204
4162
4162
4162
6101
Boiler
BW41
BW42
BW43
BW44
BW71
BW72
BW73
BW74
1
2
3
1
2
3
BW91
Compliance
Approach
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emission
Limit
0.46
0.46
0.68
0.40
0.45
0.45
0.45
0.40
0.46
0.46
0.46
0.40
0.40
0.40
0.50
Actual
Emission
Rate
0.43
0.42
0.56
0.41
0.40
0.39
0.37
0.38
0.25
0.27
0.25
0.51
0.48
0.35
0.29
Avg. Plan,
AEL, or
Early
Election
Limit
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.45
0.45
0.45
0.45
Actual
Avg. Plan
Rate
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
1990
Emission
Rate
0.48
0.54
0.71
0.55
0.63
0.51
0.42
0.41
0.35
0.32
0.42
0.42
0.55
0.62
0.37
Change
from 1990
to 2000
-10%
-22%
-21%
-25%
-37%
-24%
-12%
-7%
-29%
-16%
-40%
21%
-13%
-44%
-22%
B-l, 44
-------
Appendix B-2: List of Averaging Plans and Results in 2000
Company
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
AES Westover, LLC
Allegheny Energy Supply Co., LLC
Ameren Services
Ameren Services
2526
2527
6082
2535
AES Westover NY Units 11-13
Greenidge NY Units 4 - 6
KintighNY Unit 1
MillikenNY Units 1,2
3942
3178
3943
3944
3179
3181
6004
1570
3945
3946
Albright WV Units 1 - 3
Armstrong PA Units 1 , 2
Fort Martin WV Units 1, 2
Harrison WV Units 1 - 3
Hatfield's Ferry PA Units 1 - 3
Mitchell PA Unit 33
PleasantsWV Units 1,2
R P Smith MD Units 9, 1 1
Rivesville WV Units 7, 8
Willow Island WV Units 1, 2
861
862
863
864
6017
CoffeenIL Units 01, 02
Grand Tower IL Units 07 - 09
Hutsonville IL Units 05, 06
Meredosia IL Units 01-05
Newton IL Units 1, 2
2103
2104
6155
2107
Labadie MO Units 1 - 4
Meramec MO Units 1 - 4
Rush Island MO Units 1 , 2
Sioux MO Units 1,2
B-2, 1
-------
Appendix B-2: List of Averaging Plans and Results in 2000
Company
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
American Electric Power Service
Arizona Public Service Company
Associated Electric Cooperative
Boswell Energy Center
1353
2828
3775
2840
8102
3776
3947
3936
3948
6264
2872
3938
2843
6166
988
Big Sandy KY Unit BSU1
Cardinal/Tidd OH Units 1 - 3
Clinch River VA Units 1 - 3
Conesville OH Units 3, 4
Gen J M Gavin OH Units 1, 2
Glen Lyn VA Units 6, 51, 52
KammerWV Units 1 - 3
Kanawha River WV Units 1 , 2
Mitchell WV Units 1,2
Mountaineer (1301) WV Unit 1
Muskingum River OH Units 1-5
PhilSpomWV Units 11, 21, 31, 41, 51
Picway OH Unit 9
RockportIN Units MB 1,MB2
Tanners Creek IN Units Ul - U4
2442
Four Corners NM Units 1-5
2167
2168
New Madrid MO Units 1 , 2
Thomas Hill MO Units MB1 - MB3
1893
1891
Clay Boswell MN Units 1, 2, 4
Syl Laskin MN Units 1 , 2
B-2, 2
-------
Appendix B-2: List of Averaging Plans and Results in 2000
Company
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
Carolina Power and Light Company
Cinergy Corp.
