Acid Rain Program
2004 Progress Report
10 YEARS OF ACHIEVEMENT
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Acid Rain Program
2004 Progress Report
CONTENTS
Summary 2
Origins of the Acid Rain Program 3
SO2 Emission Reductions 4
SO2 Allowance Market 6
SO2 Program Compliance 8
NOX Emission Reductions 9
Emissions Monitoring and Reporting 11
Status and Trends in Air Quality, Acid Deposition, and Ecological Effects ...13
Understanding the Monitoring Networks 14
Air Quality 15
Acid Deposition 17
Recovery of Acidified Lakes and Streams 19
Quantifying Costs and Benefits of the Acid Rain Program 21
National Actions for Further Emission Reductions—2005 Clean Air Rules....23
Online Information, Data, and Resources Inside back cover
EPA430-R-05-01_
Clean Air Markets Division
Office of Air and Radiation
U.S. Environmental I
October 2005
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EPA publishes an annual report to update the public
on compliance with the Acid Rain Program, the
status of implementation, and progress toward
achieving environmental goals. Because this report builds
upon and updates previous reports, those who are new to
the program might find it helpful to first read some back-
ground material on the EPA Web site at www.epa.gov/
air markets/arp.
The Add Rain Program 2004 Progress Report updates
data reported in previous years, specifically:
• Sulfur dioxide (SC^) emissions, allowance market
information, and program compliance.
• Nitrogen oxides (NOX) emissions and program
compliance.
• Status and trends in acid deposition, air quality, and
ecological effects.
• Benefits and costs of the Acid Rain Program.
This report marks the 10th year of the Acid Rain
Program by highlighting some of the major developments
that have occurred over that time, including advances in
emission controls, improvements in program management,
and electronic delivery of services, and maturity of the
program's allowance trading market.
For more information on the Acid Rain Program,
including additional information on SC>2 and NOX emis-
sions, acid deposition monitoring, environmental effects of
acid deposition, and detailed unit-level emissions data,
please visit EPA's Clean Air Markets Web site at
www. ep a. gov/ air markets.
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2 < Acid Rain Program, 2004 Progress Report
Summary
Sulfur dioxide (SC>2) and nitrogen oxides (NOX) are the key pol-
lutants in the formation of acid rain. These pollutants also contribute
to the formation of fine particles (sulfates and nitrates) that are asso-
ciated with significant human health effects and regional haze.
Additionally, NOX combines with volatile organic compounds
(VOCs) to form ground-level ozone (smog) and nitrates that are
transported and deposited at environmentally detrimental levels in
parts of the country. In the United States, the electric power industry
accounts for nearly 70 percent of total annual SO2 emissions and
slightly more than 20 percent of total annual NOX emissions.
The Acid Rain Program was created to implement Title IV of
the 1990 Clean Air Act Amendments. The purpose of Title IV is to
reduce the adverse effects of acid deposition through reductions in
annual emissions of SO2 and NOX by 10 million tons and by 2
million tons below projected levels, respectively.
Since the start of the Acid Rain Program in 1995, the lower SO2
and NOX emission levels from the power sector have contributed to
significant air quality and environmental and human health improve-
ments. The 2004 compliance year marked the 10th year of the pro-
gram. During that period, the Acid Rain Program has:
• Reduced SO2 emissions by over 5 million tons from 1990 levels,
or about 34 percent of total emissions from the power sector.
Compared to 1980 levels, SO2 emissions from power plants have
dropped by 7 million tons, or more than 40 percent.
• Cut NOX emissions by about 3 million tons from 1990 levels, so
that emissions in 2004 were less than half the level anticipated
without the program. Other efforts, such as the NOX Budget
Trading Program in the eastern United States, also contributed
significantly to this reduction.
• Led to significant cuts in acid deposition, including reductions in
sulfate deposition of about 36 percent in some regions of the
United States and improvements in environmental indicators,
such as fewer acidic lakes.
• Provided the most complete and accurate emission data ever
developed under a federal air pollution control program and
made that data available and accessible by using comprehensive
electronic data reporting and Web-based tools for agencies,
researchers, affected sources, and the public.
• Served as a leader in delivering e-government, automating
administrative processes, reducing paper use, and providing online
systems for doing business with EPA.
• Resulted in nearly 100 percent compliance through rigorous
emissions monitoring, allowance tracking, and an automatic,
Acid Rain Program
1995-2005:
From Grand Policy
Experiment to
Demonstrated
Results
Congress created the
Acid Rain Program's SO2
emissions cap-and-trade
approach in 1990 amid
uncertainty that the inno-
vative, market-based
control program would
work. Since the pro-
gram's implementation,
air pollution control
experts from a wide
range of perspectives
agree that it is one of the
most successful environ-
mental programs in U.S.
history. The program
serves as a model for a
al and national control
programs, such as the
2005 Clean Air Interstate
Rule(CAIR). A 2005
study estimates that in
2010, the Acid Rain
Program's annual bene-
fits will be approximately
$122 billion (2000$), at
an annual cost of about
$3 billion-a 40-to-1
benefit-to-cost ratio.
