# Ac id Rain Progra m :

Annual Progress Report, 2000

www

. epa

. gov / airmarkets 

# Compliance and Emissions Trends United States Office of Air and Radiation August, 2001

Environmental Protection Clean Air Markets Division EPA-430-R-01-008

Agency 6204N

# Table of Contents

Page

Background 1

• Multiple Benefits of Reducing Acid Rain 2

SO

2 

# Program Compliance Results 5

• Deducting Allowances for Compliance 8

• Geographic Trends in Sulfur Dioxide Emissions 9

SO

2 

# Allowance Market 11

NO

X 

# Program Compliance Results 13

• Geographic Trends in Nitrogen Oxide Emissions 17

SO

2 

# and NO

x 

# Monitoring in 2000 19

Conclusion 21

# 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 SO

2 

# Emissions Trend for All Acid Rain Program Affected Units 5

4. The SO

2 

# Allowance Bank: Emissions and Allocations (1995-2000) 6

5. Origin of 2000 Allowable Emissions Level 7

6. SO

2 

# 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. SO

2 

# Allowance Price Indices 12

10. SO

2 

# Allowances Transferred Under the Acid Rain Program 12

11. Phase II NO

X 

# Units by Boiler Type 14

12. Compliance Options Chosen in 2000 15

13. NO

X 

# 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

# 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 (SO

2 

# ) and nitrogen oxides (NO

X 

# ), 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 SO

2 

# 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 NO

X 

# emission

limitations (in lb/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 SO

2 

# and from1996 through 1999 for NO

X 

# ; 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 SO

2 

# provisions of the Acid Rain Program

, meaning they operated, submitted emissions data for SO

2 

# , and

were subject to annual reconciliation of allowable emissions with actual emissions. Additionally,

1,046 of these units were required to meet a NO

X 

# emissions limit under the Acid Rain Program

provisions.

Exhibit 1

Affected Sources under the Acid Rain Program

# Acid Rain Program: Annual Progress Report, 2000 Page 2



# The SO

2 

# 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 SO

2 

# 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 SO

2 

# emissions allowances, where one allowance is a limited authorization

to emit one ton of SO

2 

# . 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 SO

2 

# emissions.

The NO

X 

# 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 II units

elected to become subject to Phase I limits beginning in 1997. These early election units are not

subject to the more stringent Phase II limits until 2008.

At the end of each year, utilities must demonstrate compliance with the provisions of the Acid Rain

Program. For SO

2 

# , utilities are granted a 60-day grace period during which additional SO

2 

# 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 SO

2 

# emissions. Any remaining SO

2 

# allowances may be sold or banked for use in future years. For the NO

X 

# 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 (SO

2 

# )

and oxides of nitrogen (NO

x 

# ) 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. SO

2 

# and NO

x 

# 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.

# Acid Rain Program: Annual Progress Report, 2000 Page 3



# By reducing the pollutants that cause acid rain, significant environmental and health benefits are being

achieved.

Exhibit 2 illustrates the geographic extent of multiple sensitive resources in the United States: nitrogensaturated 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.

# 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

The Acid Rain Program’s ultimate objective is to protect the environment and improve human health

by reducing both SO

2 

# 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), SO

2 

# 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.

# Acid Rain Program: Annual Progress Report, 2000 Page 5



# Starting in Phase II (2000), additional units are affected with more stringent SO

2 

# 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 lbs/mmBtu, depending on the boiler type). In the first year of Phase II,

emissions continued to decline. In 2000, SO

2 

# 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.



# SO

2 

# 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 SO

2 

# emissions of almost

29 percent, when compared to 1990 levels. Compared to 1999 levels, these units reduced their SO

2 

# emissions by 10 percent or 1.25 million tons, while increasing their utilization by 2.7 percent. Exhibit 3

illustrates the trend in SO

2 

# emissions since 1980 for all affected units.

Exhibit 3

National SO

2 

# Emissions Trend for All Acid Rain Program Affected Units

# Acid Rain Program: Annual Progress Report, 2000 Page 6



# There were 2,262 operating units that underwent annual reconciliation for SO

2 

# in 2000. (These units

are listed on our website at www.epa.gov/airmarkets/cmprpt/arp00/index.html in Appendix A).

The allowances (i.e., authorizations to emit SO

2 

# ) 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 SO

2 

# Allowance Bank: Emissions and Allocations (1995-2000*)

# 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 Number of

Allowances Explanation of Allowance Allocation Type

Initial Allocation 9,166,614 1 

# 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 Credits 416,989 Early Reduction Credit allowances were given to eligible Phase

II units for voluntary emissions reductions made between

January 1, 1995 and January 1, 2000.

Allowances for Substitution Units 10,636 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 250,000 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 97,824 Opt-in Allowances are provided to units entering the program

voluntarily. There were 11 opt-in units in 2000.

Small Diesel Allowances 24,468 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.

TOTAL 2000 ALLOCATION 9,966,531

BANKED ALLOWANCES 11,607,955 Banked Allowances are those held over from 1995 through

1999 which can be used for compliance in 2000 or any future

year.

Conservation and Renewable

Energy Allowances 9,054 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.

TOTAL 2000 ALLOWABLE 21,583,540

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.

# Acid Rain Program: Annual Progress Report, 2000 Page 8

1 

# A source that does not hold enough allowances in its unit account to cover its annual SO

2 

# 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. 

# Exhibit 6

SO

2 

# Allowance Reconciliation Summary

Total Allowances Held in Accounts as of 3/1/2001 (1995 through 2000 Vintages) 1 

# 21,583,540

Unit Accounts 15,753,910

General Accounts 2 

# 5,829,630

Allowances Deducted for Emissions (1995 through 2000) 11,201,999

2001 Penalty Allowances Deducted 54

Banked Allowances 10,381,541

Unit Accounts 4,551,911

General Accounts 2 

# 5,829,630 

# 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. 1 

# Exhibit 6 displays these allowance deductions, as well as the remaining bank of

1995 through 2000 allowances.

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.

# 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 SO

2 

# 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)

# Acid Rain Program: Annual Progress Report, 2000 Page 10



# Several geographic trends are shown:

• The bar graphs illustrate that total SO

2 

# emissions, as well as the greatest reductions, are

largely taking place in the Midwest;

• The states colored yellow represent states with lower SO

2 

# emissions in Phase II (2000),

as compared to both 1990 levels and the 1995-1999 Phase I average. Unlike the SO

2 

# 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 II 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)

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).

# Acid Rain Program: Annual Progress Report, 2000 Page 11



# In 2000, Title IV sources achieved a 29 percent reduction from 1990 SO

2 

# levels nationwide. As

illustrated in Exhibit 8, although most SO

2 

# 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 SO

2 

# emissions in the

country. The highest SO

2 

# 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

2 

# ALLOWANCE MARKET

The flexibility provided by the Acid Rain Program enable the 2,262 units subject to the SO

2 

# requirements in 2000 to pursue a variety of compliance options to meet their SO

2 

# 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 SO

2 

# 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 SO

2 

# . 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 SO

2 

# 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, SO

2 

# 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 II’s 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 mid1994, 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 II

of the program.

# Acid Rain Program: Annual Progress Report, 2000 Page 12



# 0 50 100 150 200 2508/1/942/1/958/1/952/1/968/1/962/1/978/1/972/1/988/1/982/1/998/1/992/1/008/1/00



# Month/YearAllowance Price in dollars 

# Fieldston Publications Price Index Cantor Fitzgerald Market Price Index



# 0 5 10 15 20 25 30 35

1994 1995 1996 1997 1998 1999 2000Allowances Transferred(Millions)



# Between Economically Related Organizations

Between Economically Unrelated Organizations 

# Exhibit 9

SO

2 

# Allowance Price Indices

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 SO

2 

# 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

SO

2 

# Allowances Transferred Under the Acid Rain Program

# 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.



# NO

X 

# PROGRAM COMPLIANCE RESULTS

Instead of using allowance trading to facilitate emissions reductions, the Title IV NO

X 

# program

establishes standard emission limitations for certain affected units. Title IV of the 1990 Clean Air Act

Amendments required EPA to establish NO

X 

# annual average emission limits (in pounds of NO

X 

# per

million British thermal units of fuel consumed (lb/mmBtu)) for coal-fired electric utility units. The

NO

X 

# program was implemented in two phases.

In April 1995, EPA published regulations which established NO

X 

# emission limits beginning on January

1, 1996 for Group 1 boilers that were also part of the Phase I SO

2 

# 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 NO

X 

# emission limit of 0.50 lb/mmBtu and Phase I tangentially-fired

boilers were subject to a NO

X 

# emission limit of 0.45 lb/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 II Group 1 NO

X 

# 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 II 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 NO

X 

# emission limits for Phase II 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, NO

X 

# 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 II) below what the emissions would have been without

the Acid Rain Program.

There were 1,046 units subject to NO

X 

# emissions limitations in 2000. Exhibit 11 shows the number of

NO

X 

# affected units by boiler type.

For each NO

X 

# 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:

# 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 NO

X 

# 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

NO

X 

# control equipment.

Exhibit 12 summarizes the compliance options chosen by NO

X 

# 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 NO

X 

# 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-1: Compliance Results for NO

X 

# Affected Units. For a more detailed

description of EPA's methodology for determining unit compliance with NO

X 

# limits, see Appendix B3: Description of NO

X 

# Compliance Assessment Methodology.)

Exhibit 11

Phase II NO

X 

# Units by Boiler Type

Boiler Type Standard

Emission

Limit Number

of Units

Phase I Group1 Tangentially-fired 0.45 135

Phase I Group1 Dry Bottom Wall-fired 0.50 130

Phase II Group 1 Tangentially-fired 0.40 304

Phase II Group 1 Dry Bottom Wall-fired 0.46 312

Cell Burners 0.68 37

Cyclones > 155 MW 0.86 56

Wet Bottom > 65 MW 0.84 31

Vertically-fired 0.80 41

Total 1,046

# Acid Rain Program: Annual Progress Report, 2000 Page 15



# Only one unit failed to meet its emissions limit in 2000. This unit had NO

X 

# 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 Number of Units

Standard Emission Limitation 133

Early Election 274

Emissions Averaging 645

Alternative Emission Limitation 27

TOTAL 1,079 1

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.



# NO

X 

# 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 NO

X 

# 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 NO

X 

# mass emissions since 1990 for all affected units.

For the 2,262 Phase II units, total NO

X 

# 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 to1999. As illustrated in Exhibit 14, many

states with increasing electrical production have also decreased total NO

X 

# emissions in 2000, as

compared to 1990 levels. Without further reductions in emissions rates, though, NO

X 

# emissions would

be expected to rise with increased utilization.

# Acid Rain Program: Annual Progress Report, 2000 Page 16



# Exhibit 13

NO

X 

# Mass Emissions for Phase II Units

# Acid Rain Program: Annual Progress Report, 2000 Page 17



# Exhibit 14

State-level Electrical Production (Heat Input): 1990, 1999, 2000

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 NO

X 

# 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 NO

X 

# emissions from 1990 levels, with the greatest reduction occurring in the Eastern United States;

# 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)

• The states colored yellow represent states with lower NO

X 

# emissions in Phase II (2000), as

compared to both 1990 levels and the 1996-1999 Phase I average. Like SO

2 

# , during Phase I, the

majority of NO

X 

# 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 NO

X 

# emissions occurred in the Midwestern, MidAtlantic 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)



# SO

2 

# AND NO

X 

# MONITORING IN 2000

In order to verify the reductions of SO

2 

# and NO

X 

# emissions mandated under the Act and to support the

SO

2 

# 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 SO

2 

# and NO

X 

# 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.

SO

2 

# mass emissions are determined using CEMS to measure SO

2 

# concentration and stack flow rate.

NO

X 

# emission rates, on the other hand, are determined with NO

X 

# and diluent gas (CO

2 

# or O

2 

# )

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

SO

2 

# Concentration Volumetric Flow

Rate NO

X 

# Rate

Mean Relative Accuracy 3.65% 3.30% 4.22%

Median Relative Accuracy 2.84% 2.69% 3.36%

Percent Meeting Relative Accuracy

Standard 96.6% 98.6% 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 SO

2 

# mass

emissions and NO

X 

# emission rates are well maintained and fulfilling the high performance standards

required by the Acid Rain Program.

Exhibit 18

2000 CEMS Availability

Parameter Median % Availability at End of 2000

Coal-Fired Units Oil and Gas Units

SO

2 

# 99.5 98.7

Flow 99.6 99.2

NO

X 

# 99.2 98.2

# Acid Rain Program: Annual Progress Report, 2000 Page 21

2 

# For more information on these regional NOx reduction programs, visit http://www.epa.gov/airmarkets. 

# CONCLUSION

Both SO

2 

# and NO

X 

# emissions declined in the first year of Phase II of the Acid

Rain Program. Phase II sources continue to close in on the 10 million ton

reduction of SO

2 

# emissions and exceeded the goal of a two million ton

reduction of NO

X 

# emissions by a sizeable margin.

In 2000, SO

2 

# emissions fell, however the use of allowances saved by sources

from emitting less than required in Phase I resulted in SO

2 

# 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 II sources to continue to

use up the bank of allowances over the next several years, and to achieve the goal of an annual10 million

ton reduction from 1980 levels by 2010.

NO

X 

# 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 NO

X 

# cap-and-trade

programs (i.e., the NO

X 

# Budget Program in the Ozone Transport Region and the NO

X 

# SIP Call 2 

# ) are

changing expectations concerning future emissions levels. EPA’s expectation had been that over time,