City Utilities of Springfield
Colorado Springs Utilities
2706
2708
3251
2713
2709
6250
2712
2716
AshevilleNC Units 1,2
Cape Fear NC Units 5, 6
H B Robinson SC Unit 1
LVSuttonNC Units 1 -3
LeeNC Units 1 - 3
Mayo NC Units 1A, IB
Roxboro NC Units 1, 2, 3A, 3B, 4A, 4B
W H Weatherspoon NC Units 1 - 3
1001
6018
1004
6113
2832
1007
1008
1010
2830
CayugaIN Units 1,2
East Bend KY Unit 2
Edwardsport IN Units 7-1, 7-2, 8-1
Gibson IN Units 1 - 5
Miami Fort OH Units 5-1, 5-2, 6 - 8
Noblesville IN Units 1 - 3
R Gallagher IN Units 1 - 4
Wabash River IN Units 1 - 6
Walter C Beckjord OH Units 1 - 6
2161
6195
James River MO Units 3-5
Southwest MO Unit 1
492
Martin Drake CO Units 5 - 7
B-2, 3
-------
Appendix B-2: List of Averaging Plans and Results in 2000
Company
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
Constellation Power Source Gen..
Inc.
Consumers Energy Company
Dairyland Power Cooperative
Dayton Power & Light Company
Detroit Edison Company
602
1552
1554
Brandon Shores MD Units 1, 2
CP Crane MD Units 1,2
Herbert A Wagner MD Units 2, 3
1695
1702
1720
1710
1723
B C Cobb MI Units 4, 5
Dan E Karn MI Units 1, 2
JCWeadockMI Units 7, 8
J H Campbell MI Units 2, 3
JR Whiting MI Units 1-3
4140
4143
4271
AlmaWI Units B4,B5
Genoa WI Unit 1
JPMadgettWI UnitBl
2850
6031
2848
J M Stuart OH Units 1 - 4
Killen Station OH Unit 2
0 H Hutchings OH Units H-l - H-6
6034
1731
1732
1733
1740
1743
1745
Belle River MI Units 1,2
Harbor Beach MI Unit 1
MarysvilleMI Units 9, 10, 11, 12
Monroe MI Units 1-4
River Rouge MI Units 2, 3
St Clair MI Units 1 - 4, 6, 7
Trenton Channel MI Units 9A, 16 - 19
B-2, 4
-------
Appendix B-2: List of Averaging Plans and Results in 2000
Company
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
Dominion Generation
Dynegy Midwest Generation, Inc.
Dynegy Northeast Generation
FirstEnergy Corporation
3796
3803
3797
7213
3804
Bremo Bluff VA Units 3, 4
Chesapeake VA Unit 3
Chesterfield VA Units 5, 6
Clover VA Units 1,2
Possum Point VA Unit 4
889
891
892
897
898
Baldwin IL Units 1 - 3
Havana IL Unit 9
Hennepin IL Units 1 , 2
Vermilion IL Units 1 , 2
Wood River IL Units 4, 5
2480
DanskammerNY Units 3, 4
2835
2878
6094
2837
2857
2858
2838
2864
2867
2866
Ashtabula OH Units 7, 8, 10, 1 1
Bay Shore OH Units 1 - 4
Bruce Mansfield PA Units 1-3
Eastlake OH Units 1 - 5
EdgewaterOH Units 11-13
Gorge OH Units 25, 26
Lake Shore OH Unit 18
R E Burger OH Units 1 - 8
Toronto OH Units 9-11
W H Sammis OH Units 1 - 7
B-2, 5
-------
Appendix B-2: List of Averaging Plans and Results in 2000
Company
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
Grand River Dam Authority
165
GRDAOK Units 1,2
Hoosier Energy, REC, Inc.
1043
6213
Frank E Ratts IN Units 1 SGI , 2SG1
MeromIN Units 1 SGI, 2SG1
IES Utilities, Inc.
Indianapolis Power & Light Co.
Kansas City Power & Light Co.