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Acid Rain Program, 2004 Progress Report 3
easily understood penalty system for noncorn-
pliance. Flexibility in compliance strategies
reduced implementation costs.
Building on the Acid Rain Program model, EPA
promulgated the Clean Air Interstate Rule (CAIR)
in March 2005, to address transport of fine particles
and ozone in the eastern United States, the Clean
Air Mercury Rule (CAMR) to reduce nation-wide
mercury emissions from power plants, and the Clean
Air Visibility Rule (CAVR) to improve visibility in
national parks and wilderness areas.
Origins of the Acid Rain Program
Acid deposition, more commonly known as
acid rain, occurs when emissions of SO2 and NOX
react with water, oxygen, and oxidants in the
atmosphere to form various acidic compounds.
Prevailing winds transport the acidic compounds
hundreds of miles, often across state and national
borders, where they impair air quality and damage
public health, acidify lakes and streams, harm sensi-
tive forest and coastal ecosystems, degrade visibility,
and accelerate the decay of building materials.
The Acid Rain Program, established under
Title IV of the 1990 Clean Air Act Amendments,
requires major reductions of SO2 and NOX emis-
sions from the electric power industry. The SO2
program sets a permanent cap on the total amount
of SO2 that may be emitted by electric power
plants in the contiguous United
States. The program is phased in,
with the 2010 SO2 cap set at
about one-half of the 1980 emis-
sions from the power sector.
As seen in Figure 1, emissions
of both SO2 and NOX have fallen
significantly at the same time as
combustion of fossil fuel (coal,
oil, or natural gas), measured as
"heat input," for electricity gener-
ation, has increased. The increase
in electricity generation has not
only been achieved at lower
emission levels, it has occurred
while the real retail price of elec-
tricity has fallen.
Using a market-based
cap and trade mechanism to
reduce SO2 emissions allows
flexibility for individual fossil
fuel-burning units at electric
power plants regulated under the Acid Rain
Program to select their own methods of compli-
ance. Currently, one allowance provides a limited
authorization to emit one ton of SO2.The Clean
Air Act allocated allowances to regulated units
based on historic fuel consumption and specific
emission rates prior to the start of the program. The
total allowances allocated for each year equal the
SO2 emissions cap. The program encouraged early
reductions by allowing sources to bank unused
allowances in one year and use them in a later year.
The program uses a more traditional approach
to achieve NOX emission reductions. Rate-based
limits apply to most of the coal-fired electric utility
boilers subject to the Acid Rain Program. The pro-
gram does not establish a cap on NOX emissions;
Figure 1. Trends in Electricity Generation and Emissions from
Electric Power Sources
Heat Input
SO2 Emissions
NOX Emissions
Electricity Net Generation
Average Retail Price
of Electricity
1990 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Year
Sources: EPA (heat input and emissions) and Energy Information Administration (electricity
generation and price values).
Note: Heat input and emissions data reflect Acid Ram Program units. Generation reflects all
fossil fuel-fired electricity-only plants in the United States. Retail price reflects full national
values for the electricity-generating sector.
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4 ^ Acid Rain Program, 2004 Progress Report
SO2 Emission
Reductions from
Acid Rain Program
Sources: A Decade
of Cost-Effective
Progress
In 1995, the first year of
implementation, SO2
emissions decreased by 24
percent—nearly 4 million
tons—from 1990 levels.
During the past decade,
SO2 emissions dropped an
additional 13 percent from
1995 levels despite a 20
percent increase in utiliza-
tion (based on heat input).
In 2004, SO2 emissions
from all Acid Rain Program
units totaled 10.3 million
tons, a 34 percent
decrease from 1990 levels
Until SO2 allowance prices
began to increase in 2004
in anticipation of EPA's
2005 Clean Air Interstate
Rule (CAIR), allowance
prices generally remained
under $200/ton, well
below expected control
costs for the program.
instead, it is designed to achieve a 2 million ton reduction from pro-
jected 2000 NOX emission levels without implementation of Title IV
The Acid Rain Program is composed of two phases for SO2 and
NOX. Phase I applied primarily to the largest coal-fired electric gen-
eration sources from 1995 through 1999 for SO2 and from 1996
through 1999 for NOX. Phase II for both pollutants began in 2000.
In 2004, the SO2 Phase II requirements applied to 3,391 operating
units; the Phase II NOX requirements applied to 989 operating units
that burned coal from 1990 to 1995.