NO

X 

# emissions would gradually rise due to increasing electricity production. However, because of the

eastern regional cap, it now appears that nationwide NO

X 

# emissions may decline over the next several

years as the NO

X 

# 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/score00/index.htmlAPPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001AL Barry 3 CS0AAN (1, 2, 3)AL Barry 3 1 3,882 6,490 6,065 425AL Barry 3 2 4,292 6,854 6,406 448AL Barry 3 3 8,811 10,205 9,537 668AL Barry 3 4 10,051 15,429 14,420 1,009AL Barry 3 5 24,836 26,644 24,901 1,743AL Barry 3 6A 0 10 1 9AL Barry 3 6B 0 10 2 8AL Charles R Lowman 56 1 1,853 7,502 3,174 4,328AL Charles R Lowman 56 2 7,026 7,061 6,400 661AL Charles R Lowman 56 3 5,895 7,296 6,635 661AL Chickasaw 5 110 111 111 0 111AL Colbert 47 CSCO14 (1, 2, 3, 4)AL Colbert 47 1 5,854 19,006 6,291 12,715AL Colbert 47 2 6,602 28,600 6,405 22,195AL Colbert 47 3 6,641 29,814 6,379 23,435AL Colbert 47 4 6,646 31,580 6,661 24,919AL Colbert 47 5 16,033 53,216 44,455 8,761AL E C Gaston 26 CS0CAN (1, 2)AL E C Gaston 26 1 7,805 26,699 18,188 8,511AL E C Gaston 26 2 7,996 31,283 18,685 12,598AL E C Gaston 26 CS0CBN (3, 4)AL E C Gaston 26 3 7,896 25,750 20,170 5,580AL E C Gaston 26 4 8,313 37,572 17,904 19,668AL E C Gaston 26 5 25,805 82,427 42,910 39,517AL Gadsden 7 1 1,957 5,385 5,033 352AL Gadsden 7 2 2,024 6,055 4,705 1,350AL General Electric Company 7698 CC1 0 10 2 8AL Gorgas 8 5 1,756 1,756 0 1,756AL Gorgas 8 CS0DAN (6, 7)AL Gorgas 8 6 3,036 12,026 11,146 880AL Gorgas 8 7 3,139 10,082 9,422 660AL Gorgas 8 8 4,759 10,571 9,879 692AL Gorgas 8 9 4,747 9,166 8,638 528AL Gorgas 8 10 22,443 34,062 31,830 2,232AL Greene County 10 1 8,488 24,800 23,619 1,181AL Greene County 10 2 7,923 25,109 23,914 1,195AL Greene County 10 CT2 0 100 41 59AL Greene County 10 CT3 0 100 30 70AL Greene County 10 CT4 0 100 42 58AL Greene County 10 CT5 0 100 50 50AL Greene County 10 CT6 0 100 30 70AL Greene County 10 CT7 0 100 48 52AL Greene County 10 CT8 0 100 21 79A, 1APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001AL Greene County 10 CT9 0 100 47 53AL Greene County 10 CT10 0 100 49 51AL James H Miller Jr 6002 1 14,217 17,558 16,409 1,149AL James H Miller Jr 6002 2 17,769 17,769 16,375 1,394AL James H Miller Jr 6002 3 17,422 17,422 15,460 1,962AL James H Miller Jr 6002 4 8,049 18,134 16,948 1,186AL McIntosh 7063 **1 938 503 0 503AL McIntosh 7063 **2 0 5 0 5AL McIntosh 7063 **3 0 5 1 4AL Mcwilliams 533 **4 0 5 1 4AL Washington County Cogen (Olin) 7697 CC1 0 10 3 7AL Widows Creek 50 CSWC16 (1, 2, 3, 4, 5, 6)AL Widows Creek 50 1 3,340 5,340 4,647 693AL Widows Creek 50 2 3,212 6,212 5,854 358AL Widows Creek 50 3 3,356 5,856 5,278 578AL Widows Creek 50 4 3,454 4,954 4,137 817AL Widows Creek 50 5 3,565 5,065 4,810 255AL Widows Creek 50 6 3,279 6,779 6,576 203AL Widows Creek 50 7 7,805 11,005 10,390 615AL Widows Creek 50 8 7,460 12,460 11,054 1,406AR Carl Bailey 202 01 10 310 263 47AR Cecil Lynch 167 1 0 0 0 0AR Cecil Lynch 167 2 0 1 0 1AR Cecil Lynch 167 3 3 2 0 2AR Flint Creek 6138 1 15,192 15,192 12,863 2,329AR Hamilton Moses 168 1 0 2 0 2AR Hamilton Moses 168 2 0 2 0 2AR Harvey Couch 169 1 7 2 0 2AR Harvey Couch 169 2 112 3 1 2AR Independence 6641 1 18,155 14,574 10,609 3,965AR Independence 6641 2 18,401 17,844 11,252 6,592AR Lake Catherine 170 1 0 2 0 2AR Lake Catherine 170 2 0 2 0 2AR Lake Catherine 170 3 8 4 1 3AR Lake Catherine 170 4 156 6 4 2AR Mcclellan 203 01 15 2,115 1,641 474AR Robert E Ritchie 173 1 53 6 2 4AR Robert E Ritchie 173 2 2,148 2,153 5 2,148AR Thomas Fitzhugh 201 1 1 601 145 456AR White Bluff 6009 1 20,940 22,378 19,679 2,699AR White Bluff 6009 2 23,900 20,640 18,593 2,047AZ Agua Fria 141 1 54 54 18 36AZ Agua Fria 141 2 65 65 22 43AZ Agua Fria 141 3 77 77 33 44A, 2APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001AZ Apache Station 160 1 331 11 1 10AZ Apache Station 160 2 1,609 3,417 3,411 6AZ Apache Station 160 3 3,011 3,223 3,157 66AZ Cholla 113 1 2,223 945 859 86AZ Cholla 113 2 5,443 1,528 1,389 139AZ Cholla 113 3 5,147 9,355 8,378 977AZ Cholla 113 4 8,334 8,334 7,270 1,064AZ Cholla 113 **5 0 0 0 0AZ Coronado 6177 U1B 5,733 10,052 10,051 1AZ Coronado 6177 U2B 5,903 9,409 9,409 0AZ De Moss Petrie 124 4 0 0 0 0AZ Gila Bend 923 **GT1 0 0 0 0AZ Gila Bend 923 **GT2 0 0 0 0AZ Gila Bend 923 **GT3 0 0 0 0AZ Gila Bend 923 **GT4 0 0 0 0AZ Irvington 126 1 16 2 1 1AZ Irvington 126 2 28 3 1 2AZ Irvington 126 3 0 5 1 4AZ Irvington 126 4 2,854 3,816 3,415 401AZ Kyrene 147 K-1 7 46 45 1AZ Kyrene 147 K-2 18 46 46 0AZ Navajo 4941 1 26,220 3,458 1,206 2,252AZ Navajo 4941 2 24,262 3,451 1,687 1,764AZ Navajo 4941 3 25,042 3,451 1,944 1,507AZ Ocotillo 116 1 56 7 5 2AZ Ocotillo 116 2 132 5 1 4AZ Saguaro 118 1 204 161 144 17AZ Saguaro 118 2 25 3 1 2AZ Springerville 8223 1 6,566 10,051 9,036 1,015AZ Springerville 8223 2 5,756 11,048 10,013 1,035AZ Springerville 8223 3 0 0 0 0AZ West Phoenix 117 4 11 0 0 0AZ West Phoenix 117 6 22 0 0 0AZ Yuma Axis 120 1 42 42 12 30CA AES Alamitos, LLC 315 1 2,775 51 0 51CA AES Alamitos, LLC 315 2 105 1 1 0CA AES Alamitos, LLC 315 3 290 3 3 0CA AES Alamitos, LLC 315 4 819 13 4 9CA AES Alamitos, LLC 315 5 4,227 76 6 70CA AES Alamitos, LLC 315 6 1,484 23 5 18CA AES Huntington Beach, LLC 335 1 1,325 26 2 24CA AES Huntington Beach, LLC 335 2 1,134 21 3 18CA AES Huntington Beach, LLC 335 3 161 0 0 0CA AES Huntington Beach, LLC 335 4 176 0 0 0A, 3APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001CA AES Redondo Beach, LLC 356 5 80 2 1 1CA AES Redondo Beach, LLC 356 6 105 2 1 1CA AES Redondo Beach, LLC 356 7 554 11 5 6CA AES Redondo Beach, LLC 356 8 597 13 3 10CA AES Redondo Beach, LLC 356 11 36 0 0 0CA AES Redondo Beach, LLC 356 12 0 0 0 0CA AES Redondo Beach, LLC 356 13 0 0 0 0CA AES Redondo Beach, LLC 356 14 0 0 0 0CA AES Redondo Beach, LLC 356 15 0 0 0 0CA AES Redondo Beach, LLC 356 16 0 0 0 0CA AES Redondo Beach, LLC 356 17 0 0 0 0CA Almond Power Plant 7315 1 0 20 1 19CA Alta (Cool Water) 329 1 10 2 1 1CA Alta (Cool Water) 329 2 6 2 1 1CA Alta (Cool Water) 329 31 0 2 1 1CA Alta (Cool Water) 329 32 0 2 1 1CA Alta (Cool Water) 329 41 0 4 2 2CA Alta (Cool Water) 329 42 0 4 2 2CA Anaheim Combustion Turbine 7693 1 0 0 0 0CA Avon 216 1 17 0 0 0CA Avon 216 2 0 0 0 0CA Avon 216 3 0 0 0 0CA Broadway 420 B1 127 27 0 27CA Broadway 420 B2 164 27 0 27CA Broadway 420 B3 74 26 2 24CA Cabrillo Power I LLC (Encina) 302 CS0001 (1, 2, 3, 4, 5)CA Cabrillo Power I LLC (Encina) 302 1 491 0 0 0CA Cabrillo Power I LLC (Encina) 302 2 1,131 0 0 0CA Cabrillo Power I LLC (Encina) 302 3 737 0 0 0CA Cabrillo Power I LLC (Encina) 302 4 1,946 1 0 1CA Cabrillo Power I LLC (Encina) 302 5 2,495 160 61 99CA Carson Cogeneration 7527 1 0 15 1 14CA Carson Cogeneration 7527 2 0 5 0 5CA Contra Costa 228 1 125 0 0 0CA Contra Costa 228 2 2 0 0 0CA Contra Costa 228 3 0 0 0 0CA Contra Costa 228 4 0 0 0 0CA Contra Costa 228 5 0 0 0 0CA Contra Costa 228 6 0 0 0 0CA Contra Costa 228 7 28 0 0 0CA Contra Costa 228 8 53 0 0 0CA Contra Costa 228 9 356 30 4 26CA Contra Costa 228 10 4,286 4 4 0CA Duke Energy Morro Bay LLC 259 1 1,561 12 2 10A, 4APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001CA Duke Energy Morro Bay LLC 259 2 139 18 3 15CA Duke Energy Morro Bay LLC 259 3 3,822 11 5 6CA Duke Energy Morro Bay LLC 259 4 3,053 26 5 21CA Duke Energy South Bay LLC 310 1 2,492 68 5 63CA Duke Energy South Bay LLC 310 2 1,775 64 2 62CA Duke Energy South Bay LLC 310 3 2,177 16 8 8CA Duke Energy South Bay LLC 310 4 603 59 5 54CA El Centro 389 3 614 514 1 513CA El Centro 389 4 586 586 3 583CA El Centro 389 2-2 0 100 1 99CA El Segundo 330 1 440 12 1 11CA El Segundo 330 2 90 2 1 1CA El Segundo 330 3 182 4 1 3CA El Segundo 330 4 370 7 1 6CA Glenarm 422 16 0 0 0 0CA Glenarm 422 17 0 0 0 0CA Grayson 377 4 102 102 1 101CA Grayson 377 5 36 36 0 36CA Harbor Gen Station 399 1 68 0 0 0CA Harbor Gen Station 399 2 121 0 0 0CA Harbor Gen Station 399 3 94 0 0 0CA Harbor Gen Station 399 4 104 0 0 0CA Harbor Gen Station 399 5 171 0 0 0CA Harbor Gen Station 399 **10A 699 6 1 5CA Harbor Gen Station 399 **10B 699 0 1 -1CA Haynes Gen Station 400 1 681 131 3 128CA Haynes Gen Station 400 2 338 338 2 336CA Haynes Gen Station 400 3 1,244 1,244 1 1,243CA Haynes Gen Station 400 4 1,002 1,002 1 1,001CA Haynes Gen Station 400 5 1,401 1,401 3 1,398CA Haynes Gen Station 400 6 1,527 1,527 1 1,526CA Humboldt Bay 246 1 358 302 1 301CA Humboldt Bay 246 2 24 300 102 198CA Hunters Point 247 3 76 2 0 2CA Hunters Point 247 4 5 2 0 2CA Hunters Point 247 5 74 2 0 2CA Hunters Point 247 6 1 2 0 2CA Hunters Point 247 7 192 35 1 34CA Kern 251 1 3 0 0 0CA Kern 251 2 0 0 0 0CA Kern 251 3 13 0 0 0CA Kern 251 4 0 0 0 0CA Magnolia 375 M4 37 0 0 0CA Martinez 256 1 1 0 0 0A, 5APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001CA Martinez 256 2 1 0 0 0CA Martinez 256 3 1 0 0 0CA Moss Landing 260 1 122 1 0 1CA Moss Landing 260 2 0 0 0 0CA Moss Landing 260 3 0 0 0 0CA Moss Landing 260 4 0 0 0 0CA Moss Landing 260 5 0 0 0 0CA Moss Landing 260 6 0 0 0 0CA Moss Landing 260 7 79 0 0 0CA Moss Landing 260 8 466 4 0 4CA Moss Landing 260 6-1 8,924 40 9 31CA Moss Landing 260 7-1 976 31 14 17CA Mountain Vista (Etiwanda) 331 1 117 3 1 2CA Mountain Vista (Etiwanda) 331 2 29 2 1 1CA Mountain Vista (Etiwanda) 331 3 1,372 19 3 16CA Mountain Vista (Etiwanda) 331 4 261 6 4 2CA Mountainview (San Bernadino) 358 1 118 3 0 3CA Mountainview (San Bernadino) 358 2 17 0 0 0CA NCPA Combustion Turbine Project #2 7449 NA1 0 25 1 24CA Ocean Vista (Mandalay) 345 1 1,379 24 4 20CA Ocean Vista (Mandalay) 345 2 1,291 21 4 17CA Oleum 263 1 146 0 0 0CA Oleum 263 2 138 0 0 0CA Oleum 263 3 244 4 0 4CA Oleum 263 4 102 0 0 0CA Oleum 263 5 174 2 0 2CA Oleum 263 6 204 2 0 2CA Olive 6013 01 133 15 0 15CA Olive 6013 02 25 0 0 0CA Ormond Beach 350 1 4,520 77 4 73CA Ormond Beach 350 2 4,586 81 8 73CA Pittsburg 271 1 1,641 1 1 0CA Pittsburg 271 2 1,350 2 1 1CA Pittsburg 271 3 1,586 1 1 0CA Pittsburg 271 4 1,581 2 1 1CA Pittsburg 271 5 285 12 4 8CA Pittsburg 271 6 3,754 4 3 1CA Pittsburg 271 7 740 30 10 20CA Potrero 273 3-1 321 25 3 22CA Riverside Canal (Highgrove) 334 1 4 4 0 4CA Riverside Canal (Highgrove) 334 2 1 1 0 1CA Riverside Canal (Highgrove) 334 3 1 2 0 2CA Riverside Canal (Highgrove) 334 4 3 3 0 3CA Sacramento Power Authority Cogen 7552 1 0 10 3 7A, 6APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001CA SCA Cogen II 7551 1A 0 5 1 4CA SCA Cogen II 7551 1B 0 5 1 4CA Scattergood Gen Sta 404 1 752 418 1 417CA Scattergood Gen Sta 404 2 658 658 11 647CA Scattergood Gen Sta 404 3 262 262 4 258CA Silver Gate 309 1 0 0 0 0CA Silver Gate 309 2 0 0 0 0CA Silver Gate 309 3 0 0 0 0CA Silver Gate 309 4 0 0 0 0CA Silver Gate 309 5 0 0 0 0CA Silver Gate 309 6 0 0 0 0CA Valley Gen Station 408 1 122 631 0 631CA Valley Gen Station 408 2 141 141 0 141CA Valley Gen Station 408 3 389 389 0 389CA Valley Gen Station 408 4 351 351 0 351CA Woodland Generation Station 7266 1 0 20 1 19CO Arapahoe 465 CS1 (1, 2)CO Arapahoe 465 1 221 904 840 64CO Arapahoe 465 2 247 598 583 15CO Arapahoe 465 3 181 1,084 1,079 5CO Arapahoe 465 4 1,927 1,816 1,665 151CO Arapahoe Combustion Turbines 55200 CT5 0 0 0 0CO Arapahoe Combustion Turbines 55200 CT6 0 0 0 0CO Brush 4 55209 GT4 0 0 0 0CO Brush 4 55209 GT5 0 0 0 0CO Cameo 468 2 904 2,295 2,288 7CO Cherokee 469 1 2,138 2,631 2,622 9CO Cherokee 469 2 2,838 4,571 4,561 10CO Cherokee 469 3 3,761 5,053 5,013 40CO Cherokee 469 4 7,535 6,965 6,949 16CO Comanche 470 1 7,698 5,980 5,956 24CO Comanche 470 2 6,914 8,415 8,405 10CO Craig 6021 C1 8,218 6,812 4,204 2,608CO Craig 6021 C2 7,845 6,994 4,059 2,935CO Craig 6021 C3 2,602 2,602 1,802 800CO Fort St. Vrain 6112 2 0 5 3 2CO Fort St. Vrain 6112 3 0 5 4 1CO Hayden 525 H1 6,063 2,096 695 1,401CO Hayden 525 H2 9,230 2,895 1,603 1,292CO Manchief Electric Gen Station 55127 CT1 0 1 0 1CO Manchief Electric Gen Station 55127 CT2 0 1 0 1CO Martin Drake 492 5 1,149 1,399 1,344 55CO Martin Drake 492 6 2,030 2,380 2,330 50CO Martin Drake 492 7 3,219 4,894 4,643 251A, 7APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001CO Nucla 527 1 1,122 1,522 1,273 249CO Pawnee 6248 1 14,443 14,745 14,678 67CO Pawnee 6248 **2 0 0 0 0CO Rawhide 6761 101 1,800 1,160 849 311CO Ray D Nixon 8219 1 4,477 5,500 5,220 280CO Ray D Nixon 8219 2 0 1 0 1CO Ray D Nixon 8219 3 0 1 0 1CO Valmont 477 5 3,137 4,716 4,506 210CO Valmont 477 14 4 0 0 0CO Valmont 477 21 20 0 0 0CO Valmont 477 24 0 0 0 0CO Valmont Combustion Turbine 55207 CT7 0 0 0 0CO Zuni 478 1 340 3 1 2CO Zuni 478 2 0 2 0 2CO Zuni 478 3 5 3 0 3CT Bridgeport Energy 55042 BE1 0 10 2 8CT Bridgeport Energy 55042 BE2 0 10 2 8CT Bridgeport Harbor 568 BHB1 2,079 1 0 1CT Bridgeport Harbor 568 BHB2 4,727 530 474 56CT Bridgeport Harbor 568 BHB3 11,481 9,226 8,747 479CT Devon 544 3 980 940 0 940CT Devon 544 6 898 863 0 863CT Devon 544 CS0001 (7, 8)CT Devon 544 7 2,808 2,699 1,141 1,558CT Devon 544 8 3,003 2,886 1,434 1,452CT Devon 544 11 0 0 0 0CT Devon 544 12 0 1 1 0CT Devon 544 13 0 1 1 0CT Devon 544 14 0 0 0 0CT Devon 544 4A 170 164 0 164CT Devon 544 4B 171 164 0 164CT Devon 544 5A 155 149 0 149CT Devon 544 5B 155 149 0 149CT English 569 EB13 114 114 0 114CT English 569 EB14 157 157 0 157CT Mid-Conn/S. Meadow 563 15 0 0 0 0CT Middletown 562 1 461 442 0 442CT Middletown 562 2 1,328 996 628 368CT Middletown 562 3 3,339 3,209 1,197 2,012CT Middletown 562 4 2,390 2,576 2,572 4CT Montville 546 5 1,208 1,311 1,293 18CT Montville 546 6 5,675 5,304 3,412 1,892CT New Haven Harbor 6156 NHB1 13,070 9,292 9,256 36CT Norwalk Harbor 548 CS0001 (1, 2)A, 8APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001CT Norwalk Harbor 548 1 5,141 4,941 3,379 1,562CT Norwalk Harbor 548 2 5,458 5,245 3,380 1,865DC Benning 603 15 517 517 391 126DC Benning 603 16 856 856 567 289DE Delaware City Refinery (Motiva) 52193 DCPP4 0 1,300 1,198 102DE Edge Moor 593 3 3,558 19,678 3,290 16,388DE Edge Moor 593 4 6,295 6,295 5,985 310DE Edge Moor 593 5 6,463 6,463 1,698 4,765DE Hay Road 7153 **3 158 158 1 157DE Indian River 594 1 2,998 5,998 5,679 319DE Indian River 594 2 3,182 6,132 5,741 391DE Indian River 594 3 5,441 7,870 7,409 461DE Indian River 594 4 13,414 8,914 8,399 515DE McKee Run 599 3 2,585 1,085 563 522DE Van Sant 7318 **11 138 138 5 133FL Anclote 8048 1 13,890 16,000 14,657 1,343FL Anclote 8048 2 13,895 12,500 11,425 1,075FL Arvah B Hopkins 688 1 81 101 85 16FL Arvah B Hopkins 688 2 5,524 5,504 778 4,726FL Auburndale Power Partners, LP 54658 1 0 2 2 0FL Avon Park 624 2 495 0 0 0FL Big Bend 645 XS12 (BB01, BB02)FL Big Bend 645 BB01 12,136 25,931 24,545 1,386FL Big Bend 645 BB02 12,200 7,799 6,782 1,017FL Big Bend 645 XS23 (BB03, BB04)FL Big Bend 645 BB03 11,448 13,501 12,808 693FL Big Bend 645 BB04 8,783 4,997 3,962 1,035FL C D Mcintosh Jr 676 1 907 1,131 1,114 17FL C D Mcintosh Jr 676 2 1,029 1,029 140 889FL C D Mcintosh Jr 676 3 9,931 9,931 8,423 1,508FL C D Mcintosh Jr 676 5 0 2 0 2FL Cane Island 7238 2 0 26 2 24FL Cane Island 7238 **1 0 10 0 10FL Cape Canaveral 609 PCC1 4,225 7,812 7,419 393FL Cape Canaveral 609 PCC2 4,963 5,814 5,521 293FL Combined Cycle 1 7254 32432 60 60 1 59FL Crist 641 CS001(1, 2, 3)FL Crist 641 1 35 35 1 34FL Crist 641 2 3 3 0 3FL Crist 641 3 4 4 0 4FL Crist 641 4 2,468 36,724 3,651 33,073FL Crist 641 5 2,431 33,047 5,949 27,098FL Crist 641 6 8,399 37,497 13,679 23,818FL Crist 641 7 12,526 53,830 29,803 24,027A, 9APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001FL Crystal River 628 1 12,429 19,500 18,362 1,138FL Crystal River 628 2 14,295 20,000 18,982 1,018FL Crystal River 628 4 23,659 27,500 26,301 1,199FL Crystal River 628 5 25,257 30,000 28,566 1,434FL Cutler 610 PCU5 0 5 1 4FL Cutler 610 PCU6 0 5 1 4FL Debary 6046 **7 705 55 49 6FL Debary 6046 **8 705 60 51 9FL Debary 6046 **9 705 45 39 6FL Debary 6046 **10 705 135 112 23FL Deerhaven 663 B1 98 502 500 2FL Deerhaven 663 B2 8,271 7,918 7,915 3FL Deerhaven 663 CT3 0 3 1 2FL Deerhaven 663 **NA2 0 0 0 0FL F J Gannon 646 GB01 3,843 7,843 6,898 945FL F J Gannon 646 GB02 4,426 6,426 5,906 520FL F J Gannon 646 GB03 5,666 7,666 7,349 317FL F J Gannon 646 GB04 6,225 8,125 7,831 294FL F J Gannon 646 GB05 6,539 11,539 10,776 763FL F J Gannon 646 GB06 10,084 10,084 9,310 774FL Fort Myers 612 PFM1 3,189 4,373 4,153 220FL Fort Myers 612 PFM2 9,460 15,233 14,465 768FL Fort Myers 612 FMCT2A 0 4 0 4FL Fort Myers 612 FMCT2B 0 4 0 4FL G E Turner 629 2 543 0 0 0FL G E Turner 629 3 718 0 0 0FL G E Turner 629 4 611 0 0 0FL Hardee Power Station 50949 CT2B 0 50 6 44FL Henry D King 658 7 63 63 0 63FL Henry D King 658 8 26 26 0 26FL Higgins 630 1 423 0 0 0FL Higgins 630 2 475 0 0 0FL Higgins 630 3 969 0 0 0FL Hines Facility 7302 1A 0 8 3 5FL Hines Facility 7302 1B 0 8 3 5FL Hookers Point 647 CS001 (HB01, HB02, HB05)FL Hookers Point 647 HB01 177 177 0 177FL Hookers Point 647 HB02 207 207 207 0FL Hookers Point 647 CS002 (HB03, HB04)FL Hookers Point 647 HB03 469 408 203 205FL Hookers Point 647 HB04 701 401 273 128FL Hookers Point 647 HB05 1,253 553 336 217FL Hookers Point 647 HB06 478 478 300 178FL Indian River 55318 CS1 (1, 2)A, 10APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001FL Indian River 55318 1 1,192 403 398 5FL Indian River 55318 2 1,569 2,166 2,161 5FL Indian River 55318 3 3,647 3,728 3,723 5FL Indian River 683 **C 0 1 0 1FL Indian River 683 **D 639 6 2 4FL Intercession City 8049 **7 705 35 23 12FL Intercession City 8049 **8 705 35 22 13FL Intercession City 8049 **9 705 25 12 13FL Intercession City 8049 **10 705 30 18 12FL Intercession City 8049 **11 0 125 99 26FL J D Kennedy 666 7 0 20 7 13FL J D Kennedy 666 8 196 0 0 0FL J D Kennedy 666 9 553 0 0 0FL J D Kennedy 666 10 1,976 20 2 18FL J R Kelly 664 JRK8 58 29 29 0FL Lansing Smith 643 1 6,478 12,673 9,200 3,473FL Lansing Smith 643 2 7,603 13,614 11,527 2,087FL Larsen Memorial 675 7 307 558 552 6FL Larsen Memorial 675 **8 665 188 2 186FL Larsen Memorial 675 **9 0 0 0 0FL Lauderdale 613 4GT1 948 8 4 4FL Lauderdale 613 4GT2 948 8 4 4FL Lauderdale 613 5GT1 948 8 4 4FL Lauderdale 613 5GT2 948 8 4 4FL Lauderdale 613 PFL4 0 0 0 0FL Lauderdale 613 PFL5 0 0 0 0FL Manatee 6042 PMT1 13,777 14,654 13,915 739FL Manatee 6042 PMT2 12,701 15,790 14,995 795FL Martin 6043 PMR1 5,094 8,779 8,336 443FL Martin 6043 PMR2 6,041 7,942 7,542 400FL Martin 6043 HRSG3A 1,275 8 4 4FL Martin 6043 HRSG3B 1,275 8 4 4FL Martin 6043 HRSG4A 1,275 8 4 4FL Martin 6043 HRSG4B 1,275 9 4 5FL Mulberry Cogeneration Facility 54426 1 0 4 1 3FL Northside 667 1 6,224 10,356 7,286 3,070FL Northside 667 2 6,268 0 0 0FL Northside 667 3 11,126 10,889 8,014 2,875FL Orange Cogeneration Facility 54365 1 0 2 0 2FL Orange Cogeneration Facility 54365 2 0 2 0 2FL Orlando CoGen 54466 1 0 4 2 2FL P L Bartow 634 1 2,806 6,000 5,110 890FL P L Bartow 634 2 2,962 6,000 5,230 770FL P L Bartow 634 3 5,430 11,000 9,951 1,049A, 11APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001FL Polk 7242 **1 0 1,011 918 93FL Polk 7242 **2 0 550 409 141FL Polk 7242 **3 0 0 0 0FL Polk 7242 **4 0 0 0 0FL Port Everglades 617 PPE1 2,340 3,102 2,946 156FL Port Everglades 617 PPE2 2,414 4,066 3,861 205FL Port Everglades 617 PPE3 5,882 7,785 7,392 393FL Port Everglades 617 PPE4 5,964 7,107 6,748 359FL Putnam 6246 HRSG11 1,644 6 2 4FL Putnam 6246 HRSG12 1,644 7 2 5FL Putnam 6246 HRSG21 1,568 6 1 5FL Putnam 6246 HRSG22 1,568 7 2 5FL Riviera 619 PRV2 94 0 0 0FL Riviera 619 PRV3 3,574 7,934 7,542 392FL Riviera 619 PRV4 3,546 9,697 9,228 469FL S O Purdom 689 7 443 433 96 337FL S O Purdom 689 8 0 10 1 9FL Sanford 620 PSN3 1,085 2,278 2,166 112FL Sanford 620 PSN4 8,615 8,682 8,245 437FL Sanford 620 PSN5 3,222 8,852 8,421 431FL Scholz 642 1 1,959 27,638 1,601 26,037FL Scholz 642 2 2,051 26,431 1,417 25,014FL Seminole 136 1 18,388 18,388 14,832 3,556FL Seminole 136 2 18,388 18,388 17,909 479FL Southside 668 1 930 0 0 0FL Southside 668 2 963 0 0 0FL Southside 668 3 227 0 0 0FL Southside 668 4 616 1,416 958 458FL Southside 668 5 1,811 2,082 1,278 804FL St Johns River Power 207 1 11,586 14,472 11,019 3,453FL St Johns River Power 207 2 11,374 13,420 10,295 3,125FL Stanton Energy 564 1 11,294 6,910 6,570 340FL Stanton Energy 564 2 0 3,253 3,099 154FL Stock Island 6584 1 2,572 1 0 1FL Suwannee River 638 1 254 1,600 1,353 247FL Suwannee River 638 2 253 1,500 1,271 229FL Suwannee River 638 3 649 1,700 1,492 208FL Tiger Bay 7699 1 0 8 3 5FL Tom G Smith 673 S-3 9 89 62 27FL Tom G Smith 673 S-4 80 0 0 0FL Turkey Point 621 PTP1 5,870 5,803 5,510 293FL Turkey Point 621 PTP2 5,913 5,858 5,561 297FL University of Florida 7345 1 0 5 1 4FL Vero Beach Municipal 693 3 315 315 2 313A, 12APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001FL Vero Beach Municipal 693 4 107 107 5 102FL Vero Beach Municipal 693 **5 317 317 1 316GA Arkwright 699 CS001 (1, 2, 3, 4)GA Arkwright 699 1 1,449 5,811 1,236 4,575GA Arkwright 699 2 1,470 5,242 1,237 4,005GA Arkwright 699 3 1,539 10,423 1,237 9,186GA Arkwright 699 4 1,255 7,785 1,237 6,548GA Atkinson 700 A2 4 4 0 4GA Atkinson 700 A3 6 6 0 6GA Atkinson 700 A4 5 5 0 5GA Atkinson 700 A1A 2 2 0 2GA Atkinson 700 A1B 2 2 0 2GA Baconton 55304 CT1 0 3 0 3GA Baconton 55304 CT4 0 3 0 3GA Baconton 55304 CT5 0 3 0 3GA Baconton 55304 CT6 0 3 0 3GA Bowen 703 1BLR 23,617 46,592 28,958 17,634GA Bowen 703 2BLR 24,288 35,414 35,098 316GA Bowen 703 3BLR 30,942 117,749 41,479 76,270GA Bowen 703 4BLR 30,934 98,345 49,839 48,506GA Doyle Generating Facility 55244 CTG-1 0 1 0 1GA Doyle Generating Facility 55244 CTG-2 0 1 0 1GA Doyle Generating Facility 55244 CTG-3 0 1 0 1GA Doyle Generating Facility 55244 CTG-4 0 1 0 1GA Doyle Generating Facility 55244 CTG-5 0 1 0 1GA Hammond 708 CS001 (1, 2, 3)GA Hammond 708 1 3,786 19,834 3,847 15,987GA Hammond 708 2 3,975 21,306 3,847 17,459GA Hammond 708 3 3,842 20,272 3,847 16,425GA Hammond 708 4 16,232 101,111 16,742 84,369GA Harllee Branch 709 CS001 (1, 2)GA Harllee Branch 709 1 9,859 33,349 11,601 21,748GA Harllee Branch 709 2 11,661 52,722 11,601 41,121GA Harllee Branch 709 CS002 (3, 4)GA Harllee Branch 709 3 16,044 46,490 23,182 23,308GA Harllee Branch 709 4 15,921 45,176 23,182 21,994GA Hartwell Energy Facility 70454 MAG1 0 2 1 1GA Hartwell Energy Facility 70454 MAG2 0 4 3 1GA Jack Mcdonough 710 CS001 (MB1, MB2)GA Jack Mcdonough 710 MB1 8,584 45,622 14,121 31,501GA Jack Mcdonough 710 MB2 8,885 48,611 14,121 34,490GA Jackson County Combustion Turbine 7765 1 0 5 0 5GA Jackson County Combustion Turbine 7765 2 0 5 1 4GA Jackson County Combustion Turbine 7765 3 0 5 1 4A, 13APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001GA Jackson County Combustion Turbine 7765 4 0 5 1 4GA Jackson County Combustion Turbine 7765 5 0 5 1 4GA Jackson County Combustion Turbine 7765 6 0 5 1 4GA Jackson County Combustion Turbine 7765 7 0 5 0 5GA Jackson County Combustion Turbine 7765 8 0 5 1 4GA Kraft 733 CS001 (1, 2, 3, 4)GA Kraft 733 1 1,530 3,936 2,238 1,698GA Kraft 733 2 1,510 3,513 1,791 1,722GA Kraft 733 3 2,964 5,591 4,417 1,174GA Kraft 733 4 436 4 0 4GA McIntosh 6124 1 5,556 14,001 7,830 6,171GA McIntosh 6124 CT1 0 54 10 44GA McIntosh 6124 CT2 0 54 9 45GA McIntosh 6124 CT3 0 54 5 49GA McIntosh 6124 CT4 0 54 6 48GA McIntosh 6124 CT5 0 54 8 46GA McIntosh 6124 CT6 0 54 7 47GA McIntosh 6124 CT7 0 54 7 47GA McIntosh 6124 CT8 0 54 6 48GA Mcmanus 715 CS001 (1, 2)GA Mcmanus 715 1 844 2,678 2,678 0GA Mcmanus 715 2 1,279 2,661 2,660 1GA Mid-Georgia Cogeneration 55040 1 0 25 20 5GA Mid-Georgia Cogeneration 55040 2 0 25 19 6GA Mitchell 727 3 5,463 35,688 4,929 30,759GA Monroe Power Plant 7764 1 0 10 5 5GA Riverside 734 12 5 5 0 5GA Robins 7348 CT1 0 30 29 1GA Robins 7348 CT2 0 20 17 3GA Scherer 6257 1 21,083 53,599 27,591 26,008GA Scherer 6257 2 21,232 44,705 25,697 19,008GA Scherer 6257 3 21,266 15,767 15,594 173GA Scherer 6257 4 21,242 22,412 22,404 8GA Sewell Creek Energy (Smarr 2) 7813 1 0 5 0 5GA Sewell Creek Energy (Smarr 2) 7813 2 0 5 0 5GA Sewell Creek Energy (Smarr 2) 7813 3 0 5 0 5GA Sewell Creek Energy (Smarr 2) 7813 4 0 5 0 5GA Smarr Energy Facility 7829 1 0 5 0 5GA Smarr Energy Facility 7829 2 0 5 0 5GA Sowega Power Project 7768 CT2 0 0 0 0GA Sowega Power Project 7768 CT3 0 0 0 0GA Wansley 6052 1 30,517 108,924 37,070 71,854GA Wansley 6052 2 28,211 102,622 32,148 70,474GA West Georgia Generating Co, LP 55267 1 0 12 9 3A, 14APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001GA West Georgia Generating Co, LP 55267 2 0 3 1 2GA West Georgia Generating Co, LP 55267 3 0 12 9 3GA West Georgia Generating Co, LP 55267 4 0 7 5 2GA Yates 728 Y1BR 3,107 35,148 301 34,847GA Yates 728 CS001 (Y2BR, Y3BR)GA Yates 728 Y2BR 3,036 20,222 3,342 16,880GA Yates 728 Y3BR 2,998 19,832 3,343 16,489GA Yates 728 CS002 (Y4BR, Y5BR)GA Yates 728 Y4BR 3,843 25,223 4,145 21,078GA Yates 728 Y5BR 4,056 27,381 4,145 23,236GA Yates 728 Y6BR 10,678 77,524 16,277 61,247GA Yates 728 Y7BR 10,502 61,863 13,551 48,312IA Ames1122 7 403 403 317 86IA Ames1122 8 1,834 1,316 656 660IA Burlington (IA) 1104 1 4,499 22,314 6,374 15,940IA Council Bluffs 1082 1 1,110 1,310 1,221 89IA Council Bluffs 1082 2 1,651 1,951 1,898 53IA Council Bluffs 1082 3 15,956 18,153 17,718 435IA Des Moines 1083 10 163 1 0 1IA Des Moines 1083 11 244 2 0 2IA Des Moines 1083 **5 0 0 0 0IA Dubuque 1046 1 1,120 2,199 2,189 10IA Dubuque 1046 5 305 1,454 1,444 10IA Dubuque 1046 6 0 2 1 1IA Earl F Wisdom 1217 1 379 1,229 1,192 37IA Fair Station 1218 2 5,575 6,315 6,216 99IA George Neal North 1091 1 2,310 3,864 3,431 433IA George Neal North 1091 2 9,082 6,482 6,187 295IA George Neal North 1091 3 12,296 11,396 11,071 325IA George Neal South 7343 4 15,144 15,940 14,973 967IA Grinnell 7137 **2 189 0 0 0IA Lansing 1047 CS1 (1, 2)IA Lansing 1047 1 0 35 27 8IA Lansing 1047 2 0 295 283 12IA Lansing 1047 3 478 948 933 15IA Lansing 1047 4 4,629 5,712 5,701 11IA Lime Creek 7155 **1 255 255 12 243IA Lime Creek 7155 **2 255 255 11 244IA Louisa 6664 101 15,593 15,181 14,779 402IA Maynard Station 1096 1 31 0 0 0IA Milton L Kapp 1048 2 5,795 38,797 4,922 33,875IA Muscatine 1167 8 1,362 2,990 2,511 479IA Muscatine 1167 9 2,027 2,027 646 1,381IA Na 1 -- 7230 7230 **2 0 0 0 0A, 15APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001IA Ottumwa 6254 1 19,095 19,095 18,415 680IA Pella 1175 CS67 (6, 7)IA Pella 1175 6 757 757 269 488IA Pella 1175 7 978 978 269 709IA Pella 1175 8 68 68 0 68IA Pleasant Hill Energy Center 7145 3 0 31 2 29IA Prairie Creek 1073 3 725 1,000 987 13IA Prairie Creek 1073 4 3,434 21,429 3,079 18,350IA Riverside 1081 9 1,745 3,198 2,507 691IA Sixth Street 1058 1 814 7 0 7IA Sixth Street 1058 2 177 322 313 9IA Sixth Street 1058 3 154 309 296 13IA Sixth Street 1058 4 77 309 229 80IA Sixth Street 1058 5 308 1,008 991 17IA Streeter Station 1131 7 554 754 524 230IA Sutherland 1077 1 199 899 893 6IA Sutherland 1077 2 376 696 667 29IA Sutherland 1077 3 2,191 3,191 3,113 78ID Rathdrum Combustion Turbine Project 7456 1 0 2 1 1ID Rathdrum Combustion Turbine Project 7456 2 0 2 1 1IL Baldwin 889 1 18,116 8,440 8,240 200IL Baldwin 889 2 19,154 5,533 5,333 200IL Baldwin 889 3 18,350 24,015 23,026 989IL Coffeen 861 CS0001 (01, 02)IL Coffeen 861 01 5,085 15,183 14,588 595IL Coffeen 861 02 15,381 25,056 24,501 555IL Collins 6025 CS1230 (1, 2, 3)IL Collins 6025 1 1,327 579 278 301IL Collins 6025 2 1,133 579 279 300IL Collins 6025 3 2,001 578 279 299IL Collins 6025 CS0405 (4, 5)IL Collins 6025 4 1,633 519 218 301IL Collins 6025 5 1,810 518 219 299IL Crawford 867 7 7,236 4,291 3,991 300IL Crawford 867 8 9,850 5,641 5,341 300IL Dallman 963 CS3132 (31, 32)IL Dallman 963 31 1,385 11,242 10,308 934IL Dallman 963 32 1,568 11,899 10,728 1,171IL Dallman 963 33 5,199 1,757 1,391 366IL Duck Creek 6016 1 11,201 11,201 11,115 86IL E D Edwards 856 1 2,899 16,766 16,435 331IL E D Edwards 856 2 6,916 18,066 16,964 1,102IL E D Edwards 856 3 9,125 23,935 23,410 525IL Elwood Energy Facility 55199 1 0 25 0 25A, 16APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001IL Elwood Energy Facility 55199 2 0 25 0 25IL Elwood Energy Facility 55199 3 0 25 0 25IL Elwood Energy Facility 55199 4 0 25 0 25IL Fisk 886 19 10,032 5,148 4,848 300IL Freedom Power Project 7842 CT1 0 0 0 0IL Gibson City Power Plant 55201 GCTG1 0 5 0 5IL Gibson City Power Plant 55201 GCTG2 0 5 1 4IL Grand Tower 862 07 248 3,483 3,017 466IL Grand Tower 862 08 235 3,279 2,802 477IL Grand Tower 862 09 2,547 8,621 7,955 666IL Havana 891 1 35 82 68 14IL Havana 891 2 45 76 67 9IL Havana 891 3 35 66 55 11IL Havana 891 4 35 95 87 8IL Havana 891 5 35 71 61 10IL Havana 891 6 35 16 7 9IL Havana 891 7 35 35 28 7IL Havana 891 8 35 25 18 7IL Havana 891 9 8,805 11,518 10,586 932IL Hennepin 892 CS3 (1, 2)IL Hennepin 892 1 2,018 1,404 1,204 200IL Hennepin 892 2 7,940 5,030 4,528 502IL Hutsonville 863 05 2,591 6,913 6,301 612IL Hutsonville 863 06 3,238 8,163 7,527 636IL Indeck-Rockford Energy Center 55238 0001 0 25 0 25IL Indeck-Rockford Energy Center 55238 0002 0 25 0 25IL Interstate 7425 1 0 5 1 4IL Joliet 29 384 CS7172 (71, 72)IL Joliet 29 384 71 7,580 4,580 4,334 246IL Joliet 29 384 72 6,177 4,634 4,335 299IL Joliet 29 384 CS8182 (81, 82)IL Joliet 29 384 81 7,296 5,296 5,258 38IL Joliet 29 384 82 7,558 5,559 5,259 300IL Joliet 9 874 5 8,676 4,508 4,309 199IL Joppa Steam 887 CS1 (1, 2)IL Joppa Steam 887 1 5,288 46,424 6,540 39,884IL Joppa Steam 887 2 4,523 36,807 1,229 35,578IL Joppa Steam 887 CS2 (3, 4)IL Joppa Steam 887 3 5,153 45,063 5,017 40,046IL Joppa Steam 887 4 4,773 40,253 2,359 37,894IL Joppa Steam 887 CS3 (5, 6)IL Joppa Steam 887 5 4,795 37,849 5,313 32,536IL Joppa Steam 887 6 4,460 33,623 2,980 30,643IL Kincaid 876 CS0102 (1, 2)A, 17APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001IL Kincaid 876 1 13,596 8,512 8,487 25IL Kincaid 876 2 14,982 9,987 9,962 25IL Lakeside 964 CS0078 (7, 8)IL Lakeside 964 7 2,554 2,537 2,131 406IL Lakeside 964 8 1,446 1,437 1,198 239IL Lincoln Generating Facility LLC 55222 CTG-1 0 2 0 2IL Lincoln Generating Facility LLC 55222 CTG-2 0 2 0 2IL Lincoln Generating Facility LLC 55222 CTG-3 0 2 0 2IL Lincoln Generating Facility LLC 55222 CTG-4 0 2 0 2IL Lincoln Generating Facility LLC 55222 CTG-5 0 2 0 2IL Lincoln Generating Facility LLC 55222 CTG-6 0 2 0 2IL Lincoln Generating Facility LLC 55222 CTG-7 0 2 0 2IL Lincoln Generating Facility LLC 55222 CTG-8 0 2 0 2IL Marion 976 CS0001 (1, 2)IL Marion 976 1 2,080 5,480 3,032 2,448IL Marion 976 2 2,130 3,951 3,032 919IL Marion 976 3 2,310 7,310 4,417 2,893IL Marion 976 4 6,841 11,570 3,151 8,419IL MEPI GT Facility 7858 1 0 5 0 5IL MEPI GT Facility 7858 2 0 5 0 5IL MEPI GT Facility 7858 3 0 5 0 5IL MEPI GT Facility 7858 4 0 5 0 5IL MEPI GT Facility 7858 5 0 5 0 5IL Meredosia 864 CS0001 (01, 02, 03, 04)IL Meredosia 864 01 298 2,682 2,230 452IL Meredosia 864 02 322 3,130 2,470 660IL Meredosia 864 03 280 2,942 2,426 516IL Meredosia 864 04 255 3,571 3,100 471IL Meredosia 864 05 5,991 12,382 11,959 423IL Meredosia 864 06 46 679 327 352IL Newton 6017 1 16,185 8,065 7,371 694IL Newton 6017 2 13,932 9,056 8,587 469IL Pinckneyville Power Plant 55202 CT01 0 0 0 0IL Pinckneyville Power Plant 55202 CT02 0 0 0 0IL Pinckneyville Power Plant 55202 CT03 0 0 0 0IL Pinckneyville Power Plant 55202 CT04 0 0 0 0IL Powerton 879 CS0506 (51, 52, 61, 62)IL Powerton 879 51 10,704 5,993 5,693 300IL Powerton 879 52 10,574 5,993 5,693 300IL Powerton 879 61 10,516 5,993 5,693 300IL Powerton 879 62 10,599 5,822 5,693 129IL R S Wallace 859 9 901 0 0 0IL R S Wallace 859 10 2,432 0 0 0IL Rocky Road Power, LLC 55109 T1 0 0 0 0A, 18APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001IL Rocky Road Power, LLC 55109 T2 0 0 0 0IL Rocky Road Power, LLC 55109 T3 0 0 0 0IL Rocky Road Power, LLC 55109 T4 0 0 0 0IL Shelby Energy Center 55237 CP1 (SCE1, SCE2, SCE3, SCE4, SCE5, SCE6)IL Shelby Energy Center 55237 SCE1 0 0 0 0IL Shelby Energy Center 55237 SCE2 0 0 0 0IL Shelby Energy Center 55237 SCE3 0 0 0 0IL Shelby Energy Center 55237 SCE4 0 0 0 0IL Shelby Energy Center 55237 SCE5 0 0 0 0IL Shelby Energy Center 55237 SCE6 0 0 0 0IL Tilton 7760 1 0 0 0 0IL Tilton 7760 2 0 0 0 0IL Tilton 7760 3 0 0 0 0IL Tilton 7760 4 0 0 0 0IL Venice 913 1 5 5 0 5IL Venice 913 2 2 2 0 2IL Venice 913 3 17 7 0 7IL Venice 913 4 14 4 0 4IL Venice 913 5 10 10 1 9IL Venice 913 6 10 10 1 9IL Venice 913 7 2 12 2 10IL Venice 913 8 2 12 3 9IL Vermilion 897 CS3 (1, 2)IL Vermilion 897 1 2,835 6,167 5,720 447IL Vermilion 897 2 3,831 7,712 7,281 431IL Waukegan 883 7 8,214 7,161 6,886 275IL Waukegan 883 8 7,840 8,881 8,544 337IL Waukegan 883 17 3,104 2,328 2,220 108IL Will County 884 1 5,322 2,492 2,309 183IL Will County 884 2 4,850 2,648 2,348 300IL Will County 884 3 6,995 5,247 5,092 155IL Will County 884 4 13,804 6,781 6,481 300IL Wood River 898 CS1 (1, 2, 3)IL Wood River 898 1 3 6 0 6IL Wood River 898 2 3 3 0 3IL Wood River 898 3 3 3 0 3IL Wood River 898 4 2,259 3,077 2,894 183IL Wood River 898 5 9,481 11,543 10,675 868IN A B Brown 6137 1 5,358 5,358 4,589 769IN A B Brown 6137 2 4,530 4,530 2,274 2,256IN A B Brown 6137 3 639 639 1 638IN Anderson 7336 ACT1 0 5 2 3IN Anderson 7336 ACT2 0 5 1 4IN Bailly 995 XS12 (7, 8)A, 19APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001IN Bailly 995 7 4,812 3,133 2,787 346IN Bailly 995 8 6,871 9,585 2,358 7,227IN Breed 984 1 7,977 17,889 0 17,889IN Cayuga 1001 1 14,390 38,812 34,978 3,834IN Cayuga 1001 2 14,715 34,313 30,755 3,558IN Cayuga 1001 4 0 15 1 14IN Clifty Creek 983 CS001 (1, 2, 3)IN Clifty Creek 983 1 8,465 7,754 7,253 501IN Clifty Creek 983 2 8,324 7,754 7,254 500IN Clifty Creek 983 3 8,573 7,754 7,254 500IN Clifty Creek 983 CS002 (4, 5, 6)IN Clifty Creek 983 4 8,434 7,473 6,973 500IN Clifty Creek 983 5 8,132 7,473 6,972 501IN Clifty Creek 983 6 8,560 7,473 6,972 501IN Dean H Mitchell 996 CS45 (4, 5)IN Dean H Mitchell 996 4 3,116 889 760 129IN Dean H Mitchell 996 5 3,018 2,072 1,698 374IN Dean H Mitchell 996 CS611 (6, 11)IN Dean H Mitchell 996 6 2,970 2,009 1,961 48IN Dean H Mitchell 996 11 2,658 2,358 1,946 412IN Edwardsport 1004 6-1 0 29 12 17IN Edwardsport 1004 7-1 347 4,281 3,961 320IN Edwardsport 1004 7-2 354 4,005 3,674 331IN Edwardsport 1004 8-1 375 3,475 3,147 328IN Elmer W Stout 990 1 0 0 0 0IN Elmer W Stout 990 2 0 0 0 0IN Elmer W Stout 990 3 0 0 0 0IN Elmer W Stout 990 4 0 0 0 0IN Elmer W Stout 990 5 0 0 0 0IN Elmer W Stout 990 6 0 0 0 0IN Elmer W Stout 990 7 0 0 0 0IN Elmer W Stout 990 8 0 0 0 0IN Elmer W Stout 990 9 1 51 3 48IN Elmer W Stout 990 10 2 52 2 50IN Elmer W Stout 990 50 1,674 8,040 7,778 262IN Elmer W Stout 990 60 2,058 7,849 7,610 239IN Elmer W Stout 990 70 10,180 25,679 24,906 773IN Elmer W Stout 990 GT4 0 50 6 44IN Elmer W Stout 990 GT5 0 50 6 44IN F B Culley 1012 1 827 2,227 2,147 80IN F B Culley 1012 XS23 (2, 3)IN F B Culley 1012 2 1,759 9,872 9,590 282IN F B Culley 1012 3 7,318 36,724 0 36,724IN Frank E Ratts 1043 1SG1 3,593 11,715 11,195 520A, 20APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001IN Frank E Ratts 1043 2SG1 3,660 13,534 11,855 1,679IN Georgetown 7759 GT1 0 0 0 0IN Georgetown 7759 GT2 0 0 0 0IN Georgetown 7759 GT3 0 0 0 0IN Gibson 6113 CS0003 (1, 2)IN Gibson 6113 1 17,420 72,443 50,620 21,823IN Gibson 6113 2 17,683 66,582 44,026 22,556IN Gibson 6113 XS34 (3, 4)IN Gibson 6113 3 17,714 67,512 28,075 39,437IN Gibson 6113 4 17,389 183,311 28,075 155,236IN Gibson 6113 5 18,187 26,576 20,708 5,868IN H T Pritchard 991 1 0 31 4 27IN H T Pritchard 991 2 1 141 8 133IN H T Pritchard 991 CS592 (3, 4)IN H T Pritchard 991 3 240 3,457 3,346 111IN H T Pritchard 991 4 533 3,883 3,713 170IN H T Pritchard 991 CS596 (5, 6)IN H T Pritchard 991 5 596 3,728 3,612 116IN H T Pritchard 991 6 2,488 7,200 6,980 220IN Merom 6213 1SG1 14,925 8,325 7,535 790IN Merom 6213 2SG1 14,823 9,817 9,285 532IN Michigan City 997 4 909 0 0 0IN Michigan City 997 5 1,010 0 0 0IN Michigan City 997 6 1,019 0 0 0IN Michigan City 997 12 10,052 24,694 11,298 13,396IN Mirant State Line Energy, LLC (IN) 981 3 4,726 3,920 3,895 25IN Mirant State Line Energy, LLC (IN) 981 4 6,924 5,124 5,099 25IN Na 1 -- 7221 7221 **1 0 0 0 0IN Na 1 -- 7221 7221 **3 0 0 0 0IN Na 1 -- 7221 7221 **4 0 0 0 0IN Na 1 -- 7228 7228 **2 0 0 0 0IN Na 1 -- 7228 7228 **3 0 0 0 0IN Noblesville 1007 1 66 2,357 2,312 45IN Noblesville 1007 2 54 2,332 2,298 34IN Noblesville 1007 3 40 2,292 2,264 28IN Perry K Steam Plant 992 11 432 32 18 14IN Petersburg 994 1 7,088 1,719 1,638 81IN Petersburg 994 2 13,965 3,240 3,121 119IN Petersburg 994 3 16,886 20,939 20,321 618IN Petersburg 994 4 16,155 17,485 16,975 510IN R Gallagher 1008 CS0001 (1, 2)IN R Gallagher 1008 1 2,909 16,857 15,379 1,478IN R Gallagher 1008 2 3,138 15,880 14,686 1,194IN R Gallagher 1008 CS0002 (3, 4)A, 21APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001IN R Gallagher 1008 3 2,815 16,425 14,902 1,523IN R Gallagher 1008 4 2,933 15,511 14,041 1,470IN R M Schahfer 6085 14 10,357 11,403 11,319 84IN R M Schahfer 6085 15 10,693 13,370 13,281 89IN R M Schahfer 6085 17 5,224 6,185 5,629 556IN R M Schahfer 6085 18 5,189 4,939 4,706 233IN Richmond (IN) 7335 RCT1 0 19 2 17IN Richmond (IN) 7335 RCT2 0 5 2 3IN Rockport 6166 CS012 (MB1, MB2)IN Rockport 6166 MB1 33,003 42,462 32,940 9,522IN Rockport 6166 MB2 33,003 33,003 30,449 2,554IN Tanners Creek 988 CS013 (U1, U2, U3)IN Tanners Creek 988 U1 2,776 4,945 4,800 145IN Tanners Creek 988 U2 2,798 5,234 5,081 153IN Tanners Creek 988 U3 4,080 6,854 6,653 201IN Tanners Creek 988 U4 10,705 118,159 50,912 67,247IN Vermillion Generating Station 55111 1 0 4 0 4IN Vermillion Generating Station 55111 2 0 4 0 4IN Vermillion Generating Station 55111 3 0 4 0 4IN Vermillion Generating Station 55111 4 0 4 0 4IN Vermillion Generating Station 55111 5 0 4 0 4IN Vermillion Generating Station 55111 6 0 4 0 4IN Vermillion Generating Station 55111 7 0 4 0 4IN Vermillion Generating Station 55111 8 0 4 0 4IN Wabash River 1010 1 1,723 17,223 657 16,566IN Wabash River 1010 CS0005 (2, 3, 4, 5, 6)IN Wabash River 1010 2 1,392 7,151 6,534 617IN Wabash River 1010 3 1,616 12,078 7,574 4,504IN Wabash River 1010 4 1,532 6,723 6,091 632IN Wabash River 1010 5 1,582 9,662 8,859 803IN Wabash River 1010 6 5,295 30,947 28,756 2,191IN Warrick6705 1 30,372 20,606 20,583 23IN Warrick6705 2 30,732 29,037 20,069 8,968IN Warrick6705 3 27,668 19,201 19,140 61IN Warrick6705 4 10,509 32,487 31,595 892IN Warrick6705 XS123 (1, 2, 3)IN Whitewater Valley 1040 CS12 (1, 2)IN Whitewater Valley 1040 1 2,237 2,237 2,226 11IN Whitewater Valley 1040 2 6,695 9,895 9,847 48KS Arthur Mullergren 1235 3 1 1 1 0KS Cimarron River 1230 1 12 12 1 11KS Coffeyville 1271 4 11 11 0 11KS East 12Th St 7013 4 10 10 0 10KS Garden City 1336 S-2 0 10 1 9A, 22APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001KS Gordon Evans 1240 1 64 244 229 15KS Gordon Evans 1240 2 25 418 378 40KS Gordon Evans 1240 E1CT 0 10 4 6KS Gordon Evans 1240 E2CT 0 10 2 8KS Holcomb 108 SGU1 4,011 2,501 2,094 407KS Hutchinson 1248 CP001(1,2,3)KS Hutchinson 1248 1 0 0 0 0KS Hutchinson 1248 2 0 0 0 0KS Hutchinson 1248 3 0 0 0 0KS Hutchinson 1248 4 18 1,098 997 101KS Jeffrey Energy Centr 6068 1 17,113 18,774 18,184 590KS Jeffrey Energy Centr 6068 2 18,087 20,383 19,771 612KS Jeffrey Energy Centr 6068 3 20,635 21,235 20,540 695KS Judson Large 1233 4 39 39 2 37KS Kaw 1294 1 787 2 0 2KS Kaw 1294 2 619 0 0 0KS Kaw 1294 3 516 2 0 2KS La Cygne 1241 1 17,946 11,431 9,698 1,733KS La Cygne 1241 2 15,061 21,161 20,983 178KS Lawrence 1250 2 2 2 0 2KS Lawrence 1250 3 2,148 2,148 1,480 668KS Lawrence 1250 4 1,819 539 219 320KS Lawrence 1250 5 5,377 1,677 1,262 415KS Mcpherson 2 1305 1 1 76 7 69KS McPherson 3 7515 1 0 40 1 39KS Murray Gill 1242 1 1 1 0 1KS Murray Gill 1242 2 5 5 0 5KS Murray Gill 1242 3 50 430 388 42KS Murray Gill 1242 4 62 1,262 1,162 100KS Nearman Creek 6064 N1 6,930 8,987 7,596 1,391KS Neosho 1243 7 13 33 16 17KS Quindaro 1295 1 2,032 2,032 1,031 1,001KS Quindaro 1295 2 2,079 7,486 2,139 5,347KS Ripley 1244 **2 0 0 0 0KS Ripley 1244 **3 0 0 0 0KS Riverton 1239 39 1,039 2,539 1,798 741KS Riverton 1239 40 1,764 1,264 892 372KS Tecumseh 1252 9 2,256 2,036 1,785 251KS Tecumseh 1252 10 3,916 3,916 3,624 292KS Wamego1328 7 0 0 0 0KY Big Sandy 1353 CS012 (BSU1, BSU2)KY Big Sandy 1353 BSU1 6,430 20,271 13,980 6,291KY Big Sandy 1353 BSU2 19,718 47,911 37,830 10,081KY Cane Run 1363 3 39 0 0 0A, 23APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001KY Cane Run 1363 4 4,522 6,958 6,245 713KY Cane Run 1363 5 4,341 5,341 5,329 12KY Cane Run 1363 6 5,500 6,103 5,865 238KY Cane Run 1363 **12 0 0 0 0KY Cane Run 1363 **13 0 0 0 0KY Coleman 1381 C1 4,854 16,210 15,485 725KY Coleman 1381 C2 5,536 15,268 14,362 906KY Coleman 1381 C3 5,324 16,266 15,350 916KY Cooper 1384 CS1 (1, 2)KY Cooper 1384 1 3,210 9,124 5,974 3,150KY Cooper 1384 2 6,608 20,595 12,128 8,467KY D B Wilson 6823 W1 12,465 10,965 10,109 856KY Dale 1385 CS2 (3, 4)KY Dale 1385 3 1,984 3,184 3,143 41KY Dale 1385 4 1,847 3,247 3,143 104KY E W Brown 1355 1 3,066 18,432 7,867 10,565KY E W Brown 1355 CS003 (2, 3)KY E W Brown 1355 2 5,807 28,632 10,855 17,777KY E W Brown 1355 3 11,254 71,257 31,638 39,619KY E W Brown 1355 6 0 100 10 90KY E W Brown 1355 7 0 100 10 90KY E W Brown 1355 8 0 100 0 100KY E W Brown 1355 9 0 100 0 100KY E W Brown 1355 10 0 100 0 100KY E W Brown 1355 11 0 100 0 100KY East Bend 6018 2 18,322 25,898 14,850 11,048KY Elmer Smith 1374 XS12 (1, 2)KY Elmer Smith 1374 1 2,805 8,330 2,057 6,273KY Elmer Smith 1374 2 6,213 18,464 4,799 13,665KY Ghent 1356 1 12,252 103,708 4,109 99,599KY Ghent 1356 2 12,737 17,737 17,240 497KY Ghent 1356 CS002 (3, 4)KY Ghent 1356 3 13,960 19,960 18,815 1,145KY Ghent 1356 4 13,717 19,717 19,022 695KY Green River 1357 XS123 (1, 2, 3)KY Green River 1357 1 130 130 125 5KY Green River 1357 2 851 851 174 677KY Green River 1357 3 744 744 223 521KY Green River 1357 4 2,826 12,826 9,987 2,839KY Green River 1357 5 3,372 14,229 12,851 1,378KY H L Spurlock 6041 1 9,824 40,954 16,300 24,654KY H L Spurlock 6041 2 16,591 25,618 22,352 3,266KY Henderson I 1372 6 810 810 698 112KY Hmp&L Station 2 1382 H1 5,758 11,746 2,794 8,952A, 24APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001KY Hmp&L Station 2 1382 H2 5,936 9,289 3,108 6,181KY J K Smith 54 SCT1 0 10 0 10KY J K Smith 54 SCT2 0 10 1 9KY J K Smith 54 SCT3 0 10 0 10KY Mill Creek 1364 1 8,082 8,082 7,677 405KY Mill Creek 1364 2 8,142 10,142 9,841 301KY Mill Creek 1364 3 10,982 9,982 8,806 1,176KY Mill Creek 1364 4 13,622 8,622 8,179 443KY Na 1 -- 7220 7220 **3 0 0 0 0KY Na 1 -- 7220 7220 **4 0 0 0 0KY Na 1 -- 7220 7220 **5 0 0 0 0KY Paradise 1378 1 10,821 20,321 17,733 2,588KY Paradise 1378 2 12,304 24,804 24,387 417KY Paradise 1378 3 25,513 183,941 102,920 81,021KY Pineville 1360 3 914 2,914 1,449 1,465KY R D Green 6639 G1 5,294 2,617 1,838 779KY R D Green 6639 G2 6,378 2,616 1,544 1,072KY Robert Reid 1383 R1 942 8,942 7,439 1,503KY Shawnee 1379 CSSH15 (1, 2, 3, 4, 5)KY Shawnee 1379 1 3,644 4,144 3,495 649KY Shawnee 1379 2 3,673 4,173 3,324 849KY Shawnee 1379 3 3,708 4,708 4,022 686KY Shawnee 1379 4 3,594 4,094 3,678 416KY Shawnee 1379 5 3,826 4,326 3,895 431KY Shawnee 1379 CSSH60 (6, 7, 8, 9, 10)KY Shawnee 1379 6 3,712 3,712 2,604 1,108KY Shawnee 1379 7 3,640 4,640 3,794 846KY Shawnee 1379 8 3,571 4,571 3,877 694KY Shawnee 1379 9 3,666 4,166 3,405 761KY Shawnee 1379 10 4,895 4,992 1,993 2,999KY Trimble County 6071 1 9,634 9,969 7,583 2,386KY Tyrone 1361 1 0 0 0 0KY Tyrone 1361 2 0 0 0 0KY Tyrone 1361 3 0 0 0 0KY Tyrone 1361 4 0 0 0 0KY Tyrone 1361 5 1,713 3,713 2,607 1,106LA A B Paterson 1407 3 7 2 0 2LA A B Paterson 1407 4 8 2 0 2LA Arsenal Hill 1416 5A 30 30 1 29LA Big Cajun 1 1464 1B1 27 27 1 26LA Big Cajun 1 1464 1B2 27 27 4 23LA Big Cajun 2 6055 2B1 14,868 16,079 16,069 10LA Big Cajun 2 6055 2B2 14,640 17,036 17,026 10LA Big Cajun 2 6055 2B3 14,657 17,304 17,289 15A, 25APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001LA Calcasieu Power, LLC 55165 GTG1 0 0 0 0LA D G Hunter 6558 3 0 0 0 0LA D G Hunter 6558 4 32 32 15 17LA Doc Bonin 1443 1 12 12 1 11LA Doc Bonin 1443 2 24 24 1 23LA Doc Bonin 1443 3 45 45 1 44LA Dolet Hills 51 1 20,501 20,501 19,518 983LA Evangeline (Coughlin) 1396 6 46 0 0 0LA Evangeline (Coughlin) 1396 7 128 0 0 0LA Evangeline (Coughlin) 1396 6-1 0 46 2 44LA Evangeline (Coughlin) 1396 7-1 0 64 1 63LA Evangeline (Coughlin) 1396 7-2 0 64 1 63LA Houma 1439 15 10 10 0 10LA Houma 1439 16 14 14 0 14LA Lieberman 1417 3 86 111 102 9LA Lieberman 1417 4 72 47 4 43LA Little Gypsy 1402 1 245 245 1 244LA Little Gypsy 1402 2 378 378 13 365LA Little Gypsy 1402 3 543 543 5 538LA Louisiana 1 1391 1A 116 6 3 3LA Louisiana 1 1391 2A 2 7 2 5LA Louisiana 1 1391 3A 2 7 2 5LA Louisiana 1 1391 4A 0 36 18 18LA Louisiana 1 1391 5A 0 33 19 14LA Louisiana 2 1392 10 0 2 0 2LA Louisiana 2 1392 11 0 2 0 2LA Louisiana 2 1392 12 0 2 0 2LA Michoud 1409 1 71 3 1 2LA Michoud 1409 2 106 5 3 2LA Michoud 1409 3 491 2,321 2,252 69LA Monroe 1448 11 13 13 0 13LA Monroe 1448 12 45 45 0 45LA Morgan City 1449 4 5 5 0 5LA Natchitoches 1450 10 0 1 0 1LA Ninemile Point 1403 1 62 62 1 61LA Ninemile Point 1403 2 112 112 2 110LA Ninemile Point 1403 3 96 96 1 95LA Ninemile Point 1403 4 691 691 163 528LA Ninemile Point 1403 5 930 930 11 919LA Opelousas 1454 10 1 1 0 1LA R S Nelson 1393 3 39 4 2 2LA R S Nelson 1393 4 123 8 7 1LA R S Nelson 1393 6 19,569 20,834 20,422 412LA Rodemacher 6190 1 3,249 3,249 136 3,113A, 26APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001LA Rodemacher 6190 2 18,909 18,909 14,703 4,206LA Ruston 1458 2 4 4 0 4LA Ruston 1458 3 5 5 0 5LA Sterlington 1404 10 174 174 2 172LA Sterlington 1404 7C 0 15 5 10LA Sterlington 1404 7AB 72 57 2 55LA Teche 1400 2 27 27 1 26LA Teche 1400 3 446 446 58 388LA Waterford 1 & 2 8056 1 4,554 4,554 1,183 3,371LA Waterford 1 & 2 8056 2 3,535 3,535 627 2,908LA Willow Glen 1394 1 99 4 1 3LA Willow Glen 1394 2 26 6 3 3LA Willow Glen 1394 3 93 8 3 5LA Willow Glen 1394 4 291 11 6 5LA Willow Glen 1394 5 458 746 707 39MA Berkshire Power 55041 1 0 10 3 7MA Brayton Point 1619 1 8,481 10,873 9,370 1,503MA Brayton Point 1619 2 8,911 10,532 9,070 1,462MA Brayton Point 1619 3 18,625 22,505 21,427 1,078MA Brayton Point 1619 4 12,139 4,959 4,719 240MA Canal 1599 1 13,235 13,235 12,472 763MA Canal 1599 2 17,999 12,999 11,376 1,623MA Cannon Street 1616 3 374 374 0 374MA Cleary Flood 1682 8 143 158 137 21MA Cleary Flood 1682 9 2,679 2,664 142 2,522MA Dighton 55026 1 0 34 2 32MA Kendall Square 1595 CS12 (1, 2)MA Kendall Square 1595 1 199 199 45 154MA Kendall Square 1595 2 208 208 46 162MA Kendall Square 1595 3 421 421 94 327MA Millennium Power Partners, L.P. 55079 1 0 5 0 5MA Mount Tom 1606 1 6,347 12,440 7,373 5,067MA Mystic 1588 4 2,607 1,607 1,103 504MA Mystic 1588 5 3,092 2,092 1,116 976MA Mystic 1588 6 3,076 2,076 1,016 1,060MA Mystic 1588 7 17,244 7,604 6,149 1,455MA New Boston 1589 1 6,158 58 1 57MA New Boston 1589 2 6,324 64 1 63MA Salem Harbor 1626 1 3,339 3,753 3,576 177MA Salem Harbor 1626 2 3,408 4,072 3,877 195MA Salem Harbor 1626 3 5,461 5,885 5,603 282MA Salem Harbor 1626 4 12,571 7,834 7,458 376MA Somerset 1613 1 0 0 0 0MA Somerset 1613 2 0 0 0 0A, 27APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001MA Somerset 1613 3 0 0 0 0MA Somerset 1613 4 0 0 0 0MA Somerset 1613 5 0 0 0 0MA Somerset 1613 6 0 0 0 0MA Somerset 1613 7 2,765 1,715 0 1,715MA Somerset 1613 8 3,985 5,035 5,023 12MA West Springfield 1642 1 378 352 0 352MA West Springfield 1642 2 356 331 0 331MA West Springfield 1642 3 3,012 2,803 840 1,963MD Brandon Shores 602 1 18,510 32,099 28,465 3,634MD Brandon Shores 602 2 7,795 27,834 21,235 6,599MD C P Crane 1552 1 4,349 24,129 15,633 8,496MD C P Crane 1552 2 4,043 16,705 15,044 1,661MD Chalk Point 1571 CSE12 (1, 2)MD Chalk Point 1571 1 9,202 19,202 17,258 1,944MD Chalk Point 1571 2 10,219 17,219 15,343 1,876MD Chalk Point 1571 3 12,610 12,503 1,643 10,860MD Chalk Point 1571 4 3,557 2,600 1,215 1,385MD Chalk Point 1571 **GT3 707 707 5 702MD Chalk Point 1571 **GT4 707 707 5 702MD Chalk Point 1571 **GT5 894 894 17 877MD Chalk Point 1571 **GT6 894 894 4 890MD Dickerson 1572 XS123 (1, 2, 3)MD Dickerson 1572 1 5,848 8,848 8,145 703MD Dickerson 1572 2 5,500 13,500 11,763 1,737MD Dickerson 1572 3 5,846 10,846 9,305 1,541MD Dickerson 1572 CW1 0 0 0 0MD Dickerson 1572 GT2 1,082 1,082 0 1,082MD Dickerson 1572 GT3 1,082 1,082 2 1,080MD Dickerson 1572 HCT3 0 0 0 0MD Dickerson 1572 HCT4 0 0 0 0MD Easton 2 4257 **25 0 0 0 0MD Easton 2 4257 **26 0 0 0 0MD Easton 2 4257 **27 0 0 0 0MD Gould Street 1553 3 821 814 582 232MD Herbert A Wagner 1554 1 1,291 1,418 813 605MD Herbert A Wagner 1554 2 1,299 7,316 5,610 1,706MD Herbert A Wagner 1554 3 8,381 17,858 14,939 2,919MD Herbert A Wagner 1554 4 1,520 2,800 2,240 560MD Morgantown 1573 1 16,932 43,263 37,896 5,367MD Morgantown 1573 2 16,189 43,189 37,722 5,467MD Nanticoke 4207 **ST1 0 0 0 0MD Panda Brandywine 54832 1 0 1 1 0MD Panda Brandywine 54832 2 0 1 1 0A, 28APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001MD Perryman 1556 **51 0 2,401 134 2,267MD Perryman 1556 **52 0 0 0 0MD Perryman 1556 **61 0 0 0 0MD Perryman 1556 **62 0 0 0 0MD R P Smith 1570 9 634 722 482 240MD R P Smith 1570 11 2,314 4,117 4,017 100MD Riverside 1559 1 189 0 0 0MD Riverside 1559 2 171 0 0 0MD Riverside 1559 3 354 0 0 0MD Riverside 1559 4 455 4 0 4MD Riverside 1559 5 294 0 0 0MD Vienna 1564 8 3,645 3,645 3,312 333MD Westport 1560 3 186 0 0 0MD Westport 1560 4 258 0 0 0ME Androscoggin Cogeneration Center 55031 CT01 0 2 2 0ME Androscoggin Cogeneration Center 55031 CT02 0 2 2 0ME Androscoggin Cogeneration Center 55031 CT03 0 2 0 2ME Graham Station 1470 5 344 3 0 3ME Maine Independence Station 55068 1 0 10 2 8ME Maine Independence Station 55068 2 0 10 2 8ME Mason Steam 1496 3 2 8 4 4ME Mason Steam 1496 4 1 7 4 3ME Mason Steam 1496 5 1 9 5 4ME Rumford Power Associates 55100 1 0 33 1 32ME William F Wyman1507 1 1,159 1,159 894 265ME William F Wyman1507 2 1,161 1,161 876 285ME William F Wyman1507 3 2,946 5,018 4,124 894ME William F Wyman1507 4 6,274 6,274 4,678 1,596MI 48th Street Peaking Station 7258 9 0 10 0 10MI 48th Street Peaking Station 7258 **7 298 88 5 83MI 48th Street Peaking Station 7258 **8 298 98 1 97MI B C Cobb 1695 1 1,142 63,186 0 63,186MI B C Cobb 1695 2 1,229 2,022 0 2,022MI B C Cobb 1695 3 1,223 1,223 0 1,223MI B C Cobb 1695 4 4,573 9,950 8,291 1,659MI B C Cobb 1695 5 4,695 9,349 7,790 1,559MI Belle River 6034 1 18,505 18,505 15,178 3,327MI Belle River 6034 2 18,769 18,769 14,179 4,590MI Belle River 6034 CTG121 0 5 0 5MI Belle River 6034 CTG122 0 5 0 5MI Belle River 6034 CTG131 0 5 0 5MI Conners Creek 1726 15 4,285 171 0 171MI Conners Creek 1726 16 4,279 981 0 981MI Conners Creek 1726 17 4,034 4,034 0 4,034A, 29APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001MI Conners Creek 1726 18 3,353 3,353 0 3,353MI Dan E Karn 1702 1 8,388 12,737 8,614 4,123MI Dan E Karn 1702 2 8,567 13,097 8,914 4,183MI Dan E Karn 1702 CS0009 (3, 4)MI Dan E Karn 1702 3 1,020 3,912 3,259 653MI Dan E Karn 1702 4 948 3,468 2,890 578MI Dearborn Industrial Generation 55088 GTP1 0 0 0 0MI Delray 1728 7 0 0 0 0MI Delray 1728 8 12 12 0 12MI Delray 1728 9 0 0 0 0MI Delray 1728 10 14 14 0 14MI Delray 1728 11 0 0 0 0MI Delray 1728 12 14 14 0 14MI Delray 1728 CTG111 0 5 0 5MI Delray 1728 CTG121 0 5 0 5MI Eckert Station 1831 1 1,298 1,298 779 519MI Eckert Station 1831 2 1,354 1,354 727 627MI Eckert Station 1831 3 1,327 1,327 576 751MI Eckert Station 1831 4 2,223 2,223 1,775 448MI Eckert Station 1831 5 2,666 2,666 1,833 833MI Eckert Station 1831 6 2,343 2,343 988 1,355MI Endicott Generating 4259 1 1,810 1,810 755 1,055MI Erickson 1832 1 6,646 6,646 6,504 142MI Greenwood 6035 1 539 1,696 1,157 539MI Greenwood 6035 CTG111 0 5 0 5MI Greenwood 6035 CTG112 0 5 0 5MI Greenwood 6035 CTG121 0 5 0 5MI Harbor Beach 1731 1 3,520 3,520 2,246 1,274MI J B Sims1825 3 1,484 1,484 626 858MI J C Weadock 1720 CS0009 (7, 8)MI J C Weadock 1720 7 4,745 5,885 4,904 981MI J C Weadock 1720 8 4,691 5,653 4,711 942MI J H Campbell 1710 CS0009 (1, 2)MI J H Campbell 1710 1 8,098 15,521 9,218 6,303MI J H Campbell 1710 2 9,685 16,986 10,822 6,164MI J H Campbell 1710 3 27,805 23,949 20,722 3,227MI J R Whiting 1723 1 3,412 3,797 3,348 449MI J R Whiting 1723 2 3,842 4,253 2,859 1,394MI J R Whiting 1723 3 4,919 5,413 4,169 1,244MI James De Young 1830 5 1,048 1,448 1,438 10MI Kalamazoo River Generating Station 55101 1 0 0 0 0MI Livingston Generating Station 55102 1 0 0 0 0MI Livingston Generating Station 55102 2 0 0 0 0MI Livingston Generating Station 55102 3 0 0 0 0A, 30APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001MI Livingston Generating Station 55102 4 0 0 0 0MI Marysville 1732 CS0001 (9, 10)MI Marysville 1732 9 1,637 1,637 313 1,324MI Marysville 1732 10 1,261 1,261 452 809MI Marysville 1732 CS0002 (11, 12)MI Marysville 1732 11 1,315 1,315 315 1,000MI Marysville 1732 12 1,061 1,061 394 667MI Michigan Power Limited Partnership 54915 1 0 4 3 1MI Mistersky 1822 5 257 257 1 256MI Mistersky 1822 6 437 437 3 434MI Mistersky 1822 7 485 485 2 483MI Monroe 1733 CS0012 (1, 2)MI Monroe 1733 1 23,669 32,630 28,549 4,081MI Monroe 1733 2 24,307 44,013 29,706 14,307MI Monroe 1733 CS0034 (3, 4)MI Monroe 1733 3 22,771 49,164 26,393 22,771MI Monroe 1733 4 24,617 45,334 22,894 22,440MI Presque Isle 1769 CS4 (1, 2, 3, 4)MI Presque Isle 1769 2 637 637 318 319MI Presque Isle 1769 3 1,907 2,711 2,510 201MI Presque Isle 1769 4 1,677 2,549 2,361 188MI Presque Isle 1769 5 2,934 4,619 4,199 420MI Presque Isle 1769 6 2,941 4,086 3,714 372MI Presque Isle 1769 7 2,216 1,770 1,708 62MI Presque Isle 1769 8 2,192 2,302 2,091 211MI Presque Isle 1769 9 2,346 2,138 1,943 195MI River Rouge 1740 1 79 4 0 4MI River Rouge 1740 2 6,323 6,323 5,939 384MI River Rouge 1740 3 9,103 9,103 6,549 2,554MI Shiras 1843 3 500 500 356 144MI St Clair 1743 1 3,666 5,756 5,756 0MI St Clair 1743 2 3,543 5,567 5,138 429MI St Clair 1743 3 3,525 4,473 4,473 0MI St Clair 1743 4 3,396 5,596 5,596 0MI St Clair 1743 5 0 0 0 0MI St Clair 1743 6 7,342 7,452 7,452 0MI St Clair 1743 7 13,459 21,912 21,912 0MI Trenton Channel 1745 CS0006 (16, 17, 18, 19)MI Trenton Channel 1745 16 3,292 3,357 3,357 0MI Trenton Channel 1745 17 767 3,222 3,222 0MI Trenton Channel 1745 18 3,563 3,563 2,620 943MI Trenton Channel 1745 19 698 2,875 2,875 0MI Trenton Channel 1745 9A 14,507 15,684 15,684 0MI Wyandotte 1866 5 960 151 0 151A, 31APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001MI Wyandotte 1866 7 953 1,525 1,523 2MI Wyandotte 1866 8 0 237 237 0MN Allen S King 1915 1 15,628 30,399 27,251 3,148MN Black Dog 1904 CS1 (1, 2, 3, 4)MN Black Dog 1904 1 1,914 1,914 10 1,904MN Black Dog 1904 2 3,683 3,683 11 3,672MN Black Dog 1904 3 2,275 2,275 1,070 1,205MN Black Dog 1904 4 4,056 4,056 2,352 1,704MN Clay Boswell 1893 CS0003 (1, 2, 3)MN Clay Boswell 1893 1 1,827 1,827 1,827 0MN Clay Boswell 1893 2 1,800 1,800 1,800 0MN Clay Boswell 1893 3 9,866 8,753 8,748 5MN Clay Boswell 1893 4 10,324 3,311 2,774 537MN Cottage Grove 55010 01 0 5 4 1MN Fox Lake 1888 3 2,069 2,069 1 2,068MN High Bridge 1912 CS0001 (3, 4, 5, 6)MN High Bridge 1912 3 2,118 5,314 254 5,060MN High Bridge 1912 4 1,458 3,059 273 2,786MN High Bridge 1912 5 2,194 3,062 1,092 1,970MN High Bridge 1912 6 1,852 9,546 1,840 7,706MN Hoot Lake 1943 2 1,242 1,850 1,201 649MN Hoot Lake 1943 3 1,978 1,978 1,438 540MN Hutchinson Utils Comm - Plant 2 6358 1 0 1 0 1MN M L Hibbard 1897 CS0001 (3, 4)MN M L Hibbard 1897 3 987 55 54 1MN M L Hibbard 1897 4 1,094 55 54 1MN Minnesota Valley 1918 4 938 938 2 936MN Northeast Station 1961 NEPP 1,052 4,006 1,906 2,100MN Riverside 1927 XS67 (6, 7)MN Riverside 1927 6 3,076 2,797 1,105 1,692MN Riverside 1927 7 1,339 1,339 1,105 234MN Riverside 1927 8 5,068 11,645 10,585 1,060MN Sherburne County 6090 CS1 (1, 2)MN Sherburne County 6090 1 13,091 14,679 6,396 8,283MN Sherburne County 6090 2 13,184 14,833 5,277 9,556MN Sherburne County 6090 3 12,956 12,979 11,090 1,889MN Silver Lake 2008 4 3,133 3,132 2,028 1,104MN Syl Laskin 1891 CS0001 (1, 2)MN Syl Laskin 1891 1 1,692 808 754 54MN Syl Laskin 1891 2 1,649 807 754 53MO Asbury 2076 1 6,975 42,870 3,735 39,135MO Blue Valley 2132 3 4,670 4,670 3,903 767MO Chamois 2169 2 5,457 2,701 2,654 47MO Columbia 2123 CS5 (6, 7)A, 32APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001MO Columbia 2123 6 903 903 237 666MO Columbia 2123 7 3,631 3,220 406 2,814MO Columbia 2123 8 125 125 0 125MO Combustion Turbine 1 7160 **1 0 0 0 0MO Combustion Turbine 1 7160 **NA4 0 0 0 0MO Combustion Turbine 1 7160 **NA5 0 0 0 0MO Combustion Turbine 1 7160 **NA6 0 0 0 0MO Combustion Turbine 2 7161 **2 0 0 0 0MO Combustion Turbine 3 7162 **3 0 0 0 0MO Essex Power Plant 7749 1 0 50 0 50MO Hawthorn 2079 5 12,773 33,639 0 33,639MO Hawthorn 2079 6 0 5 1 4MO Hawthorn 2079 7 0 5 0 5MO Hawthorn 2079 8 0 5 0 5MO Hawthorn 2079 9 0 5 0 5MO Iatan 6065 1 16,208 16,208 13,430 2,778MO Iatan 6065 **2 0 0 0 0MO James River 2161 3 3,327 1,863 1,503 360MO James River 2161 4 5,975 2,277 1,538 739MO James River 2161 5 2,133 4,045 3,472 573MO James River 2161 **GT2 604 4 0 4MO Jim Hill 2073 **1 0 0 0 0MO Labadie 2103 1 17,553 12,413 8,278 4,135MO Labadie 2103 2 16,363 16,233 9,949 6,284MO Labadie 2103 3 17,487 17,347 11,450 5,897MO Labadie 2103 4 15,584 15,460 9,616 5,844MO Lake Road 2098 6 605 2,840 1,760 1,080MO Meramec 2104 1 2,745 2,736 1,358 1,378MO Meramec 2104 2 2,778 4,251 1,249 3,002MO Meramec 2104 3 6,058 6,049 5,142 907MO Meramec 2104 4 7,175 12,154 10,181 1,973MO Montrose 2080 1 3,189 4,990 3,023 1,967MO Montrose 2080 CS023 (2, 3)MO Montrose 2080 2 3,535 5,724 2,695 3,029MO Montrose 2080 3 4,349 8,498 3,799 4,699MO Na 1 -- 7223 7223 **1 0 0 0 0MO Na 1 -- 7223 7223 **2 0 0 0 0MO Na 1 -- 7223 7223 **3 0 0 0 0MO Na 1 -- 7226 7226 **1 0 0 0 0MO New Madrid 2167 1 12,178 8,425 8,324 101MO New Madrid 2167 2 14,009 8,243 8,127 116MO Nodaway Power Plant 7754 1 0 50 0 50MO Nodaway Power Plant 7754 2 0 50 0 50MO Rg 1 & 2 212 **1 0 0 0 0A, 33APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001MO Rg 1 & 2 212 **2 0 0 0 0MO Rush Island 6155 1 14,960 17,327 13,643 3,684MO Rush Island 6155 2 15,652 18,230 13,257 4,973MO Sibley 2094 CS0001 (1, 2, 3)MO Sibley 2094 1 519 2,190 1,588 602MO Sibley 2094 2 638 3,727 1,588 2,139MO Sibley 2094 3 7,634 13,767 12,703 1,064MO Sikeston 6768 1 6,791 7,063 6,523 540MO Sioux 2107 1 10,823 23,737 20,017 3,720MO Sioux 2107 2 9,492 23,417 16,522 6,895MO Southwest 6195 1 4,184 4,376 2,737 1,639MO St. Francis 7604 1 0 50 1 49MO State Line (MO) 7296 1 0 30 2 28MO State Line (MO) 7296 2-2 0 110 1 109MO Thomas Hill 2168 MB1 4,421 2,985 2,948 37MO Thomas Hill 2168 MB2 7,432 4,088 4,028 60MO Thomas Hill 2168 MB3 18,257 11,492 11,337 155MS Batesville Generation Facility 55063 1 0 2 1 1MS Batesville Generation Facility 55063 2 0 2 1 1MS Batesville Generation Facility 55063 3 0 2 1 1MS Baxter Wilson 2050 1 360 60 53 7MS Baxter Wilson 2050 2 3,564 10,151 9,951 200MS Caledonia Power I, LLC 2783 AA-001 0 1 0 1MS Caledonia Power I, LLC 2783 AA-002 0 1 0 1MS Caledonia Power I, LLC 2783 AA-003 0 1 0 1MS Caledonia Power I, LLC 2783 AA-004 0 1 0 1MS Caledonia Power I, LLC 2783 AA-005 0 1 0 1MS Caledonia Power I, LLC 2783 AA-006 0 1 0 1MS Chevron Cogenerating Station 2047 5 0 25 9 16MS Daniel Electric Generating Plant 6073 1 11,228 16,056 13,948 2,108MS Daniel Electric Generating Plant 6073 2 14,277 14,690 13,060 1,630MS Delta 2051 1 26 6 1 5MS Delta 2051 2 50 5 1 4MS Gerald Andrus 8054 1 3,282 33,390 31,740 1,650MS Jack Watson 2049 1 172 172 2 170MS Jack Watson 2049 2 180 180 1 179MS Jack Watson 2049 3 273 273 1 272MS Jack Watson 2049 4 7,525 26,555 16,152 10,403MS Jack Watson 2049 5 15,415 39,813 36,751 3,062MS Moselle 2070 1 35 35 2 33MS Moselle 2070 2 76 66 1 65MS Moselle 2070 3 42 42 2 40MS Moselle 2070 **4 0 10 0 10MS Moselle 2070 **5 0 0 0 0A, 34APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001MS Moselle 2070 **6 0 0 0 0MS Moselle 2070 **7 0 0 0 0MS Natchez 2052 1 2 2 0 2MS New Albany Power I, LLC 13213 AA-001 0 1 0 1MS New Albany Power I, LLC 13213 AA-002 0 1 0 1MS New Albany Power I, LLC 13213 AA-003 0 1 0 1MS New Albany Power I, LLC 13213 AA-004 0 1 0 1MS New Albany Power I, LLC 13213 AA-005 0 1 0 1MS New Albany Power I, LLC 13213 AA-006 0 1 0 1MS R D Morrow 6061 1 4,800 6,414 4,138 2,276MS R D Morrow 6061 2 5,254 8,197 4,095 4,102MS Rex Brown 2053 3 41 2 1 1MS Rex Brown 2053 4 159 3 1 2MS Rex Brown 2053 1A 6 1 0 1MS Rex Brown 2053 1B 6 1 0 1MS Sweatt 2048 CS01 (1, 2)MS Sweatt 2048 1 78 78 0 78MS Sweatt 2048 2 86 86 1 85MS Wright 2063 W4 0 0 0 0MT Colstrip 6076 1 7,859 5,208 5,059 149MT Colstrip 6076 2 7,870 5,624 5,559 65MT Colstrip 6076 3 4,405 2,933 2,859 74MT Colstrip 6076 4 2,917 2,329 2,315 14MT Frank Bird 2184 1 0 0 0 0MT J E Corette 2187 2 5,062 3,614 3,315 299MT Lewis & Clark 6089 B1 1,444 1,444 1,141 303NC Asheville 2706 1 6,622 10,893 10,793 100NC Asheville 2706 2 5,261 9,475 9,375 100NC Asheville 2706 3 0 10 8 2NC Asheville 2706 4 0 10 5 5NC Belews Creek 8042 1 134,376 27,108 24,643 2,465NC Belews Creek 8042 2 131,213 52,453 47,686 4,767NC Buck 2720 5 1,709 828 759 69NC Buck 2720 6 1,208 837 761 76NC Buck 2720 7 1,831 922 838 84NC Buck 2720 8 6,407 3,572 3,247 325NC Buck 2720 9 7,354 5,093 4,640 453NC Cape Fear 2708 3 599 0 0 0NC Cape Fear 2708 4 599 0 0 0NC Cape Fear 2708 5 3,382 5,955 5,854 101NC Cape Fear 2708 6 3,913 6,897 6,797 100NC Cliffside 2721 1 1,612 1,313 1,194 119NC Cliffside 2721 2 1,625 1,346 1,224 122NC Cliffside 2721 3 2,486 2,080 1,891 189A, 35APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001NC Cliffside 2721 4 2,555 973 884 89NC Cliffside 2721 5 33,588 26,323 23,946 2,377NC Dan River 2723 1 3,749 1,448 1,316 132NC Dan River 2723 2 4,665 1,578 1,433 145NC Dan River 2723 3 7,467 3,393 3,084 309NC G G Allen 2718 1 11,374 6,018 5,471 547NC G G Allen 2718 2 11,552 4,768 4,334 434NC G G Allen 2718 3 23,354 10,045 9,132 913NC G G Allen 2718 4 21,382 10,266 9,333 933NC G G Allen 2718 5 22,823 6,368 5,789 579NC L V Sutton 2713 CS0002 (1, 2)NC L V Sutton 2713 1 2,051 3,807 3,706 101NC L V Sutton 2713 2 2,270 3,807 3,707 100NC L V Sutton 2713 3 8,298 15,236 15,135 101NC Lee 2709 1 2,226 3,519 3,418 101NC Lee 2709 2 2,277 3,426 3,326 100NC Lee 2709 3 7,132 10,195 10,094 101NC Lee 2709 10 0 10 4 6NC Lee 2709 11 0 10 4 6NC Lee 2709 12 0 10 4 6NC Lee 2709 13 0 10 3 7NC Lincoln 7277 1 0 6 3 3NC Lincoln 7277 2 0 4 2 2NC Lincoln 7277 3 0 4 2 2NC Lincoln 7277 4 0 4 2 2NC Lincoln 7277 5 0 4 2 2NC Lincoln 7277 6 0 4 2 2NC Lincoln 7277 7 0 4 2 2NC Lincoln 7277 8 0 4 2 2NC Lincoln 7277 9 0 6 3 3NC Lincoln 7277 10 0 5 2 3NC Lincoln 7277 11 0 5 2 3NC Lincoln 7277 12 0 5 2 3NC Lincoln 7277 13 0 4 2 2NC Lincoln 7277 14 0 5 2 3NC Lincoln 7277 15 0 4 2 2NC Lincoln 7277 16 0 4 2 2NC Marshall 2727 1 24,311 17,054 15,503 1,551NC Marshall 2727 2 26,809 15,631 14,303 1,328NC Marshall 2727 3 43,969 26,260 23,872 2,388NC Marshall 2727 4 44,018 27,772 25,363 2,409NC Mayo 6250 CS0005 (1A, 1B)NC Mayo 6250 1A 12,785 14,857 14,756 101NC Mayo 6250 1B 12,785 14,857 14,756 101A, 36APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001NC Riverbend 2732 7 3,754 3,574 3,250 324NC Riverbend 2732 8 3,759 3,411 3,101 310NC Riverbend 2732 9 5,071 6,263 5,693 570NC Riverbend 2732 10 5,406 5,959 5,418 541NC Rockingham Power, LLC 55116 CT1 0 5 3 2NC Rockingham Power, LLC 55116 CT2 0 5 4 1NC Rockingham Power, LLC 55116 CT3 0 4 2 2NC Rockingham Power, LLC 55116 CT4 0 4 3 1NC Rockingham Power, LLC 55116 CT5 0 5 4 1NC Roxboro 2712 1 11,088 16,158 16,058 100NC Roxboro 2712 2 19,642 30,386 30,286 100NC Roxboro 2712 CS0003 (3A, 3B)NC Roxboro 2712 3A 9,096 15,458 15,357 101NC Roxboro 2712 3B 9,096 15,458 15,357 101NC Roxboro 2712 CS0004 (4A, 4B)NC Roxboro 2712 4A 10,407 10,029 9,927 102NC Roxboro 2712 4B 10,407 10,029 9,928 101NC W H Weatherspoon 2716 CS0001 (1, 2)NC W H Weatherspoon 2716 1 1,122 2,097 1,997 100NC W H Weatherspoon 2716 2 1,125 2,097 1,997 100NC W H Weatherspoon 2716 3 1,626 2,732 2,632 100ND Antelope Valley 6469 B1 11,947 11,947 6,640 5,307ND Antelope Valley 6469 B2 11,131 11,131 6,407 4,724ND Coal Creek 6030 1 23,310 14,410 14,332 78ND Coal Creek 6030 2 21,187 17,587 12,817 4,770ND Coyote 8222 B1 16,182 16,117 14,521 1,596ND Leland Olds 2817 1 9,105 17,605 16,864 741ND Leland Olds 2817 2 26,401 32,901 28,587 4,314ND Milton R Young 2823 B1 12,951 25,512 18,095 7,417ND Milton R Young 2823 B2 15,885 23,291 21,134 2,157ND R M Heskett 2790 B2 3,202 3,162 1,778 1,384ND Stanton 2824 1 7,447 11,847 7,660 4,187ND Stanton 2824 10 1,334 1,334 973 361NE Bluffs 2276 4 18 18 0 18NE C W Burdick 2241 B-3 0 10 1 9NE Canaday 2226 1 627 627 81 546NE Gerald Gentleman Sta 6077 1 10,805 10,714 9,604 1,110NE Gerald Gentleman Sta 6077 2 17,572 17,302 12,988 4,314NE Gerald Whelan Energy Center 60 1 2,335 2,335 2,164 171NE Harold Kramer 2269 1 38 38 0 38NE Harold Kramer 2269 2 40 40 0 40NE Harold Kramer 2269 3 1,052 1,052 0 1,052NE Harold Kramer 2269 4 2,079 2,079 0 2,079NE Lon Wright 2240 8 2,044 2,044 841 1,203A, 37APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001NE Na 1 -- 7019 7019 **NA1 0 0 0 0NE Nebraska City 6096 1 13,194 15,234 15,227 7NE North Omaha 2291 CS000A (1, 2, 3)NE North Omaha 2291 1 2,388 2,388 2,045 343NE North Omaha 2291 2 3,287 3,287 2,046 1,241NE North Omaha 2291 3 3,208 3,208 2,046 1,162NE North Omaha 2291 4 3,849 3,849 2,873 976NE North Omaha 2291 5 4,647 4,647 3,631 1,016NE Platte 59 1 2,927 2,917 2,497 420NE Rokeby 6373 2 0 20 0 20NE Sarpy County Station 2292 CT3 0 0 0 0NE Sarpy County Station 2292 CT4A 0 0 0 0NE Sarpy County Station 2292 CT4B 0 0 0 0NE Sarpy County Station 2292 CT5A 0 0 0 0NE Sarpy County Station 2292 CT5B 0 0 0 0NE Sheldon 2277 1 2,168 2,190 2,106 84NE Sheldon 2277 2 2,280 2,308 2,084 224NH Merrimack 2364 1 4,288 14,634 14,113 521NH Merrimack 2364 2 9,242 27,596 26,426 1,170NH Newington 8002 1 12,103 25,764 4,967 20,797NH Schiller 2367 4 1,514 2,162 2,030 132NH Schiller 2367 5 1,457 2,072 1,997 75NH Schiller 2367 6 1,643 2,143 1,794 349NJ B L England 2378 1 3,811 14,775 13,606 1,169NJ B L England 2378 2 4,931 1,535 1,084 451NJ B L England 2378 3 2,420 1,170 817 353NJ Bergen 2398 1 1,978 6,500 0 6,500NJ Bergen 2398 2 2,044 0 0 0NJ Bergen 2398 1101 0 4 3 1NJ Bergen 2398 1201 0 3 2 1NJ Bergen 2398 1301 0 3 2 1NJ Bergen 2398 1401 0 2 1 1NJ Burlington (NJ) 2399 7 561 0 0 0NJ Burlington (NJ) 2399 101 0 2 1 1NJ Burlington (NJ) 2399 102 0 2 1 1NJ Burlington (NJ) 2399 103 0 2 0 2NJ Burlington (NJ) 2399 104 0 2 1 1NJ Burlington (NJ) 2399 121 0 8 5 3NJ Burlington (NJ) 2399 122 0 12 1 11NJ Burlington (NJ) 2399 123 0 17 13 4NJ Burlington (NJ) 2399 124 0 12 8 4NJ Butler 7152 **1 0 0 0 0NJ Deepwater 2384 1 1,164 14 0 14NJ Deepwater 2384 3 11 11 0 11A, 38APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001NJ Deepwater 2384 4 59 59 0 59NJ Deepwater 2384 5 5 5 0 5NJ Deepwater 2384 6 59 59 0 59NJ Deepwater 2384 8 2,744 3,894 3,190 704NJ Deepwater 2384 9 1,814 1,814 0 1,814NJ Gilbert 2393 1 60 60 0 60NJ Gilbert 2393 2 37 37 0 37NJ Gilbert 2393 3 700 700 0 700NJ Gilbert 2393 9 0 4 2 2NJ Gilbert 2393 04 600 596 3 593NJ Gilbert 2393 05 596 596 3 593NJ Gilbert 2393 06 593 593 3 590NJ Gilbert 2393 07 605 605 3 602NJ Hudson 2403 1 1,197 119 115 4NJ Hudson 2403 2 15,972 23,134 23,119 15NJ Kearny 2404 7 145 145 120 25NJ Kearny 2404 8 153 314 284 30NJ Linden 2406 2 644 644 298 346NJ Linden 2406 4 423 0 0 0NJ Linden 2406 5 0 11 10 1NJ Linden 2406 6 0 7 5 2NJ Linden 2406 7 0 45 32 13NJ Linden 2406 8 0 2 1 1NJ Linden 2406 11 968 968 157 811NJ Linden 2406 12 665 665 0 665NJ Linden 2406 13 877 246 179 67NJ Mercer 2408 1 7,683 8,448 8,441 7NJ Mercer 2408 2 7,439 8,375 8,370 5NJ Na 1 -- 7139 7139 **1 0 0 0 0NJ Na 2 -- 7140 7140 **1 0 0 0 0NJ Na 3 -- 7141 7141 **1 0 0 0 0NJ Na 3 -- 7141 7141 **2 0 0 0 0NJ Na 4 -- 7142 7142 **1 0 0 0 0NJ Na 5 -- 7217 7217 **1 0 0 0 0NJ Na 6 -- 7218 7218 **1 0 0 0 0NJ Pedricktown Cogen 10099 001001 0 5 5 0NJ Pedricktown Cogen 10099 005004 0 2 0 2NJ Sayreville 2390 2 2 2 0 2NJ Sayreville 2390 3 2 2 0 2NJ Sayreville 2390 5 41 41 0 41NJ Sayreville 2390 6 39 39 0 39NJ Sayreville 2390 07 766 766 0 766NJ Sayreville 2390 08 892 892 0 892NJ Sewaren 2411 1 117 117 53 64A, 39APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001NJ Sewaren 2411 2 340 40 25 15NJ Sewaren 2411 3 254 254 38 216NJ Sewaren 2411 4 574 574 45 529NJ Sewaren 2411 5 0 0 0 0NJ Sherman Avenue 7288 1 0 100 1 99NJ Werner 2385 4 194 194 0 194NM Cunningham 2454 121B 42 42 1 41NM Cunningham 2454 122B 269 265 3 262NM Cunningham 2454 123T 0 2 0 2NM Cunningham 2454 124T 0 2 0 2NM Four Corners 2442 1 3,593 3,980 3,618 362NM Four Corners 2442 2 3,589 3,989 3,629 360NM Four Corners 2442 3 4,478 4,550 4,140 410NM Four Corners 2442 4 12,507 14,515 11,935 2,580NM Four Corners 2442 5 13,275 18,211 15,011 3,200NM Maddox 2446 051B 170 170 2 168NM Milagro 54814 1 0 1 0 1NM Milagro 54814 2 0 1 0 1NM North Lovington 2473 S2 0 0 0 0NM Person 2448 3 0 0 0 0NM Person 2448 4 0 0 0 0NM Person Generating Project 55039 GT-1 0 5 2 3NM Prewitt Escalante Generating Statio 87 1 1,874 1,874 1,385 489NM Reeves 2450 1 4 4 0 4NM Reeves 2450 2 7 7 0 7NM Reeves 2450 3 104 104 0 104NM Rio Grande 2444 6 3 3 1 2NM Rio Grande 2444 7 1 1 1 0NM Rio Grande 2444 8 80 80 2 78NM San Juan 2451 1 7,941 6,629 5,543 1,086NM San Juan 2451 2 5,922 5,752 5,579 173NM San Juan 2451 3 13,878 13,878 9,117 4,761NM San Juan 2451 4 13,047 13,047 8,647 4,400NV Clark 2322 1 20 20 1 19NV Clark 2322 2 273 151 1 150NV Clark 2322 3 18 18 1 17NV El Dorado Energy 55077 CP1 (EDE1, EDE2)NV El Dorado Energy 55077 EDE1 0 3 2 1NV El Dorado Energy 55077 EDE2 0 3 2 1NV Fort Churchill 2330 1 371 371 27 344NV Fort Churchill 2330 2 577 577 100 477NV Harry Allen 7082 **5 0 0 0 0NV Harry Allen 7082 **6 0 0 0 0NV Harry Allen 7082 **3 0 1 0 1A, 40APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001NV Harry Allen 7082 **GT1 0 0 0 0NV Harry Allen 7082 **GT2 0 0 0 0NV Mohave 2341 1 26,660 26,660 20,300 6,360NV Mohave 2341 2 26,556 26,556 22,450 4,106NV North Valmy 8224 1 6,960 6,315 5,673 642NV North Valmy 8224 2 4,262 2,916 1,567 1,349NV Reid Gardner 2324 1 2,173 1,273 714 559NV Reid Gardner 2324 2 2,202 1,402 769 633NV Reid Gardner 2324 3 2,125 1,325 729 596NV Reid Gardner 2324 4 2,814 1,114 765 349NV Sunrise 2326 1 50 50 22 28NV Tracy 2336 1 15 27 27 0NV Tracy 2336 2 46 46 39 7NV Tracy 2336 3 314 295 11 284NV Tracy 2336 4 0 2 1 1NV Tracy 2336 5 0 3 1 2NV Tracy 2336 6 0 2 2 0NY 59Th Street 2503 110 64 0 0 0NY 74Th Street 2504 CS0002 (120, 121, 122)NY 74Th Street 2504 120 447 447 416 31NY 74Th Street 2504 121 449 449 417 32NY 74Th Street 2504 122 447 447 417 30NY AES Cayuga, L.L.C.(Milliken) 2535 XS12 (1, 2)NY AES Cayuga, L.L.C.(Milliken) 2535 1 4,928 6,406 4,805 1,601NY AES Cayuga, L.L.C.