1104
1046
1047
1048
1073
1058
1077
Burlington IA Unit 1
Dubuque I A Units 1 , 5
Lansing IA Units 1-3
Milton L Kapp IA Unit 2
Prairie Creek IA Units 3, 4
Sixth Street IA Units 2 - 5
Sutherland IA Units 1, 2
990
991
994
Elmer W Stout IN Units 50, 60, 70
H T Pritchard IN Units 3 - 6
Petersburg IN Units 1 - 4
1241
LaCygneKS Units 1,2
Lansing Board of Water and Light
1831
1832
Eckert Station MI Units 1 - 6
Erickson MI Unit 1
B-2, 6
-------
Appendix B-2: List of Averaging Plans and Results in 2000
Company
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
Louisville Gas and Electric Co.
Midwest Generation EME, LLC
Mirant State Line Energy, LLC
Northern Indiana Public Service Co.
NSP (dba Xcel Energy)
1355
1356
1357
1360
1361
EW Brown KY Units 1 - 3
Ghent KY Units 1 - 4
Green River KY Units 1 - 5
Pineville KY Unit 3
Tyrone KY Unit 5
867
886
384
874
879
883
884
Crawford IL Units 7, 8
FiskIL Unit 19
Joliet 29 IL Units 71, 72, 81, 82
Joliet 9 IL UnitS
PowertonIL Units 51, 52, 61, 62
Waukegan IL Units 7, 8
Will County IL Units 1 - 3
981
State Line IN Units 3, 4
995
997
6085
Bailly IN Units 7, 8
Michigan City IN Unit 12
R M Schahfer IN Units 14, 15
1915
1904
1912
1918
1927
6090
Allen S King MN Unit 1
Black Dog MN Units 1, 3, 4
High Bridge MN Units 3 - 6
Minnesota Valley MN Unit 4
Riverside MN Units 6 - 8
Sherburne County MN Units 1 - 3
B-2, 7
-------
Appendix B-2: List of Averaging Plans and Results in 2000
Company
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
Ohio Valley Electric Corporation
983
2876
Clifty Creek IN Units 1 - 6
Kyger Creek OH Units 1 - 5
Orion Power Holdings, Inc.
Pacificorp
Public Service Co. of New Mexico
2836
8226
3098
3138
Avon Lake OH Units 10, 12
Cheswick PA Unit 1
Elrama PA Units 1 - 4
New Castle PA Units 3 - 5
4158
6165
8069
8066
4162
6101
Dave Johnston WY Units BW43, BW44
Hunter (Emery) UT Unit 3
HuntingtonUT Unit 2
Jim Bridger WY Units BW71 - BW73
Naughton WY Units 1 - 3
WyodakWY UnitBW91
2451
San Juan NM Units 1 -4
Public Service Company of Colorado
Public Service Company of Colorado
Public Service Electric & Gas Co.
465
Arapahoe CO Units 1 - 4
469
Cherokee CO Units 1,2
2403 Hudson NJ Unit 2
2408 Mercer NJ Units 1,2
B-2, 8
-------
Appendix B-2: List of Averaging Plans and Results in 2000
Company
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
Reliant Energy Mid-Atlantic Power
Rochester Gas & Electric Corp.
3113
3130
3132
Portland PA Units 1,2
SewardPA Units 12, 14, 15
Warren PA Units 1 - 4
2642
Rochester 7 NY Units 1 - 4
Santee Cooper
South Carolina Electric & Gas Co.
South Mississippi Electric Power
Association
130
3317
3319
6249
Cross SC Unit 1
Dolphus M Grainger SC Units 1
JefferiesSC Units 3, 4
Winyah SC Unit 1
,2
3280
7210
3287
3295
Canadys Steam SC Units CAN1 - CAN3
Cope Station SC Unit COP 1
McMeekinSC Units MCM 1, MCM2
Urquhart SC Units URQ1 - URQ3
6061
R D Morrow MS Units 1, 2
0.44
0.35
B-2, 9
-------
Appendix B-2: List of Averaging Plans and Results in 2000
Company
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
Southern Company
Southern Indiana Gas & Electric Co.