SO2 Emission Reductions
Electric power generation is by far the largest single source of
SO2 emissions in the United States, accounting for nearly 70 percent
of total SO2 emissions nation-wide.1
In 2004, 3,391 operating units were subject to the SO2 provisions
of the Acid Rain Program. As shown in Figure 2, Acid Rain Program
sources have reduced annual SO2 emissions by 40 percent compared to
1980 levels and 34 percent compared to 1990 levels. Reductions in
SO2 emissions from other sources not affected by the Acid Rain
Program, including industrial and commercial boilers and the metals
and refining industries, and use of cleaner fuels in residential and com-
mercial burners, have also contributed to an even greater decline (45
percent) in annual SO2 emissions from all sources since 1980 (see
www. epa.gov/ airtrends).
For 2004, EPA allocated a total of 9.5 million SO2 allowances under
the Acid Rain Program. Adding these allowances to the 7.6 million
unused allowances carried over (or banked) from prior years, there were
17.1 million allowances available for use in 2004. Sources emitted 10.3
million tons of SO2 in 2004, somewhat more than the allowances allocat-
ed for the year but far less than the total allowable level (see Figure 3).2
The number of banked allowances dropped from 7.58 million
available for 2004 compliance, to 6.86 million available for compli-
ance in 2005 and future years.This reduction amounts to 9.5 percent
of the total bank. Over time, the bank is expected to continue to be
depleted as sources use banked allowances to comply with the strin-
gent Phase II requirements. In 2010, the annual total number of
allowances allocated drops to 8.95 million (about half of the emis-
sions from the power industry in 1980) and remains statutorily fixed
at that annual level permanently. Figure 4 explains in more detail the
origin of the allowances that were available for use in 2004, and
Figure 9 (on page 8) shows how those allowances were used.
1 National Emission Inventory 2002: www.epa.gov/ttn/chief/trends/index.html.
2 Detailed emissions data for Acid Rain Program sources are available on the Data and Maps
portion of EPA's Clean Air Markets Web site at www.epa.gov/airmarkets.
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Acid Rain Program, 2004 Progress Report 5
Figure 2: SO2 Emissions under the Acid Rain
Program
2
o
LLJ
Phase I Sources
Phase II Sources
All Sources
Allowances allocated
for that year
1980 1985 1990 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Source: EPA Year
Figure 3: SO2 Emissions and the Allowance
Bank, 1995-2004
Year(bank)
Actual Emissions from affected sources
~8.7
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Source: EPA Year
The states with the highest-emitting
sources in 1990 have seen the greatest SO2
reductions during the Acid Rain Program.
Most of these states are upwind of the areas
the Acid Rain Program was designed to pro-
tect, and reductions have resulted in important
environmental and health benefits over a large
regional scale (see Figure 5 on page 6). In
addition, the states that reduced emission from
1990 to 2004 had total annual reductions of
approximately 5.9 million tons, while the states
that had increased emissions—largely attributa-
ble to growth and not increases in emission
Figure 4: Origin of 2004 Allowable SO2
Emission Levels
Type of Number Explanation
Allowance ofSO2 of Allowance
Allocation Allowances Allocation Type
Initial
Allocation
Allowance
Auction
Opt-in
Allowances
9,191,897
250,000
99,188
Initial allocation is the
number of allowances
granted to units*
based on the product
of their historic utiliza-
tion and emission
rates specified in the
Clean Air Act.
The allowance
Auction provides
allowances to the
market that were set
aside in a Special
Allowance Reserve
when the initial
allowance allocation
was made.
Total 2004 9,541,085
Allocation
Total
Banked
Allowances
7,574,959
Opt-in allowances are
provided to units
entering the program
voluntarily. There
were 11 opt-in units
in 2004.
Banked allowances
are those allowances
accrued in a unit's
account from previ-
ous years, which can
be used for compli-
ance in 2004 or any
future year.
Total 2004 17,116,044
Allowable
Emissions
Source: EPA
*Note: In this report, the term "unit" means a fossil fuel-fired combustor
that serves a generator that provides electricity for sale. The vast majority
ofSO2 emissions affected by the program come from coal-fired genera-
tion units, but oil and natural gas units are also included in the program.
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6 •& Acid Rain Program, 2004 Progress Report
rates—had much smaller annual
increases (a total increase of
approximately 430,000 tons).
For 32 states and the District
of Columbia, annual SO2 emis-
sions in 2004 were lower than
emissions in 1990. Among these
states, 13 decreased their annual
emissions by more than 100,000
tons between 1990 and 2004:
Alabama, Florida, Georgia,
Illinois, Indiana, Kentucky,
Massachusetts, Missouri, New
York, Ohio, Pennsylvania,
Tennessee, and West Virginia. The
states with the greatest reductions
were in the Midwest and include
Ohio (1.1 million tons reduced),
Illinois, Indiana, and Missouri,
each of which reduced over
500,000 tons.