(Milliken) 2535 2 5,215 6,296 4,207 2,089NY AES Greenidge LLC 2527 CSG003 (4, 5)NY AES Greenidge LLC 2527 4 982 7,018 7,018 0NY AES Greenidge LLC 2527 5 980 58 57 1NY AES Greenidge LLC 2527 6 3,185 12,819 12,818 1NY AES Hickling L.L.C. 2529 CSH001 (1, 2)NY AES Hickling L.L.C. 2529 1 725 235 235 0NY AES Hickling L.L.C. 2529 2 725 725 725 0NY AES Hickling L.L.C. 2529 CSH002 (3, 4)NY AES Hickling L.L.C. 2529 3 895 550 550 0NY AES Hickling L.L.C. 2529 4 933 933 933 0NY AES Jennison, L.L.C. 2531 CSJ001 (1, 2)NY AES Jennison, L.L.C. 2531 1 650 750 750 0NY AES Jennison, L.L.C. 2531 2 676 676 676 0NY AES Jennison, L.L.C. 2531 CSJ002 (3, 4)NY AES Jennison, L.L.C. 2531 3 724 1,088 1,088 0NY AES Jennison, L.L.C. 2531 4 724 725 725 0NY AES Somerset L.L.C. 6082 1 13,889 8,770 8,296 474NY AES Westover 2526 CSW003 (11, 12)NY AES Westover 2526 11 792 5,944 5,944 0A, 41APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001NY AES Westover 2526 12 780 688 687 1NY AES Westover 2526 13 3,288 10,860 10,859 1NY Albany 2539 1 1,801 932 929 3NY Albany 2539 2 1,556 1,151 960 191NY Albany 2539 3 1,593 843 841 2NY Albany 2539 4 1,687 1,568 994 574NY Allegany Station #133 10619 00001 0 1 0 1NY Arthur Kill 2490 CS0002 (20, 30)NY Arthur Kill 2490 20 1,478 600 3 597NY Arthur Kill 2490 30 2,367 401 4 397NY Astoria 8906 10 1,216 0 0 0NY Astoria 8906 20 1,554 0 0 0NY Astoria 8906 30 3,024 475 464 11NY Astoria 8906 40 2,376 409 399 10NY Astoria 8906 50 2,700 219 214 5NY Bowline Point 2625 1 4,240 900 895 5NY Bowline Point 2625 2 4,241 581 575 6NY Brooklyn Navy Yard Cogeneration Fac 54914 1 0 0 12 -12NY Brooklyn Navy Yard Cogeneration Fac 54914 2 0 0 6 -6NY Carthage Energy, LLC 10620 1 0 2 2 0NY CH Resources - Niagara Falls 50202 1 0 1,190 1,105 85NY CH Resources - Syracuse 10621 1 0 10 7 3NY Charles Poletti 2491 001 6,438 6,238 2,337 3,901NY Dunkirk 2554 1 2,843 11,001 11,001 0NY Dunkirk 2554 2 3,229 11,633 11,652 -19NY Dunkirk 2554 CS0003 (3, 4)NY Dunkirk 2554 3 5,292 15,527 15,527 0NY Dunkirk 2554 4 5,906 17,597 16,528 1,069NY Dynegy Danskammer, LLC 2480 1 948 156 151 5NY Dynegy Danskammer, LLC 2480 2 920 200 195 5NY Dynegy Danskammer, LLC 2480 3 3,129 3,614 3,609 5NY Dynegy Danskammer, LLC 2480 4 6,030 8,475 8,470 5NY Dynegy Roseton, LLC 8006 1 15,584 14,966 7,408 7,558NY Dynegy Roseton, LLC 8006 2 14,912 14,294 9,256 5,038NY E F Barrett 2511 10 2,372 2,372 133 2,239NY E F Barrett 2511 20 2,337 2,337 370 1,967NY East River 2493 50 1,396 0 0 0NY East River 2493 60 1,430 1,430 259 1,171NY East River 2493 70 1,033 1,033 276 757NY Far Rockaway 2513 40 469 469 1 468NY Glenwood 2514 40 939 939 1 938NY Glenwood 2514 50 903 903 1 902NY Huntley Power 2549 CS0002 (63, 64, 65, 66)NY Huntley Power 2549 63 2,657 3,790 3,790 0A, 42APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001NY Huntley Power 2549 64 2,664 8,397 8,397 0NY Huntley Power 2549 65 2,693 5,592 5,592 0NY Huntley Power 2549 66 2,729 3,651 3,657 -6NY Huntley Power 2549 CS0001 (67, 68)NY Huntley Power 2549 67 5,775 16,004 16,004 0NY Huntley Power 2549 68 5,381 15,971 14,862 1,109NY Lovett 2629 3 225 225 14 211NY Lovett 2629 4 4,569 5,019 5,011 8NY Lovett 2629 5 4,988 4,888 4,879 9NY Northport 2516 1 8,323 23,048 7,396 15,652NY Northport 2516 2 10,130 12,096 4,522 7,574NY Northport 2516 3 11,122 30,518 9,661 20,857NY Northport 2516 4 5,794 18,539 4,070 14,469NY Oswego 2594 1 0 0 0 0NY Oswego 2594 2 0 0 0 0NY Oswego 2594 3 90 0 0 0NY Oswego 2594 4 398 0 0 0NY Oswego 2594 5 17,242 1,492 1,502 -10NY Oswego 2594 6 4,808 4,767 216 4,551NY Port Jefferson 2517 1 475 475 0 475NY Port Jefferson 2517 2 498 498 0 498NY Port Jefferson 2517 3 4,397 12,300 3,085 9,215NY Port Jefferson 2517 4 5,181 19,002 4,220 14,782NY Ravenswood 2500 10 3,165 401 2 399NY Ravenswood 2500 20 2,678 901 384 517NY Ravenswood 2500 30 4,992 2,702 1,570 1,132NY Richard M Flynn 7314 001 0 200 99 101NY Rochester 3, Beebee Station 2640 1 0 0 0 0NY Rochester 3, Beebee Station 2640 2 0 0 0 0NY Rochester 3, Beebee Station 2640 3 2 0 0 0NY Rochester 3, Beebee Station 2640 4 0 0 0 0NY Rochester 3, Beebee Station 2640 7 201 0 0 0NY Rochester 3, Beebee Station 2640 8 0 0 0 0NY Rochester 3, Beebee Station 2640 12 2,269 0 0 0NY Rochester 7, Russell Station 2642 CS1 (1, 2)NY Rochester 7, Russell Station 2642 1 1,093 5,632 5,560 72NY Rochester 7, Russell Station 2642 2 1,626 5,609 5,561 48NY Rochester 7, Russell Station 2642 CS2 (3, 4)NY Rochester 7, Russell Station 2642 3 1,586 7,375 7,195 180NY Rochester 7, Russell Station 2642 4 2,213 7,335 7,195 140NY S A Carlson 2682 CS0001 (9, 12)NY S A Carlson 2682 9 664 664 659 5NY S A Carlson 2682 CS0002 (10, 11)NY S A Carlson 2682 10 673 673 673 0A, 43APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001NY S A Carlson 2682 11 424 847 847 0NY S A Carlson 2682 12 1,276 1,053 912 141NY South Glens Falls Energy, LLC 10618 1 0 3 2 1NY Waterside 2502 41 252 0 0 0NY Waterside 2502 42 247 0 0 0NY Waterside 2502 51 416 0 0 0NY Waterside 2502 52 417 0 0 0NY Waterside 2502 CS0002 (61, 62)NY Waterside 2502 61 431 431 3 428NY Waterside 2502 62 507 507 3 504NY Waterside 2502 CS0003 (80, 90)NY Waterside 2502 80 1,128 1,128 2 1,126NY Waterside 2502 90 1,234 1,234 3 1,231OH Acme2877 9 1 0 0 0OH Acme2877 11 7 0 0 0OH Acme2877 13 1,846 0 0 0OH Acme2877 14 2,519 0 0 0OH Acme2877 15 3,365 0 0 0OH Acme2877 16 2,421 0 0 0OH Acme2877 91 2,012 0 0 0OH Acme2877 92 1,800 0 0 0OH AMP-Ohio Bowling Green 7783 P001 0 1 0 1OH AMP-Ohio Hamilton 7782 P001 0 1 0 1OH Ashtabula 2835 7 7,220 4,403 3,647 756OH Ashtabula 2835 CS1 (8, 9, 10, 11)OH Ashtabula 2835 8 2,337 800 737 63OH Ashtabula 2835 9 1,990 0 0 0OH Ashtabula 2835 10 1,795 2,141 2,044 97OH Ashtabula 2835 11 1,890 1,519 1,433 86OH Avon Lake 2836 9 2,567 0 0 0OH Avon Lake 2836 10 2,254 2,800 2,724 76OH Avon Lake 2836 11 5,025 0 0 0OH Avon Lake 2836 12 15,199 20,000 19,372 628OH Bay Shore 2878 XS14 (1, 2, 3, 4)OH Bay Shore 2878 1 4,719 796 761 35OH Bay Shore 2878 2 4,495 2,488 2,392 96OH Bay Shore 2878 3 4,277 2,229 2,139 90OH Bay Shore 2878 4 7,038 3,885 3,770 115OH Cardinal 2828 1 14,778 71,986 69,884 2,102OH Cardinal 2828 2 16,526 47,289 26,698 20,591OH Cardinal 2828 3 17,301 23,460 22,772 688OH Conesville 2840 CS012 (1, 2)OH Conesville 2840 1 1,814 17,076 16,578 498OH Conesville 2840 2 2,110 15,173 14,730 443A, 44APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001OH Conesville 2840 3 2,370 16,843 16,351 492OH Conesville 2840 4 21,031 77,478 76,277 1,201OH Conesville 2840 CS056 (5, 6)OH Conesville 2840 5 9,025 7,483 7,263 220OH Conesville 2840 6 9,394 6,947 6,741 206OH Dover 2914 **6 153 0 0 0OH Eastlake 2837 1 3,366 4,953 4,855 98OH Eastlake 2837 2 3,725 5,338 5,284 54OH Eastlake 2837 3 4,319 7,025 6,955 70OH Eastlake 2837 4 6,258 8,946 8,855 91OH Eastlake 2837 5 16,605 37,017 36,646 371OH Edgewater 2857 11 878 0 0 0OH Edgewater 2857 12 947 0 0 0OH Edgewater 2857 13 2,179 113 11 102OH Frank M Tait 2847 1 0 4 0 4OH Frank M Tait 2847 2 0 4 0 4OH Frank M Tait 2847 3 0 4 0 4OH Gen J M Gavin 8102 1 34,099 12,763 12,381 382OH Gen J M Gavin 8102 2 34,738 12,697 12,314 383OH Gorge 2858 25 1,498 0 0 0OH Gorge 2858 26 1,677 0 0 0OH Greenville Electric Gen Station 55228 G1CT1 0 0 0 0OH Greenville Electric Gen Station 55228 G1CT2 0 0 0 0OH Greenville Electric Gen Station 55228 G2CT1 0 0 0 0OH Greenville Electric Gen Station 55228 G2CT2 0 0 0 0OH Greenville Electric Gen Station 55228 G3CT1 0 0 0 0OH Greenville Electric Gen Station 55228 G3CT2 0 0 0 0OH Greenville Electric Gen Station 55228 G4CT1 0 0 0 0OH Greenville Electric Gen Station 55228 G4CT2 0 0 0 0OH Hamilton 2917 9 1,665 1,665 997 668OH J M Stuart 2850 1 19,632 45,673 29,043 16,630OH J M Stuart 2850 2 18,611 38,922 28,501 10,421OH J M Stuart 2850 3 18,454 39,008 22,686 16,322OH J M Stuart 2850 4 19,503 40,571 25,425 15,146OH Killen Station 6031 2 16,928 24,937 24,636 301OH Kyger Creek 2876 CS001 (1, 2, 3, 4, 5)OH Kyger Creek 2876 1 8,100 25,736 25,238 498OH Kyger Creek 2876 2 7,797 25,736 25,238 498OH Kyger Creek 2876 3 7,524 25,736 25,238 498OH Kyger Creek 2876 4 7,860 25,736 25,238 498OH Kyger Creek 2876 5 7,874 25,736 25,238 498OH Lake Road 2908 6 1,340 1,340 0 1,340OH Lake Shore 2838 18 6,033 1,302 1,238 64OH Lake Shore 2838 91 47 0 0 0A, 45APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001OH Lake Shore 2838 92 84 0 0 0OH Lake Shore 2838 93 65 0 0 0OH Lake Shore 2838 94 107 0 0 0OH Madison Generating Station 55110 1 0 4 0 4OH Madison Generating Station 55110 2 0 4 0 4OH Madison Generating Station 55110 3 0 4 0 4OH Madison Generating Station 55110 4 0 4 0 4OH Madison Generating Station 55110 5 0 4 0 4OH Madison Generating Station 55110 6 0 4 0 4OH Madison Generating Station 55110 7 0 4 0 4OH Madison Generating Station 55110 8 0 4 0 4OH Miami Fort 2832 CS056 (5-1, 5-2, 6)OH Miami Fort 2832 6 4,908 20,521 16,671 3,850OH Miami Fort 2832 7 16,607 40,929 39,663 1,266OH Miami Fort 2832 8 18,233 19,418 18,801 617OH Miami Fort 2832 5-1 144 3,342 3,189 153OH Miami Fort 2832 5-2 144 3,341 3,189 152OH Muskingum River 2872 CS014 1, 2, 3, 4)OH Muskingum River 2872 1 6,414 31,148 30,239 909OH Muskingum River 2872 2 6,108 30,348 29,462 886OH Muskingum River 2872 3 6,018 37,158 36,074 1,084OH Muskingum River 2872 4 5,080 37,583 36,487 1,096OH Muskingum River 2872 5 17,450 25,495 23,776 1,719OH Niles 2861 XS12 (1, 2)OH Niles 2861 1 2,995 5,925 5,824 101OH Niles 2861 2 3,924 14,444 14,013 431OH O H Hutchings 2848 CS0001 (H-1, H-2)OH O H Hutchings 2848 H-1 1,736 594 589 5OH O H Hutchings 2848 H-2 1,671 538 531 7OH O H Hutchings 2848 CS0002 (H-3, H-4)OH O H Hutchings 2848 H-3 1,603 1,421 1,402 19OH O H Hutchings 2848 H-4 1,623 1,340 1,323 17OH O H Hutchings 2848 CS0003 (H-5, H-6)OH O H Hutchings 2848 H-5 1,630 1,338 1,326 12OH O H Hutchings 2848 H-6 1,660 1,499 1,486 13OH Picway 2843 9 2,128 10,879 10,563 316OH Poston 2844 1 787 0 0 0OH Poston 2844 2 731 0 0 0OH Poston 2844 3 957 0 0 0OH R E Burger 2864 CS0001 (1, 2, 3, 4, 5, 6, 7, 8)OH R E Burger 2864 1 1,233 0 0 0OH R E Burger 2864 2 1,206 0 0 0OH R E Burger 2864 3 1,246 0 0 0OH R E Burger 2864 4 1,275 0 0 0A, 46APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001OH R E Burger 2864 5 1,327 722 709 13OH R E Burger 2864 6 1,325 799 756 43OH R E Burger 2864 7 4,648 25,538 25,275 263OH R E Burger 2864 8 5,361 33,218 20,504 12,714OH Refuse & Coal 312 CSSA12 (001, 002)OH Refuse & Coal 312 001 426 0 0 0OH Refuse & Coal 312 002 381 0 0 0OH Refuse & Coal 312 CSSA34 (003, 004)OH Refuse & Coal 312 003 402 0 0 0OH Refuse & Coal 312 004 438 0 0 0OH Refuse & Coal 312 CSSA56 (005, 006)OH Refuse & Coal 312 005 375 0 0 0OH Refuse & Coal 312 006 366 0 0 0OH Richard Gorsuch 7253 CS0001 (1, 2, 3, 4)OH Richard Gorsuch 7253 1 6,152 9,285 8,428 857OH Richard Gorsuch 7253 2 5,064 9,285 8,428 857OH Richard Gorsuch 7253 3 6,880 9,285 8,428 857OH Richard Gorsuch 7253 4 1,404 9,283 8,428 855OH Tidd 2828 **1 714 0 0 0OH Toronto 2867 9 1,873 0 0 0OH Toronto 2867 10 3,343 0 0 0OH Toronto 2867 11 3,612 0 0 0OH W H Sammis2866 CS0001 (1, 2)OH W H Sammis2866 1 6,239 12,468 12,342 126OH W H Sammis2866 2 5,472 13,081 12,950 131OH W H Sammis2866 CS0002 (3, 4)OH W H Sammis2866 3 6,238 12,713 12,576 137OH W H Sammis2866 4 5,529 11,764 11,656 108OH W H Sammis2866 5 10,422 21,507 21,291 216OH W H Sammis2866 6 19,953 25,976 25,713 263OH W H Sammis2866 7 18,639 24,339 24,092 247OH W H Zimmer6019 1 16,154 21,465 19,411 2,054OH Walter C Beckjord 2830 1 1,834 4,657 4,437 220OH Walter C Beckjord 2830 2 1,859 5,163 4,941 222OH Walter C Beckjord 2830 3 2,530 8,110 7,753 357OH Walter C Beckjord 2830 4 3,262 8,081 7,722 359OH Walter C Beckjord 2830 5 3,858 16,870 16,139 731OH Walter C Beckjord 2830 6 9,925 38,017 30,442 7,575OH Woodsdale 7158 **GT1 294 294 0 294OH Woodsdale 7158 **GT2 294 294 0 294OH Woodsdale 7158 **GT3 294 294 0 294OH Woodsdale 7158 **GT4 294 294 0 294OH Woodsdale 7158 **GT5 294 294 0 294OH Woodsdale 7158 **GT6 294 294 0 294A, 47APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001OH Woodsdale 7158 **GT7 0 0 0 0OH Woodsdale 7158 **GT8 0 0 0 0OH Woodsdale 7158 **GT9 0 0 0 0OH Woodsdale 7158 **GT10 0 0 0 0OH Woodsdale 7158 **GT11 0 0 0 0OH Woodsdale 7158 **GT12 0 0 0 0OK Anadarko 3006 3 0 1 0 1OK Arbuckle 2947 ARB 45 45 0 45OK Chouteau Power Plant 7757 1 0 76 1 75OK Chouteau Power Plant 7757 2 0 75 0 75OK Comanche 8059 7251 333 323 2 321OK Comanche 8059 7252 2 12 3 9OK Conoco 7185 **1 222 222 6 216OK Conoco 7185 **2 222 222 12 210OK Grda 165 1 14,642 15,633 15,516 117OK Grda 165 2 8,396 7,405 4,877 2,528OK Horseshoe Lake 2951 6 173 173 3 170OK Horseshoe Lake 2951 7 231 231 4 227OK Horseshoe Lake 2951 8 313 253 1 252OK Horseshoe Lake 2951 9 0 30 0 30OK Horseshoe Lake 2951 10 0 30 0 30OK Hugo 6772 1 11,877 9,377 7,379 1,998OK Mooreland 3008 1 0 1 0 1OK Mooreland 3008 2 44 42 1 41OK Mooreland 3008 3 7 7 1 6OK Muskogee 2952 3 141 141 1 140OK Muskogee 2952 4 9,311 9,811 9,359 452OK Muskogee 2952 5 8,277 11,277 10,327 950OK Muskogee 2952 6 14,425 10,925 9,731 1,194OK Mustang 2953 1 32 32 0 32OK Mustang 2953 2 26 26 0 26OK Mustang 2953 3 1 1 1 0OK Mustang 2953 4 163 163 2 161OK Na 1 -- 5030 5030 **1 0 0 0 0OK Na 1 -- 5030 5030 **2 0 0 0 0OK Na 1 -- 5030 5030 **3 0 0 0 0OK Northeastern 2963 3301 1,742 1,742 1 1,741OK Northeastern 2963 3302 5,935 5,935 4 5,931OK Northeastern 2963 CS100 (3313, 3314)OK Northeastern 2963 3313 13,833 13,833 8,842 4,991OK Northeastern 2963 3314 14,884 14,884 8,843 6,041OK Ponca 762 2 0 0 0 0OK Ponca 762 3 0 0 0 0OK Riverside 4940 1501 519 489 286 203A, 48APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001OK Riverside 4940 1502 285 315 304 11OK Seminole 2956 1 412 412 4 408OK Seminole 2956 2 453 453 4 449OK Seminole 2956 3 494 494 5 489OK Sooner 6095 1 10,471 10,471 8,944 1,527OK Sooner 6095 2 9,979 9,979 8,923 1,056OK Southwestern 2964 CP001(8002,8003,801N,801S)OK Southwestern 2964 8002 15 15 0 15OK Southwestern 2964 8003 164 164 28 136OK Southwestern 2964 801N 3 3 0 3OK Southwestern 2964 801S 0 0 0 0OK Tulsa 2965 CP001(1402,1403,1404)OK Tulsa 2965 1402 98 98 1 97OK Tulsa 2965 1403 4 4 0 4OK Tulsa 2965 1404 58 58 0 58OR Boardman 6106 1SG 13,377 14,375 14,374 1OR Coyote Springs 7350 CTG1 0 4 4 0OR Hermiston 54761 1 0 7 4 3OR Hermiston 54761 2 0 7 4 3PA Allegheny Energy Unit 1 and Unit 2 55196 1 0 1 0 1PA Allegheny Energy Unit 1 and Unit 2 55196 2 0 1 0 1PA Allegheny Energy Unit 8 and Unit 9 55377 8 0 1 0 1PA Allegheny Energy Unit 8 and Unit 9 55377 9 0 1 0 1PA Armstrong 3178 1 6,215 17,621 17,421 200PA Armstrong 3178 2 6,654 17,166 16,966 200PA Bruce Mansfield 6094 1 12,717 14,134 8,549 5,585PA Bruce Mansfield 6094 2 14,069 14,793 8,380 6,413PA Bruce Mansfield 6094 3 14,473 14,473 12,133 2,340PA Brunner Island 3140 CS102 (1, 2)PA Brunner Island 3140 1 11,972 14,701 14,679 22PA Brunner Island 3140 2 13,414 17,371 17,307 64PA Brunner Island 3140 3 23,209 28,957 28,911 46PA Cheswick 8226 1 16,891 46,544 44,908 1,636PA Conemaugh 3118 1 25,938 10,764 3,119 7,645PA Conemaugh 3118 2 28,752 11,198 3,988 7,210PA Cromby 3159 1 2,203 4,668 3,971 697PA Cromby 3159 2 2,110 2,110 955 1,155PA Delaware 3160 71 743 743 189 554PA Delaware 3160 81 537 1,071 220 851PA Eddystone 3161 1 2,845 3,851 2,915 936PA Eddystone 3161 2 3,005 4,241 3,668 573PA Eddystone 3161 CS034 (3, 4)PA Eddystone 3161 3 1,895 1,895 1,252 643PA Eddystone 3161 4 2,011 2,011 1,202 809A, 49APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001PA Elrama 3098 CS001 (1, 2, 3, 4)PA Elrama 3098 1 1,650 910 889 21PA Elrama 3098 2 1,616 700 683 17PA Elrama 3098 3 1,568 555 543 12PA Elrama 3098 4 2,580 2,580 2,519 61PA F R Phillips 3099 CS001 (1, 2, 3, 4, 5, 6)PA F R Phillips 3099 1 663 0 0 0PA F R Phillips 3099 2 504 0 0 0PA F R Phillips 3099 3 1,165 0 0 0PA F R Phillips 3099 4 1,112 0 0 0PA F R Phillips 3099 5 1,131 0 0 0PA F R Phillips 3099 6 2,022 0 0 0PA Front Street 3121 7 294 0 0 0PA Front Street 3121 8 294 0 0 0PA Front Street 3121 9 1,176 0 0 0PA Front Street 3121 10 1,176 0 0 0PA Grays Ferry Cogen 54785 2 0 9 9 0PA Hatfields Ferry 3179 XS123 (1, 2, 3)PA Hatfields Ferry 3179 1 16,313 56,715 56,115 600PA Hatfields Ferry 3179 2 16,094 56,690 56,090 600PA Hatfields Ferry 3179 3 17,365 54,090 53,490 600PA Holtwood 3145 17 3,571 1 0 1PA Homer City 3122 1 17,759 61,674 52,865 8,809PA Homer City 3122 2 16,314 51,007 50,539 468PA Homer City 3122 3 27,629 28,362 27,865 497PA Hunlock Power 3176 6 2,257 3,578 3,576 2PA Keystone 3136 1 28,219 77,886 77,479 407PA Keystone 3136 2 30,045 76,366 76,011 355PA Martins Creek 3148 CS102 (1, 2)PA Martins Creek 3148 1 5,457 9,919 8,822 1,097PA Martins Creek 3148 2 5,528 10,630 9,953 677PA Martins Creek 3148 3 13,183 4,180 4,168 12PA Martins Creek 3148 4 12,127 2,792 2,757 35PA Mitchell 3181 1 0 37 17 20PA Mitchell 3181 2 1 50 30 20PA Mitchell 3181 3 0 44 24 20PA Mitchell 3181 33 5,495 1,356 1,256 100PA Montour 3149 1 24,191 58,361 58,244 117PA Montour 3149 2 24,680 49,795 49,723 72PA New Castle 3138 1 1,292 0 0 0PA New Castle 3138 2 1,439 0 0 0PA New Castle 3138 3 2,843 7,871 7,612 259PA New Castle 3138 4 2,817 8,294 8,018 276PA New Castle 3138 5 4,514 9,335 9,029 306A, 50APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001PA Portland 3113 1 2,560 9,056 9,036 20PA Portland 3113 2 4,413 11,265 11,260 5PA Portland 3113 5 0 2 1 1PA Richmond 3168 63 0 0 0 0PA Richmond 3168 64 0 0 0 0PA Schuylkill 3169 1 572 572 128 444PA Seward 3130 CS2 (12, 14, 15)PA Seward 3130 12 1,096 1,096 1,093 3PA Seward 3130 14 1,096 1,217 1,212 5PA Seward 3130 15 5,002 8,593 8,588 5PA Shawville 3131 1 4,430 9,478 9,473 5PA Shawville 3131 2 4,456 10,956 10,951 5PA Shawville 3131 CS1 (3, 4)PA Shawville 3131 3 6,111 12,806 12,801 5PA Shawville 3131 4 6,070 15,033 15,028 5PA Southwark 3170 11 0 0 0 0PA Southwark 3170 12 0 0 0 0PA Southwark 3170 21 0 0 0 0PA Southwark 3170 22 0 0 0 0PA Springdale 3182 77 0 0 0 0PA Springdale 3182 88 0 0 0 0PA Sunbury 3152 3 4,029 16,527 8,005 8,522PA Sunbury 3152 4 5,250 9,654 7,806 1,848PA Sunbury 3152 CS1 (1A, 1B)PA Sunbury 3152 1A 1,818 3,718 3,436 282PA Sunbury 3152 1B 1,817 3,582 3,382 200PA Sunbury 3152 CS2 (2A, 2B)PA Sunbury 3152 2A 1,818 2,818 2,708 110PA Sunbury 3152 2B 1,818 3,018 2,735 283PA Titus 3115 1 2,150 5,459 5,454 5PA Titus 3115 2 2,272 4,858 4,853 5PA Titus 3115 3 2,195 4,991 4,986 5PA Warren 3132 CS3 (1, 2, 3, 4)PA Warren 3132 1 720 525 502 23PA Warren 3132 2 720 584 579 5PA Warren 3132 3 740 876 873 3PA Warren 3132 4 740 935 930 5PA Westwood 50611 031 0 350 293 57PA Williamsburg 3135 11 935 935 0 935RI Manchester Street 3236 6 693 0 0 0RI Manchester Street 3236 7 458 0 0 0RI Manchester Street 3236 9 0 7 2 5RI Manchester Street 3236 10 0 7 2 5RI Manchester Street 3236 11 0 7 2 5A, 51APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001RI Manchester Street 3236 12 512 0 0 0RI South Street 3238 121 1,086 0 0 0RI South Street 3238 122 946 0 0 0RI Tiverton 55048 1 0 33 1 32SC Broad River Energy Center (I) 55166 CT-1 0 6 1 5SC Broad River Energy Center (I) 55166 CT-2 0 4 2 2SC Broad River Energy Center (I) 55166 CT-3 0 3 1 2SC Canadys Steam 3280 CAN1 3,248 10,432 5,085 5,347SC Canadys Steam 3280 CAN2 2,979 9,976 5,727 4,249SC Canadys Steam 3280 CAN3 4,223 12,324 7,855 4,469SC Cherokee County Cogen 55043 CCCP1 0 4 1 3SC Cope Station 7210 COP1 2,616 4,884 2,012 2,872SC Cross 130 1 5,603 4,175 2,725 1,450SC Cross 130 2 8,941 10,109 9,728 381SC Darlington County 3250 12 0 10 6 4SC Darlington County 3250 13 0 10 6 4SC Dolphus M Grainger 3317 1 3,114 4,820 4,581 239SC Dolphus M Grainger 3317 2 277 4,054 3,963 91SC H B Robinson 3251 1 3,815 7,995 7,894 101SC Hagood 3285 HAG1 3 0 0 0SC Hagood 3285 HAG2 451 0 0 0SC Hagood 3285 HAG3 787 0 0 0SC Hagood 3285 HAG4 948 982 34 948SC Jefferies 3319 1 0 656 314 342SC Jefferies 3319 2 1 692 367 325SC Jefferies 3319 3 3,886 10,622 9,698 924SC Jefferies 3319 4 3,743 10,991 8,955 2,036SC Mcmeekin 3287 MCM1 4,080 21,805 6,776 15,029SC Mcmeekin 3287 MCM2 4,038 13,915 7,380 6,535SC Na 1 -- 7106 7106 **GT1 0 0 0 0SC Urquhart 3295 URQ1 2,195 7,249 3,852 3,397SC Urquhart 3295 URQ2 1,927 6,957 4,092 2,865SC Urquhart 3295 URQ3 2,914 10,285 6,043 4,242SC Urquhart 3295 URQ4 0 3 3 0SC W S Lee 3264 1 3,381 2,582 2,347 235SC W S Lee 3264 2 3,727 2,995 2,721 274SC W S Lee 3264 3 6,800 5,631 5,203 428SC Wateree 3297WAT1 9,717 19,225 16,126 3,099SC Wateree 3297WAT2 9,270 27,923 15,058 12,865SC Williams3298WIL1 15,821 24,517 24,205 312SC Winyah 6249 1 7,574 21,442 19,646 1,796SC Winyah 6249 2 6,234 9,818 9,235 583SC Winyah 6249 3 3,610 4,998 4,737 261SC Winyah 6249 4 3,427 4,008 3,924 84A, 52APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001SD Angus Anson 7237 2 851 851 3 848SD Angus Anson 7237 3 1,020 1,020 2 1,018SD Big Stone 6098 1 13,715 13,780 13,528 252SD Huron 3344 **2A 80 5 0 5SD Huron 3344 **2B 103 3 0 3SD Pathfinder 3334 11 11 11 0 11SD Pathfinder 3334 12 2 2 0 2SD Pathfinder 3334 13 2 2 0 2TN Allen 3393 1 6,608 27,049 6,462 20,587TN Allen 3393 2 7,231 22,894 7,536 15,358TN Allen 3393 3 6,756 23,901 4,864 19,037TN Brownsville Power I, LLC 2387 AA-001 0 1 0 1TN Brownsville Power I, LLC 2387 AA-002 0 1 0 1TN Brownsville Power I, LLC 2387 AA-003 0 1 0 1TN Brownsville Power I, LLC 2387 AA-004 0 1 0 1TN Bull Run 3396 1 25,047 39,513 36,669 2,844TN Cumberland 3399 1 37,386 123,716 8,995 114,721TN Cumberland 3399 2 40,896 150,697 10,861 139,836TN DuPont Johnsonville 880001 JVD1 1,778 0 0 0TN DuPont Johnsonville 880001 JVD2 1,778 0 0 0TN DuPont Johnsonville 880001 JVD3 1,777 0 0 0TN DuPont Johnsonville 880001 JVD4 1,777 0 0 0TN Gallatin 3403 CSGA12 (1, 2)TN Gallatin 3403 1 7,605 18,339 17,181 1,158TN Gallatin 3403 2 7,464 18,864 17,070 1,794TN Gallatin 3403 CSGA34 (3, 4)TN Gallatin 3403 3 8,635 21,881 19,860 2,021TN Gallatin 3403 4 9,168 26,361 24,189 2,172TN Gallatin 3403 GCT5 0 500 3 497TN Gallatin 3403 GCT6 0 500 2 498TN Gallatin 3403 GCT7 0 500 3 497TN Gallatin 3403 GCT8 0 500 2 498TN Gleason Generating Facility LLC 55251 CTG-1 0 2 0 2TN Gleason Generating Facility LLC 55251 CTG-2 0 2 0 2TN Gleason Generating Facility LLC 55251 CTG-3 0 2 0 2TN John Sevier 3405 CSJS12 (1, 2)TN John Sevier 3405 1 6,361 16,361 14,071 2,290TN John Sevier 3405 2 6,358 16,858 14,253 2,605TN John Sevier 3405 CSJS34 (3, 4)TN John Sevier 3405 3 6,519 14,019 12,886 1,133TN John Sevier 3405 4 6,669 15,669 14,690 979TN Johnsonville 3406 CSJO10 (1, 2, 3, 4, 5, 6, 7, 8, 9, 10)TN Johnsonville 3406 1 3,358 13,610 11,992 1,618TN Johnsonville 3406 2 3,465 13,874 12,044 1,830A, 53APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001TN Johnsonville 3406 3 3,628 13,340 11,608 1,732TN Johnsonville 3406 4 3,443 13,307 11,774 1,533TN Johnsonville 3406 5 3,553 11,650 10,460 1,190TN Johnsonville 3406 6 3,404 12,806 10,987 1,819TN Johnsonville 3406 7 3,871 14,212 12,436 1,776TN Johnsonville 3406 8 3,753 15,128 13,250 1,878TN Johnsonville 3406 9 3,052 14,422 11,758 2,664TN Johnsonville 3406 10 3,256 14,079 12,114 1,965TN Johnsonville 3406 JCT17 0 500 1 499TN Johnsonville 3406 JCT18 0 500 1 499TN Johnsonville 3406 JCT19 0 500 1 499TN Johnsonville 3406 JCT20 0 500 1 499TN Kingston 3407 CSKI15 (1, 2, 3, 4, 5)TN Kingston 3407 1 4,152 10,652 9,225 1,427TN Kingston 3407 2 3,992 10,492 9,399 1,093TN Kingston 3407 3 4,751 11,751 10,086 1,665TN Kingston 3407 4 5,041 9,541 8,226 1,315TN Kingston 3407 5 6,194 12,694 11,498 1,196TN Kingston 3407 CSKI69 (6, 7, 8, 9)TN Kingston 3407 6 6,347 12,347 11,426 921TN Kingston 3407 7 6,189 12,189 10,895 1,294TN Kingston 3407 8 5,784 14,284 13,325 959TN Kingston 3407 9 6,405 14,405 12,872 1,533TN Watts Bar3419 A 0 0 0 0TN Watts Bar3419 B 0 0 0 0TN Watts Bar3419 C 0 0 0 0TN Watts Bar3419 D 0 0 0 0TX Barney M. Davis 4939 1 496 456 149 307TX Barney M. Davis 4939 2 398 438 426 12TX Bay Port 10298 CG801 0 0 0 0TX Bay Port 10298 CG802 0 0 0 0TX Bay Port 10298 CG803 0 0 0 0TX Bay Port 10298 CG804 0 0 0 0TX Big Brown 3497 1 20,985 42,985 42,401 584TX Big Brown 3497 2 19,878 44,093 43,590 503TX Blackhawk Station 55064 001 0 5 3 2TX Blackhawk Station 55064 002 0 5 3 2TX Bosque County Power Plant 55172 GT-1 0 5 1 4TX Bosque County Power Plant 55172 GT-2 0 5 0 5TX Bryan 3561 6 19 19 2 17TX C E Newman 3574 BW5 3 3 2 1TX Cedar Bayou 3460 CBY1 814 814 102 712TX Cedar Bayou 3460 CBY2 921 921 194 727TX Cedar Bayou 3460 CBY3 725 725 63 662A, 54APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001TX Cleburne Cogeneration Facility 54817 EAST 0 5 4 1TX Cleburne Cogeneration Facility 54817WEST 0 0 0 0TX Coleto Creek 6178 1 14,721 14,741 14,721 20TX Coleto Creek 6178 **2 0 0 0 0TX Collin 3500 1 92 62 5 57TX Concho 3518 7 11 11 0 11TX Dallas 3451 3 27 0 0 0TX Dallas 3451 9 26 0 0 0TX Dansby 6243 1 94 94 6 88TX Decker Creek 3548 1 128 128 10 118TX Decker Creek 3548 2 195 195 22 173TX Decordova 8063 1 1,018 218 69 149TX Deepwater 3461 DWP1 0 0 0 0TX Deepwater 3461 DWP2 0 0 0 0TX Deepwater 3461 DWP3 0 0 0 0TX Deepwater 3461 DWP4 0 0 0 0TX Deepwater 3461 DWP5 0 0 0 0TX Deepwater 3461 DWP6 0 0 0 0TX Deepwater 3461 DWP7 0 0 0 0TX Deepwater 3461 DWP8 0 0 0 0TX Deepwater 3461 DWP9 28 28 1 27TX Denver City 3480 6 0 0 0 0TX E S Joslin 3436 1 260 260 52 208TX Eagle Mountain 3489 1 52 52 1 51TX Eagle Mountain 3489 2 140 90 23 67TX Eagle Mountain 3489 3 100 60 2 58TX Forest Grove 6148 **1 0 0 0 0TX Fort Phantom 4938 1 126 136 125 11TX Fort Phantom 4938 2 187 177 56 121TX Frontera Power Facility 55098 1 0 8 2 6TX Frontera Power Facility 55098 2 0 8 2 6TX Generic Stat 7235 **1 0 0 0 0TX Generic Stat 7235 **2 0 0 0 0TX Gibbons Creek 6136 1 14,414 12,567 11,639 928TX Graham 3490 1 235 135 57 78TX Graham 3490 2 496 446 377 69TX Greens Bayou 3464 GBY1 1 1 0 1TX Greens Bayou 3464 GBY2 2 2 0 2TX Greens Bayou 3464 GBY3 15 15 0 15TX Greens Bayou 3464 GBY4 19 19 0 19TX Greens Bayou 3464 GBY5 352 352 13 339TX Gregory Power Facility 55086 101 0 5 2 3TX Gregory Power Facility 55086 102 0 5 2 3TX Handley 3491 2 21 21 1 20A, 55APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001TX Handley 3491 3 423 73 4 69TX Handley 3491 4 118 468 102 366TX Handley 3491 5 136 106 34 72TX Handley 3491 1A 7 7 0 7TX Handley 3491 1B 0 0 0 0TX Harrington Station 6193 061B 8,234 9,018 8,818 200TX Harrington Station 6193 062B 8,721 8,621 8,303 318TX Harrington Station 6193 063B 9,269 8,585 8,361 224TX Hidalgo Energy Facility 7762 HRSG1 0 2 1 1TX Hidalgo Energy Facility 7762 HRSG2 0 2 1 1TX Hiram Clarke 3465 HOC1 0 0 0 0TX Hiram Clarke 3465 HOC2 0 0 0 0TX Hiram Clarke 3465 HOC3 3 3 0 3TX Hiram Clarke 3465 HOC4 2 2 0 2TX Holly Ave 3602 1 59 59 1 58TX Holly Ave 3602 2 71 71 1 70TX Holly Street 3549 1 49 49 0 49TX Holly Street 3549 2 31 31 0 31TX Holly Street 3549 3 68 68 2 66TX Holly Street 3549 4 43 43 2 41TX J K Spruce 7097 **1 6,692 6,692 3,642 3,050TX J K Spruce 7097 **2 0 0 0 0TX J L Bates 3438 1 48 48 28 20TX J L Bates 3438 2 124 124 25 99TX J T Deely 6181 CS012 (1, 2)TX J T Deely 6181 1 13,136 13,136 9,802 3,334TX J T Deely 6181 2 13,705 13,705 9,803 3,902TX J. Robert Massengale Generating 3604 GT1 0 0 0 0TX Jones Station 3482 151B 125 124 4 120TX Jones Station 3482 152B 93 93 27 66TX Knox Lee 3476 2 0 5 0 5TX Knox Lee 3476 3 5 5 0 5TX Knox Lee 3476 4 29 24 0 24TX Knox Lee 3476 5 251 251 145 106TX La Palma 3442 7 178 178 99 79TX Lake Creek 3502 1 39 39 1 38TX Lake Creek 3502 2 191 91 7 84TX Lake Hubbard 3452 1 170 120 31 89TX Lake Hubbard 3452 2 604 204 52 152TX Lamar Power (Paris Generating Stati 55097 1 0 2 2 0TX Lamar Power (Paris Generating Stati 55097 2 0 2 0 2TX Laredo 3439 1 15 15 1 14TX Laredo 3439 2 14 14 1 13TX Laredo 3439 3 85 85 6 79A, 56APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001TX Leon Creek 3609 3 2 2 0 2TX Leon Creek 3609 4 10 10 0 10TX Lewis Creek 3457 1 317 7 5 2TX Lewis Creek 3457 2 271 7 5 2TX Limestone 298 LIM1 23,787 21,787 16,862 4,925TX Limestone 298 LIM2 14,158 16,158 15,209 949TX Lon C Hill 3440 1 9 9 0 9TX Lon C Hill 3440 2 10 10 1 9TX Lon C Hill 3440 3 179 179 3 176TX Lon C Hill 3440 4 197 197 46 151TX Lone Star 3477 1 0 0 0 0TX Malakoff 370 **1 1,539 1,539 0 1,539TX Martin Lake 6146 1 33,231 26,631 16,490 10,141TX Martin Lake 6146 2 32,266 31,266 21,172 10,094TX Martin Lake 6146 3 33,436 30,436 20,396 10,040TX Midlothian Energy 55091 STK1 0 1 1 0TX Midlothian Energy 55091 STK2 0 1 1 0TX Mission Road 3610 3 3 3 0 3TX Monticello 6147 1 23,641 38,641 37,587 1,054TX Monticello 6147 2 22,938 34,246 33,186 1,060TX Monticello 6147 3 35,232 18,272 17,572 700TX Moore County Station 3483 3 0 1 0 1TX Morgan Creek 3492 3 8 8 0 8TX Morgan Creek 3492 4 72 72 1 71TX Morgan Creek 3492 5 154 154 44 110TX Morgan Creek 3492 6 836 136 8 128TX Mountain Creek 3453 2 4 4 0 4TX Mountain Creek 3453 6 63 63 25 38TX Mountain Creek 3453 7 62 212 175 37TX Mountain Creek 3453 8 527 102 5 97TX Mountain Creek 3453 3A 11 11 0 11TX Mountain Creek 3453 3B 2 2 0 2TX Mustang Station 55065 1 0 5 3 2TX Mustang Station 55065 2 0 5 3 2TX Na 1 -- 7219 7219 **1 0 0 0 0TX Na 1 -- 7219 7219 **2 0 0 0 0TX Na 2 -- 4274 4274 **NA1 0 0 0 0TX Neches 3458 11 0 0 0 0TX Neches 3458 13 0 0 0 0TX Neches 3458 15 0 0 0 0TX Neches 3458 18 0 0 0 0TX Newgulf 50137 1 0 4 0 4TX Newman 3456 1 14 14 1 13TX Newman 3456 2 29 29 1 28A, 57APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001TX Newman 3456 3 88 7 1 6TX Newman 3456 **4 99 49 2 47TX Newman 3456 **5 0 50 2 48TX Nichols Station 3484 141B 77 77 1 76TX Nichols Station 3484 142B 86 86 1 85TX Nichols Station 3484 143B 50 50 2 48TX North Lake 3454 1 131 131 36 95TX North Lake 3454 2 150 100 16 84TX North Lake 3454 3 294 164 34 130TX North Main 3493 4 42 42 1 41TX North Texas 3627 3 13 1 1 0TX Nueces Bay 3441 5 1 1 0 1TX Nueces Bay 3441 6 140 140 8 132TX Nueces Bay 3441 7 496 476 177 299TX O W Sommers3611 1 478 472 6 466TX O W Sommers3611 2 188 188 4 184TX Oak Creek 3523 1 106 106 2 104TX Oklaunion 127 1 7,859 7,859 5,602 2,257TX P H Robinson 3466 PHR1 645 645 6 639TX P H Robinson 3466 PHR2 494 494 7 487TX P H Robinson 3466 PHR3 685 685 7 678TX P H Robinson 3466 PHR4 796 796 8 788TX Paint Creek 3524 1 11 21 13 8TX Paint Creek 3524 2 11 41 29 12TX Paint Creek 3524 3 28 28 8 20TX Paint Creek 3524 4 105 125 113 12TX Parkdale 3455 1 34 34 1 33TX Parkdale 3455 2 62 62 1 61TX Parkdale 3455 3 61 61 1 60TX Pasadena Power Plant 55047 CG-1 0 7 4 3TX Pasadena Power Plant 55047 CG-2 0 1 1 0TX Pasadena Power Plant 55047 CG-3 0 1 1 0TX Permian Basin 3494 5 103 53 1 52TX Permian Basin 3494 6 804 254 118 136TX Pirkey 7902 1 20,532 20,532 18,828 1,704TX Plant X 3485 111B 0 1 0 1TX Plant X 3485 112B 2 2 0 2TX Plant X 3485 113B 89 76 1 75TX Plant X 3485 114B 0 12 8 4TX Port Neches 54748 GT1 0 0 0 0TX Powerlane Plant 4195 2 459 459 0 459TX Powerlane Plant 4195 3 37 37 0 37TX R W Miller 3628 1 55 1 1 0TX R W Miller 3628 2 98 2 2 0A, 58APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001TX R W Miller 3628 3 218 3 3 0TX R W Miller 3628 **4 851 1 1 0TX R W Miller 3628 **5 851 1 1 0TX Ray Olinger 3576 BW2 60 60 5 55TX Ray Olinger 3576 BW3 79 79 2 77TX Ray Olinger 3576 CE1 42 42 1 41TX Rio Pecos 3526 5 64 44 2 42TX Rio Pecos 3526 6 179 139 2 137TX River Crest 3503 1 61 61 1 60TX Sabine 3459 1 152 7 4 3TX Sabine 3459 2 164 9 3 6TX Sabine 3459 3 576 11 6 5TX Sabine 3459 4 504 9 6 3TX Sabine 3459 5 323 13 8 5TX Sabine Cogeneration Facility 55104 SAB-1 0 1 1 0TX Sabine Cogeneration Facility 55104 SAB-2 0 1 1 0TX Sam Bertron 3468 SRB1 57 57 1 56TX Sam Bertron 3468 SRB2 18 18 1 17TX Sam Bertron 3468 SRB3 120 100 2 98TX Sam Bertron 3468 SRB4 79 79 2 77TX Sam Seymour 6179 1 15,910 14,982 14,150 832TX Sam Seymour 6179 2 17,396 16,072 14,743 1,329TX Sam Seymour 6179 3 10,494 1,746 1,736 10TX San Angelo 3527 2 161 161 4 157TX San Jacinto Steam Electric Station 7325 SJS1 0 10 3 7TX San Jacinto Steam Electric Station 7325 SJS2 0 10 3 7TX San Miguel 6183 SM-1 17,216 17,216 12,223 4,993TX Sandow 6648 4 25,698 25,698 19,546 6,152TX Seaholm 3550 9 4 4 0 4TX Silas Ray 3559 9 0 5 0 5TX Sim Gideon 3601 1 47 47 1 46TX Sim Gideon 3601 2 56 56 1 55TX Sim Gideon 3601 3 277 277 4 273TX Spencer 4266 4 19 19 0 19TX Spencer 4266 5 23 23 1 22TX Stryker Creek 3504 1 170 120 38 82TX Stryker Creek 3504 2 525 425 182 243TX Sweeny Cogeneration Facility 55015 1 0 36 3 33TX Sweeny Cogeneration Facility 55015 2 0 12 3 9TX Sweeny Cogeneration Facility 55015 3 0 12 3 9TX T C Ferguson 4937 1 253 253 5 248TX T H Wharton 3469THW1 7 7 0 7TX T H Wharton 3469THW2 97 97 2 95TX Tenaska Frontier Generating Station 55062 1 0 2 2 0A, 59APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001TX Tenaska Frontier Generating Station 55062 2 0 2 2 0TX Tenaska Frontier Generating Station 55062 3 0 2 2 0TX TNP One 7030 U1 2,123 2,624 2,350 274TX TNP One 7030 U2 3,500 2,999 2,695 304TX Tolk Station 6194 171B 14,781 14,293 13,536 757TX Tolk Station 6194 172B 14,444 14,932 14,665 267TX Tradinghouse 3506 1 593 193 5 188TX Tradinghouse 3506 2 995 395 96 299TX Trinidad 3507 7 6 6 0 6TX Trinidad 3507 8 1 1 0 1TX Trinidad 3507 9 135 85 1 84TX Twin Oak 6180 1 8,015 0 0 0TX Twin Oak 6180 2 1,540 0 0 0TX V H Braunig 3612 1 78 78 6 72TX V H Braunig 3612 2 121 121 1 120TX V H Braunig 3612 3 416 416 4 412TX V H Braunig 3612 CP01 (CT01, CT02)TX V H Braunig 3612 CT01 0 3 2 1TX V H Braunig 3612 CT02 0 3 2 1TX Valley (Texas Utilities) 3508 1 77 77 11 66TX Valley (Texas Utilities) 3508 2 518 168 39 129TX Valley (Texas Utilities) 3508 3 124 124 2 122TX Victoria 3443 5 6 6 0 6TX Victoria 3443 6 8 8 0 8TX Victoria 3443 7 110 110 19 91TX Victoria 3443 8 238 238 32 206TX W a Parish 3470WAP1 57 57 1 56TX W a Parish 3470WAP2 56 56 1 55TX W a Parish 3470WAP3 245 245 3 242TX W a Parish 3470WAP4 558 558 4 554TX W a Parish 3470WAP5 22,878 21,378 16,206 5,172TX W a Parish 3470WAP6 20,761 19,261 14,894 4,367TX W a Parish 3470WAP7 15,142 19,500 18,500 1,000TX W a Parish 3470WAP8 7,287 5,929 4,933 996TX W B Tuttle3613 1 2 2 0 2TX W B Tuttle3613 2 19 19 0 19TX W B Tuttle3613 3 11 11 0 11TX W B Tuttle3613 4 48 48 0 48TX Webster 3471WEB1 14 14 0 14TX Webster 3471WEB2 17 17 0 17TX Webster 3471WEB3 343 343 2 341TX Welsh6139 1 13,329 14,029 14,024 5TX Welsh6139 2 12,846 12,846 12,599 247TX Welsh6139 3 15,220 14,520 12,843 1,677A, 60APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001TX Wilkes3478 1 30 30 16 14TX Wilkes3478 2 118 118 3 115TX Wilkes3478 3 129 129 3 126UT Bonanza 7790 1-1 10,785 1,824 1,038 786UT Carbon 3644 1 1,913 1,560 1,535 25UT Carbon 3644 2 2,499 3,094 3,069 25UT Gadsby 3648 1 24 2 1 1UT Gadsby 3648 2 1,690 2 1 1UT Gadsby 3648 3 2,265 2 1 1UT Hale 3652 1 1 0 0 0UT Hunter (Emery) 6165 1 7,454 2,512 2,156 356UT Hunter (Emery) 6165 2 7,960 2,599 1,764 835UT Hunter (Emery) 6165 3 11,254 1,075 1,050 25UT Huntington 8069 1 7,925 1,853 1,798 55UT Huntington 8069 2 9,753 11,339 11,314 25UT Intermountain 6481 1SGA 2,875 2,875 1,855 1,020UT Intermountain 6481 2SGA 2,895 2,895 1,619 1,276VA Bellemeade 50966 1 0 25 7 18VA Bellemeade 50966 2 0 25 7 18VA Bremo 3796 3 2,029 6,029 3,859 2,170VA Bremo 3796 4 5,160 11,160 7,678 3,482VA Chesapeake 3803 1 2,117 10,117 5,367 4,750VA Chesapeake 3803 2 2,210 8,210 5,005 3,205VA Chesapeake 3803 3 4,560 12,560 8,274 4,286VA Chesapeake 3803 4 5,872 15,872 10,663 5,209VA Chesterfield 3797 3 2,561 9,561 5,510 4,051VA Chesterfield 3797 4 4,670 10,670 6,751 3,919VA Chesterfield 3797 5 9,166 19,166 18,068 1,098VA Chesterfield 3797 6 17,139 42,139 37,145 4,994VA Chesterfield 3797 **8A 1,387 1,387 45 1,342VA Chesterfield 3797 **8B 0 0 0 0VA Clinch River 3775 CS012 (1, 2)VA Clinch River 3775 1 5,348 8,514 8,264 250VA Clinch River 3775 2 6,113 8,733 8,477 256VA Clinch River 3775 3 5,651 9,590 9,309 281VA Clover 7213 1 2,938 1,900 867 1,033VA Clover 7213 2 2,938 1,900 1,059 841VA Commonwealth Chesapeake Pwr Station 55381 CT-001 0 10 1 9VA Commonwealth Chesapeake Pwr Station 55381 CT-002 0 10 1 9VA Commonwealth Chesapeake Pwr Station 55381 CT-003 0 10 1 9VA East Chandler 7186 **2 0 0 0 0VA Glen Lyn 3776 6 5,535 9,827 9,539 288VA Glen Lyn 3776 51 1,152 2,458 2,386 72VA Glen Lyn 3776 52 1,113 2,803 2,721 82A, 61APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001VA Possum Point 3804 1 0 0 0 0VA Possum Point 3804 2 0 10 5 5VA Possum Point 3804 3 2,647 10,647 6,045 4,602VA Possum Point 3804 4 6,725 18,725 12,149 6,576VA Possum Point 3804 5 4,336 4,336 2,371 1,965VA Potomac River 3788 1 2,334 2,334 1,997 337VA Potomac River 3788 2 2,309 2,309 2,093 216VA Potomac River 3788 3 2,756 3,756 3,251 505VA Potomac River 3788 4 3,037 4,037 3,352 685VA Potomac River 3788 5 2,913 3,913 3,255 658VA Remington Combustion Turbine 7839 1 0 25 1 24VA Remington Combustion Turbine 7839 2 0 25 0 25VA Remington Combustion Turbine 7839 3 0 25 1 24VA Remington Combustion Turbine 7839 4 0 25 2 23VA Yorktown 3809 CS0 (1, 2)VA Yorktown 3809 1 4,671 14,671 9,408 5,263VA Yorktown 3809 2 4,674 17,014 11,612 5,402VA Yorktown 3809 3 6,305 10,305 7,688 2,617VT J C Mcneil 589 1 104 104 9 95WA Centralia 3845BW21 19,076 43,453 41,824 1,629WA Centralia 3845BW22 20,337 50,749 41,776 8,973WA River Road 7605 1 0 12 4 8WA Shuffleton 3858 1 0 0 0 0WA Shuffleton 3858 2 0 0 0 0WA Shuffleton 3858 3 0 0 0 0WI Alma 4140 CS1 (B1, B2, B3, B4, B5)WI Alma 4140 B1 537 872 236 636WI Alma 4140 B2 518 898 187 711WI Alma 4140 B3 455 716 226 490WI Alma 4140 B4 1,193 8,578 1,182 7,396WI Alma 4140 B5 1,906 18,401 1,614 16,787WI Bay Front 3982 1 1,046 761 131 630WI Bay Front 3982 2 529 529 143 386WI Bay Front 3982 3 0 0 0 0WI Bay Front 3982 4 33 33 0 33WI Bay Front 3982 5 281 566 512 54WI Blount Street 3992 3 6 6 1 5WI Blount Street 3992 5 7 7 0 7WI Blount Street 3992 6 7 7 0 7WI Blount Street 3992 7 1,476 1,708 1,485 223WI Blount Street 3992 8 1,130 2,366 2,057 309WI Blount Street 3992 9 1,183 8,584 3,380 5,204WI Blount Street 3992 11 1 6 1 5WI Columbia 8023 1 15,484 16,216 15,055 1,161A, 62APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001WI Columbia 8023 2 8,758 15,037 13,270 1,767WI Combustion Turbine 7157 **2 0 0 0 0WI Commerce 4036 25 4 4 0 4WI Concord 7159 **1 126 13 1 12WI Concord 7159 **2 126 10 2 8WI Concord 7159 **3 126 10 1 9WI Concord 7159 **4 126 10 1 9WI DePere Energy Center 55029 B01 0 1 1 0WI Edgewater 4050 3 1,237 18,025 1,809 16,216WI Edgewater 4050 4 10,396 37,370 7,153 30,217WI Edgewater 4050 5 11,459 10,664 8,744 1,920WI Genoa 4143 1 8,019 22,247 8,165 14,082WI Germantown Power Plant 6253 **5 0 10 4 6WI J P Madgett 4271 B1 7,436 14,988 5,376 9,612WI Manitowoc 4125 CS0020 (6, 7, 8)WI Manitowoc 4125 6 672 3,172 1,817 1,355WI Manitowoc 4125 7 814 814 814 0WI Manitowoc 4125 8 238 238 238 0WI Na 1 -- 7205 7205 **1 0 0 0 0WI Na 1 -- 7205 7205 **2 0 0 0 0WI Na 1 -- 7205 7205 **3 0 0 0 0WI Na3 7251 **1 0 0 0 0WI Na4 7252 **1 0 0 0 0WI Neenah Power Plant 55135 CT01 0 3 1 2WI Neenah Power Plant 55135 CT02 0 7 3 4WI Nelson Dewey 4054 CS1 (1, 2)WI Nelson Dewey 4054 1 2,524 8,177 7,484 693WI Nelson Dewey 4054 2 2,808 10,739 6,787 3,952WI North Oak Creek 4039 1 2,119 18 0 18WI North Oak Creek 4039 2 2,081 18 0 18WI North Oak Creek 4039 3 2,130 18 0 18WI North Oak Creek 4039 4 2,482 20 0 20WI Paris 7270 **1 124 10 1 9WI Paris 7270 **2 124 10 2 8WI Paris 7270 **3 124 10 1 9WI Paris 7270 **4 124 20 1 19WI Pleasant Prairie 6170 CS1 (1, 2)WI Pleasant Prairie 6170 1 11,802 17,566 