699
3
703
641
26
7
8
10
708
709
710
2049
6002
733
643
6124
727
6257
642
6073
6052
728
Arkwright GA Units 1 - 4
Barry AL Units 1 - 5
Bowen GA Units 1BLR - 4BLR
Crist FL Units4-7
ECGastonAL Units 1 -5
GadsdenAL Units 1,2
GorgasAL Units 6 - 10
Greene County AL Units 1 , 2
Hammond GA Units 1-4
Harllee Branch GA Units 1 - 4
Jack McDonough GA Units MB 1 , MB2
Jack Watson MS Units 4, 5
James H Miller Jr AL Units 1 - 4
Kraft GA Units 1 - 3
Lansing Smith FL Units 1 , 2
Mclntosh GA Unit 1
Mitchell GA Unit 3
Scherer GA Units 1 - 4
ScholzFL Units 1,2
Victor J Daniel Jr MS Units 1 , 2
WansleyGA Units 1,2
Yates GA Units Y1BR - Y7BR
1012
F B Culley IN Units 1 - 3
B-2, 10
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Appendix B-2: List of Averaging Plans and Results in 2000
Company
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
Tampa Electric Company
645
646
Tennessee Valley Authority
3393
3396
47
3399
3403
3406
3407
1378
1379
50
Western Kentucky Energy Co.
Western Resources
Big Bend FL Units BB01 - BB04
F J Gannon FL Units GB03 - GB06
Allen TN Units 1 - 3
Bull Run TN Unit 1
Colbert AL Units 1 -5
Cumberland TN Units 1, 2
Gallatin TN Units 1 - 4
Johnsonville TN Units 1-10
Kingston TN Units 1 - 9
Paradise KY Units 1 - 3
Shawnee KY Units 1 - 9
Widows Creek AL Units 1 - 8
1381
6823
1382
6639
1383
ColemanKY Units C1-C3
D B Wilson KY Unit Wl
HMP&L Station 2 KY Units HI , H2
R D Green KY Units Gl , G2
Robert Reid KY UnitRl
6068 Jeffrey Energy Centr KS Units 1 - 3
1250 Lawrence KS Units 3 - 5
1252 TecumsehKS Units 9, 10
B-2, 11
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Appendix B-2: List of Averaging Plans and Results in 2000
Company
Wisconsin Electric Power Company
Wisconsin Power & Light Co
Wisconsin Public Service Corp.
ORIS Code Plant Name, State and Units
6170 Pleasant Prairie WI Units 1, 2
4040 Port Washington WI Units 1 - 4
1769 Presque Isle MI Units2-6
4041 South Oak Creek WI Units 5 - 8
4042 Valley WI Units 1 - 4
4050
4072
4146
4078
Edgewater WI Units 4, 5
Pulliam WI Units 3 - 8
StonemanWI Units B1,B2
Weston WI Units 1 - 3
Plan Limit
Plan Rate
0.47
0.41
B-2, 12
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Appendix B-3: Description of NOX Compliance Assessment Methodology
1. Emission Rate Evaluation for Single Unit Compliance
(a) Compliance Determination
The NOX emission limit for each unit is compared to the actual annual NOX emissions rates at the unit as
follows. If the unit has an alternative emissions limit (AEL) this limit is used instead of the base emission limit.
(1) For units not associated with a specific stack or associated with multiple stacks only:
If unit NOX emission rate • ninit NOX emission limit
Unit compliance status is Pass
else
Unit compliance status is Fail.
(2) For units associated with a single common stack:
a. Locate the associated Stack ID for the unit in the ARCONFIG file.
b. If stack NOX emission rate • -NOX emission limit
Unit compliance status is Pass
else
Unit compliance status is Fail.