Figure 5: State-by-State SO2 Emissions Levels, 1990-2004
Emissions in 1 990
Phase I Average 1 995-1 999
I Emissions in 2004
Scale: Largest bar equals 2.2 million tons of emissions in Ohio, 1 990
SO2 Allowance Market
The allowance trading mechanism enables Acid
Rain Program sources to pursue a variety of com-
pliance options, while the cap on SO2 emissions
ensures that reductions are made and maintained
over time. Some sources have opted to reduce
their SO2 emissions below the level of their
allowance allocation in order to bank their
allowances for use in future years or to sell them.
Other sources have been able to postpone or
reduce expenditures for control by purchasing
Figure 6: SO2 Allowance Prices
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Year
Source: Cantor Fitzgerald
allowances from sources that controlled below
their allowance allocation level. The allowance
prices end up reflecting these flexible compliance
decisions. Economists refer to this as the marginal
cost of compliance—the cost of reducing the next
ton of SO2 emitted from the power sector.
The price of an allowance increased sharply
during 2004, ending the year at about $700 after
beginning the year at about $215 (see Figure 6).
The increase primarily occurred because of EPA s
Clean Air Interstate Rule (CAIR). CAIR requires
further SO2 reductions from sources in many east-
ern U.S. states beginning in 2010, and the market
has already begun to factor the marginal cost of
future compliance with CAIR and the future
value of banked allowances today.
In 2004, nearly 20,000 private allowance trans-
fers affecting roughly 15.3 million allowances (of
past, current, and future vintages) were recorded in
the EPA Allowance Tracking System (ATS). Of the
allowances transferred, 7.5 million (49 percent)
were transferred in economically significant
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Acid Rain Program, 2004 Progress Report
transactions (i.e., between economically unrelated
parties). The majority of the allowances transferred
in economically significant transactions were
acquired by power companies. Figure 7 (on page 8)
shows the annual volume of SO2 allowances trans-
ferred under the Acid Rain Program (excluding
allocations, retirements, and other transfers by EPA)
since official recording of transfers began in 1994.
Figure 8 (on page 8) shows the cumulative vol-
ume of SO9 allowances transferred under the Acid
Rain Program. The figure differentiates between
allowances transferred in private transactions and
those annually allocated and transferred to sources'
accounts by EPA. Nearly 270 million allowances
have been transferred since 1994, with about 68
percent of those transfers submitted by authorized
account representatives. In December 2001, parties
began to use a system developed by EPA to allow
transfers to occur online. In 2004, account holders
registered about 93 percent of all private allowance
transfers through EPA's online transfer system.3
3 All official allowance transactions are posted and updated daily on www.epa.gov/airmarkets.
Then and Now—The Evolving Market for Acid Rain Program SO2 Allowances
Since the inception of the Acid Rain Program, traders in utilities and brokerages have seen con-
siderable developments in the SO2 allowance market. Changes in fuel supply, trading processes,
electronic data transfer, market participants, economic and business conditions, weather, EPA
regulations and settlements, and tax laws have all influenced the market's first decade. Informal
discussions with market participants provided anecdotal evidence of several changes, including:
•v" Early trades required considerable legal advice, cost as much as $5 per ton in brokerage
fees, and took months to complete. With standardized transaction agreements and con-
tract forms, one broker noted that transaction fees have dropped to $0.50 per ton and
trades typically take one or two weeks.
•v" In 1995, utilities tended to engage in simple trades to cover their needs. By 2000, energy
marketers had joined in speculative trading and introduced instruments like options and
vintage year swaps. In 2002, some traders observe that reaction to the dissolution of
Enron temporarily reversed the trend toward a larger, more complex market. Recently,
banks and hedge funds have brought back speculative trading, and two trading systems
(the New York Mercantile Exchange [NYMEX] and the Chicago Climate Exchange [CCX])
have created futures markets for allowances.
•v" Traders note that improved access to allowance and emission data, such as through
EPA's Data and Maps Web site, has provided increasingly accessible, up-to-date informa-
tion, providing a firm foundation for well-informed allowance transactions.
•v" Initially, utilities banked allowances and prices fell based on the relatively low-cost compliance
option of using low-sulfur coal from Wyoming's Powder River Basin. The additional reduc-
tions required under CAIR have already begun to influence market prices for SO2 allowances.
-*J
__ *-
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8 ^ Acid Rain Program, 2004 Progress Report
Figure 7: SO2 Allowances Transferred under the
Acid Rain Program
u
r
O
20
l/>
c
O
9.2
I Between Economically Related Organizations
I Between Economically Unrelated Organizations
25.0
22.5
21.4
16.7
0
1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Source: EPA Year
Figure 8: Cumulative SO2 Allowances
Transferred (through 2004)
300
C 250
_0 200
t 15°
(/)
0 100
1 50
0
1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Year
Source: EPA
SO2 Program Compliance
A total of nearly 10.3 million allowances were
deducted from sources' accounts in 2004 to cover
emissions. Figure 9 displays these allowance deduc-
tions, as well as the remaining banked allowances
from 1995 through 2004.