17,129 437WI Pleasant Prairie 6170 2 16,680 20,121 17,130 2,991WI Port Washington 4040 CS7 (1, 2, 3)WI Port Washington 4040 1 529 4,771 4,277 494WI Port Washington 4040 2 1,031 4,592 4,278 314WI Port Washington 4040 3 858 4,756 4,278 478WI Port Washington 4040 4 804 4,223 3,839 384A, 63APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001WI Port Washington 4040 5 1,061 9 0 9WI Pulliam 4072 CS34 (3, 4)WI Pulliam 4072 3 140 220 200 20WI Pulliam 4072 4 208 470 430 40WI Pulliam 4072 CS56 (5, 6)WI Pulliam 4072 5 764 902 818 84WI Pulliam 4072 6 885 1,370 1,250 120WI Pulliam 4072 7 2,280 1,800 1,676 124WI Pulliam 4072 8 3,153 2,100 1,940 160WI Rock River 4057 1 1,560 18,938 8 18,930WI Rock River 4057 2 1,482 14,414 17 14,397WI South Fond Du Lac 7203 **CT1 639 639 0 639WI South Fond Du Lac 7203 **CT2 39 39 0 39WI South Fond Du Lac 7203 **CT3 39 39 0 39WI South Fond Du Lac 7203 **CT4 0 0 0 0WI South Oak Creek 4041 CS3 (5, 6)WI South Oak Creek 4041 5 3,885 7,399 6,725 674WI South Oak Creek 4041 6 4,861 9,047 8,223 824WI South Oak Creek 4041 CS4 (7, 8)WI South Oak Creek 4041 7 6,504 5,661 4,969 692WI South Oak Creek 4041 8 6,392 5,275 4,970 305WI Stoneman 4146 CS12 (B1, B2)WI Stoneman 4146 B1 177 427 407 20WI Stoneman 4146 B2 223 456 448 8WI Valley (WEPCO) 4042 CS1 (1, 2)WI Valley (WEPCO) 4042 1 1,805 3,330 3,008 322WI Valley (WEPCO) 4042 2 1,824 3,289 3,008 281WI Valley (WEPCO) 4042 CS2 (3, 4)WI Valley (WEPCO) 4042 3 1,954 4,461 4,108 353WI Valley (WEPCO) 4042 4 1,900 4,579 4,108 471WI West Marinette 4076 **33 765 765 1 764WI West Marinette 4076 **34 0 5 0 5WI Weston4078 1 1,396 1,300 1,220 80WI Weston4078 2 3,547 2,300 2,120 180WI Weston4078 3 9,704 9,550 8,358 1,192WI Whitewater 55011 01 0 5 3 2WV Albright 3942 1 1,974 5,180 5,080 100WV Albright 3942 2 2,054 5,255 5,155 100WV Albright 3942 3 4,598 12,740 12,540 200WV Fort Martin 3943 1 17,935 42,603 42,103 500WV Fort Martin 3943 2 17,767 48,452 47,952 500WV Harrison 3944 XS123 (1, 2, 3)WV Harrison 3944 1 20,966 2,429 2,110 319WV Harrison 3944 2 19,902 2,667 2,110 557A, 64APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001WV Harrison 3944 3 17,898 2,435 2,110 325WV John E Amos 3935 CS012 (1, 2)WV John E Amos 3935 1 22,589 31,739 30,807 932WV John E Amos 3935 2 25,899 25,455 24,704 751WV John E Amos 3935 3 41,512 39,237 35,595 3,642WV Kammer 3947 CS013 (1, 2, 3)WV Kammer 3947 1 8,082 16,393 15,914 479WV Kammer 3947 2 8,390 14,282 13,863 419WV Kammer 3947 3 7,499 13,530 13,134 396WV Kanawha River 3936 CS012 (1, 2)WV Kanawha River 3936 1 4,462 8,545 7,933 612WV Kanawha River 3936 2 4,291 7,459 6,852 607WV Mitchell 3948 CS012 (1, 2)WV Mitchell 3948 1 18,963 31,210 30,295 915WV Mitchell 3948 2 19,622 24,397 23,681 716WV Mountaineer (1301) 6264 1 35,223 39,513 38,350 1,163WV Mt Storm 3954 CS0 (1, 2)WV Mt Storm 3954 1 18,855 72,083 53,900 18,183WV Mt Storm 3954 2 17,688 59,979 56,054 3,925WV Mt Storm 3954 3 18,296 8,471 3,118 5,353WV North Branch Power Station 7537 CS1 (1A, 1B)WV North Branch Power Station 7537 1A 0 500 259 241WV North Branch Power Station 7537 1B 0 500 255 245WV Phil Sporn 3938 CS014 (11, 21, 31, 41)WV Phil Sporn 3938 11 3,130 8,672 8,436 236WV Phil Sporn 3938 21 2,965 8,084 7,873 211WV Phil Sporn 3938 31 3,313 8,116 7,886 230WV Phil Sporn 3938 41 3,053 9,428 9,179 249WV Phil Sporn 3938 51 10,617 21,348 20,792 556WV Pleasants 6004 1 17,603 23,557 23,357 200WV Pleasants 6004 2 20,194 17,905 17,705 200WV Rivesville 3945 7 1,237 1,665 1,565 100WV Rivesville 3945 8 2,529 4,406 4,306 100WV Willow Island 3946 1 1,496 5,627 5,527 100WV Willow Island 3946 2 4,684 13,016 12,816 200WY Dave Johnston 4158BW41 4,706 3,749 3,724 25WY Dave Johnston 4158BW42 4,572 3,718 3,693 25WY Dave Johnston 4158BW43 8,830 6,484 6,284 200WY Dave Johnston 4158BW44 6,804 5,710 5,685 25WY Jim Bridger 8066BW71 20,913 6,843 6,818 25WY Jim Bridger 8066BW72 20,470 5,711 5,686 25WY Jim Bridger 8066BW73 19,590 5,167 4,985 182WY Jim Bridger 8066BW74 4,065 3,270 3,245 25WY Laramie River 6204 1 5,113 4,534 3,264 1,270A, 65APPENDIX A: ACID RAIN PROGRAM - YEAR 2000 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONSSTATE PLANT NAMEPLANTCODE STACK/UNIT ID*2000ALLOWANCESALLOCATEDHELD INACCOUNTS ASOF 3/1/2001ALLOWANCESDEDUCTEDALLOWANCESCARRIED OVERTO 2001WY Laramie River 6204 2 4,303 4,303 3,752 551WY Laramie River 6204 3 3,823 4,402 4,402 0WY Naughton 4162 1 5,203 7,295 7,270 25WY Naughton 4162 2 6,743 9,321 9,296 25WY Naughton 4162 3 5,216 4,992 4,967 25WY Neil Simpson II 7504 001 0 750 662 88WY Neil Simpson II 7504 CT1 0 4 1 3WY Wyodak 6101BW91 18,317 6,618 6,566 52* CS stands for Common Stack, which includes emissions from more than one unit. XS stands for Complex Stack, which includes emissions from one or moreCommon Stacks and/or Multiple Stacks (MS).A, 66B-1, 1Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000AL Barry Alabama Power Co. 3 1 Averaging Plan 0.40 0.53 0.46 0.43 0.54 -2%AL Barry Alabama Power Co. 3 2 Averaging Plan 0.40 0.53 0.46 0.43 0.54 -2%AL Barry Alabama Power Co. 3 3 Averaging Plan 0.40 0.53 0.46 0.43 0.54 -2%AL Barry Alabama Power Co. 3 4 Averaging Plan 0.40 0.35 0.46 0.43 0.65 -46%AL Barry Alabama Power Co. 3 5 Averaging Plan 0.40 0.35 0.46 0.43 0.68 -49%AL Charles R Lowman Alabama Electric Coop. 56 1 Standard Limitation 0.46 0.38 0.69 -45%AL Charles R Lowman Alabama Electric Coop. 56 2 Early Election 0.46 0.48 0.50 0.62 -23%AL Charles R Lowman Alabama Electric Coop. 56 3 Early Election 0.46 0.47 0.50 0.66 -29%AL Colbert Tennessee Valley Authority 47 1 Averaging Plan 0.50 0.41 0.57 0.54 0.80 -49%AL Colbert Tennessee Valley Authority 47 2 Averaging Plan 0.50 0.41 0.57 0.54 0.67 -39%AL Colbert Tennessee Valley Authority 47 3 Averaging Plan 0.50 0.41 0.57 0.54 0.83 -51%AL Colbert Tennessee Valley Authority 47 4 Averaging Plan 0.50 0.41 0.57 0.54 0.86 -52%AL Colbert Tennessee Valley Authority 47 5 Averaging Plan 0.50 0.42 0.57 0.54 0.78 -46%AL E C Gaston Alabama Power Co. 26 1 Averaging Plan 0.50 0.46 0.46 0.43 0.90 -49%AL E C Gaston Alabama Power Co. 26 2 Averaging Plan 0.50 0.46 0.46 0.43 0.78 -41%AL E C Gaston Alabama Power Co. 26 3 Averaging Plan 0.50 0.45 0.46 0.43 0.80 -44%AL E C Gaston Alabama Power Co. 26 4 Averaging Plan 0.50 0.45 0.46 0.43 0.80 -44%AL E C Gaston Alabama Power Co. 26 5 Averaging Plan 0.45 0.41 0.46 0.43 0.78 -47%AL Gadsden Alabama Power Co. 7 1 Averaging Plan 0.45 0.58 0.46 0.43 0.51 14%AL Gadsden Alabama Power Co. 7 2 Averaging Plan 0.45 0.63 0.46 0.43 0.56 13%AL Gorgas Alabama Power Co. 8 6 Averaging Plan 0.46 0.83 0.46 0.43 0.83 0%AL Gorgas Alabama Power Co. 8 7 Averaging Plan 0.46 0.83 0.46 0.43 0.83 0%AL Gorgas Alabama Power Co. 8 8 Averaging Plan 0.40 0.58 0.46 0.43 0.55 5%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 2AL Gorgas Alabama Power Co. 8 9 Averaging Plan 0.40 0.36 0.46 0.43 0.57 -37%AL Gorgas Alabama Power Co. 8 10 Averaging Plan 0.40 0.43 0.46 0.43 0.73 -41%AL Greene County Alabama Power Co. 10 1 Averaging Plan 0.68 0.59 0.46 0.43 0.92 -36%AL Greene County Alabama Power Co. 10 2 Averaging Plan 0.46 0.41 0.46 0.43 0.82 -50%AL James H Miller Jr Alabama Power Co. 6002 1 Averaging Plan 0.46 0.25 0.46 0.43 0.73 -66%AL James H Miller Jr Alabama Power Co. 6002 2 Averaging Plan 0.46 0.26 0.46 0.43 0.54 -52%AL James H Miller Jr Alabama Power Co. 6002 3 Averaging Plan 0.46 0.32 0.46 0.43 0.44 -27%AL James H Miller Jr Alabama Power Co. 6002 4 Averaging Plan 0.46 0.34 0.46 0.43 0.58 -41%AL Widows Creek Tennessee Valley Authority 50 1 Averaging Plan 0.46 0.72 0.57 0.54 0.76 -5%AL Widows Creek Tennessee Valley Authority 50 2 Averaging Plan 0.46 0.72 0.57 0.54 0.76 -5%AL Widows Creek Tennessee Valley Authority 50 3 Averaging Plan 0.46 0.72 0.57 0.54 0.76 -5%AL Widows Creek Tennessee Valley Authority 50 4 Averaging Plan 0.46 0.72 0.57 0.54 0.76 -5%AL Widows Creek Tennessee Valley Authority 50 5 Averaging Plan 0.46 0.72 0.57 0.54 0.76 -5%AL Widows Creek Tennessee Valley Authority 50 6 Averaging Plan 0.46 0.72 0.57 0.54 0.76 -5%AL Widows Creek Tennessee Valley Authority 50 7 Averaging Plan 0.40 0.38 0.57 0.54 0.78 -51%AL Widows Creek Tennessee Valley Authority 50 8 Averaging Plan 0.40 0.42 0.57 0.54 0.63 -33%AR Flint Creek American Electric Power Service 6138 1 Early Election 0.46 0.28 0.50 0.31 -10%AR Independence Entergy Arkansas, Inc. 6641 1 Early Election 0.40 0.25 0.45 0.34 -26%AR Independence Entergy Arkansas, Inc. 6641 2 Early Election 0.40 0.26 0.45 0.35 -26%AR White Bluff Entergy Arkansas, Inc. 6009 1 Early Election 0.40 0.43 0.45 0.29 48%AR White Bluff Entergy Arkansas, Inc. 6009 2 Early Election 0.40 0.33 0.45 0.34 -3%AZ Apache Station Arizona Electric Power Coop., Inc. 160 2 Early Election 0.46 0.48 0.50 0.58 -17%AZ Apache Station Arizona Electric Power Coop., Inc. 160 3 Early Election 0.46 0.43 0.50 0.58 -26%AZ Cholla Arizona Public Service Co. 113 1 Early Election 0.40 0.40 0.45 0.46 -13%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 3AZ Cholla Arizona Public Service Co. 113 2 Early Election 0.40 0.37 0.45 0.42 -12%AZ Cholla Arizona Public Service Co. 113 3 Early Election 0.40 0.32 0.45 0.36 -11%AZ Cholla Arizona Public Service Co. 113 4 Early Election 0.40 0.28 0.45 0.38 -26%AZ Coronado Salt River Proj. Ag. I & P Dis 6177 U1B Early Election 0.46 0.42 0.50 0.51 -18%AZ Coronado Salt River Proj. Ag. I & P Dis 6177 U2B Early Election 0.46 0.40 0.50 0.51 -22%AZ Irvington Tucson Electric Power Co. 126 4 Standard Limitation 0.46 0.42 0.71 -41%AZ Navajo Salt River Proj. Ag. I & P Dis 4941 1 Early Election 0.40 0.41 0.45 0.41 0%AZ Navajo Salt River Proj. Ag. I & P Dis 4941 2 Early Election 0.40 0.35 0.45 0.41 -15%AZ Navajo Salt River Proj. Ag. I & P Dis 4941 3 Early Election 0.40 0.37 0.45 0.37 0%AZ Springerville Tucson Electric Power Co. 8223 1 Early Election 0.40 0.39 0.45 0.34 15%AZ Springerville Tucson Electric Power Co. 8223 2 Early Election 0.40 0.38 0.45 0.33 15%CO Arapahoe Public Service Company of CO 465 1 Averaging Plan 0.80 0.71 0.80 0.49 1.14 -38%CO Arapahoe Public Service Company of CO 465 2 Averaging Plan 0.80 0.71 0.80 0.49 1.14 -38%CO Arapahoe Public Service Company of CO 465 3 Averaging Plan 0.80 0.66 0.80 0.49 1.12 -41%CO Arapahoe Public Service Company of CO 465 4 Averaging Plan 0.80 0.26 0.80 0.49 1.10 -76%CO Cameo Public Service Company of CO 468 2 Standard Limitation 0.46 0.41 0.96 -57%CO Cherokee Public Service Company of CO 469 1 Averaging Plan 0.80 0.34 0.80 0.60 1.38 -75%CO Cherokee Public Service Company of CO 469 2 Averaging Plan 0.80 0.80 0.80 0.60 1.67 -52%CO Cherokee Public Service Company of Colorado 469 3 Early Election 0.46 0.38 0.50 0.73 -48%CO Cherokee Public Service Company of Colorado 469 4 Early Election 0.40 0.34 0.45 0.51 -33%CO Comanche Public Service Company of Colorado 470 1 Early Election 0.40 0.24 0.45 0.24 0%CO Comanche Public Service Company of Colorado 470 2 Early Election 0.46 0.32 0.50 0.31 3%CO Craig Tri-State G&T Association, Inc. 6021 C1 Early Election 0.46 0.36 0.50 0.39 -8%CO Craig Tri-State G&T Association, Inc. 6021 C2 Early Election 0.46 0.42 0.50 0.40 5%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 4CO Craig Tri-State G&T Association, Inc. 6021 C3 Early Election 0.46 0.36 0.50 0.28 29%CO Hayden Public Service Company of CO 525 H1 Standard Limitation 0.46 0.40 0.89 -55%CO Hayden Public Service Company of CO 525 H2 Standard Limitation 0.40 0.36 0.45 -20%CO Martin Drake Colorado Springs Utilities 492 5 Averaging Plan 0.46 0.42 0.46 0.39 1.09 -61%CO Martin Drake Colorado Springs Utilities 492 6 Averaging Plan 0.46 0.39 0.46 0.39 0.83 -53%CO Martin Drake Colorado Springs Utilities 492 7 Averaging Plan 0.46 0.39 0.46 0.39 0.93 -58%CO Pawnee Public Service Company of Colorado 6248 1 Early Election 0.46 0.21 0.50 0.62 -66%CO Rawhide Platte River Power Authority 6761 101 Early Election 0.40 0.29 0.45 0.43 -33%CO Ray D Nixon Colorado Springs Utilities 8219 1 Early Election 0.46 0.39 0.50 0.54 -28%CO Valmont Public Service Company of Colorado 477 5 Early Election 0.40 0.26 0.45 0.17 53%CT Bridgeport Harbor The United Illuminating Co. 568 BHB3 Early Election 0.40 0.25 0.45 0.56 -55%DE Edge Moor Conectiv Delmarva Generation, Inc. 593 3 Standard Limitation 0.40 0.39 0.74 -47%DE Edge Moor Conectiv Delmarva Generation, Inc. 593 4 Standard Limitation 0.40 0.22 0.55 -60%DE Indian River Delmarva Power & Light Co. 594 1 Standard Limitation 0.46 0.40 0.81 -51%DE Indian River Delmarva Power & Light Co. 594 2 Standard Limitation 0.46 0.36 0.81 -56%DE Indian River Delmarva Power & Light Co. 594 3 Standard Limitation 0.46 0.31 0.97 -68%DE Indian River Delmarva Power & Light Co. 594 4 Standard Limitation 0.46 0.32 0.57 -44%FL Big Bend Tampa Electric Co. 645 BB01 Averaging Plan 0.84 0.74 0.75 0.65 1.24 -40%FL Big Bend Tampa Electric Co. 645 BB02 Averaging Plan 0.84 0.74 0.75 0.65 1.26 -41%FL Big Bend Tampa Electric Co. 645 BB03 Averaging Plan 0.84 0.61 0.75 0.65 0.64 -5%FL Big Bend Tampa Electric Co. 645 BB04 Averaging Plan 0.45 0.44 0.75 0.65 0.46 -4%FL C D McIntosh Jr City of Lakeland, Dept. of Ele 676 3 Early Election 0.46 0.48 0.50 0.46 4%FL Crist Gulf Power Co. 641 4 Averaging Plan 0.45 0.39 0.46 0.43 0.43 -9%FL Crist Gulf Power Co. 641 5 Averaging Plan 0.45 0.39 0.46 0.43 0.49 -20%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 5FL Crist Gulf Power Co. 641 6 Averaging Plan 0.50 0.47 0.46 0.43 1.04 -55%FL Crist Gulf Power Co. 641 7 Averaging Plan 0.50 0.47 0.46 0.43 1.16 -59%FL Crystal River Florida Power Corp. 628 1 Standard Limitation 0.40 0.37 0.79 -53%FL Crystal River Florida Power Corp. 628 2 Early Election 0.40 0.44 0.45 0.38 16%FL Crystal River Florida Power Corp. 628 4 Early Election 0.46 0.48 0.50 0.50 -4%FL Crystal River Florida Power Corp. 628 5 Early Election 0.46 0.48 0.50 0.47 2%FL Deerhaven Gainesville Regional Utilities 663 B2 Early Election 0.46 0.48 0.50 0.53 -9%FL F J Gannon Tampa Electric Co. 646 GB03 Averaging Plan 0.86 0.78 0.75 0.65 1.52 -49%FL F J Gannon Tampa Electric Co. 646 GB04 Averaging Plan 0.86 0.76 0.75 0.65 1.48 -49%FL F J Gannon Tampa Electric Co. 646 GB05 Averaging Plan 0.84 0.66 0.75 0.65 1.26 -48%FL F J Gannon Tampa Electric Co. 646 GB06 Averaging Plan 0.84 0.79 0.75 0.65 1.61 -51%FL Lansing Smith Gulf Power Co. 643 1 Averaging Plan 0.40 0.51 0.46 0.43 0.71 -28%FL Lansing Smith Gulf Power Co. 643 2 Averaging Plan 0.40 0.38 0.46 0.43 0.63 -40%FL Scholz Gulf Power Co. 642 1 Averaging Plan 0.50 0.59 0.46 0.43 0.69 -14%FL Scholz Gulf Power Co. 642 2 Averaging Plan 0.50 0.63 0.46 0.43 0.80 -21%FL Seminole Seminole Electric Coop. 136 1 Early Election 0.46 0.45 0.50 0.43 5%FL Seminole Seminole Electric Coop. 136 2 Early Election 0.46 0.39 0.50 0.36 8%FL St Johns River Power Jacksonville Electric Authority 207 1 Early Election 0.46 0.47 0.50 0.50 -6%FL St Johns River Power Jacksonville Electric Authority 207 2 Early Election 0.46 0.47 0.50 0.59 -20%FL Stanton Energy Orlando Utilities Comm. 564 1 Standard Limitation 0.46 0.43 0.43 0%GA Arkwright Georgia Power Co. 699 1 Averaging Plan 0.45 0.76 0.46 0.43 0.90 -16%GA Arkwright Georgia Power Co. 699 2 Averaging Plan 0.45 0.76 0.46 0.43 0.90 -16%GA Arkwright Georgia Power Co. 699 3 Averaging Plan 0.50 0.76 0.46 0.43 0.90 -16%GA Arkwright Georgia Power Co. 699 4 Averaging Plan 0.50 0.76 0.46 0.43 0.90 -16%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 6GA Bowen Georgia Power Co. 703 1BLR Averaging Plan 0.45 0.41 0.46 0.43 0.67 -39%GA Bowen Georgia Power Co. 703 2BLR Averaging Plan 0.45 0.41 0.46 0.43 0.65 -37%GA Bowen Georgia Power Co. 703 3BLR Averaging Plan 0.45 0.42 0.46 0.43 0.56 -25%GA Bowen Georgia Power Co. 703 4BLR Averaging Plan 0.45 0.42 0.46 0.43 0.58 -28%GA Hammond Georgia Power Co. 708 1 Averaging Plan 0.50 0.87 0.46 0.43 0.84 4%GA Hammond Georgia Power Co. 708 2 Averaging Plan 0.50 0.87 0.46 0.43 0.84 4%GA Hammond Georgia Power Co. 708 3 Averaging Plan 0.50 0.87 0.46 0.43 0.84 4%GA Hammond Georgia Power Co. 708 4 Averaging Plan 0.50 0.45 0.46 0.43 1.20 -63%GA Harllee Branch Georgia Power Co. 709 1 Averaging Plan 0.68 0.86 0.46 0.43 1.18 -27%GA Harllee Branch Georgia Power Co. 709 2 Averaging Plan 0.50 0.77 0.46 0.43 0.99 -22%GA Harllee Branch Georgia Power Co. 709 3 Averaging Plan 0.68 0.89 0.46 0.43 1.04 -14%GA Harllee Branch Georgia Power Co. 709 4 Averaging Plan 0.68 0.89 0.46 0.43 1.04 -14%GA Jack McDonough Georgia Power Co. 710 MB1 Averaging Plan 0.45 0.33 0.46 0.43 0.66 -50%GA Jack McDonough Georgia Power Co. 710 MB2 Averaging Plan 0.45 0.33 0.46 0.43 0.60 -45%GA Kraft Savannah Electric & Power Co. 733 1 Averaging Plan 0.45 0.48 0.46 0.43 0.40 20%GA Kraft Savannah Electric & Power Co. 733 2 Averaging Plan 0.45 0.48 0.46 0.43 0.40 20%GA Kraft Savannah Electric & Power Co. 733 3 Averaging Plan 0.45 0.48 0.46 0.43 0.40 20%GA McIntosh Savannah Electric & Power Co. 6124 1 Averaging Plan 0.50 0.72 0.46 0.43 0.83 -13%GA Mitchell Georgia Power Co. 727 3 Averaging Plan 0.45 0.60 0.46 0.43 0.61 -2%GA Scherer Georgia Power Co. 6257 1 Averaging Plan 0.40 0.41 0.46 0.43 0.52 -21%GA Scherer Georgia Power Co. 6257 2 Averaging Plan 0.40 0.38 0.46 0.43 0.35 9%GA Scherer Georgia Power Co. 6257 3 Averaging Plan 0.45 0.25 0.46 0.43 0.20 25%GA Scherer Georgia Power Co. 6257 4 Averaging Plan/EE 0.40 0.27 0.46 / 0.45 0.43 0.21 29%GA Wansley Oglethorpe Power Co. 6052 1 Averaging Plan 0.45 0.39 0.46 0.43 0.73 -47%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 7GA Wansley Georgia Power Co. 6052 2 Averaging Plan 0.45 0.40 0.46 0.43 0.67 -40%GA Yates Georgia Power Co. 728 Y1BR Averaging Plan 0.45 0.42 0.46 0.43 0.56 -25%GA Yates Georgia Power Co. 728 Y2BR Averaging Plan 0.45 0.42 0.46 0.43 0.62 -32%GA Yates Georgia Power Co. 728 Y3BR Averaging Plan 0.45 0.42 0.46 0.43 0.62 -32%GA Yates Georgia Power Co. 728 Y4BR Averaging Plan 0.45 0.36 0.46 0.43 0.56 -36%GA Yates Georgia Power Co. 728 Y5BR Averaging Plan 0.45 0.36 0.46 0.43 0.65 -45%GA Yates Georgia Power Co. 728 Y6BR Averaging Plan 0.45 0.28 0.46 0.43 0.67 -58%GA Yates Georgia Power Co. 728 Y7BR Averaging Plan 0.45 0.28 0.46 0.43 0.61 -54%IA Ames City of Ames 1122 7 Early Election 0.40 0.38 0.45 0.60 -37%IA Ames City of Ames 1122 8 Early Election 0.46 0.43 0.50 0.55 -22%IA Burlington IES Utilities, Inc. 1104 1 Averaging Plan 0.45 0.19 0.46 0.36 0.63 -70%IA Council Bluffs MidAmerican Energy Co. 1082 1 Early Election 0.46 0.45 0.50 0.56 -20%IA Council Bluffs MidAmerican Energy Co. 1082 2 Early Election 0.40 0.38 0.45 0.33 15%IA Council Bluffs Atlantic Municipal Utilities 1082 3 Early Election 0.46 0.45 0.50 0.37 22%IA Dubuque Interstate Power Co. 1046 1 Averaging Plan 0.46 0.68 0.46 0.36 0.69 -1%IA Dubuque Interstate Power Co. 1046 5 Averaging Plan 0.46 0.98 0.46 0.36 0.80 23%IA Earl F Wisdom Corn Belt Power Coop. 1217 1 AEL Final 0.46 0.56 0.59 1.11 -50%IA Fair Station Eastern Iowa Light and Power C 1218 2 Standard Limitation 0.46 0.39 0.97 -60%IA George Neal North MidAmerican Energy Co. 1091 2 Early Election 0.46 0.38 0.50 1.06 -64%IA George Neal North MidAmerican Energy Co. 1091 3 Early Election 0.46 0.46 0.50 0.39 18%IA George Neal South MidAmerican Energy Co. 7343 4 Early Election 0.46 0.34 0.50 0.64 -47%IA Lansing Interstate Power Co. 1047 1 Averaging Plan 0.46 0.62 0.46 0.36 0.80 -23%IA Lansing Interstate Power Co. 1047 2 Averaging Plan 0.46 0.62 0.46 0.36 0.80 -23%IA Lansing Interstate Power Co. 1047 3 Averaging Plan 0.46 0.85 0.46 0.36 1.03 -17%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 8IA Lansing Interstate Power Co. 1047 4 Early Election 0.46 0.41 0.50 0.50 -18%IA Louisa MidAmerican Energy Co. 6664 101 Early Election 0.46 0.28 0.50 0.25 12%IA Milton L Kapp Interstate Power Co. 1048 2 Averaging Plan 0.45 0.19 0.46 0.36 0.80 -76%IA Muscatine City of Muscatine 1167 9 Standard Limitation 0.40 0.27 0.35 -23%IA Ottumwa IES Utilities, Inc. 6254 1 Early Election 0.40 0.33 0.45 0.69 -52%IA Prairie Creek IES Utilities, Inc. 1073 3 Averaging Plan 0.46 0.40 0.46 0.36 0.83 -52%IA Prairie Creek IES Utilities, Inc. 1073 4 Averaging Plan 0.50 0.32 0.46 0.36 1.05 -70%IA Riverside MidAmerican Energy Co. 1081 9 Standard Limitation 0.45 0.34 0.82 -59%IA Sixth Street IES Utilities, Inc. 1058 2 Averaging Plan 0.46 0.33 0.46 0.36 Not Oper.IA Sixth Street IES Utilities, Inc. 1058 3 Averaging Plan 0.46 0.38 0.46 0.36 Not Oper.IA Sixth Street IES Utilities, Inc. 1058 4 Averaging Plan 0.46 0.45 0.46 0.36 Not Oper.IA Sixth Street IES Utilities, Inc. 1058 5 Averaging Plan 0.46 0.75 0.46 0.36 Not Oper.IA Sutherland IES Utilities, Inc. 1077 1 Averaging Plan 0.46 0.72 0.46 0.36 0.48 50%IA Sutherland IES Utilities, Inc. 1077 2 Averaging Plan 0.46 0.56 0.46 0.36 0.48 17%IL Baldwin Dynegy Midwest Generation, Inc. 889 1 Averaging Plan 0.86 0.66 0.59 0.48 1.70 -61%IL Baldwin Dynegy Midwest Generation, Inc. 889 2 Averaging Plan 0.86 0.70 0.59 0.48 1.47 -52%IL Baldwin Dynegy Midwest Generation, Inc. 889 3 Averaging Plan 0.45 0.21 0.59 0.48 0.67 -69%IL Coffeen Ameren Energy Generating Co. 861 01 Averaging Plan 0.86 1.05 0.59 0.55 1.23 -15%IL Coffeen Ameren Energy Generating Co. 861 02 Averaging Plan 0.86 1.05 0.59 0.55 1.23 -15%IL Crawford Midwest Generation EME, LLC 867 7 Averaging Plan/EE 0.40 0.30 0.59 / 0.45 0.48 0.33 -9%IL Crawford Midwest Generation EME, LLC 867 8 Averaging Plan/EE 0.40 0.38 0.59 / 0.45 0.48 0.48 -21%IL Dallman City of Springfield, Illinois 963 33 Early Election 0.40 0.40 0.45 0.55 -27%IL Duck Creek Central Illinois Light Co. 6016 1 AEL Final 0.46 0.54 0.58 0.90 -40%IL E D Edwards Central Illinois Light Co. 856 1 Standard Limitation 0.46 0.46 0.98 -53%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 9IL E D Edwards Central Illinois Light Co. 856 2 AEL Final 0.46 0.44 1.00 -56%IL E D Edwards Central Illinois Light Co. 856 3 AEL Final 0.46 0.51 0.53 1.25 -59%IL Fisk Midwest Generation EME, LLC 886 19 Averaging Plan/EE 0.40 0.37 0.59 / 0.45 0.48 0.39 -5%IL Grand Tower Ameren Energy Generating Co. 862 07 Averaging Plan 0.50 0.75 0.59 0.55 0.78 -4%IL Grand Tower Ameren Energy Generating Co. 862 08 Averaging Plan 0.50 0.75 0.59 0.55 0.96 -22%IL Grand Tower Ameren Energy Generating Co. 862 09 Averaging Plan 0.50 0.71 0.59 0.55 0.64 11%IL Havana Dynegy Midwest Generation, Inc. 891 9 Averaging Plan 0.46 0.43 0.59 0.48 0.46 -7%IL Hennepin Dynegy Midwest Generation, Inc. 892 1 Averaging Plan 0.40 0.37 0.59 0.48 0.57 -35%IL Hennepin Dynegy Midwest Generation, Inc. 892 2 Averaging Plan 0.45 0.37 0.59 0.48 0.59 -37%IL Hutsonville Ameren Energy Generating Co. 863 05 Averaging Plan 0.45 0.55 0.59 0.55 0.70 -21%IL Hutsonville Ameren Energy Generating Co. 863 06 Averaging Plan 0.45 0.52 0.59 0.55 0.67 -22%IL Joliet 29 Midwest Generation EME, LLC 384 71 Averaging Plan 0.40 0.18 0.59 0.48 0.32 -44%IL Joliet 29 Midwest Generation EME, LLC 384 72 Averaging Plan 0.40 0.18 0.59 0.48 0.32 -44%IL Joliet 29 Midwest Generation EME, LLC 384 81 Averaging Plan 0.40 0.38 0.59 0.48 0.46 -17%IL Joliet 29 Midwest Generation EME, LLC 384 82 Averaging Plan 0.40 0.38 0.59 0.48 0.46 -17%IL Joliet 9 Midwest Generation EME, LLC 874 5 Averaging Plan 0.86 0.68 0.59 0.48 0.91 -25%IL Joppa Steam Electric Energy Inc. 887 1 Standard Limitation 0.45 0.20 0.56 -64%IL Joppa Steam Electric Energy Inc. 887 2 Standard Limitation 0.45 0.20 0.56 -64%IL Joppa Steam Electric Energy Inc. 887 3 Standard Limitation 0.45 0.19 0.56 -66%IL Joppa Steam Electric Energy Inc. 887 4 Standard Limitation 0.45 0.19 0.56 -66%IL Joppa Steam Electric Energy Inc. 887 5 Standard Limitation 0.45 0.19 0.56 -66%IL Joppa Steam Electric Energy Inc. 887 6 Standard Limitation 0.45 0.19 0.56 -66%IL Kincaid Dominion Energy Services Co. 876 1 Standard Limitation 0.86 0.75 1.47 -49%IL Kincaid Dominion Energy Services Co. 876 2 Standard Limitation 0.86 0.75 1.47 -49%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 10IL Marion Southern Illinois Power Coop. 976 4 Standard Limitation 0.86 0.85 1.15 -26%IL Meredosia Ameren Energy Generating Co. 864 01 Averaging Plan 0.45 0.50 0.59 0.55 0.50 0%IL Meredosia Ameren Energy Generating Co. 864 02 Averaging Plan 0.45 0.50 0.59 0.55 0.50 0%IL Meredosia Ameren Energy Generating Co. 864 03 Averaging Plan 0.45 0.50 0.59 0.55 0.50 0%IL Meredosia Ameren Energy Generating Co. 864 04 Averaging Plan 0.45 0.50 0.59 0.55 0.50 0%IL Meredosia Ameren Energy Generating Co. 864 05 Averaging Plan 0.45 0.52 0.59 0.55 0.67 -22%IL Newton Ameren Energy Generating Co. 6017 1 Averaging Plan 0.45 0.17 0.59 0.55 0.47 -64%IL Newton Ameren Energy Generating Co. 6017 2 Averaging Plan 0.45 0.22 0.59 0.55 0.39 -44%IL Powerton Midwest Generation EME, LLC 879 51 Averaging Plan 0.86 0.77 0.59 0.48 0.92 -16%IL Powerton Midwest Generation EME, LLC 879 52 Averaging Plan 0.86 0.77 0.59 0.48 0.92 -16%IL Powerton Midwest Generation EME, LLC 879 61 Averaging Plan 0.86 0.77 0.59 0.48 0.92 -16%IL Powerton Midwest Generation EME, LLC 879 62 Averaging Plan 0.86 0.77 0.59 0.48 0.92 -16%IL Vermilion Dynegy Midwest Generation, Inc. 897 1 Averaging Plan 0.45 0.46 0.59 0.48 0.94 -51%IL Vermilion Dynegy Midwest Generation, Inc. 897 2 Averaging Plan 0.45 0.46 0.59 0.48 0.74 -38%IL Waukegan Midwest Generation EME, LLC 883 7 Averaging Plan/EE 0.40 0.26 0.59 / 0.45 0.48 0.26 0%IL Waukegan Midwest Generation EME, LLC 883 8 Averaging Plan/EE 0.40 0.15 0.59 / 0.45 0.48 0.41 -63%IL Will County Midwest Generation EME, LLC 884 1 Averaging Plan 0.86 0.84 0.59 0.48 0.89 -6%IL Will County Midwest Generation EME, LLC 884 2 Averaging Plan 0.86 0.85 0.59 0.48 0.87 -2%IL Will County Midwest Generation EME, LLC 884 3 Averaging Plan/EE 0.40 0.33 0.59 / 0.45 0.48 0.39 -15%IL Will County Midwest Generation EME, LLC 884 4 Early Election 0.40 0.18 0.45 0.31 -42%IL Wood River Dynegy Midwest Generation, Inc. 898 4 Averaging Plan 0.40 0.70 0.59 0.48 0.70 0%IL Wood River Dynegy Midwest Generation, Inc. 898 5 Averaging Plan 0.40 0.55 0.59 0.48 0.61 -10%IN A B Brown Southern Indiana Gas & Electric Co. 6137 1 Early Election 0.46 0.40 0.50 0.61 -34%IN A B Brown Southern Indiana Gas & Electric Co. 6137 2 Early Election 0.46 0.45 0.50 0.39 15%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 11IN Bailly Northern Indiana Public Service Co. 995 7 Averaging Plan 0.86 1.29 0.75 0.66 1.51 -15%IN Bailly Northern Indiana Public Service Co. 995 8 Averaging Plan 0.86 1.29 0.75 0.66 1.51 -15%IN Cayuga PSI Energy, Inc. 1001 1 Averaging Plan 0.45 0.32 0.49 0.46 0.42 -24%IN Cayuga PSI Energy, Inc. 1001 2 Averaging Plan 0.45 0.30 0.49 0.46 0.47 -36%IN Clifty Creek Indiana-Kentucky Electric Corp. 983 1 Averaging Plan 0.84 0.75 0.84 0.76 1.68 -55%IN Clifty Creek Indiana-Kentucky Electric Corp. 983 2 Averaging Plan 0.84 0.75 0.84 0.76 1.68 -55%IN Clifty Creek Indiana-Kentucky Electric Corp. 983 3 Averaging Plan 0.84 0.75 0.84 0.76 1.68 -55%IN Clifty Creek Indiana-Kentucky Electric Corp. 983 4 Averaging Plan 0.84 0.73 0.84 0.76 1.88 -61%IN Clifty Creek Indiana-Kentucky Electric Corp. 983 5 Averaging Plan 0.84 0.73 0.84 0.76 1.88 -61%IN Clifty Creek Indiana-Kentucky Electric Corp. 983 6 Averaging Plan 0.84 0.73 0.84 0.76 1.88 -61%IN Dean H Mitchell Northern Indiana Public Service Co. 996 4 Early Election 0.40 0.29 0.45 0.43 -33%IN Dean H Mitchell Northern Indiana Public Service Co. 996 5 Early Election 0.40 0.29 0.45 0.43 -33%IN Dean H Mitchell Northern Indiana Public Service Co. 996 6 Early Election 0.40 0.26 0.45 0.58 -55%IN Dean H Mitchell Northern Indiana Public Service Co. 996 11 Early Election 0.46 0.26 0.50 0.58 -55%IN Edwardsport PSI Energy, Inc. 1004 7-1 Averaging Plan 0.46 0.72 0.49 0.46 0.77 -6%IN Edwardsport PSI Energy, Inc. 1004 7-2 Averaging Plan 0.46 0.67 0.49 0.46 0.98 -32%IN Edwardsport PSI Energy, Inc. 1004 8-1 Averaging Plan 0.46 0.67 0.49 0.46 0.76 -12%IN Elmer W Stout Indianapolis Power & Light Co. 990 50 Averaging Plan 0.45 0.37 0.45 0.35 0.63 -41%IN Elmer W Stout Indianapolis Power & Light Co. 990 60 Averaging Plan 0.45 0.36 0.45 0.35 0.65 -45%IN Elmer W Stout Indianapolis Power & Light Co. 990 70 Averaging Plan 0.45 0.32 0.45 0.35 0.71 -55%IN F B Culley Southern Indiana Gas & Elec Co. 1012 1 Averaging Plan 0.46 0.72 0.50 0.48 0.79 -9%IN F B Culley Southern Indiana Gas & Elec Co. 1012 2 Averaging Plan 0.50 0.46 0.50 0.48 1.05 -56%IN F B Culley Southern Indiana Gas & Elec Co. 1012 3 Averaging Plan 0.50 0.46 0.50 0.48 1.23 -63%IN Frank E Ratts Hoosier Energy R E C Inc. 1043 1SG1 Averaging Plan 0.50 0.50 0.47 0.39 1.08 -54%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 12IN Frank E Ratts Hoosier Energy R E C Inc. 1043 2SG1 Averaging Plan 0.50 0.47 0.47 0.39 1.09 -57%IN Gibson PSI Energy, Inc. 6113 1 Averaging Plan 0.50 0.45 0.49 0.46 1.03 -56%IN Gibson PSI Energy, Inc. 6113 2 Averaging Plan 0.50 0.45 0.49 0.46 1.12 -60%IN Gibson PSI Energy, Inc. 6113 3 Averaging Plan 0.50 0.46 0.49 0.46 0.52 -12%IN Gibson PSI Energy, Inc. 6113 4 Averaging Plan 0.50 0.43 0.49 0.46 0.66 -35%IN Gibson PSI Energy, Inc. 6113 5 Averaging Plan 0.46 0.42 0.49 0.46 0.50 -16%IN H T Pritchard Indianapolis Power & Light Co. 991 3 Averaging Plan 0.45 0.68 0.45 0.35 0.74 -8%IN H T Pritchard Indianapolis Power & Light Co. 991 4 Averaging Plan 0.45 0.68 0.45 0.35 0.74 -8%IN H T Pritchard Indianapolis Power & Light Co. 991 5 Averaging Plan 0.45 0.41 0.45 0.35 0.67 -39%IN H T Pritchard Indianapolis Power & Light Co. 991 6 Averaging Plan 0.45 0.41 0.45 0.35 0.47 -13%IN Merom Hoosier Energy R E C Inc. 6213 1SG1 Averaging Plan/EE 0.46 0.39 0.47 / 0.50 0.39 0.23 70%IN Merom Hoosier Energy R E C Inc. 6213 2SG1 Averaging Plan/EE 0.46 0.36 0.47 / 0.50 0.39 0.63 -43%IN Michigan City Northern Indiana Public Service Co. 997 12 Averaging Plan 0.86 0.51 0.75 0.66 1.32 -61%IN Noblesville PSI Energy, Inc. 1007 1 Averaging Plan 0.46 0.93 0.49 0.46 0.62 50%IN Noblesville PSI Energy, Inc. 1007 2 Averaging Plan 0.46 0.89 0.49 0.46 0.91 -2%IN Noblesville PSI Energy, Inc. 1007 3 Averaging Plan 0.46 0.93 0.49 0.46 1.21 -23%IN Petersburg Indianapolis Power & Light Co. 994 1 Averaging Plan 0.45 0.29 0.45 0.35 0.56 -48%IN Petersburg Indianapolis Power & Light Co. 994 2 Averaging Plan 0.45 0.32 0.45 0.35 0.63 -49%IN Petersburg Indianapolis Power & Light Co. 994 3 Averaging Plan 0.45 0.36 0.45 0.35 0.37 -3%IN Petersburg Indianapolis Power & Light Co. 994 4 Averaging Plan 0.45 0.32 0.45 0.35 0.37 -14%IN R Gallagher PSI Energy, Inc. 1008 1 Averaging Plan 0.50 0.44 0.49 0.46 0.74 -41%IN R Gallagher PSI Energy, Inc. 1008 2 Averaging Plan 0.50 0.44 0.49 0.46 0.95 -54%IN R Gallagher PSI Energy, Inc. 1008 3 Averaging Plan 0.50 0.41 0.49 0.46 0.95 -57%IN R Gallagher PSI Energy, Inc. 1008 4 Averaging Plan 0.50 0.41 0.49 0.46 0.95 -57%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 13IN R M Schahfer Northern Indiana Public Service Co. 6085 14 Averaging Plan 0.86 0.57 0.75 0.66 1.33 -57%IN R M Schahfer Northern Indiana Public Service Co. 6085 15 Averaging Plan/EE 0.46 0.26 0.75 / 0.50 0.66 0.42 -38%IN R M Schahfer Northern Indiana Public Service Co. 6085 17 Early Election 0.40 0.36 0.45 0.46 -22%IN R M Schahfer Northern Indiana Public Service Co. 6085 18 Early Election 0.40 0.35 0.45 0.44 -20%IN Rockport American Electric Power Genera 6166 MB1 Averaging Plan/EE 0.46 0.40 0.61 / 0.50 0.56 0.32 25%IN Rockport Passive Lessors 6166 MB2 Averaging Plan/EE 0.46 0.40 0.61 / 0.50 0.56 0.32 25%IN State Line Mirant State Line Energy, LLC 981 3 Averaging Plan/EE 0.40 0.21 0.68 / 0.45 0.58 0.32 -34%IN State Line Mirant State Line Energy, LLC 981 4 Averaging Plan 0.86 0.83 0.68 0.58 0.75 11%IN Tanners Creek Indiana Michigan Power Co. 988 U1 Averaging Plan 0.80 0.70 0.61 0.56 1.14 -39%IN Tanners Creek Indiana Michigan Power Co. 988 U2 Averaging Plan 0.80 0.70 0.61 0.56 1.14 -39%IN Tanners Creek Indiana Michigan Power Co. 988 U3 Averaging Plan 0.80 0.70 0.61 0.56 1.14 -39%IN Tanners Creek Indiana Michigan Power Co. 988 U4 Averaging Plan 0.86 1.50 0.61 0.56 1.91 -21%IN Wabash River PSI Energy, Inc. 1010 1 Averaging Plan 0.50 0.14 0.49 0.46 0.95 -85%IN Wabash River PSI Energy, Inc. 1010 2 Averaging Plan 0.50 0.51 0.49 0.46 0.95 -46%IN Wabash River PSI Energy, Inc. 1010 3 Averaging Plan 0.50 0.64 0.49 0.46 0.92 -30%IN Wabash River PSI Energy, Inc. 1010 4 Averaging Plan 0.46 0.61 0.49 0.46 Not Oper.IN Wabash River PSI Energy, Inc. 1010 5 Averaging Plan 0.50 0.63 0.49 0.46 0.85 -26%IN Wabash River PSI Energy, Inc. 1010 6 Averaging Plan 0.45 0.36 0.49 0.46 0.37 -3%IN Warrick AGC Div of Alcoa Pwr Gen, Inc. 6705 4 Standard Limitation 0.68 0.45 1.00 -55%IN Whitewater Valley City of Richmond, Indiana 1040 1 Early Election 0.46 0.44 0.50 0.71 -38%IN Whitewater Valley City of Richmond, Indiana 1040 2 Early Election 0.40 0.44 0.45 0.71 -38%KS Holcomb Sunflower Electric Power Corp. 108 SGU1 Standard Limitation 0.46 0.27 0.32 -16%KS Jeffrey Energy Centre Western Resources, Inc. 6068 1 Averaging Plan 0.40 0.39 0.40 0.36 0.36 8%KS Jeffrey Energy Centre Western Resources, Inc. 6068 2 Averaging Plan 0.40 0.36 0.40 0.36 0.47 -23%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 14KS Jeffrey Energy Centre Western Resources, Inc. 6068 3 Averaging Plan 0.40 0.31 0.40 0.36 0.46 -33%KS La Cygne Kansas City Power & Light Co. 1241 1 Averaging Plan 0.86 0.97 0.66 0.60 1.09 -11%KS La Cygne Kansas City Power & Light Co. 1241 2 Averaging Plan 0.50 0.31 0.66 0.60 0.29 7%KS Lawrence Western Resources, Inc. 1250 3 Averaging Plan 0.40 0.33 0.40 0.36 0.45 -27%KS Lawrence Western Resources, Inc. 1250 4 Averaging Plan 0.40 0.44 0.40 0.36 0.51 -14%KS Lawrence Western Resources, Inc. 1250 5 Averaging Plan 0.40 0.36 0.40 0.36 0.34 6%KS Nearman Creek Board of Public Utilities, Kansas 6064 N1 Early Election 0.46 0.42 0.50 0.46 -9%KS Quindaro K.C. Board of Public Utilities 1295 1 Standard Limitation 0.86 0.81 0.97 -16%KS Quindaro K.C. Board of Public Utilities 1295 2 Standard Limitation 0.50 0.27 0.64 -58%KS Riverton Empire District Electric Co. 1239 39 Early Election 0.46 0.47 0.50 0.83 -43%KS Riverton Empire District Electric Co. 1239 40 Early Election 0.40 0.42 0.45 0.55 -24%KS Tecumseh Western Resources, Inc. 1252 9 Averaging Plan 0.40 0.40 0.40 0.36 0.42 -5%KS Tecumseh Western Resources, Inc. 1252 10 Averaging Plan 0.40 0.41 0.40 0.36 0.44 -7%KY Big Sandy Kentucky Power Co. 1353 BSU1 Averaging Plan 0.46 0.54 0.61 0.56 1.33 -59%KY Big Sandy Kentucky Power Co. 1353 BSU2 AEL Final 0.46 0.55 0.57 1.33 -59%KY Cane Run Louisville Gas and Electric Co. 1363 4 Early Election 0.46 0.44 0.50 0.84 -48%KY Cane Run Louisville Gas and Electric Co. 1363 5 Early Election 0.46 0.45 0.50 1.15 -61%KY Cane Run Louisville Gas and Electric Co. 1363 6 Early Election 0.40 0.32 0.45 1.02 -69%KY Coleman Big Rivers Electric Corp. 1381 C1 Averaging Plan 0.50 0.42 0.49 0.44 1.41 -70%KY Coleman Big Rivers Electric Corp. 1381 C2 Averaging Plan 0.50 0.44 0.49 0.44 1.29 -66%KY Coleman Big Rivers Electric Corp. 1381 C3 Averaging Plan 0.50 0.43 0.49 0.44 1.14 -62%KY Cooper East Kentucky Power Coop. Inc. 1384 1 Standard Limitation 0.50 0.42 0.90 -53%KY Cooper East Kentucky Power Coop. Inc. 1384 2 Standard Limitation 0.50 0.42 0.90 -53%KY D B Wilson Big Rivers Electric Corp. 6823 W1 Averaging Plan 0.46 0.43 0.49 / 0.50 0.44 0.56 -23%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 15KY Dale East Kentucky Power Coop., Inc. 1385 3 Early Election 0.46 0.36 0.50 0.73 -51%KY Dale East Kentucky Power Coop., Inc. 1385 4 Early Election 0.46 0.36 0.50 0.73 -51%KY E W Brown Kentucky Utilities Co. 1355 1 Averaging Plan 0.50 0.51 0.45 0.39 1.00 -49%KY E W Brown Kentucky Utilities Co. 1355 2 Averaging Plan 0.45 0.38 0.45 0.39 0.59 -36%KY E W Brown Kentucky Utilities Co. 1355 3 Averaging Plan 0.45 0.38 0.45 0.39 0.57 -33%KY East Bend Cincinnati Gas & Electric Co. 6018 2 Averaging Plan 0.50 0.37 0.49 0.46 0.31 19%KY Elmer Smith City of Owensboro 1374 2 Standard Limitation 0.45 0.39 0.86 -55%KY Ghent Kentucky Utilities Co. 1356 1 Averaging Plan 0.45 0.42 0.45 0.39 0.56 -25%KY Ghent Kentucky Utilities Co. 1356 2 Averaging Plan 0.40 0.35 0.45 0.39 0.54 -35%KY Ghent Kentucky Utilities Co. 1356 3 Averaging Plan 0.46 0.33 0.45 0.39 0.55 -40%KY Ghent Kentucky Utilities Co. 1356 4 Averaging Plan 0.46 0.33 0.45 0.39 0.55 -40%KY Green River Kentucky Utilities Co. 1357 1 Averaging Plan 0.46 0.69 0.45 0.39 0.65 6%KY Green River Kentucky Utilities Co. 1357 2 Averaging Plan 0.46 0.69 0.45 0.39 0.65 6%KY Green River Kentucky Utilities Co. 1357 3 Averaging Plan 0.46 0.69 0.45 0.39 0.65 6%KY Green River Kentucky Utilities Co. 1357 4 Averaging Plan 0.46 0.75 0.45 0.39 0.99 -24%KY Green River Kentucky Utilities Co. 1357 5 Averaging Plan 0.50 0.39 0.45 0.39 0.84 -54%KY H L Spurlock East Kentucky Power Coop. Inc. 6041 1 Standard