(3) For units associated with a complex stack configuration:
a. Locate all associated Stack IDs in ARCONFIG file.
b. Select highest NOX emission rate for all stacks.
c. If selected stack NOX emission rate • *NOX emission limit
Unit compliance status is Pass
else
d. Calculate NOX pounds for the unit as apportioned to the unit from each
stack
Unit/Stack NOX Pounds = Actual Stack NOX Emission Rate * Unit Heat Input Apportioned from the Stack
B-3, 1
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e. Calculate the total actual NOX pounds for the unit:
Unit NOX Pounds Emitted = Sum of Unit/Stack NOX Pounds Emitted for Each Unit/Stack
f. Calculate the allowable NOX pounds for the unit:
Unit Allowable NOx Pounds = Unit NOX Emission Limit * Actual Unit Heat Input
g. Determine compliance on a NOX pounds basis for the unit:
If Unit NOX Pounds Emitted • 'Unit Allowable NOX Pounds
Unit compliance status is Pass
else
Unit compliance status is Fail.
(b) Excess Emission Calculation
If the unit compliance status is fail, excess emissions are computed as follows:
(1) Compute allowable tons from the unit:
NOX Pounds Allowable = Unit NOX Emission Limit * Actual Annual Unit Heat Input
(2) Compute actual pounds emitted from the unit:
a. For units not associated with any stack or for units associated with a single common stack or for
units with multiple stacks only:
Unit NOX Pounds Emitted = Actual NOX Emission Rate * Actual Annual Unit Heat Input
b. For units in a complex stack configuration
Unit NOX Pounds Emitted = Sum of (Unit Apportioned Heat Input from Each Stack *
Actual NOX Emission Rate for Each Stack)
B-3,2
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(3) Determine exceedance (tons, rounded to one decimal place):
NOX Tons Exceedance = (NOX Pounds Emitted • -NOX Pounds Allowable) /2000
1. Determining Compliance of Units in Averaging Plans
(a) Compliance Determination
For each averaging plan, a NOX emissions limit is calculated as follows.
(1) Calculate the allowable NOX pounds for the each unit in the plan:
Unit NOX Pounds Allowable = Unit NOX Emission Limit * Actual Annual Unit Heat Input
(2) Calculate the total allowable NOX pounds for the plan:
Total NOX Pounds Allowable for Plan = Sum of All Units NOX Pounds Allowable
(3) Calculate the total actual heat input for the plan:
Total Actual Heat Input for Plan = Sum of Annual Heat Input for All Units
(4) Calculate the allowable NOX emission rate for the plan:
Allowable NOX Emission Rate for Plan = Total NOX Pounds Allowable for Plan / Total Heat Input for Plan
(5) Calculate the actual NOX pounds for each unit:
a. For units not associated with a common stack:
Unit NOX Pounds Emitted = Actual NOX Emission Rate * Annual Unit Heat Input
b. For each stack associated with the plan:
Stack NOX Pounds Emitted = Actual NOX Emission Rate * Annual Stack Heat Input
B-3,3
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(6) Calculate the actual NOX pounds for the plan:
Actual NOX Pounds Emitted for the Plan = Sum of the Unit and Stack NOX Pounds Emitted
(7) Calculate the total actual heat input for the plan:
Total Heat Input for the Plan = Sum of the Annual Heat Input for Each Unit
or Stack with Measured Data
(8) Calculate the Annual NOX emission rate for the plan:
Annual NOX Emissions Rate for the Plan = Actual NOX Pounds Emitted/
Annual Heat Input for the Plan
(9) Determine NOX compliance for the plan:
If Actual NOX Pounds Emitted for the Plan • • NOX Pounds Allowable for the plan
plan compliance status is Pass
else
plan compliance status is Fail.
(b) Excess Emission Calculation
If the plan compliance status is fail, excess emissions are computed in tons to one decimal place as follows:
NOX Tons Exceedance = (NOX Pounds Emitted • -NOX Pounds Allowable) /2000
B-3,4
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