As in previous years, compliance with the Acid
Rain Program continues to be extraordinarily
high—nearly 100 percent. In 2004, four units out
of 3,391 were out of compliance. A source that
does not hold enough allowances in its unit
account to cover its annual SO2 emissions has
"excess emissions" and must pay an automatic
penalty. Title IV set a penalty of $2,000 per ton in
1990, which has been adjusted annually for infla-
tion; the 2004 penalty was $2,963 per ton.The
owners of the four units out of compliance in
2004 were assessed a penalty of approximately $1.4
million for emitting 465 tons of SO2 in excess of
the allowances held in their accounts.
Figure 9: SO2 Allowance Reconciliation Summary, 2004
Total Allowances Held (1995-2004 vintages)4
Unit Accounts
17,116,044
13,610,501
General Accounts5
3,505,543
Allowances Deducted for Emissions6
10,259,771
Penalty Allowance Deductions (2005 Vintage)
Banked Allowances
Unit Accounts
General Accounts5
465
6,856,273
3,350,730
3,505,543
Source: EPA
4 As of March 1, 2004, the Allowance Transfer Deadline, the point in time at which unit accounts are frozen and after which no transfers of
1995 through 2004 allowances will be recorded. The freeze on these accounts is removed when annual reconciliation is complete. The total
held in the ATS accounts equals the number of 2004 allowances allocated (see Figure 4 on page 5) plus the number of banked allowances.
5 General accounts can be established in the ATS by any utility, individual, or other organization.
5 Includes 212 allowances deducted from opt-in sources for reduced utilization.
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Acid Rain Program, 2004 Progress Report 9
NOv Emission Reductions
'X
Title IV of the 1990 Clean Air Act
Amendments requires NOX emission reductions
for certain coal-fired units. Unlike the SO2 pro-
gram, Congress applied rate-based emission limits
based on a unit's boiler type to achieve NOX
reductions (see Figure 10).The NOX emission rate
is expressed as pounds per unit of heat input
(Ibs/mmBtu) to the boiler. Owners can meet the
NOX limits for each individual unit or meet the
average of groups of units.
The NOX program seeks to attain a 2 million
ton annual reduction from all Acid Rain Program
sources relative to the NOX emission levels that
were projected to occur in 2000 (8.1 million tons)
absent the Acid Rain Program. This goal was first
realized in 2000, and has been met every year
thereafter, including 2004. Figure 11 (on page 10)
shows that NOX emissions from all Acid Rain
Program sources were 3.8 million tons in 2004.
This level is more than 4 million tons less than the
projected level in 2000 without the Acid Rain
Program, or more than double the Title IV NOX
emissions reduction objective. These reductions
have been achieved while the amount of fuel
burned to produce electricity, as measured by heat
input, has increased 34 percent since 1990. While
the Acid Rain Program was responsible for a large
portion of these annual NOX reductions, other pro-
grams, such as the Ozone Transport Commission
(OTC) NOX Budget Trading Program and the
EPA's NOX State Implementation Plan (SIP) Call,
both of which are seasonal, regional NOX pro-
grams, also contributed significantly to the NOX
reductions achieved by emitting sources in 2004.
As with SO2, the states with the highest NOX
emitting sources in 1990 tended to see the greatest
power plant NOX emission reductions (see Figure
12 on page 10). The sum of reductions in the 38
states and the District of Columbia, that had lower
annual NOX emissions in 2004 than in 1990 was
approximately 2.7 million tons, while the sum of
increases in the 10 states that had higher annual
NOX emissions in 2004 than in 1990 was much
smaller, less than 63,000 tons. Eight of the 11 states
with NOX emission decreases of more than
100,000 tons were in the Ohio River Basin.
Figure 10: Number of NOX-Affected Title IV Units by Boiler Type
Coal-Fired Boiler Type
Title IV Standard
Emission Limit
(Ib/mmBtu)
Number of Units
Phase I Group 1 Tangentially-fired
Phase I Group 1 Dry Bottom, Wall-fired
Phase II Group 1 Tangentially-fired
Phase II Group 1 Dry Bottom, Wall-fired
Cell Burners
Cyclones >1 55 MW
Wet Bottom >65 MW
Vertically-fired
0.45
0.50
0.40
0.46
0.68
0.86
0.84
0.80
132
116
301
298
37
54
24
27
Total 989
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10 -0" Acid Rain Program, 2004 Progress Report
Figure 11: NOX Emission Trends for Acid Rain
Program Units 1 990 to 2004
O
"6.7
6.1 5.9 6.0 6.0
S.S
I NOX Program affected sources
] Title IV sources not affected by
NOX Program
5.1
4.7
4.5
4.2
3.8
1990 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004
Year
Source: EPA
Note: The sharp decline in emissions observed since 1 999 reflects not
only the Phase II Acid Rain Program NOX requirements, but also sea-
sonal reductions from May to September that began in nine northeast-
ern U.S. states and D.C. in 1 999 and 11 additional states under the
NOX SIP Call beginning in 2004 (see the shaded states in Figure 1 2).