Limitation 0.50 0.42 0.90 -53%KY H L Spurlock East Kentucky Power Coop., Inc. 6041 2 Early Election 0.40 0.40 0.45 0.47 -15%KY HMP&L Station 2 City of Henderson 1382 H1 Averaging Plan 0.50 0.46 0.49 0.44 1.34 -66%KY HMP&L Station 2 City of Henderson 1382 H2 Averaging Plan 0.50 0.48 0.49 0.44 1.34 -64%KY Mill Creek Louisville Gas and Electric Co. 1364 1 Early Election 0.40 0.30 0.45 0.76 -61%KY Mill Creek Louisville Gas and Electric Co. 1364 2 Early Election 0.40 0.34 0.45 0.79 -57%KY Mill Creek Louisville Gas and Electric Co. 1364 3 Early Election 0.46 0.40 0.50 0.62 -35%KY Mill Creek Louisville Gas and Electric Co. 1364 4 Early Election 0.46 0.43 0.50 0.57 -25%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 16KY Paradise Tennessee Valley Authority 1378 1 Averaging Plan 0.86 0.66 0.57 0.54 1.83 -64%KY Paradise Tennessee Valley Authority 1378 2 Averaging Plan 0.86 0.72 0.57 0.54 1.72 -58%KY Paradise Tennessee Valley Authority 1378 3 Averaging Plan 0.86 1.16 0.57 0.54 1.94 -40%KY Pineville Kentucky Utilities Co. 1360 3 Averaging Plan 0.46 0.61 0.45 0.39 0.83 -27%KY R D Green Big Rivers Electric Corp. 6639 G1 Averaging Plan 0.50 0.41 0.49 0.44 0.41 0%KY R D Green Big Rivers Electric Corp. 6639 G2 Averaging Plan 0.50 0.42 0.49 0.44 0.45 -7%KY Robert Reid Big Rivers Electric Corp. 1383 R1 Averaging Plan 0.46 0.81 0.49 0.44 0.78 4%KY Shawnee Tennessee Valley Authority 1379 1 Averaging Plan 0.46 0.39 0.57 0.54 0.71 -45%KY Shawnee Tennessee Valley Authority 1379 2 Averaging Plan 0.46 0.39 0.57 0.54 0.71 -45%KY Shawnee Tennessee Valley Authority 1379 3 Averaging Plan 0.46 0.39 0.57 0.54 0.71 -45%KY Shawnee Tennessee Valley Authority 1379 4 Averaging Plan 0.46 0.39 0.57 0.54 0.71 -45%KY Shawnee Tennessee Valley Authority 1379 5 Averaging Plan 0.46 0.39 0.57 0.54 0.71 -45%KY Shawnee Tennessee Valley Authority 1379 6 Averaging Plan 0.46 0.37 0.57 0.54 0.67 -45%KY Shawnee Tennessee Valley Authority 1379 7 Averaging Plan 0.46 0.37 0.57 0.54 0.67 -45%KY Shawnee Tennessee Valley Authority 1379 8 Averaging Plan 0.46 0.37 0.57 0.54 0.67 -45%KY Shawnee Tennessee Valley Authority 1379 9 Averaging Plan 0.46 0.37 0.57 0.54 0.67 -45%KY Trimble County Louisville Gas and Electric Co. 6071 1 Early Election 0.40 0.39 0.45 0.62 -37%KY Tyrone Kentucky Utilities Co. 1361 5 Averaging Plan 0.46 0.64 0.45 0.39 0.90 -29%LA Big Cajun 2 Louisiana Generating, LLC 6055 2B1 Early Election 0.46 0.31 0.50 0.28 11%LA Big Cajun 2 Louisiana Generating, LLC 6055 2B2 Early Election 0.46 0.33 0.50 0.25 32%LA Big Cajun 2 Louisiana Generating, LLC 6055 2B3 Early Election 0.46 0.29 0.50 0.24 21%LA Dolet Hills CLECO Power, LLC 51 1 Early Election 0.46 0.45 0.50 0.62 -27%LA R S Nelson Entergy Gulf States, Inc. 1393 6 Early Election 0.40 0.33 0.45 0.20 65%LA Rodemacher CLECO Power, LLC 6190 2 Early Election 0.46 0.43 0.50 0.38 13%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 17MA Brayton Point USGen New England, Inc. 1619 1 Standard Limitation 0.40 0.30 0.70 -57%MA Brayton Point USGen New England, Inc. 1619 2 Standard Limitation 0.40 0.29 0.70 -59%MA Brayton Point USGen New England, Inc. 1619 3 Standard Limitation 0.46 0.41 1.43 -71%MA Mount Tom Holyoke Water Power Co. 1606 1 Standard Limitation 0.46 0.36 1.00 -64%MA Salem Harbor USGen New England, Inc. 1626 1 Standard Limitation 0.46 0.31 1.10 -72%MA Salem Harbor USGen New England, Inc. 1626 2 Standard Limitation 0.46 0.31 1.10 -72%MA Salem Harbor USGen New England, Inc. 1626 3 Standard Limitation 0.46 0.31 1.10 -72%MA Somerset Somerset Operations Inc. 1613 7 Standard Limitation 0.40 Not Oper. 1.00MA Somerset Somerset Operations Inc. 1613 8 Standard Limitation 0.40 0.31 0.67 -54%MD Brandon Shores Constellation Pwr Source Gen 602 1 Averaging Plan 0.46 0.41 0.56 0.51 0.47 -13%MD Brandon Shores Constellation Pwr Source Gen 602 2 Averaging Plan 0.46 0.42 0.56 0.51 0.45 -7%MD C P Crane Constellation Pwr Source Gen 1552 1 Averaging Plan 0.86 1.06 0.56 0.51 1.27 -17%MD C P Crane Constellation Pwr Source Gen 1552 2 Averaging Plan 0.86 0.92 0.56 0.51 1.46 -37%MD Chalk Point Southern Energy Mid Atlantic 1571 1 AEL Final 0.50 0.63 0.86 1.35 -53%MD Chalk Point Southern Energy Mid Atlantic 1571 2 AEL Final 0.50 0.60 1.20 1.35 -56%MD Dickerson Southern Energy Mid Atlantic 1572 1 AEL Final 0.40 0.45 0.48 0.65 -31%MD Dickerson Southern Energy Mid Atlantic 1572 2 AEL Final 0.40 0.49 0.51 0.65 -25%MD Dickerson Southern Energy Mid Atlantic 1572 3 AEL Final 0.40 0.44 0.47 0.65 -32%MD Herbert A Wagner Constellation Pwr Source Gen 1554 2 Averaging Plan 0.46 0.60 0.56 0.51 0.83 -28%MD Herbert A Wagner Constellation Pwr Source Gen 1554 3 Averaging Plan 0.68 0.35 0.56 0.51 1.11 -68%MD Morgantown Southern Energy Mid Atlantic 1573 1 AEL Final 0.45 0.51 0.70 0.95 -46%MD Morgantown Southern Energy Mid Atlantic 1573 2 AEL Final 0.45 0.48 0.70 0.95 -49%MD R P Smith Allegheny Energy Supply Co., LL 1570 9 Averaging Plan 0.50 0.70 0.56 0.50 0.87 -20%MD R P Smith Allegheny Energy Supply Co., LL 1570 11 Averaging Plan 0.45 0.41 0.56 0.50 0.78 -47%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 18MI B C Cobb Consumers Energy Co. 1695 1 Standard Limitation 0.40 0.09 1.10 -92%MI B C Cobb Consumers Energy Co. 1695 2 Standard Limitation 0.40 0.05 1.10 -95%MI B C Cobb Consumers Energy Co. 1695 3 Standard Limitation 0.40 0.09 1.10 -92%MI B C Cobb Consumers Energy Co. 1695 4 Averaging Plan/EE 0.40 0.34 0.46/0.45 0.39 0.38 -11%MI B C Cobb Consumers Energy Co. 1695 5 Averaging Plan/EE 0.40 0.37 0.46/0.45 0.39 0.36 3%MI Belle River Detroit Edison Co. 6034 1 Averaging Plan 0.46 0.27 0.53 0.43 0.26 4%MI Belle River Detroit Edison Co. 6034 2 Averaging Plan 0.46 0.26 0.53 0.43 0.16 63%MI Dan E Karn Consumers Energy Co. 1702 1 Averaging Plan 0.40 0.45 0.46 0.39 0.64 -30%MI Dan E Karn Consumers Energy Co. 1702 2 Averaging Plan 0.46 0.26 0.46 0.39 0.91 -71%MI Eckert Station Lansing Board of Water & Light 1831 1 Averaging Plan 0.46 0.49 0.45 0.39 0.77 -36%MI Eckert Station Lansing Board of Water & Light 1831 2 Averaging Plan 0.40 0.35 0.45 0.39 0.57 -39%MI Eckert Station Lansing Board of Water & Light 1831 3 Averaging Plan 0.40 0.39 0.45 0.39 0.44 -11%MI Eckert Station Lansing Board of Water & Light 1831 4 Averaging Plan 0.46 0.39 0.45 0.39 0.62 -37%MI Eckert Station Lansing Board of Water & Light 1831 5 Averaging Plan 0.46 0.32 0.45 0.39 0.63 -49%MI Eckert Station Lansing Board of Water & Light 1831 6 Averaging Plan 0.46 0.36 0.45 0.39 0.70 -49%MI Endicott Generating Village of Clinton, Michigan 4259 1 Standard Limitation 0.46 0.40 0.58 -31%MI Erickson Lansing Board of Water & Light 1832 1 Averaging Plan 0.46 0.42 0.45 0.39 0.93 -55%MI Harbor Beach Detroit Edison Co.1731 1 Averaging Plan 0.46 0.88 0.53 0.43 0.90 -2%MI J B Sims City of Grand Haven 1825 3 Early Election 0.46 0.38 0.50 0.51 -25%MI J C Weadock Consumers Energy Co. 1720 7 Averaging Plan/EE 0.40 0.30 0.46 / 0.45 0.39 0.44 -32%MI J C Weadock Consumers Energy Co. 1720 8 Averaging Plan/EE 0.40 0.31 0.46 / 0.45 0.39 0.44 -30%MI J H Campbell Consumers Energy Co. 1710 1 AEL Final 0.45 0.43 0.55 0.69 -38%MI J H Campbell Consumers Energy Co. 1710 2 Averaging Plan 0.68 0.88 0.46 0.39 1.00 -12%MI J H Campbell Bay City Electric Light and Power 1710 3 Averaging Plan 0.46 0.33 0.46 0.39 0.69 -52%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 19MI J R Whiting Consumers Energy Co. 1723 1 Averaging Plan/EE 0.46 0.27 0.46 / 0.50 0.39 0.82 -67%MI J R Whiting Consumers Energy Co. 1723 2 Averaging Plan 0.46 0.34 0.46 0.39 0.96 -65%MI J R Whiting Consumers Energy Co. 1723 3 Averaging Plan/EE 0.46 0.32 0.46 / 0.50 0.39 1.04 -69%MI James De Young City of Holland 1830 5 Standard Limitation 0.46 0.42 0.99 -58%MI Marysville Detroit Edison Co. 1732 9 Averaging Plan 0.40 0.34 0.53 0.43 Not Oper.MI Marysville Detroit Edison Co. 1732 10 Averaging Plan 0.40 0.34 0.53 0.43 Not Oper.MI Marysville Detroit Edison Co. 1732 11 Averaging Plan 0.40 0.35 0.53 0.43 Not Oper.MI Marysville Detroit Edison Co. 1732 12 Averaging Plan 0.40 0.35 0.53 0.43 Not Oper.MI Monroe Detroit Edison Co. 1733 1 Averaging Plan 0.68 0.53 0.53 0.43 0.86 -38%MI Monroe Detroit Edison Co. 1733 2 Averaging Plan 0.68 0.53 0.53 0.43 0.86 -38%MI Monroe Detroit Edison Co. 1733 3 Averaging Plan 0.68 0.53 0.53 0.43 0.78 -32%MI Monroe Detroit Edison Co. 1733 4 Averaging Plan 0.68 0.53 0.53 0.43 0.78 -32%MI Presque Isle Wisconsin Electric Power Co. 1769 2 Averaging Plan 0.40 0.64 0.47 0.41 0.75 -15%MI Presque Isle Wisconsin Electric Power Co. 1769 3 Averaging Plan 0.40 0.64 0.47 0.41 0.75 -15%MI Presque Isle Wisconsin Electric Power Co. 1769 4 Averaging Plan 0.40 0.64 0.47 0.41 0.75 -15%MI Presque Isle Wisconsin Electric Power Co. 1769 5 Averaging Plan 0.46 0.82 0.47 0.41 0.91 -10%MI Presque Isle Wisconsin Electric Power Co. 1769 6 Averaging Plan 0.46 0.86 0.47 0.41 0.88 -2%MI Presque Isle Wisconsin Electric Power Co. 1769 7 Early Election 0.46 0.48 0.50 0.49 -2%MI Presque Isle Wisconsin Electric Power Co. 1769 8 Early Election 0.46 0.49 0.50 0.53 -8%MI Presque Isle Wisconsin Electric Power Co. 1769 9 Early Election 0.46 0.48 0.50 0.66 -27%MI River Rouge Detroit Edison Co. 1740 2 Averaging Plan 0.40 0.39 0.53 0.43 0.44 -11%MI River Rouge Detroit Edison Co. 1740 3 Averaging Plan 0.46 0.42 0.53 0.43 0.83 -49%MI Shiras Marquette Board of Light & Power 1843 3 Standard Limitation 0.40 0.18 0.22 -18%MI St Clair Detroit Edison Co. 1743 1 Averaging Plan 0.46 0.68 0.53 0.43 0.54 26%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 20MI St Clair Detroit Edison Co. 1743 2 Averaging Plan 0.46 0.31 0.53 0.43 0.58 -47%MI St Clair Detroit Edison Co. 1743 3 Averaging Plan 0.46 0.68 0.53 0.43 0.63 8%MI St Clair Detroit Edison Co. 1743 4 Averaging Plan 0.46 0.71 0.53 0.43 0.57 25%MI St Clair Detroit Edison Co. 1743 6 Averaging Plan 0.40 0.22 0.53 0.43 0.39 -44%MI St Clair Detroit Edison Co. 1743 7 Averaging Plan 0.40 0.42 0.53 0.43 0.31 35%MI Trenton Channel Detroit Edison Co. 1745 9A Averaging Plan 0.40 0.32 0.53 0.43 0.33 -3%MI Trenton Channel Detroit Edison Co. 1745 16 Averaging Plan 0.40 0.42 0.53 0.43 0.47 -11%MI Trenton Channel Detroit Edison Co. 1745 17 Averaging Plan 0.40 0.42 0.53 0.43 0.47 -11%MI Trenton Channel Detroit Edison Co. 1745 18 Averaging Plan 0.40 0.42 0.53 0.43 0.47 -11%MI Trenton Channel Detroit Edison Co. 1745 19 Averaging Plan 0.40 0.42 0.53 0.43 0.47 -11%MI Wyandotte Wyandotte Municipal Service Co. 1866 7 Standard Limitation 0.46 0.50 0.69 -28%MN Allen S King NSP (d/b/a Xcel Energy) 1915 1 Averaging Plan 0.86 0.71 0.54 0.48 1.22 -42%MN Black Dog NSP (d/b/a Xcel Energy) 1904 1 Averaging Plan 0.40 0.76 0.54 0.48 0.75 1%MN Black Dog NSP (d/b/a Xcel Energy) 1904 3 Averaging Plan 0.46 0.76 0.54 0.48 0.95 -20%MN Black Dog NSP (d/b/a Xcel Energy) 1904 4 Averaging Plan 0.46 0.76 0.54 0.48 0.95 -20%MN Clay Boswell Minnesota Power and Light Co. 1893 1 Averaging Plan 0.46 0.43 0.41 0.33 0.42 2%MN Clay Boswell Minnesota Power and Light Co. 1893 2 Averaging Plan 0.46 0.43 0.41 0.33 0.42 2%MN Clay Boswell Minnesota Power and Light Co. 1893 3 Early Election 0.40 0.38 0.45 0.41 0.42 -10%MN Clay Boswell Minnesota Power and Light Co. 1893 4 Averaging Plan 0.46 0.28 0.41 0.33 0.38 -26%MN High Bridge NSP (d/b/a Xcel Energy) 1912 3 Averaging Plan 0.50 0.58 0.54 0.48 0.48 21%MN High Bridge NSP (d/b/a Xcel Energy) 1912 4 Averaging Plan 0.50 0.58 0.54 0.48 0.48 21%MN High Bridge NSP (d/b/a Xcel Energy) 1912 5 Averaging Plan 0.50 0.58 0.54 0.48 0.48 21%MN High Bridge NSP (d/b/a Xcel Energy) 1912 6 Averaging Plan 0.50 0.58 0.54 0.48 0.48 21%MN Hoot Lake Otter Tail Power Co. 1943 2 Early Election 0.40 0.44 0.45 0.58 -24%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 21MN Hoot Lake Otter Tail Power Co. 1943 3 Standard Limitation 0.46 0.29 0.67 -57%MN Minnesota Valley NSP (d/b/a Xcel Energy) 1918 4 Averaging Plan 0.46 0.14 0.54 0.48 0.52 -73%MN Northeast Station City of Austin Utilities 1961 NEPP Standard Limitation 0.46 0.44 0.78 -44%MN Riverside NSP (d/b/a Xcel Energy) 1927 6 Averaging Plan 0.46 0.89 0.54 0.48 Not Oper.MN Riverside NSP (d/b/a Xcel Energy) 1927 7 Averaging Plan 0.46 0.89 0.54 0.48 0.70 27%MN Riverside NSP (d/b/a Xcel Energy) 1927 8 Averaging Plan 0.86 0.98 0.54 0.48 0.98 0%MN Sherburne County NSP (d/b/a Xcel Energy) 6090 1 Averaging Plan 0.45 0.30 0.54 0.48 0.45 -33%MN Sherburne County NSP (d/b/a Xcel Energy) 6090 2 Averaging Plan 0.45 0.30 0.54 0.48 0.45 -33%MN Sherburne County NSP (d/b/a Xcel Energy) 6090 3 Averaging Plan 0.46 0.34 0.54 0.48 0.28 21%MN Silver Lake Rochester Public Utilities 2008 4 Standard Limitation 0.46 0.36 0.82 -56%MN Syl Laskin Minnesota Power and Light Co. 1891 1 Averaging Plan 0.40 0.47 0.41 0.33 0.64 -27%MN Syl Laskin Minnesota Power and Light Co. 1891 2 Averaging Plan 0.40 0.47 0.41 0.33 0.64 -27%MO Asbury Empire District Electric Co. 2076 1 Standard Limitation 0.86 0.85 1.09 -22%MO Blue Valley City of Independence 2132 3 Standard Limitation 0.40 0.34 0.79 -57%MO Hawthorn Kansas City Power & Light Co. 2079 5 Standard Limitation 0.45 Not Oper. 0.36MO Iatan Empire District Electric Co. 6065 1 Standard Limitation 0.50 0.29 0.31 -6%MO James River City of Springfield (MO) 2161 3 Averaging Plan 0.50 0.53 0.50 0.45 1.02 -48%MO James River City of Springfield (MO) 2161 4 Averaging Plan 0.50 0.54 0.50 0.45 0.87 -38%MO James River City of Springfield (MO) 2161 5 Averaging Plan 0.50 0.62 0.50 0.45 0.93 -33%MO Labadie Union Electric Co. 2103 1 Averaging Plan 0.45 0.11 0.52 0.29 0.62 -82%MO Labadie Union Electric Co. 2103 2 Averaging Plan 0.45 0.12 0.52 0.29 0.62 -81%MO Labadie Union Electric Co. 2103 3 Averaging Plan 0.45 0.12 0.52 0.29 0.62 -81%MO Labadie Union Electric Co. 2103 4 Averaging Plan 0.45 0.12 0.52 0.29 0.62 -81%MO Meramec Union Electric Co. 2104 1 Averaging Plan 0.45 0.38 0.52 0.29 0.82 -54%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 22MO Meramec Union Electric Co. 2104 2 Averaging Plan 0.45 0.29 0.52 0.29 0.63 -54%MO Meramec Union Electric Co. 2104 3 Averaging Plan 0.50 0.75 0.52 0.29 0.96 -22%MO Meramec Union Electric Co. 2104 4 Averaging Plan 0.50 0.30 0.52 0.29 1.17 -74%MO Montrose Kansas City Power & Light Co. 2080 1 Standard Limitation 0.45 0.30 0.32 -6%MO Montrose Kansas City Power & Light Co. 2080 2 Standard Limitation 0.45 0.36 0.34 6%MO Montrose Kansas City Power & Light Co. 2080 3 Standard Limitation 0.45 0.36 0.34 6%MO New Madrid City of New Madrid, Missouri 2167 1 Averaging Plan 0.86 1.23 0.74 0.72 1.47 -16%MO New Madrid Associated Electric Coop. Inc. 2167 2 Averaging Plan 0.86 0.52 0.74 0.72 1.32 -61%MO Rush Island Union Electric Co. 6155 1 Averaging Plan 0.45 0.14 0.52 0.29 0.63 -78%MO Rush Island Union Electric Co. 6155 2 Averaging Plan 0.45 0.13 0.52 0.29 0.63 -79%MO Sibley Utilicorp United Inc. 2094 3 Standard Limitation 0.86 0.74 1.37 -46%MO Sikeston City of Columbia, MO 6768 1 Early Election 0.46 0.23 0.50 0.51 -55%MO Sioux Union Electric Co. 2107 1 Averaging Plan 0.86 1.33 0.52 0.29 1.07 24%MO Sioux Union Electric Co. 2107 2 Averaging Plan 0.86 0.47 0.52 0.29 1.21 -61%MO Southwest City of Springfield (MO) 6195 1 Averaging Plan 0.50 0.31 0.50 0.45 0.47 -34%MO Thomas Hill Associated Electric Coop. Inc. 2168 MB1 Averaging Plan 0.86 0.99 0.74 0.72 0.90 10%MO Thomas Hill Associated Electric Coop. Inc. 2168 MB2 Averaging Plan 0.86 1.01 0.74 0.72 0.90 12%MO Thomas Hill Associated Electric Coop. Inc. 2168 MB3 Averaging Plan 0.50 0.33 0.74 0.72 0.31 6%MS Jack Watson Mississippi Power Co. 2049 4 Averaging Plan 0.50 0.53 0.46 0.43 1.10 -52%MS Jack Watson Mississippi Power Co. 2049 5 Averaging Plan 0.50 0.71 0.46 0.43 1.22 -42%MS R D Morrow South Mississippi Electric Power A 6061 1 Averaging Plan 0.50 0.45 0.50 0.46 0.42 7%MS R D Morrow South Mississippi Electric Power A 6061 2 Averaging Plan 0.50 0.47 0.50 0.46 0.43 9%MS Victor J Daniel Jr Mississippi Power Co. 6073 1 Averaging Plan 0.45 0.31 0.46 0.43 0.27 15%MS Victor J Daniel Jr Mississippi Power Co. 6073 2 Averaging Plan 0.45 0.29 0.46 0.43 0.28 4%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 23MT Colstrip P P & L Montana, LLC 6076 1 Early Election 0.40 0.35 0.45 0.42 -17%MT Colstrip P P & L Montana, LLC 6076 2 Early Election 0.40 0.42 0.45 0.43 -2%MT Colstrip P P & L Montana, LLC 6076 3 Early Election 0.40 0.40 0.45 0.34 18%MT Colstrip Puget Sound Power & Light Co. 6076 4 Early Election 0.40 0.41 0.45 0.35 17%MT J E Corette P P & L Montana, LLC 2187 2 Standard Limitation 0.40 0.24 0.65 -63%MT Lewis & Clark Montana-Dakota Utilities Co. 6089 B1 Early Election 0.40 0.40 0.45 0.57 -30%NC Asheville Carolina Power & Light Co. 2706 1 Averaging Plan 0.46 0.46 0.44 0.41 1.08 -57%NC Asheville Carolina Power & Light Co. 2706 2 Averaging Plan 0.46 0.36 0.44 0.41 0.86 -58%NC Belews Creek Duke Energy Corp. 8042 1 Standard Limitation 0.68 0.60 1.46 -59%NC Belews Creek Duke Energy Corp. 8042 2 Standard Limitation 0.68 0.55 1.36 -60%NC Buck Duke Energy Corp. 2720 5 Early Election 0.40 0.41 0.45 0.59 -31%NC Buck Duke Energy Corp. 2720 6 Early Election 0.40 0.42 0.45 0.54 -22%NC Buck Duke Energy Corp. 2720 7 Early Election 0.40 0.44 0.45 0.57 -23%NC Buck Duke Energy Corp. 2720 8 Early Election 0.40 0.43 0.45 0.45 -4%NC Buck Duke Energy Corp. 2720 9 Early Election 0.40 0.44 0.45 0.51 -14%NC Cape Fear Carolina Power & Light Co. 2708 5 Averaging Plan 0.40 0.46 0.44 0.41 0.47 -2%NC Cape Fear Carolina Power & Light Co. 2708 6 Averaging Plan 0.40 0.59 0.44 0.41 0.66 -11%NC Cliffside Duke Energy Corp. 2721 1 Early Election 0.40 0.38 0.45 Not Oper.NC Cliffside Duke Energy Corp. 2721 2 Early Election 0.40 0.40 0.45 Not Oper.NC Cliffside Duke Energy Corp. 2721 3 Early Election 0.40 0.39 0.45 Not Oper.NC Cliffside Duke Energy Corp. 2721 4 Early Election 0.40 0.42 0.45 Not Oper.NC Cliffside Duke Energy Corp. 2721 5 Early Election 0.40 0.44 0.45 0.51 -14%NC Dan River Duke Energy Corp. 2723 1 Early Election 0.40 0.41 0.45 0.52 -21%NC Dan River Duke Energy Corp. 2723 2 Early Election 0.40 0.43 0.45 0.55 -22%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 24NC Dan River Duke Energy Corp. 2723 3 Early Election 0.40 0.44 0.45 0.56 -21%NC G G Allen Duke Energy Corp. 2718 1 Early Election 0.40 0.45 0.45 0.65 -31%NC G G Allen Duke Energy Corp. 2718 2 Early Election 0.40 0.45 0.45 0.61 -26%NC G G Allen Duke Energy Corp. 2718 3 Early Election 0.40 0.44 0.45 0.64 -31%NC G G Allen Duke Energy Corp. 2718 4 Early Election 0.40 0.44 0.45 0.68 -35%NC G G Allen Duke Energy Corp. 2718 5 Early Election 0.40 0.45 0.45 0.68 -34%NC L V Sutton Carolina Power & Light Co. 2713 1 Averaging Plan 0.40 0.58 0.44 0.41 0.63 -8%NC L V Sutton Carolina Power & Light Co. 2713 2 Averaging Plan 0.46 0.58 0.44 0.41 0.63 -8%NC L V Sutton Carolina Power & Light Co. 2713 3 Averaging Plan 0.46 0.37 0.44 0.41 1.19 -69%NC Lee Carolina Power & Light Co. 2709 1 Averaging Plan 0.40 0.60 0.44 0.41 0.82 -27%NC Lee Carolina Power & Light Co. 2709 2 Averaging Plan 0.46 0.70 0.44 0.41 0.73 -4%NC Lee Carolina Power & Light Co. 2709 3 Averaging Plan 0.46 0.36 0.44 0.41 0.90 -60%NC Marshall Duke Energy Corp. 2727 1 Early Election 0.40 0.44 0.45 0.48 -8%NC Marshall Duke Energy Corp. 2727 2 Early Election 0.40 0.44 0.45 0.61 -28%NC Marshall Duke Energy Corp. 2727 3 Early Election 0.40 0.34 0.45 0.52 -35%NC Marshall Duke Energy Corp. 2727 4 Early Election 0.40 0.45 0.45 0.70 -36%NC Mayo Carolina Power & Light Co. 6250 1A Averaging Plan 0.46 0.35 0.44 0.41 0.64 -45%NC Mayo Carolina Power & Light Co. 6250 1B Averaging Plan 0.46 0.35 0.44 0.41 Not Oper.NC Riverbend Duke Energy Corp. 2732 7 Early Election 0.40 0.42 0.45 0.58 -28%NC Riverbend Duke Energy Corp. 2732 8 Early Election 0.40 0.39 0.45 0.58 -33%NC Riverbend Duke Energy Corp. 2732 9 Early Election 0.40 0.42 0.45 0.58 -28%NC Riverbend Duke Energy Corp. 2732 10 Early Election 0.40 0.41 0.45 0.70 -41%NC Roxboro Carolina Power & Light Co. 2712 1 Averaging Plan 0.46 0.46 0.44 0.41 1.30 -65%NC Roxboro Carolina Power & Light Co. 2712 2 Averaging Plan 0.40 0.29 0.44 0.41 0.76 -62%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 25NC Roxboro Carolina Power & Light Co. 2712 3A Averaging Plan 0.46 0.38 0.44 0.41 1.31 -71%NC Roxboro Carolina Power & Light Co. 2712 3B Averaging Plan 0.46 0.38 0.44 0.41 Not Oper.NC Roxboro Carolina Power & Light Co. 2712 4A Averaging Plan 0.46 0.39 0.44 0.41 0.57 -32%NC Roxboro Carolina Power & Light Co. 2712 4B Averaging Plan 0.46 0.39 0.44 0.41 Not Oper.NC W H Weatherspoon Carolina Power & Light Co. 2716 1 Averaging Plan 0.46 0.70 0.44 0.41 0.73 -4%NC W H Weatherspoon Carolina Power & Light Co. 2716 2 Averaging Plan 0.46 0.70 0.44 0.41 0.73 -4%NC W H Weatherspoon Carolina Power & Light Co. 2716 3 Averaging Plan 0.40 0.42 0.44 0.41 0.72 -42%ND Antelope Valley Basin Electric Power Coop. 6469 B1 Early Election 0.40 0.38 0.45 0.43 -12%ND Antelope Valley Basin Electric Power Coop. 6469 B2 Early Election 0.40 0.33 0.45 0.27 22%ND Coal Creek Great River Energy 6030 1 Standard Limitation 0.40 0.21 0.55 -62%ND Coal Creek Great River Energy 6030 2 Standard Limitation 0.40 0.22 0.82 -73%ND Coyote Montana-Dakota Utilities Co. 8222 B1 Standard Limitation 0.86 0.74 0.81 -9%ND Leland Olds Basin Electric Power Coop. 2817 1 Early Election 0.46 0.25 0.50 0.74 -66%ND Leland Olds Basin Electric Power Coop. 2817 2 Standard Limitation 0.86 0.60 1.03 -42%ND Milton R Young Minnkota Power Coop., Inc. 2823 B1 Standard Limitation 0.86 0.80 0.81 -1%ND Milton R Young Minnkota Power Coop., Inc. 2823 B2 Standard Limitation 0.86 0.84 1.05 -20%ND Stanton Great River Energy 2824 1 Standard Limitation 0.46 0.41 0.84 -51%ND Stanton Great River Energy 2824 10 Early Election 0.40 0.37 0.45 0.47 -21%NE Gerald Whelan Energy City of Hastings 60 1 Early Election 0.40 0.29 0.45 0.30 -3%NE Gerald Gentleman Station Nebraska Public Power District 6077 1 Early Election 0.46 0.43 0.50 0.40 7%NE Gerald Gentleman Station Nebraska Public Power District 6077 2 Early Election 0.46 0.32 0.50 0.35 -9%NE Lon Wright City of Fremont 2240 8 Standard Limitation 0.46 0.18 0.19 -5%NE Nebraska City Omaha Public Power District 6096 1 Early Election 0.46 0.41 0.50 0.48 -15%NE North Omaha Omaha Public Power District 2291 1 Standard Limitation 0.40 0.29 0.41 -29%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 26NE North Omaha Omaha Public Power District 2291 2 Standard Limitation 0.40 0.29 0.41 -29%NE North Omaha Omaha Public Power District 2291 3 Standard Limitation 0.40 0.29 0.41 -29%NE North Omaha Omaha Public Power District 2291 4 Early Election 0.40 0.32 0.45 0.38 -16%NE North Omaha Omaha Public Power District 2291 5 Standard Limitation 0.46 0.32 0.95 -66%NE Platte City of Grand Island 59 1 Early Election 0.40 0.41 0.45 0.48 -15%NH Merrimack Vermont Electric Power 2364 2 Standard Limitation 0.86 0.38 1.96 -81%NH Schiller Public Service Co. of NH 2367 4 Standard Limitation 0.46 0.34 1.00 -66%NH Schiller Public Service Co. of NH 2367 5 Standard Limitation 0.46 0.37 1.26 -71%NH Schiller Public Service Co. of NH 2367 6 Standard Limitation 0.46 0.32 1.07 -70%NJ B L England Atlantic City Electric Co. 2378 2 Standard Limitation 0.86 0.50 1.19 -58%NJ Deepwater Atlantic City Electric Co. 2384 8 Standard Limitation 0.46 0.38 0.71 -46%NJ Hudson PSEG Fossil LLC 2403 2 Averaging Plan 0.46 0.46 0.64 0.58 1.34 -66%NJ Mercer PSEG Fossil LLC 2408 1 Averaging Plan 0.84 0.69 0.64 0.58 1.35 -49%NJ Mercer PSEG Fossil LLC 2408 2 Averaging Plan 0.84 0.74 0.64 0.58 1.90 -61%NM Escalante Tri-State G&T Association, Inc. 87 1 Early Election 0.40 0.41 0.45 0.35 17%NM Four Corners Arizona Public Service Co. 2442 1 Averaging Plan 0.46 0.76 0.61 0.55 0.82 -7%NM Four Corners Arizona Public Service Co. 2442 2 Averaging Plan 0.46 0.49 0.61 0.55 0.78 -37%NM Four Corners Arizona Public Service Co. 2442 3 Averaging Plan 0.46 0.56 0.61 0.55 1.00 -44%NM Four Corners Arizona Public Service Co. 2442 4 Averaging Plan 0.68 0.55 0.61 0.55 0.51 8%NM Four Corners Arizona Public Service Co. 2442 5 Averaging Plan 0.68 0.52 0.61 0.55 1.10 -53%NM San Juan Public Service Co. of NM 2451 1 Averaging Plan 0.46 0.45 0.46 0.44 0.42 7%NM San Juan Public Service Co. of NM 2451 2 Averaging Plan 0.46 0.49 0.46 0.44 0.65 -25%NM San Juan Public Service Co. of NM 2451 3 Averaging Plan 0.46 0.41 0.46 0.44 0.39 5%NM San Juan Public Service Co. of NM 2451 4 Averaging Plan 0.46 0.42 0.46 0.44 0.42 0%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 27NV Mohave Nevada Power Co. 2341 1 Early Election 0.40 0.42 0.45 0.38 11%NV Mohave Southern California Edison Co. 2341 2 Early Election 0.40 0.40 0.45 0.46 -13%NV North Valmy Idaho Power Co. 8224 1 Early Election 0.46 0.35 0.50 0.51 -31%NV North Valmy Sierra Pacific Power Co. 8224 2 Early Election 0.46 0.38 0.50 0.40 -5%NV Reid Gardner Nevada Power Co. 2324 1 Standard Limitation 0.46 0.41 1.12 -63%NV Reid Gardner Nevada Power Co. 2324 2 Standard Limitation 0.46 0.43 1.13 -62%NV Reid Gardner Nevada Power Co. 2324 3 Standard Limitation 0.46 0.43 0.53 -19%NV Reid Gardner Nevada Power Co. 2324 4 Early Election 0.46 0.28 0.50 0.38 -26%NY AES Westover NGE Generation, Inc. 2526 11 Averaging Plan 0.46 0.59 0.45 0.35 0.62 -5%NY AES Westover NGE Generation, Inc. 2526 12 Averaging Plan 0.46 0.59 0.45 0.35 0.62 -5%NY AES Westover NGE Generation, Inc. 2526 13 Averaging Plan 0.40 0.44 0.45 0.35 0.68 -35%NY C R Huntley Huntley Power Operations, Inc. 2549 63 Standard Limitation 0.84 0.74 0.91 -19%NY C R Huntley Huntley Power Operations, Inc. 2549 64 Standard Limitation 0.84 0.74 0.91 -19%NY C R Huntley Huntley Power Operations, Inc. 2549 65 Standard Limitation 0.84 0.74 0.91 -19%NY C R Huntley Huntley Power Operations, Inc. 2549 66 Standard Limitation 0.84 0.74 0.91 -19%NY C R Huntley Huntley Power Operatons, Inc. 2549 67 Early Election 0.40 0.37 0.45 0.64 -42%NY C R Huntley Huntley Power Operatons, Inc. 2549 68 Early Election 0.40 0.37 0.45 0.64 -42%NY Danskammer Dynegy Northeast Generation 2480 3 Averaging Plan 0.40 0.43 0.40 0.40 0.54 -20%NY Danskammer Dynegy Northeast Generation 2480 4 Averaging Plan 0.40 0.38 0.40 0.40 0.62 -39%NY Dunkirk Niagara Mohawk Power Corp. 2554 1 Early Election 0.40 0.36 0.45 0.48 -25%NY Dunkirk Niagara Mohawk Power Corp. 2554 2 Early Election 0.40 0.35 0.45 0.48 -27%NY Dunkirk Niagara Mohawk Power Corp. 2554 3 Standard Limitation 0.45 0.35 0.48 -27%NY Dunkirk Niagara Mohawk Power Corp. 2554 4 Standard Limitation 0.45 0.35 0.48 -27%NY Greenidge AES Greenidge, LLC 2527 4 Averaging Plan 0.46 0.70 0.45 0.35 0.69 1%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 28NY Greenidge AES Greenidge, LLC 2527 5 Averaging Plan 0.46 0.70 0.45 0.35 0.69 1%NY Greenidge AES Greenidge, LLC 2527 6 Averaging Plan 0.45 0.35 0.45 0.35 0.55 -36%NY Kintigh NGE Generation, Inc. 6082 1 Averaging Plan/EE 0.46 0.31 0.45 / 0.50 0.35 0.62 -50%NY Lovett Southern Energy Lovett, LLC 2629 4 Standard Limitation 0.46 0.35 0.57 -39%NY Lovett Southern Energy Lovett, LLC 2629 5 Standard Limitation 0.46 0.36 0.59 -39%NY Milliken NGE Generation, Inc. 2535 1 Averaging Plan 0.45 0.31 0.45 0.35 0.66 -53%NY Milliken NGE Generation, Inc. 2535 2 Averaging Plan 0.45 0.31 0.45 0.35 0.59 -47%NY Rochester 3 Rochester Gas & Electric Corp. 2640 12 Standard Limitation 0.40 Not Oper. 0.77NY Rochester 7 Rochester Gas & Electric Corp. 2642 1 Averaging Plan 0.40 0.40 0.40 0.37 0.62 -35%NY Rochester 7 Rochester Gas & Electric Corp. 2642 2 Averaging Plan 0.40 0.40 0.40 0.37 0.65 -38%NY Rochester 7 Rochester Gas & Electric Corp. 2642 3 Averaging Plan 0.40 0.35 0.40 0.37 0.44 -20%NY Rochester 7 Rochester Gas & Electric Corp. 2642 4 Averaging Plan 0.40 0.35 0.40 0.37 0.59 -41%NY S A Carlson City of Jamestown 2682 9 Early Election 0.46 0.41 0.50 0.90 -54%NY S A Carlson City of Jamestown 2682 10 Early Election 0.46 0.45 0.50 0.90 -50%NY S A Carlson City of Jamestown 2682 11 Early Election 0.46 0.45 0.50 1.05 -57%NY S A Carlson City of Jamestown 2682 12 Early Election 0.46 0.41 0.50 0.83 -51%OH Acme Toledo Edison Co. 2877 14 Standard Limitation 0.80 Not Oper. 1.34OH Acme Toledo Edison Co. 2877 15 Standard Limitation 0.80 Not Oper. 1.34OH Acme Toledo Edison Co. 2877 16 Standard Limitation 0.80 Not Oper. 1.34OH Acme Toledo Edison Co. 2877 91 Standard Limitation 0.80 Not Oper. 1.34OH Acme Toledo Edison Co. 2877 92 Standard Limitation 0.80 Not Oper. 1.34OH Ashtabula Cleveland Electric Illum Co. 2835 7 Averaging Plan 0.45 0.36 0.51 0.47 0.61 -41%OH Ashtabula Cleveland Electric Illum Co. 2835 8 Averaging Plan 0.46 0.52 0.51 0.47 0.51 2%OH Ashtabula Cleveland Electric Illum Co. 2835 9 Standard Limitation 0.46 Not Oper. 0.51Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 29OH Ashtabula Cleveland Electric Illum Co. 2835 10 Averaging Plan 0.46 0.52 0.51 0.47 0.51 2%OH Ashtabula Cleveland Electric Illum Co. 2835 11 Averaging Plan 0.46 0.52 0.51 0.47 0.51 2%OH Avon Lake Orion Power Midwest, LP 2836 9 Standard Limitation 0.40 Not Oper. 0.63OH Avon Lake Orion Power Midwest, LP 2836 10 Averaging Plan 0.40 0.39 0.55 0.49 0.58 -33%OH Avon Lake Orion Power Midwest, LP 2836 12 Averaging Plan 0.68 0.80 0.55 0.49 0.96 -17%OH Bay Shore Toledo Edison Co. 2878 1 Averaging Plan 0.80 Not Oper. 0.51 0.47 1.08OH Bay Shore Toledo Edison Co. 2878 2 Averaging Plan 0.80 0.73 0.51 0.47 1.08 -32%OH Bay Shore Toledo Edison Co. 2878 3 Averaging Plan 0.46 0.73 0.51 0.47 1.08 -32%OH Bay Shore Toledo Edison Co. 2878 4 Averaging Plan 0.46 0.73 0.51 0.47 1.08 -32%OH Cardinal/Tidd Ohio Power Co. 2828 1 Averaging Plan 0.68 0.57 0.61 0.56 0.90 -37%OH Cardinal/Tidd Buckeye Power, Inc. 2828 2 Averaging Plan 0.68 0.54 0.61 0.56 1.02 -47%OH Cardinal/Tidd Buckeye Power, Inc. 2828 3 Averaging Plan 0.46 0.56 0.61 0.56 0.74 -24%OH Conesville Columbus Southern Power Co. 2840 3 Averaging Plan 0.50 0.46 0.61 0.56 0.93 -51%OH Conesville Dayton Power & Light Co. 2840 4 Averaging Plan 0.45 0.47 0.61 0.56 0.55 -15%OH Conesville Columbus Southern Power Co. 2840 5 Early Election 0.40 0.42 0.45 0.44 -5%OH Conesville Columbus Southern Power Co. 2840 6 Early Election 0.40 0.42 0.45 0.44 -5%OH Eastlake Cleveland Electric Illum Co. 2837 1 Averaging Plan 0.45 0.37 0.51 0.47 0.49 -24%OH Eastlake Cleveland Electric Illum Co. 2837 2 Averaging Plan 0.45 0.41 0.51 0.47 0.68 -40%OH Eastlake Cleveland Electric Illum Co. 2837 3 Averaging Plan 0.45 0.36 0.51 0.47 0.54 -33%OH Eastlake Cleveland Electric Illum Co. 2837 4 Averaging Plan 0.45 0.35 0.51 0.47 0.51 -31%OH Eastlake Cleveland Electric Illum Co. 2837 5 Averaging Plan 0.68 0.77 0.51 0.47 0.67 15%OH Edgewater Ohio Edison Co. 2857 11 Averaging Plan 0.80 Not Oper. 0.51 0.47 1.16OH Edgewater Ohio Edison Co. 2857 12 Averaging Plan 0.80 Not Oper. 0.51 0.47 1.16OH Edgewater Ohio Edison Co. 2857 13 Averaging Plan 0.50 0.18 0.51 0.47 1.16 -84%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 30OH Gen J M Gavin Ohio Power Co. 8102 1 Averaging Plan 0.68 0.45 0.61 0.56 1.16 -61%OH Gen J M Gavin Ohio Power Co. 8102 2 Averaging Plan 0.68 0.49 0.61 0.56 1.16 -58%OH Gorge Ohio Edison Co. 2858 25 Averaging Plan 0.50 Not Oper. 0.51 0.47 1.16OH Gorge Ohio Edison Co. 2858 26 Averaging Plan 0.50 Not Oper. 0.51 0.47 1.16OH Hamilton City of Hamilton 2917 9 Standard Limitation 0.40 0.38 0.60 -37%OH J M Stuart Dayton Power & Light Co. 2850 1 Averaging Plan 0.68 0.59 0.62 0.55 1.11 -47%OH J M Stuart Dayton Power & Light Co. 2850 2 Averaging Plan 0.68 0.58 0.62 0.55 1.05 -45%OH J M Stuart Cinergy 2850 3 Averaging Plan 0.68 0.60 0.62 0.55 0.95 -37%OH J M Stuart Dayton Power & Light Co. 2850 4 Averaging Plan 0.68 0.54 0.62 0.55 1.16 -53%OH Killen Station Cincinnati Gas & Electric Co. 6031 2 Averaging Plan 0.46 0.45 0.62 0.55 0.51 -12%OH Kyger Creek Ohio Valley Electric Corp. 2876 1 Averaging Plan 0.84 0.78 0.84 0.76 1.34 -42%OH Kyger Creek Ohio Valley Electric Corp. 2876 2 Averaging Plan 0.84 0.78 0.84 0.76 1.34 -42%OH Kyger Creek Ohio Valley Electric Corp. 2876 3 Averaging Plan 0.84 0.78 0.84 0.76 1.34 -42%OH Kyger Creek Ohio Valley Electric Corp. 2876 4 Averaging Plan 0.84 0.78 0.84 0.76 1.34 -42%OH Kyger Creek Ohio Valley Electric Corp. 2876 5 Averaging Plan 0.84 0.78 0.84 0.76 1.34 -42%OH Lake Shore Cleveland Electric Illum Co. 2838 18 Averaging Plan 0.40 0.39 0.51 0.47 0.67 -42%OH Miami Fort Cincinnati Gas & Electric Co. 2832 5-1 Averaging Plan 0.80 1.00 0.49 0.46 0.71 41%OH Miami Fort Cincinnati Gas & Electric Co. 2832 5-2 Averaging Plan 0.80 1.00 0.49 0.46 0.71 41%OH Miami Fort Cincinnati Gas & Electric Co. 2832 6 Averaging Plan 0.45 0.47 0.49 0.46 0.73 -36%OH Miami Fort Cincinnati Gas & Electric Co. 2832 7 Averaging Plan 0.68 0.52 0.49 0.46 1.07 -51%OH Miami Fort Cincinnati Gas & Electric Co. 2832 8 Averaging Plan 0.46 0.56 0.49 0.46 0.62 -10%OH Muskingum River Ohio Power Co. 2872 1 Averaging Plan 0.84 0.74 0.61 0.56 1.09 -32%OH Muskingum River Ohio Power Co. 2872 2 Averaging Plan 0.84 0.74 0.61 0.56 1.09 -32%OH Muskingum River Ohio Power Co. 2872 3 Averaging Plan 0.86 0.74 0.61 0.56 1.09 -32%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 31OH Muskingum River Ohio Power Co. 2872 4 Averaging Plan 0.86 0.74 0.61 0.56 1.09 -32%OH Muskingum River Ohio Power Co. 2872 5 Averaging Plan 0.68 0.65 0.61 0.56 1.20 -46%OH O H Hutchings Dayton Power & Light Co. 2848 H-1 Averaging Plan 0.40 0.56 0.62 0.55 0.67 -16%OH O H Hutchings Dayton Power & Light Co. 2848 H-2 Averaging Plan 0.40 0.56 0.62 0.55 0.67 -16%OH O H Hutchings Dayton Power & Light Co. 2848 H-3 Averaging Plan 0.40 0.58 0.62 0.55 0.63 -8%OH O H Hutchings Dayton Power & Light Co. 2848 H-4 Averaging Plan 0.40 0.58 0.62 0.55 0.63 -8%OH O H Hutchings Dayton Power & Light Co. 2848 H-5 Averaging Plan 0.40 0.58 0.62 0.55 0.51 14%OH O H Hutchings Dayton Power & Light Co. 2848 H-6 Averaging Plan 0.40 0.58 0.62 0.55 0.51 14%OH Picway Columbus Southern Power Co. 2843 9 Averaging Plan 0.50 0.43 0.61 0.56 0.87 -51%OH R E Burger Ohio Edison Co. 2864 1 Averaging Plan 0.84 Not Oper. 0.51 0.47 0.83OH R E Burger Ohio Edison Co. 2864 2 Averaging Plan 0.84 Not Oper. 0.51 0.47 0.90OH R E Burger Ohio Edison Co. 2864 3 Averaging Plan 0.84 Not Oper. 0.51 0.47 0.94OH R E Burger Ohio Edison Co. 2864 4 Averaging Plan 0.84 Not Oper. 0.51 0.47 1.09OH R E Burger Ohio Edison Co. 2864 5 Averaging Plan 0.84 0.89 0.51 0.47 0.75 19%OH R E Burger Ohio Edison Co. 2864 6 Averaging Plan 0.84 0.87 0.51 0.47 0.73 19%OH R E Burger Ohio Edison Co. 2864 7 Averaging Plan 0.50 0.67 0.51 0.47 0.66 2%OH R E Burger Ohio Edison Co. 2864 8 Averaging Plan 0.50 0.64 0.51 0.47 0.72 -11%OH Richard Gorsuch American Municipal Power - OH 7253 1 Standard Limitation 0.46 0.38 Not Oper.OH Richard Gorsuch American Municipal Power - OH 7253 2 Standard Limitation 0.46 0.38 Not Oper.OH Richard Gorsuch American Municipal Power - OH 7253 3 Standard Limitation 0.46 0.38 Not Oper.OH Richard Gorsuch American Municipal Power - OH 7253 4 Standard Limitation 0.46 0.38 Not Oper.OH Toronto Ohio Edison Co. 2867 9 Averaging Plan 0.84 Not Oper. 0.51 0.47 1.06OH Toronto Ohio Edison Co. 2867 10 Averaging Plan 0.50 Not Oper. 0.51 0.47 1.06OH Toronto Ohio Edison Co. 2867 11 Averaging Plan 0.50 Not Oper. 0.51 0.47 1.06Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 32OH W H Sammis Ohio Edison Co. 2866 1 Averaging Plan 0.46 0.44 0.51 0.47 0.87 -49%OH W H Sammis Ohio Edison Co. 2866 2 Averaging Plan 0.46 0.45 0.51 0.47 0.85 -47%OH W H Sammis Ohio Edison Co. 2866 3 Averaging Plan 0.46 1.03 0.51 0.47 0.86 20%OH W H Sammis Ohio Edison Co. 2866 4 Averaging Plan 0.46 0.62 0.51 0.47 0.81 -23%OH W H Sammis Ohio Edison Co. 2866 5 Averaging Plan 0.50 0.47 0.51 0.47 0.52 -10%OH W H Sammis Ohio Edison Co. 2866 6 Averaging Plan 0.50 0.40 0.51 0.47 1.10 -64%OH W H Sammis Ohio Edison Co. 2866 7 Averaging Plan 0.68 0.36 0.51 0.47 1.06 -66%OH W H Zimmer Cincinnati Gas & Electric Co. 6019 1 Early Election 0.46 0.46 0.50 Not Oper.OH Walter C Beckjord Cincinnati Gas & Electric Co. 2830 1 Averaging Plan 0.40 0.67 0.49 0.46 0.58 16%OH Walter C Beckjord Cincinnati Gas & Electric Co. 2830 2 Averaging Plan 0.40 0.65 0.49 0.46 0.65 0%OH Walter C Beckjord Cincinnati Gas & Electric Co. 2830 3 Averaging Plan 0.46 1.00 0.49 0.46 1.21 -17%OH Walter C Beckjord Cincinnati Gas & Electric Co. 2830 4 Averaging Plan 0.40 0.63 0.49 0.46 0.51 24%OH Walter C Beckjord Cincinnati Gas & Electric Co. 2830 5 Averaging Plan 0.45 0.44 0.49 0.46 0.72 -39%OH Walter C Beckjord Cincinnati Gas & Electric Co. 2830 6 Averaging Plan 0.45 0.33 0.49 0.46 0.71 -54%OK GRDA Grand River Dam Authority 165 1 Averaging Plan 0.46 0.43 0.46 0.35 0.41 5%OK GRDA Grand River Dam Authority 165 2 Averaging Plan 0.46 0.27 0.46 0.35 0.27 0%OK Hugo Western Farmers Electric Coop. 