New Hampshire participated in the northeastern U.S. program through
2002, but does not participate in the NOX SIP Call program.
Figure 12: State-by-State NOX Emission Levels
for All Acid Rain Program Sources 1990 to 2004
Source: EPA
^J Emissions in 1 990
I | Phase I Average 1 996-1 999
| | Emissions in 2004
Scale: Largest bar equals 500,000 tons of emissions in Ohio, 1990
| | 2004 NOX SIP Call States
Sources Achieved 100 Percent NOX Compliance in 2004, Using a
Variety of NOX Compliance Plan Options
Standard Limitation. A unit with a standard limit meets the applicable individual NOX limit pre-
scribed for its boiler type under 40 CFR 76.5, 76.6, or 76.7 (116 units used this option in 2004).
Early Election. Phase II Group 1 NOX affected units could meet a less stringent Phase I NOX
limit beginning in 1997, three years before 2000, when they would normally become subject to
an Acid Rain NOX limit. In return for accepting a NOX limit three years earlier than would nor-
mally be required, an early election unit does not become subject to the more stringent Phase II
NOX limit until 2008 (273 units used this option in 2004).
Emissions Averaging. Many companies have their units meet their NOX emission reduction
requirements by choosing to become subject to a group NOX limit, rather than by meeting individ-
ual NOX limits for each unit. The group limit is established at the end of each calendar year, and
the group rate for the units must be less than or equal to the Btu-weighted group rate units would
have had if each had emitted at their standard limit rate (620 units used this option in 2004).
Alternative Emission Limitation (AEL). A utility can petition for a less stringent AEL if it prop-
erly installs and operates the NOX emissions reduction technology prescribed for that boiler, but
is unable to meet its standard limit. EPA determines whether an AEL is warranted based on
analyses of emission dat£ and information about the NOX control equipment (21 units used
this option in 2004).
on. Also, some units used multiple compliance options. Ten units
nits were under both an emissions averaging and early election pla
:ions. len units under an emis-
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Acid Rain Program, 2004 Progress Report > 11
Then and Now: Advances in NOX Control
Since Congress enacted the Acid Rain Program in 1990, the electric power industry has made
significant innovations and advances in reducing NOX emissions. The Acid Rain Program
served as the impetus for some of these changes, but other programs, such as EPA's 1998
NOX SIP Call, have led to many of the advances. Some highlights include:
4* Boiler optimization. Boiler optimization modeling systems manipulate multiple control
parameters simultaneously in order to meet a unit's specific operational needs and emis-
sion reduction goals. Sources have shown that optimization is capable of reducing NOX
emissions by between 13 and 24 percent, while maintaining or increasing boiler efficiency
and significantly reducing fuel costs. In addition, optimization and NOX reductions in
units with selective catalytic reduction systems (SCRs) can lower ammonia usage and
extend catalyst life, resulting in lower operational costs.
4* Advanced combustion controls. The design of low-NOx burner (LNB) emission control
technologies has improved significantly since 1995, leading to lower NOX emission rates.
The average NOX emission rate from boilers utilizing LNB technology in 2003 was
between 35 and 60 percent lower than the average emission rate from LNB units in 1995.
•v" Application of SCR to coal-fired boilers. In 1995, there were significant doubts in the
electric power industry about the application of SCR technology to U.S. coal-fired boilers,
particularly because of high-sulfur fuel interfering with catalyst performance. With the
reductions required under the 1998 NOX SIP Call, the industry has moved to resolve those
issues, and by the end of 2004, over 130 coal-fired boilers in the United States had
istalled SCRs (primarily for NOX SIP Call compliance) and were able to achieve sustained
mission rates as low as 0.03 Ibs/mmBtu.
Emissions Monitoring and Reporting
The Acid Rain Program requires program
participants to measure, record, and report emis-
sions using continuous emission monitoring sys-
tems (GEMS) or an approved alternative measure-
ment method. Since the program's inception in
1995, emissions have been continuously monitored
and reported by sources, verified and recorded by
EPA, and provided to the public through EPA's
Web site. All affected sources report hourly emis-
sion data in electronic reports (submitted quarter-
ly), and EPA conducts automated software audits
that perform rigorous checks to ensure the
completeness, high quality, and integrity of the
emission data. GEMS and approved alternatives are
a cornerstone of the Acid Rain Program's account-
ability and transparency.
The emission monitoring requirements are
found in 40 CFR Part 75. In addition to the Acid
Rain Program, these provisions are also required for
participation in the NOX Budget Trading Program,
a NOX trading program used by many eastern states
in response to EPA's 1998 NOX SIP Call, and will
be used in the future to implement two new rules
promulgated in 2005, CAIR and CAMR.
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12 < Acid Rain Program, 2004 Progress Report
Advances in Emissions and Allowance Transfer Reporting
•v" At the start of the Acid Rain Program, sources used a combination of paper forms
and floppy disks. The program required submission of emission data on floppy disks,
and other source information management activities, such as monitoring plan infor-
mation, allowance transfer, and certificates of representation, were all originally
addressed through paper forms.
•v" This approach required manual review and entry for paper submissions and individ-
ual file uploads for emission data. EPA feedback on submission issues involved indi-
vidual letters to sources.
•v" Over time, EPA moved to electronic transfer of information:
Monitoring plans moved primarily to electronic submission as part of the quarter-
ly reporting process. EPA released Monitoring Data Checking (MDC) software
that allowed sources to enter, analyze, print, and export electronic monitoring
plans. EPA uses MDC to conduct electronic audits of submittals and provide
automated feedback to sources.
Through the Emissions Tracking System file transfer protocol (ETS-FTP), EPA
moved to direct, secure electronic transfer of quarterly reports from a source's
computer to EPA's mainframe system. EPA then was able to provide instant auto-
mated feedback to sources concerning issues with submitted emission data.
In 2001, an Online Allowance Tracking System enabled direct Internet recording
for allowance trades.
" Now the Online Allowance Tracking System is integrated with an enhanced Clean Air
Markets Division Business System (CBS) and offers online allowance trading as well
as online options for other account and source information management activities.
" Public access to information has advanced dramatically. Early access was through
paper compliance reports, and then individual unit data files that were diffi-
cult to use. Now, detailed unit, facility, state, and national emissions
and other data for ARP sources is available from EPA's Data
and Maps Web site (http://cfpub.epa.gov/gdm/).
This site provides a combination of easy to access
"quick" reports and highly flexible, custom
"query" reports.
EPA is in the process of designing a com-
prehensive Emissions Collection and
Monitoring Plan System (ECMPS) to cover
all aspects of secure reporting of emis-
sions, monitoring plans, and quality assur-
ance data.
-------
Acid Rain Program, 2004 Progress Report > 13
Status and Trends in Air Quality, Acid Deposition
and Ecological Effects
The emission reductions achieved under the
Acid Rain Program have led to important envi-
ronmental and public health benefits. These
include improvements in air quality with signifi-
cant benefits to human health, reductions in acid
deposition, the beginnings of recovery from acidi-
fication of fresh water lakes and streams, improve-
ments in visibility, and reduced risk to forests,
materials, and structures. Figure 13 shows the
regional changes in many of these key variables
linked to the Acid Rain Program's SO2 and NOX
emission reductions.
Figure 13: Regional Changes in Air Quality and Deposition of Sulfur and Nitrogen
(1989 to 1991 versus 2002 to 2004)
Measurement
Wet sulfate deposition
Wet sulfate concentration
Unit
kg/ha
mg/L
Region
Mid-Atlantic
Midwest
Northeast
Southeast
Mid-Atlantic
Midwest
Northeast
Averag
1989-1991
27
23
23
18
2.4
2.3
1.9
e*
2002-2004
20
16
14
15
1.6
1.5
1.2
Percent
Change**
-24
-32
-36
-19
-33
-32
-35
Ambient sulfur dioxide
concentration
Ambient sulfate concentration
Southeast
Mid-Atlantic
Midwest
Northeast
Southeast
Mid-Atlantic
Midwest
Northeast
Southeast
1.3
Wet inorganic nitrogen kg/ha
deposition
Wet nitrate concentration mg/L
Mid-Atlantic
Midwest
Northeast
Southeast
Mid-Atlantic
Midwest
Northeast
Southeast
Ambient nitrate concentration (ig/m3
Total ambient |^g/nV
nitrate concentration
(nitrate + nitric acid)
Mid-Atlantic
Midwest
Northeast
Southeast
Mid-Atlantic
Midwest
Northeast
Southeast
0.9
2.1
0.4
0.6
3.5
4.0
2.0
2.2
0.9
1.8
0.5
0.7
2.9
3.5
1.8
2.0
-3
-11
27
14
-15
-13
-7
-6
Source: CASTNETand NADP/NTN
*Measurement data are reported as two significant digits and reflect an updated rounding convention from last year's report.
**Percent change is estimated from raw measurement data, not rounded; some of the measurement data used to calculate percentages may be at or
below detection limits.
-------
14 ^ Acid Rain Program, 2004 Progress Report
Understanding the Monitoring Networks
To evaluate the impact of emission reductions
on the environment, scientists and policymakers
use data collected from long-term national moni-
toring networks such as the Clean Air Status and
Trends Network (CASTNET) and the National
Atmospheric Deposition Program/National Trends
Network (NADP/NTN).These complementary,
long-term monitoring networks provide informa-
tion on a variety of indicators necessary for track-
ing temporal and spatial trends in regional air qual-
ity and acid deposition (see Figure 14).