6772 1 Standard Limitation 0.46 0.22 0.27 -19%OK Muskogee Oklahoma Gas & Electric Co. 2952 4 Early Election 0.40 0.38 0.45 0.44 -14%OK Muskogee Oklahoma Gas & Electric Co. 2952 5 Early Election 0.40 0.32 0.45 0.41 -22%OK Muskogee Oklahoma Gas & Electric Co. 2952 6 Early Election 0.40 0.42 0.45 0.44 -5%OK Northeastern American Electric Power Service 2963 3313 Early Election 0.40 0.36 0.45 0.53 -32%OK Northeastern American Electric Power Service 2963 3314 Early Election 0.40 0.36 0.45 0.53 -32%OK Sooner Oklahoma Gas & Electric Co. 6095 1 Early Election 0.40 0.37 0.45 0.33 12%OK Sooner Oklahoma Gas & Electric Co. 6095 2 Early Election 0.40 0.35 0.45 0.42 -17%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 33OR Boardman Portland General Electric Co. 6106 1SG Early Election 0.46 0.41 0.50 0.40 2%PA Armstrong Allegheny Energy Supply Co., LL 3178 1 Averaging Plan 0.50 0.37 0.56 0.50 0.90 -59%PA Armstrong Allegheny Energy Supply Co., LL 3178 2 Averaging Plan 0.50 0.37 0.56 0.50 1.04 -64%PA Bruce Mansfield Pennsylvania Power Co. 6094 1 Averaging Plan 0.50 0.36 0.51 0.47 0.98 -63%PA Bruce Mansfield Pennsylvania Power Co. 6094 2 Averaging Plan 0.50 0.34 0.51 0.47 1.13 -70%PA Bruce Mansfield Pennsylvania Power Co. 6094 3 Averaging Plan/EE 0.46 0.38 0.51 / 0.50 0.47 0.57 -33%PA Brunner Island PPL Brunner Island, LLC 3140 1 Standard Limitation 0.45 0.38 0.65 -42%PA Brunner Island PPL Brunner Island, LLC 3140 2 Standard Limitation 0.45 0.38 0.71 -46%PA Brunner Island PPL Brunner Island, LLC 3140 3 Standard Limitation 0.45 0.36 0.83 -57%PA Cheswick Orion Power Midwest, LP 8226 1 Averaging Plan 0.45 0.36 0.55 0.49 0.71 -49%PA Conemaugh Reliant Energy NE Management C 3118 1 Standard Limitation 0.45 0.34 0.65 -48%PA Conemaugh Reliant Energy NE Management C 3118 2 Standard Limitation 0.45 0.34 0.71 -52%PA Cromby Exelon Generation Co. 3159 1 Early Election 0.46 0.36 0.50 0.60 -40%PA Eddystone Exelon Generation Co. 3161 1 Early Election 0.40 0.29 0.45 0.42 -31%PA Eddystone Exelon Generation Co. 3161 2 Early Election 0.40 0.27 0.45 0.50 -46%PA Elrama Orion Power Midwest, LP 3098 1 Averaging Plan 0.80 0.48 0.55 0.49 0.80 -40%PA Elrama Orion Power Midwest, LP 3098 2 Averaging Plan 0.80 0.48 0.55 0.49 0.80 -40%PA Elrama Orion Power Midwest, LP 3098 3 Averaging Plan 0.80 0.48 0.55 0.49 0.80 -40%PA Elrama Orion Power Midwest, LP 3098 4 Averaging Plan 0.46 0.48 0.55 0.49 0.85 -44%PA F R Phillips Orion Power Midwest, LP 3099 1 Standard Limitation 0.80 Not Oper. 0.85PA F R Phillips Orion Power Midwest, LP 3099 2 Standard Limitation 0.80 Not Oper. 0.85PA F R Phillips Orion Power Midwest, LP 3099 3 Standard Limitation 0.80 Not Oper. 0.85PA F R Phillips Orion Power Midwest, LP 3099 4 Standard Limitation 0.80 Not Oper. 0.85PA F R Phillips Orion Power Midwest, LP 3099 5 Standard Limitation 0.80 Not Oper. 0.85Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 34PA F R Phillips Orion Power Midwest, LP 3099 6 Standard Limitation 0.80 Not Oper. 0.85PA Hatfield's Ferry Allegheny Energy Supply Co., LL 3179 1 Averaging Plan 0.68 0.46 0.56 0.50 1.13 -59%PA Hatfield's Ferry Allegheny Energy Supply Co., LL 3179 2 Averaging Plan 0.68 0.46 0.56 0.50 1.17 -61%PA Hatfield's Ferry Allegheny Energy Supply Co., LL 3179 3 Averaging Plan 0.68 0.46 0.56 0.50 0.90 -49%PA Homer City EME Homer City Generation, LP 3122 1 Early Election 0.46 0.41 0.50 1.09 -62%PA Homer City EME Homer City Generation, LP 3122 2 Early Election 0.46 0.44 0.50 1.04 -58%PA Homer City EME Homer City Generation, LP 3122 3 Early Election 0.46 0.44 0.50 0.62 -29%PA Keystone Reliant Energy NE Management C 3136 1 Early Election 0.40 0.32 0.45 0.79 -59%PA Keystone Reliant Energy NE Management C 3136 2 Early Election 0.40 0.33 0.45 0.79 -58%PA Martins Creek PPL Martins Creek, LLC 3148 1 Standard Limitation 0.50 0.44 1.03 -57%PA Martins Creek PPL Martins Creek, LLC 3148 2 Standard Limitation 0.50 0.44 0.93 -53%PA Mitchell Allegheny Energy Supply Co., LL 3181 33 Averaging Plan 0.45 0.37 0.56 0.50 0.68 -46%PA Montour PPL Montour, LLC 3149 1 Early Election 0.40 0.42 0.45 0.95 -56%PA Montour PPL Montour, LLC 3149 2 Early Election 0.40 0.32 0.45 0.46 -30%PA New Castle Orion Power Midwest, LP 3138 1 Standard Limitation 0.50 Not Oper. 0.79PA New Castle Orion Power Midwest, LP 3138 2 Standard Limitation 0.50 Not Oper. 0.79PA New Castle Orion Power Midwest, LP 3138 3 Averaging Plan/EE 0.46 0.33 0.55 / 0.50 0.49 0.63 -48%PA New Castle Orion Power Midwest, LP 3138 4 Averaging Plan/EE 0.46 0.36 0.55 / 0.50 0.49 0.57 -37%PA New Castle Orion Power Midwest, LP 3138 5 Averaging Plan/EE 0.46 0.39 0.55 / 0.50 0.49 0.73 -47%PA Portland Reliant Energy Mid-Atl Pwr Hol 3113 1 Averaging Plan 0.45 0.25 0.44 0.35 0.46 -46%PA Portland Reliant Energy Mid-Atl Pwr Hol 3113 2 Averaging Plan 0.45 0.30 0.44 0.35 0.66 -55%PA Seward Reliant Energy Mid-Atl Pwr Hol 3130 12 Averaging Plan 0.46 0.45 0.44 0.35 0.83 -46%PA Seward Reliant Energy Mid-Atl Pwr Hol 3130 14 Averaging Plan 0.46 0.45 0.44 0.35 0.83 -46%PA Seward Reliant Energy Mid-Atl Pwr Hol 3130 15 Averaging Plan 0.40 0.45 0.44 0.35 0.75 -40%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 35PA Shawville Reliant Energy Mid-Atl Pwr Hol 3131 1 Standard Limitation 0.50 0.45 0.99 -55%PA Shawville Reliant Energy Mid-Atl Pwr Hol 3131 2 Standard Limitation 0.50 0.45 1.02 -56%PA Shawville Reliant Energy Mid-Atl Pwr Hol 3131 3 Standard Limitation 0.45 0.39 0.83 -53%PA Shawville Reliant Energy Mid-Atl Pwr Hol 3131 4 Standard Limitation 0.45 0.39 0.82 -52%PA Sunbury Sunbury Generation, LLC 3152 3 Standard Limitation 0.50 0.38 0.93 -59%PA Sunbury Sunbury Generation, LLC 3152 4 Standard Limitation 0.50 0.38 1.29 -71%PA Titus Reliant Energy Mid-Atlantic Pwr Holdings 3115 1 Early Election 0.40 0.32 0.45 0.73 -56%PA Titus Reliant Energy Mid-Atlantic Pwr Holdings 3115 2 Early Election 0.40 0.32 0.45 0.68 -53%PA Titus Reliant Energy Mid-Atlantic Pwr Holdings 3115 3 Early Election 0.40 0.33 0.45 0.77 -57%PA Warren Reliant Energy Mid-Atl Pwr Holdings 3132 1 Averaging Plan 0.46 0.52 0.44 0.35 0.63 -17%PA Warren Reliant Energy Mid-Atl Pwr Holdings 3132 2 Averaging Plan 0.46 0.52 0.44 0.35 0.63 -17%PA Warren Reliant Energy Mid-Atl Pwr Holdings 3132 3 Averaging Plan 0.46 0.52 0.44 0.35 0.63 -17%PA Warren Reliant Energy Mid-Atl Pwr Holdings 3132 4 Averaging Plan 0.46 0.52 0.44 0.35 0.63 -17%SC Canadys Steam South Carolina Electric & Gas 3280 CAN1 Averaging Plan 0.40 0.40 0.41 0.35 0.45 -11%SC Canadys Steam South Carolina Electric & Gas 3280 CAN2 Averaging Plan 0.40 0.41 0.41 0.35 0.60 -32%SC Canadys Steam South Carolina Electric & Gas 3280 CAN3 Averaging Plan 0.46 0.38 0.41 0.35 1.00 -62%SC Cope Station South Carolina Electric & Gas 7210 COP1 Averaging Plan 0.40 0.26 0.41 0.35 Not Oper.SC Cross South Carolina Public Serv. Authority 130 1 Averaging Plan/EE 0.46 0.31 0.46 / 0.50 0.40 Not Oper.SC Cross South Carolina Public Service Authority 130 2 Early Election 0.40 0.39 0.45 0.46 -15%SC Dolphus M Grainger South Carolina Public Serv. Authority 3317 1 Averaging Plan 0.46 0.48 0.46 0.40 0.90 -47%SC Dolphus M Grainger South Carolina Public Serv. Authority 3317 2 Averaging Plan 0.46 0.90 0.46 0.40 1.07 -16%SC H B Robinson Carolina Power & Light Co. 3251 1 Averaging Plan 0.40 0.76 0.44 0.41 0.63 21%SC Jefferies South Carolina Public Serv. Authority 3319 3 Averaging Plan 0.46 0.41 0.46 0.40 1.01 -59%SC Jefferies South Carolina Public Serv. Authority 3319 4 Averaging Plan 0.46 0.44 0.46 0.40 1.15 -62%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 36SC McMeekin South Carolina Electric & Gas 3287 MCM1 Averaging Plan 0.40 0.39 0.41 0.35 0.61 -36%SC McMeekin South Carolina Electric & Gas 3287 MCM2 Averaging Plan 0.40 0.38 0.41 0.35 0.59 -36%SC Urquhart South Carolina Electric & Gas 3295 URQ1 Averaging Plan 0.40 0.47 0.41 0.35 0.69 -32%SC Urquhart South Carolina Electric & Gas 3295 URQ2 Averaging Plan 0.40 0.51 0.41 0.35 0.64 -20%SC Urquhart South Carolina Electric & Gas 3295 URQ3 Averaging Plan 0.40 0.35 0.41 0.35 0.51 -31%SC W S Lee Duke Energy Corp. 3264 1 Early Election 0.40 0.43 0.45 0.64 -33%SC W S Lee Duke Energy Corp. 3264 2 Early Election 0.40 0.43 0.45 0.61 -30%SC W S Lee Duke Energy Corp. 3264 3 Early Election 0.40 0.43 0.45 0.50 -14%SC Wateree South Carolina Electric & Gas 3297 WAT1 AEL Final 0.46 0.46 0.59 1.30 -65%SC Wateree South Carolina Electric & Gas 3297 WAT2 AEL Final 0.46 0.41 0.59 1.47 -72%SC Williams South Carolina Electric & Gas 3298 WIL1 AEL Final 0.40 0.47 0.48 0.87 -46%SC Winyah South Carolina Public Serv. Au 6249 1 Averaging Plan/AEL 0.46 0.44 0.46 / 0.61 0.40 1.03 -57%SC Winyah South Carolina Public Serv. Au 6249 2 AEL Final 0.46 0.52 0.61 0.65 -20%SC Winyah South Carolina Public Serv. Au 6249 3 AEL Final 0.46 0.59 0.60 0.63 -6%SC Winyah South Carolina Public Serv. Au 6249 4 AEL Final 0.46 0.54 0.60 0.50 8%SD Big Stone Northwestern Public Service Co. 6098 1 Standard Limitation 0.86 0.84 1.29 -35%TN Allen Tennessee Valley Authority 3393 1 Averaging Plan 0.86 0.75 0.57 0.54 1.95 -62%TN Allen Tennessee Valley Authority 3393 2 Averaging Plan 0.86 0.73 0.57 0.54 1.91 -62%TN Allen Tennessee Valley Authority 3393 3 Averaging Plan 0.86 0.76 0.57 0.54 1.87 -59%TN Bull Run Tennessee Valley Authority 3396 1 Averaging Plan 0.40 0.63 0.57 0.54 0.67 -6%TN Cumberland Tennessee Valley Authority 3399 1 Averaging Plan 0.68 0.47 0.57 0.54 1.57 -70%TN Cumberland Tennessee Valley Authority 3399 2 Averaging Plan 0.68 0.52 0.57 0.54 1.33 -61%TN Gallatin Tennessee Valley Authority 3403 1 Averaging Plan 0.45 0.29 0.57 0.54 0.59 -51%TN Gallatin Tennessee Valley Authority 3403 2 Averaging Plan 0.45 0.29 0.57 0.54 0.63 -54%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 37TN Gallatin Tennessee Valley Authority 3403 3 Averaging Plan 0.45 0.30 0.57 0.54 0.59 -49%TN Gallatin Tennessee Valley Authority 3403 4 Averaging Plan 0.45 0.30 0.57 0.54 0.55 -45%TN John Sevier Tennessee Valley Authority 3405 1 Early Election 0.40 0.40 0.45 0.62 -35%TN John Sevier Tennessee Valley Authority 3405 2 Early Election 0.40 0.40 0.45 0.62 -35%TN John Sevier Tennessee Valley Authority 3405 3 Early Election 0.40 0.41 0.45 0.64 -36%TN John Sevier Tennessee Valley Authority 3405 4 Early Election 0.40 0.41 0.45 0.64 -36%TN Johnsonville Tennessee Valley Authority 3406 1 Averaging Plan 0.45 0.48 0.57 0.54 0.45 7%TN Johnsonville Tennessee Valley Authority 3406 2 Averaging Plan 0.45 0.48 0.57 0.54 0.48 0%TN Johnsonville Tennessee Valley Authority 3406 3 Averaging Plan 0.45 0.48 0.57 0.54 0.46 4%TN Johnsonville Tennessee Valley Authority 3406 4 Averaging Plan 0.45 0.48 0.57 0.54 0.54 -11%TN Johnsonville Tennessee Valley Authority 3406 5 Averaging Plan 0.45 0.48 0.57 0.54 0.45 7%TN Johnsonville Tennessee Valley Authority 3406 6 Averaging Plan 0.45 0.48 0.57 0.54 0.50 -4%TN Johnsonville Tennessee Valley Authority 3406 7 Averaging Plan 0.50 0.48 0.57 0.54 1.00 -52%TN Johnsonville Tennessee Valley Authority 3406 8 Averaging Plan 0.50 0.48 0.57 0.54 0.97 -51%TN Johnsonville Tennessee Valley Authority 3406 9 Averaging Plan 0.50 0.48 0.57 0.54 1.10 -56%TN Johnsonville Tennessee Valley Authority 3406 10 Averaging Plan 0.50 0.48 0.57 0.54 1.07 -55%TN Kingston Tennessee Valley Authority 3407 1 Averaging Plan 0.40 0.55 0.57 0.54 0.60 -8%TN Kingston Tennessee Valley Authority 3407 2 Averaging Plan 0.40 0.55 0.57 0.54 0.60 -8%TN Kingston Tennessee Valley Authority 3407 3 Averaging Plan 0.40 0.55 0.57 0.54 0.60 -8%TN Kingston Tennessee Valley Authority 3407 4 Averaging Plan 0.40 0.55 0.57 0.54 0.60 -8%TN Kingston Tennessee Valley Authority 3407 5 Averaging Plan 0.40 0.55 0.57 0.54 0.60 -8%TN Kingston Tennessee Valley Authority 3407 6 Averaging Plan 0.40 0.43 0.57 0.54 0.63 -32%TN Kingston Tennessee Valley Authority 3407 7 Averaging Plan 0.40 0.43 0.57 0.54 0.63 -32%TN Kingston Tennessee Valley Authority 3407 8 Averaging Plan 0.40 0.43 0.57 0.54 0.63 -32%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 38TN Kingston Tennessee Valley Authority 3407 9 Averaging Plan 0.40 0.43 0.57 0.54 0.63 -32%TX Big Brown TXU Electric Co. 3497 1 Early Election 0.40 0.38 0.45 0.40 -5%TX Big Brown TXU Electric Co. 3497 2 Early Election 0.40 0.36 0.45 0.34 6%TX Coleto Creek American Electric Power Service 6178 1 Early Election 0.40 0.24 0.45 0.38 -37%TX Gibbons Creek Texas Municipal Power Agency 6136 1 Early Election 0.40 0.29 0.45 0.47 -38%TX Harrington Station Southwestern Public Service Co. 6193 061B Early Election 0.40 0.28 0.45 0.27 4%TX Harrington Station Southwestern Public Service Co. 6193 062B Early Election 0.40 0.30 0.45 0.36 -17%TX Harrington Station Southwestern Public Service Co. 6193 063B Early Election 0.40 0.25 0.45 0.36 -31%TX J T Deely City of San Antonio 6181 1 Early Election 0.40 0.26 0.45 0.31 -16%TX J T Deely City of San Antonio 6181 2 Early Election 0.40 0.26 0.45 0.31 -16%TX J K Spruce City of San Antonio 7097 **1 Early Election 0.40 0.18 0.45 Not Oper.TX Limestone Houston Lighting & Power Co. 298 LIM1 Early Election 0.40 0.40 0.45 0.50 -20%TX Limestone Houston Lighting & Power Co. 298 LIM2 Early Election 0.40 0.28 0.45 0.48 -42%TX Martin Lake TXU Electric Co. 6146 1 Early Election 0.40 0.28 0.45 0.36 -22%TX Martin Lake TXU Electric Co. 6146 2 Early Election 0.40 0.29 0.45 0.35 -17%TX Martin Lake TXU Electric Co. 6146 3 Early Election 0.40 0.31 0.45 0.42 -26%TX Monticello TXU Electric Co. 6147 1 Early Election 0.40 0.30 0.45 0.31 -3%TX Monticello TXU Electric Co. 6147 2 Early Election 0.40 0.30 0.45 0.40 -25%TX Monticello TXU Electric Co. 6147 3 Early Election 0.46 0.24 0.50 0.21 14%TX Oklaunion American Electric Power Service 127 1 Early Election 0.46 0.29 0.50 0.54 -46%TX Pirkey American Electric Power Service 7902 1 Early Election 0.46 0.36 0.50 0.34 6%TX Sam Seymour City of Austin, Texas 6179 1 Early Election 0.40 0.33 0.45 0.34 -3%TX Sam Seymour City of Austin, Texas 6179 2 Early Election 0.40 0.31 0.45 0.29 7%TX Sam Seymour Lower Colorado River Authority 6179 3 Early Election 0.40 0.33 0.45 0.25 32%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 39TX San Miguel San Miguel Electric Coop. 6183 SM-1 Early Election 0.46 0.40 0.50 0.41 -2%TX Sandow TXU Electric Co. 6648 4 Early Election 0.40 0.33 0.45 0.43 -23%TX Tolk Station Southwestern Public Service Co. 6194 171B Early Election 0.40 0.30 0.45 0.38 -21%TX Tolk Station Southwestern Public Service Co. 6194 172B Early Election 0.40 0.30 0.45 0.24 25%TX W A Parish Houston Lighting & Power Co. 3470 WAP5 Early Election 0.46 0.34 0.50 0.47 -28%TX W A Parish Houston Lighting & Power Co. 3470 WAP6 Early Election 0.46 0.20 0.50 0.53 -62%TX W A Parish Houston Lighting & Power Co. 3470 WAP7 Early Election 0.40 0.14 0.45 0.35 -60%TX W A Parish Houston Lighting & Power Co. 3470 WAP8 Early Election 0.40 0.30 0.45 0.31 -3%TX Welsh American Electric Power Service 6139 1 Early Election 0.46 0.29 0.50 0.27 7%TX Welsh American Electric Power Service 6139 2 Early Election 0.46 0.33 0.50 0.36 -8%TX Welsh American Electric Power Service 6139 3 Early Election 0.46 0.36 0.50 0.37 -3%UT Bonanza Deseret Generation & Transmission 7790 1-1 Early Election 0.46 0.34 0.50 0.42 -19%UT Carbon PacifiCorp 3644 1 Early Election 0.40 0.42 0.45 0.50 -16%UT Carbon PacifiCorp 3644 2 Early Election 0.40 0.44 0.45 0.58 -24%UT Hunter (Emery) PacifiCorp 6165 1 Early Election 0.40 0.44 0.45 0.50 -12%UT Hunter (Emery) PacifiCorp 6165 2 Early Election 0.40 0.42 0.45 0.55 -24%UT Hunter (Emery) PacifiCorp 6165 3 Averaging Plan 0.46 0.41 0.45 0.40 0.34 21%UT Huntington PacifiCorp 8069 1 Early Election 0.40 0.43 0.45 0.52 -17%UT Huntington PacifiCorp 8069 2 Averaging Plan 0.40 0.42 0.45 0.40 0.43 -2%UT Intermountain Intermountain Power Service Co. 6481 1SGA Early Election 0.46 0.42 0.50 0.45 -7%UT Intermountain Intermountain Power Service Co. 6481 2SGA Early Election 0.46 0.41 0.50 0.38 8%VA Bremo Bluff Dominion Generation 3796 3 Averaging Plan 0.46 0.75 0.41 0.36 0.78 -4%VA Bremo Bluff Dominion Generation 3796 4 Averaging Plan 0.46 0.41 0.41 0.36 0.93 -56%VA Chesapeake Virginia Electric & Power Co. 3803 1 Early Election 0.40 0.41 0.45 0.42 -2%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 40VA Chesapeake Virginia Electric & Power Co. 3803 2 Early Election 0.40 0.41 0.45 0.48 -15%VA Chesapeake Virginia Electric & Power Co. 3803 3 Averaging Plan 0.46 0.42 0.41 0.36 1.07 -61%VA Chesapeake Virginia Electric & Power Co. 3803 4 Early Election 0.40 0.43 0.45 0.54 -20%VA Chesterfield Virginia Electric & Power Co. 3797 3 Early Election 0.40 0.42 0.45 0.52 -19%VA Chesterfield Virginia Electric & Power Co. 3797 4 Early Election 0.40 0.42 0.45 0.49 -14%VA Chesterfield Virginia Electric & Power Co. 3797 5 Averaging Plan 0.40 0.36 0.41 0.36 0.62 -42%VA Chesterfield Virginia Electric & Power Co. 3797 6 Averaging Plan 0.40 0.37 0.41 0.36 0.73 -49%VA Clinch River Appalachian Power Co. 3775 1 Averaging Plan 0.80 0.64 0.61 0.56 1.34 -52%VA Clinch River Appalachian Power Co. 3775 2 Averaging Plan 0.80 0.64 0.61 0.56 1.34 -52%VA Clinch River Appalachian Power Co. 3775 3 Averaging Plan 0.80 0.59 0.61 0.56 1.42 -58%VA Clover Virginia Electric & Power Co. 7213 1 Averaging Plan 0.40 0.29 0.41 0.36 Not Oper.VA Clover Virginia Electric & Power Co. 7213 2 Averaging Plan 0.40 0.30 0.41 0.36 Not Oper.VA Glen Lyn Appalachian Power Co. 3776 6 Averaging Plan 0.46 0.62 0.61 0.56 0.76 -18%VA Glen Lyn Appalachian Power Co. 3776 51 Averaging Plan/EE 0.40 0.40 0.61 / 0.45 0.56 0.46 -13%VA Glen Lyn Appalachian Power Co. 3776 52 Averaging Plan/EE 0.40 0.43 0.61 / 0.45 0.56 Not Oper.VA Possum Point Virginia Electric & Power Co. 3804 3 Early Election 0.40 0.43 0.45 0.60 -28%VA Possum Point Virginia Electric & Power Co. 3804 4 Averaging Plan 0.40 0.36 0.41 0.36 0.61 -41%VA Potomac River Southern Energy Mid Atlantic 3788 1 Early Election 0.40 0.43 0.45 0.51 -16%VA Potomac River Southern Energy Mid Atlantic 3788 2 Early Election 0.40 0.42 0.45 0.44 -5%VA Potomac River Southern Energy Mid Atlantic 3788 3 Early Election 0.40 0.41 0.45 0.64 -36%VA Potomac River Southern Energy Mid Atlantic 3788 4 Early Election 0.40 0.44 0.45 0.46 -4%VA Potomac River Southern Energy Mid Atlantic 3788 5 Early Election 0.40 0.42 0.45 0.72 -42%VA Yorktown Virginia Electric & Power Co. 3809 1 Early Election 0.40 0.45 0.45 0.57 -21%VA Yorktown Virginia Electric & Power Co. 3809 2 Early Election 0.40 0.40 0.45 0.57 -30%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 41WA Centralia Transalta Centralia Generation 3845 BW21 Early Election 0.40 0.40 0.45 0.40 0%WA Centralia Transalta Centralia Generation 3845 BW22 Early Election 0.40 0.40 0.45 0.45 -11%WI Alma Dairyland Power Coop. 4140 B4 Averaging Plan 0.50 0.63 0.48 0.42 0.85 -26%WI Alma Dairyland Power Coop. 4140 B5 Averaging Plan 0.50 0.63 0.48 0.42 0.85 -26%WI Blount Street Madison Gas & Electric Co. 3992 7 Standard Limitation 0.68 0.62 0.89 -30%WI Blount Street Madison Gas & Electric Co. 3992 8 Early Election 0.46 0.37 0.50 0.71 -48%WI Blount Street Madison Gas & Electric Co. 3992 9 Early Election 0.46 0.41 0.50 0.61 -33%WI Columbia Wisconsin Power & Light Co. 8023 1 Early Election 0.40 0.37 0.45 0.46 -20%WI Columbia Wisconsin Power & Light Co. 8023 2 Early Election 0.40 0.34 0.45 0.49 -31%WI Edgewater Wisconsin Power & Light Co. 4050 4 Averaging Plan 0.86 1.06 0.62 0.56 1.17 -9%WI Edgewater Wisconsin Power & Light Co. 4050 5 Averaging Plan/EE 0.46 0.21 0.62 / 0.50 0.56 0.21 0%WI Genoa Dairyland Power Coop. 4143 1 Averaging Plan 0.45 0.37 0.48 0.42 0.75 -51%WI J P Madgett Dairyland Power Coop. 4271 B1 Averaging Plan 0.50 0.39 0.48 0.42 0.30 30%WI Pleasant Prairie Wisconsin Electric Power Co. 6170 1 Averaging Plan 0.46 0.42 0.47 0.41 0.45 -7%WI Pleasant Prairie Wisconsin Electric Power Co. 6170 2 Averaging Plan 0.46 0.42 0.47 0.41 0.45 -7%WI Port Washington Wisconsin Electric Power Co. 4040 1 Averaging Plan 0.50 0.31 0.47 0.41 0.32 -3%WI Port Washington Wisconsin Electric Power Co. 4040 2 Averaging Plan 0.50 0.31 0.47 0.41 0.32 -3%WI Port Washington Wisconsin Electric Power Co. 4040 3 Averaging Plan 0.50 0.31 0.47 0.41 0.32 -3%WI Port Washington Wisconsin Electric Power Co. 4040 4 Averaging Plan 0.50 0.30 0.47 0.41 0.37 -19%WI Port Washington Wisconsin Electric Power Co. 4040 5 Standard Limitation 0.50 Not Oper. 0.37WI Pulliam Wisconsin Public Service Corp. 4072 3 Averaging Plan 0.46 0.72 0.47 0.41 0.76 -5%WI Pulliam Wisconsin Public Service Corp. 4072 4 Averaging Plan 0.46 0.72 0.47 0.41 0.76 -5%WI Pulliam Wisconsin Public Service Corp. 4072 5 Averaging Plan 0.46 0.78 0.47 0.41 0.94 -17%WI Pulliam Wisconsin Public Service Corp. 4072 6 Averaging Plan 0.46 0.78 0.47 0.41 0.94 -17%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 42WI Pulliam Wisconsin Public Service Corp. 4072 7 Averaging Plan 0.50 0.45 0.47 0.41 0.69 -35%WI Pulliam Wisconsin Public Service Corp. 4072 8 Averaging Plan 0.50 0.32 0.47 0.41 0.57 -44%WI South Oak Creek Wisconsin Electric Power Co. 4041 5 Averaging Plan 0.50 0.23 0.47 0.41 0.28 -18%WI South Oak Creek Wisconsin Electric Power Co. 4041 6 Averaging Plan 0.50 0.23 0.47 0.41 0.28 -18%WI South Oak Creek Wisconsin Electric Power Co. 4041 7 Averaging Plan 0.45 0.39 0.47 0.41 0.66 -41%WI South Oak Creek Wisconsin Electric Power Co. 4041 8 Averaging Plan 0.45 0.39 0.47 0.41 0.67 -42%WI Stoneman Mid-American Power, LLC 4146 B1 Averaging Plan 0.46 0.39 0.47 0.41 0.75 -48%WI Stoneman Mid-American Power, LLC 4146 B2 Averaging Plan 0.46 0.39 0.47 0.41 0.75 -48%WI Valley Wisconsin Electric Power Co. 4042 1 Averaging Plan 0.50 0.46 0.47 0.41 1.10 -58%WI Valley Wisconsin Electric Power Co. 4042 2 Averaging Plan 0.50 0.46 0.47 0.41 1.10 -58%WI Valley Wisconsin Electric Power Co. 4042 3 Averaging Plan 0.50 0.47 0.47 0.41 1.05 -55%WI Valley Wisconsin Electric Power Co. 4042 4 Averaging Plan 0.50 0.47 0.47 0.41 0.93 -49%WI Weston Wisconsin Public Service Corp. 4078 1 Averaging Plan 0.50 0.83 0.47 0.41 0.90 -8%WI Weston Wisconsin Public Service Corp. 4078 2 Averaging Plan 0.50 0.38 0.47 0.41 1.08 -65%WI Weston Wisconsin Public Service Corp. 4078 3 Averaging Plan 0.45 0.22 0.47 0.41 0.26 -15%WV Albright Monongahela Power Co. 3942 1 Averaging Plan 0.50 0.66 0.56 0.50 1.10 -40%WV Albright Monongahela Power Co. 3942 2 Averaging Plan 0.50 0.66 0.56 0.50 1.10 -40%WV Albright Monongahela Power Co. 3942 3 Averaging Plan 0.45 0.38 0.56 0.50 0.71 -46%WV Fort Martin Monongahela Power Co. 3943 1 Averaging Plan 0.45 0.40 0.56 0.50 0.62 -35%WV Fort Martin Monongahela Power Co. 3943 2 Averaging Plan 0.68 0.98 0.56 0.50 1.07 -8%WV Harrison Monongahela Power Co. 3944 1 Averaging Plan/AEL 0.50 0.46 0.56 / 0.70 0.50 0.99 -54%WV Harrison Monongahela Power Co. 3944 2 Averaging Plan 0.50 0.46 0.56 0.50 1.13 -59%WV Harrison Monongahela Power Co. 3944 3 Averaging Plan 0.50 0.46 0.56 0.50 1.06 -57%WV John E Amos Appalachian Power Co. 3935 1 AEL Final 0.46 0.55 0.59 1.00 -45%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 43WV John E Amos Appalachian Power Co. 3935 2 AEL Final 0.46 0.49 0.52 1.00 -51%WV John E Amos Ohio Power Co. 3935 3 Standard Limitation 0.68 0.64 1.05 -39%WV Kammer Ohio Power Co. 3947 1 Averaging Plan 0.86 0.76 0.61 0.56 1.21 -37%WV Kammer Ohio Power Co. 3947 2 Averaging Plan 0.86 0.76 0.61 0.56 1.21 -37%WV Kammer Ohio Power Co. 3947 3 Averaging Plan 0.86 0.76 0.61 0.56 1.21 -37%WV Kanawha River Appalachian Power Co. 3936 1 Averaging Plan 0.80 0.60 0.61 0.56 1.23 -51%WV Kanawha River Appalachian Power Co. 3936 2 Averaging Plan 0.80 0.60 0.61 0.56 1.23 -51%WV Mitchell Ohio Power Co. 3948 1 Averaging Plan/AEL 0.50 0.56 0.61 / 0.56 0.56 0.77 -27%WV Mitchell Ohio Power Co. 3948 2 Averaging Plan/AEL 0.50 0.53 0.61 / 0.56 0.56 0.77 -31%WV Mountaineer (1301) Appalachian Power Co. 6264 1 Averaging Plan/EE 0.46 0.49 0.61 / 0.50 0.56 0.47 4%WV Mt Storm Virginia Electric & Power Co. 3954 1 AEL Final 0.45 0.67 0.76 0.88 -24%WV Mt Storm Virginia Electric & Power Co. 3954 2 AEL Final 0.45 0.63 0.69 0.76 -17%WV Mt Storm Virginia Electric & Power Co. 3954 3 AEL Final 0.45 0.61 0.74 1.27 -52%WV Phil Sporn Central Operating Co. 3938 11 Averaging Plan 0.80 0.71 0.61 0.56 1.21 -41%WV Phil Sporn Central Operating Co. 3938 21 Averaging Plan 0.80 0.71 0.61 0.56 1.21 -41%WV Phil Sporn Central Operating Co. 3938 31 Averaging Plan 0.80 0.71 0.61 0.56 1.21 -41%WV Phil Sporn Central Operating Co. 3938 41 Averaging Plan 0.80 0.71 0.61 0.56 1.21 -41%WV Phil Sporn Central Operating Co. 3938 51 Averaging Plan 0.46 0.47 0.61 0.56 0.90 -48%WV Pleasants Monongahela Power Co. 6004 1 Averaging Plan 0.50 0.35 0.56 0.50 0.52 -33%WV Pleasants Monongahela Power Co. 6004 2 Averaging Plan 0.50 0.35 0.56 0.50 0.35 0%WV Rivesville Monongahela Power Co. 3945 7 Averaging Plan 0.80 0.93 0.56 0.50 0.86 8%WV Rivesville Monongahela Power Co. 3945 8 Averaging Plan 0.80 0.69 0.56 0.50 0.77 -10%WV Willow Island Monongahela Power Co. 3946 1 Averaging Plan 0.80 0.70 0.56 0.50 0.88 -20%WV Willow Island Monongahela Power Co. 3946 2 Averaging Plan 0.86 1.20 0.56 0.50 1.26 -5%Appendix B-1: Compliance Results for All NOXAffected Units in 20002000ST Plant Name Operating UtilityORISCode BoilerComplianceApproachStandardEmissionLimitActualEmissionRateAvg. Plan,AEL, orEarlyElectionLimitActualAvg. PlanRate1990EmissionRateChangefrom 1990to 2000B-1, 44WY Dave Johnston PacifiCorp 4158 BW41 Early Election 0.46 0.43 0.50 0.48 -10%WY Dave Johnston PacifiCorp 4158 BW42 Early Election 0.46 0.42 0.50 0.54 -22%WY Dave Johnston PacifiCorp 4158 BW43 Averaging Plan 0.68 0.56 0.45 0.40 0.71 -21%WY Dave Johnston PacifiCorp 4158 BW44 Averaging Plan 0.40 0.41 0.45 0.40 0.55 -25%WY Jim Bridger PacifiCorp 8066 BW71 Averaging Plan 0.45 0.40 0.45 0.40 0.63 -37%WY Jim Bridger PacifiCorp 8066 BW72 Averaging Plan 0.45 0.39 0.45 0.40 0.51 -24%WY Jim Bridger PacifiCorp 8066 BW73 Averaging Plan 0.45 0.37 0.45 0.40 0.42 -12%WY Jim Bridger PacifiCorp 8066 BW74 Early Election 0.40 0.38 0.45 0.41 -7%WY Laramie River Basin Electric Power Coop. 6204 1 Early Election 0.46 0.25 0.50 0.35 -29%WY Laramie River Basin Electric Power Coop. 6204 2 Early Election 0.46 0.27 0.50 0.32 -16%WY Laramie River Basin Electric Power Coop. 6204 3 Early Election 0.46 0.25 0.50 0.42 -40%WY Naughton PacifiCorp 4162 1 Averaging Plan 0.40 0.51 0.45 0.40 0.42 21%WY Naughton PacifiCorp 4162 2 Averaging Plan 0.40 0.48 0.45 0.40 0.55 -13%WY Naughton PacifiCorp 4162 3 Averaging Plan 0.40 0.35 0.45 0.40 0.62 -44%WY Wyodak PacifiCorp 6101 BW91 Averaging Plan 0.50 0.29 0.45 0.40 0.37 -22%B-2, 1Appendix B-2: List of Averaging Plans and Results in 2000Company ORIS Code Plant Name, State and Units Plan Limit Plan RateAES Westover, LLC2526 AES Westover NY Units 11 - 130.45 0.352527 Greenidge NY Units 4 - 66082 Kintigh NY Unit 12535 Milliken NY Units 1, 2Allegheny Energy Supply Co., LLC3942 Albright WV Units 1 - 30.56 0.503178 Armstrong PA Units 1, 23943 Fort Martin WV Units 1, 23944 Harrison WV Units 1 - 33179 Hatfield's Ferry PA Units 1 - 33181 Mitchell PA Unit 336004 Pleasants WV Units 1, 21570 R P Smith MD Units 9, 113945 Rivesville WV Units 7, 83946 Willow Island WV Units 1, 2Ameren Services861 Coffeen IL Units 01, 020.59 0.55862 Grand Tower IL Units 07 - 09863 Hutsonville IL Units 05, 06864 Meredosia IL Units 01 - 056017 Newton IL Units 1, 2Ameren Services2103 Labadie MO Units 1 - 40.52 0.292104 Meramec MO Units 1 - 46155 Rush Island MO Units 1, 22107 Sioux MO Units 1, 2Appendix B-2: List of Averaging Plans and Results in 2000Company ORIS Code Plant Name, State and Units Plan Limit Plan RateB-2, 2American Electric Power Service1353 Big Sandy KY Unit BSU10.61 0.562828 Cardinal/Tidd OH Units 1 - 33775 Clinch River VA Units 1 - 32840 Conesville OH Units 3, 48102 Gen J M Gavin OH Units 1, 23776 Glen Lyn VA Units 6, 51, 523947 Kammer WV Units 1 - 33936 Kanawha River WV Units 1, 23948 Mitchell WV Units 1, 26264 Mountaineer (1301) WV Unit 12872 Muskingum River OH Units 1 - 53938 Phil Sporn WV Units 11, 21, 31, 41, 512843 Picway OH Unit 96166 Rockport IN Units MB1, MB2988 Tanners Creek IN Units U1 - U4Arizona Public Service Company 2442 Four Corners NM Units 1 - 5 0.61 0.55Associated Electric Cooperative2167 New Madrid MO Units 1, 20.74 0.722168 Thomas Hill MO Units MB1 - MB3Boswell Energy Center1893 Clay Boswell MN Units 1, 2, 40.41 0.331891 Syl Laskin MN Units 1, 2Appendix B-2: List of Averaging Plans and Results in 2000Company ORIS Code Plant Name, State and Units Plan Limit Plan RateB-2, 3Carolina Power and Light Company2706 Asheville NC Units 1, 20.44 0.412708 Cape Fear NC Units 5, 63251 H B Robinson SC Unit 12713 L V Sutton NC Units 1 - 32709 Lee NC Units 1 - 36250 Mayo NC Units 1A, 1B2712 Roxboro NC Units 1, 2, 3A, 3B, 4A, 4B2716 W H Weatherspoon NC Units 1 - 3Cinergy Corp.1001 Cayuga IN Units 1, 20.49 0.466018 East Bend KY Unit 21004 Edwardsport IN Units 7-1, 7-2, 8-16113 Gibson IN Units 1 - 52832 Miami Fort OH Units 5-1, 5-2, 6 - 81007 Noblesville IN Units 1 - 31008 R Gallagher IN Units 1 - 41010 Wabash River IN Units 1 - 62830 Walter C Beckjord OH Units 1 - 6City Utilities of Springfield2161 James River MO Units 3 - 50.50 0.456195 Southwest MO Unit 1Colorado Springs Utilities 492 Martin Drake CO Units 5 - 7 0.46 0.39Appendix B-2: List of Averaging Plans and Results in 2000Company ORIS Code Plant Name, State and Units Plan Limit Plan RateB-2, 4Constellation Power Source Gen.,Inc.602 Brandon Shores MD Units 1, 20.56 0.511552 C P Crane MD Units 1, 21554 Herbert A Wagner MD Units 2, 3Consumers Energy Company1695 B C Cobb MI Units 4, 50.46 0.391702 Dan E Karn MI Units 1, 21720 J C Weadock MI Units 7, 81710 J H Campbell MI Units 2, 31723 J R Whiting MI Units 1 - 3Dairyland Power Cooperative4140 Alma WI Units B4, B50.48 0.424143 Genoa WI Unit 14271 J P Madgett WI Unit B1Dayton Power & Light Company2850 J M Stuart OH Units 1 - 40.62 0.556031 Killen Station OH Unit 22848 O H Hutchings OH Units H-1 - H-6Detroit Edison Company6034 Belle River MI Units 1, 20.53 0.431731 Harbor Beach MI Unit 11732 Marysville MI Units 9, 10, 11, 121733 Monroe MI Units 1 - 41740 River Rouge MI Units 2, 31743 St Clair MI Units 1 - 4, 6, 71745 Trenton Channel MI Units 9A, 16 - 19Appendix B-2: List of Averaging Plans and Results in 2000Company ORIS Code Plant Name, State and Units Plan Limit Plan RateB-2, 5Dominion Generation3796 Bremo Bluff VA Units 3, 40.41 0.363803 Chesapeake VA Unit 33797 Chesterfield VA Units 5, 67213 Clover VA Units 1, 23804 Possum Point VA Unit 4Dynegy Midwest Generation, Inc.889 Baldwin IL Units 1 - 30.59 0.48891 Havana IL Unit 9892 Hennepin IL Units 1, 2897 Vermilion IL Units 1, 2898 Wood River IL Units 4, 5Dynegy Northeast Generation 2480 Danskammer NY Units 3, 4 0.40 0.40FirstEnergy Corporation2835 Ashtabula OH Units 7, 8, 10, 110.51 0.472878 Bay Shore OH Units 1 - 46094 Bruce Mansfield PA Units 1 - 32837 Eastlake OH Units 1 - 52857 Edgewater OH Units 11 - 132858 Gorge OH Units 25, 262838 Lake Shore OH Unit 182864 R E Burger OH Units 1 - 82867 Toronto OH Units 9 - 112866 W H Sammis OH Units 1 - 7Appendix B-2: List of Averaging Plans and Results in 2000Company ORIS Code Plant Name, State and Units Plan Limit Plan RateB-2, 6Grand River Dam Authority 165 GRDA OK Units 1, 2 0.46 0.35Hoosier Energy, REC, Inc.1043 Frank E Ratts IN Units 1SG1, 2SG10.47 0.396213 Merom IN Units 1SG1, 2SG1IES Utilities, Inc.1104 Burlington IA Unit 10.46 0.361046 Dubuque IA Units 1, 51047 Lansing IA Units 1 - 31048 Milton L Kapp IA Unit 21073 Prairie Creek IA Units 3, 41058 Sixth Street IA Units 2 - 51077 Sutherland IA Units 1, 2Indianapolis Power & Light Co.990 Elmer W Stout IN Units 50, 60, 700.45 0.35991 H T Pritchard IN Units 3 - 6994 Petersburg IN Units 1 - 4Kansas City Power & Light Co. 1241 La Cygne KS Units 1, 2 0.66 0.60Lansing Board of Water and Light1831 Eckert Station MI Units 1 - 60.45 0.391832 Erickson MI Unit 1Appendix B-2: List of Averaging Plans and Results in 2000Company ORIS Code Plant Name, State and Units Plan Limit Plan RateB-2, 7Louisville Gas and Electric Co.1355 E W Brown KY Units 1 - 30.45 0.391356 Ghent KY Units 1 - 41357 Green River KY Units 1 - 51360 Pineville KY Unit 31361 Tyrone KY Unit 5Midwest Generation EME, LLC867 Crawford IL Units 7, 80.59 0.48886 Fisk IL Unit 19384 Joliet 29 IL Units 71, 72, 81, 82874 Joliet 9 IL Unit 5879 Powerton IL Units 51, 52, 61, 62883 Waukegan IL Units 7, 8884 Will County IL Units 1 - 3Mirant State Line Energy, LLC 981 State Line IN Units 3, 4 0.68 0.58Northern Indiana Public Service Co.995 Bailly IN Units 7, 80.75 0.66997 Michigan City IN Unit 126085 R M Schahfer IN Units 14, 15NSP (dba Xcel Energy)1915 Allen S King MN Unit 10.54 0.481904 Black Dog MN Units 1, 3, 41912 High Bridge MN Units 3 - 61918 Minnesota Valley MN Unit 41927 Riverside MN Units 6 - 86090 Sherburne County MN Units 1 - 3Appendix B-2: List of Averaging Plans and Results in 2000Company ORIS Code Plant Name, State and Units Plan Limit Plan RateB-2, 8Ohio Valley Electric Corporation983 Clifty Creek IN Units 1 - 60.84 0.762876 Kyger Creek OH Units 1 - 5Orion Power Holdings, Inc.2836 Avon Lake OH Units 10, 120.55 0.498226 Cheswick PA Unit 13098 Elrama PA Units 1 - 43138 New Castle PA Units 3 - 5Pacificorp4158 Dave Johnston WY Units BW43, BW440.45 0.406165 Hunter (Emery) UT Unit 38069 Huntington UT Unit 28066 Jim Bridger WY Units BW71 - BW734162 Naughton WY Units 1 - 36101 Wyodak WY Unit BW91Public Service Co. of New Mexico 2451 San Juan NM Units 1 - 4 0.46 0.44Public Service Company of Colorado 465 Arapahoe CO Units 1 - 4 0.80 0.49Public Service Company of Colorado 469 Cherokee CO Units 1, 2 0.80 0.60Public Service Electric & Gas Co.2403 Hudson NJ Unit 20.64 0.582408 Mercer NJ Units 1, 2Appendix B-2: List of Averaging Plans and Results in 2000Company ORIS Code Plant Name, State and Units Plan Limit Plan RateB-2, 9Reliant Energy Mid-Atlantic Power3113 Portland PA Units 1, 20.44 0.353130 Seward PA Units 12, 14, 153132 Warren PA Units 1 - 4Rochester Gas & Electric Corp. 2642 Rochester 7 NY Units 1 - 4 0.40 0.37Santee Cooper130 Cross SC Unit 10.46 0.403317 Dolphus M Grainger SC Units 1, 23319 Jefferies SC Units 3, 46249 Winyah SC Unit 1South Carolina Electric & Gas Co.3280 Canadys Steam SC Units CAN1 - CAN30.41 0.357210 Cope Station SC Unit COP13287 McMeekin SC Units MCM1, MCM23295 Urquhart SC Units URQ1 - URQ3South Mississippi Electric PowerAssociation6061 R D Morrow MS Units 1, 2 0.50 0.46Appendix B-2: List of Averaging Plans and Results in 2000Company ORIS Code Plant Name, State and Units Plan Limit Plan RateB-2, 10Southern Company699 Arkwright GA Units 1 - 40.46 0.433 Barry AL Units 1 - 5703 Bowen GA Units 1BLR - 4BLR641 Crist FL Units 4 - 726 E C Gaston AL Units 1 - 57 Gadsden AL Units 1, 28 Gorgas AL Units 6 - 1010 Greene County AL Units 1, 2708 Hammond GA Units 1 - 4709 Harllee Branch GA Units 1 - 4710 Jack McDonough GA Units MB1, MB22049 Jack Watson MS Units 4, 56002 James H Miller Jr AL Units 1 - 4733 Kraft GA Units 1 - 3643 Lansing Smith FL Units 1, 26124 McIntosh GA Unit 1727 Mitchell GA Unit 36257 Scherer GA Units 1 - 4642 Scholz FL Units 1, 26073 Victor J Daniel Jr MS Units 1, 26052 Wansley GA Units 1, 2728 Yates GA Units Y1BR - Y7BRSouthern Indiana Gas & Electric Co. 1012 F B Culley IN Units 1 - 3 0.50 0.48Appendix B-2: List of Averaging Plans and Results in 2000Company ORIS Code Plant Name, State and Units Plan Limit Plan RateB-2, 11Tampa Electric Company645 Big Bend FL Units BB01 - BB040.75 0.65646 F J Gannon FL Units GB03 - GB06Tennessee Valley Authority3393 Allen TN Units 1 - 30.57 0.543396 Bull Run TN Unit 147 Colbert AL Units 1 - 53399 Cumberland TN Units 1, 23403 Gallatin TN Units 1 - 43406 Johnsonville TN Units 1 - 103407 Kingston TN Units 1 - 91378 Paradise KY Units 1 - 31379 Shawnee KY Units 1 - 950 Widows Creek AL Units 1 - 8Western Kentucky Energy Co.1381 Coleman KY Units C1 - C30.49 0.446823 D B Wilson KY Unit W11382 HMP&L Station 2 KY Units H1, H26639 R D Green KY Units G1, G21383 Robert Reid KY Unit R1Western Resources6068 Jeffrey Energy Centr KS Units 1 - 30.40 0.361250 Lawrence KS Units 3 - 51252 Tecumseh KS Units 9, 10Appendix B-2: List of Averaging Plans and Results in 2000Company ORIS Code Plant Name, State and Units Plan Limit Plan RateB-2, 12Wisconsin Electric Power Company6170 Pleasant Prairie WI Units 1, 20.47 0.414040 Port Washington WI Units 1 - 41769 Presque Isle MI Units 2 - 64041 South Oak Creek WI Units 5 - 84042 Valley WI Units 1 - 4Wisconsin Power & Light Co 4050 Edgewater WI Units 4, 5 0.62 0.56Wisconsin Public Service Corp.4072 Pulliam WI Units 3 - 80.47 0.414146 Stoneman WI Units B1, B24078 Weston WI Units 1 - 3

# B-3, 1 Appendix B-3: Description of NO

x 

# Compliance Assessment Methodology

1. Emission Rate Evaluation for Single Unit Compliance

(a) Compliance Determination

The NO

x 

# emission limit for each unit is compared to the actual annual NO

x 

# 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 NO

x 

# emission rate

 unit NO

x 

# 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 NO

x 

# emission rate

 NO

x 

# 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 NO

x 

# emission rate for all stacks.

c. If selected stack NO

x 

# emission rate

 NO

x 

# emission limit

Unit compliance status is Pass

else

d. Calculate NO

x 

# pounds for the unit as apportioned to the unit from each

stack

Unit/Stack NO

x 

# Pounds = Actual Stack NO

x 

# Emission Rate * Unit Heat Input Apportioned from the Stack

# B-3, 2 e. Calculate the total actual NO

x 

# pounds for the unit:

Unit NO

x 

# Pounds Emitted = Sum of Unit/Stack NO

x 

# Pounds Emitted for Each Unit/Stack

f. Calculate the allowable NO

x 

# pounds for the unit:

Unit Allowable NO

x 

# Pounds = Unit NO

x 

# Emission Limit * Actual Unit Heat Input

g. Determine compliance on a NO

x 

# pounds basis for the unit:

If Unit NO

x 

# Pounds Emitted

 Unit Allowable NO

x 

# 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:

NO

x 

# Pounds Allowable = Unit NO

x 

# 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 NO

x 

# Pounds Emitted = Actual NO

x 

# Emission Rate * Actual Annual Unit Heat Input

b. For units in a complex stack configuration

Unit NO

x 

# Pounds Emitted = Sum of (Unit Apportioned Heat Input from Each Stack *

Actual NO

x 

# Emission Rate for Each Stack )

# B-3, 3 (3) Determine exceedance (tons, rounded to one decimal place):

NO

x 

# Tons Exceedance = (NO

x 

# Pounds Emitted  NO

x 

# Pounds Allowable) / 2000

2. Determining Compliance of Units in Averaging Plans

(a) Compliance Determination

For each averaging plan, a NO

x 

# emissions limit is calculated as follows.

(1) Calculate the allowable NO

x 

# pounds for the each unit in the plan:

Unit NO

x 

# Pounds Allowable = Unit NO

x 

# Emission Limit * Actual Annual Unit Heat Input

(2) Calculate the total allowable NO

x 

# pounds for the plan:

Total NO

x 

# Pounds Allowable for Plan = Sum of All Units NO

x 

# 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 NO

x 

# emission rate for the plan:

Allowable NO

x 

# Emission Rate for Plan = Total NO

x 

# Pounds Allowable for Plan / Total Heat Input for Plan

(5) Calculate the actual NO

x 

# pounds for each unit:

a. For units not associated with a common stack:

Unit NO

x 

# Pounds Emitted = Actual NO

x 

# Emission Rate * Annual Unit Heat Input

b. For each stack associated with the plan:

Stack NO

x 

# Pounds Emitted = Actual NO

x 

# Emission Rate * Annual Stack Heat Input

# B-3, 4 (6) Calculate the actual NO

x 

# pounds for the plan:

Actual NO

x 

# Pounds Emitted for the Plan = Sum of the Unit and Stack NO

x 

# 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 NO

x 

# emission rate for the plan:

Annual NO

x 

# Emissions Rate for the Plan = Actual NO

x 

# Pounds Emitted /

Annual Heat Input for the Plan

(9) Determine NO

x 

# compliance for the plan:

If Actual NO

x 

# Pounds Emitted for the Plan

 NO

x 

# 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:

NO

x 

# Tons Exceedance = (NO

x 

# Pounds Emitted  NO

x 

# Pounds Allowable) / 2000