CASTNET provides atmospheric data on the
dry deposition component of total acid deposition,
ground-level ozone, and other forms of atmospher-
ic pollution. Established in 1987, CASTNET now
consists of more than 80 sites across the United
States. EPA's Office of Air and Radiation operates
most of the monitoring stations; the National Park
Service (NPS) funds and operates approximately 30
stations in cooperation with EPA. Many CAST-
NET sites are approaching a continuous 20-year
data record, reflecting EPA's commitment to long-
term environmental monitoring. Public access to
CASTNET data are available through the Clean
Air Markets Web site at www.epa.gov/airmarkets.
NADP/NTN is a nation-wide, long-term network
tracking the chemistry of precipitation. NADP/NTN
offers data on hydrogen (acidity as pH), sulfate, nitrate,
ammonium, chloride, and base cations. The network is
a cooperative effort involving many groups, including
the State Agricultural Experiment Stations, U.S.
Geological Survey, U.S. Department of Agriculture,
EPA, NPS, the National Oceanic and Atmospheric
Administration (NOAA), and other governmental and
private entities. NADP/NTN has grown from 22 sta-
tions at the end of 1978 to more than 250 sites span-
ning the continental United States, Alaska, Puerto
Pvico, and the Virgin Islands.
While CASTNET provides some ambient air
quality data, EPA also uses data from other ambi-
ent monitoring networks, including the State and
Local Air Monitoring Stations and National Air
Monitoring Stations (SLAMS/NAMS).These net-
works are used to document National Ambient Air
Quality Standards (NAAQS) attainment and show
trends in ambient air quality over time.
Figure 14: Air Quality and Acid Deposition Measurements
Chemicals
SO,
SO,
Sulfur Dioxide
Ionic Sulfates,
Particulate Sulfates
Why are these measured by the networks?
Indicator of ambient air quality; measured in dry monitoring networks; major
precursor to acid deposition
Indicators of ambient air quality and sulfur deposition; regional transport;
correlated with sulfur dioxide emissions; measured in wet and dry monitoring
networks
NO,
HNO
Ionic Nitrates,
Particulate Nitrates
Ionic Ammonium,
Particulate Ammonium
Indicators of ambient air quality and nitrogen deposition; correlated with
NOX emissions; measured in wet and dry monitoring networks
Strong acidic compound; main component of dry nitrogen deposition; meas-
ured in dry monitoring networks
Indicators of ambient air quality and nitrogen deposition; associated with
production of fine particles; aerosol ammonium is associated with sulfate
ion; can play a role neutralizing atmospheric acidic species; measured in wet
and dry monitoring networks
H+
Ionic Hydrogen
Indicator of acidity in precipitation; measured in wet deposition monitoring
networks
Ca2+
Mg2
K+
Na+
Calcium
Magnesium
Potassium
Sodium
These base cations are indicators of the ability to neutralize acids in precipi-
tation; also play an important role in plant nutrition and soil productivity
-------
Acid Rain Program, 2004 Progress Report > 15
Air Quality
Figure 15: SO2 Air Quality, 1990-2004
(Based on Annual Arithmetic Average)
Data collected from monitoring networks
show that the decline in SO2 emissions from the
power industry has improved air quality.7 Based on
EPA's latest air emissions trends data located at
www.epa.gov/airtrends/index.html, the national
composite average of SO2 annual mean ambient con-
centrations decreased 49 percent between 1990 and
2004 as shown in Figure 15.The largest single-year
reduction (21 percent) occurred in the first year of
the Acid Rain Program, between 1994 and 1995.
These trends are consistent with the ambient
trends observed in the CASTNET network.
During the late 1990s, following implementation of
Phase I of the Acid Rain Program, dramatic
regional improvements in SO2 and ambient sulfate
concentrations were observed at CASTNET sites
throughout the eastern United States, due to the
large reductions in SO2 emissions from Acid Rain
Program sources. Analyses of regional monitoring
data from CASTNET show the geographic pattern
of SO2 and airborne sulfate in the eastern United
States. Three-year mean annual concentrations of
SO2 and sulfate from CASTNET long-term moni-
toring sites are compared from 1989 through 1991
and 2002 through 2004 in both tabular form and
graphically in maps (see Figure 13 on page 13 and
Figures 16a through 17b on page 16).
The map in Figure 16a shows that from 1989
through 1991, prior to implementation of Phase I
of the Acid Rain Program, the highest ambient
concentrations of SO2 in the East were observed
in western Pennsylvania and along the Ohio River
Valley. Figure 16b indicates a significant decline in
those concentrations in nearly all affected areas.
Before the Acid Rain Program, in 1989
through 1991, the highest ambient sulfate concen-
trations, greater than 7 (ig/m3, were observed in
western Pennsylvania, along the Ohio River Valley,
and in northern Alabama. Most of the eastern
United States experienced annual ambient sulfate
concentrations greater than 5 (ig/m3. Like SO2
0.04
E
Q_
Q_
£
0
National Standard
0% of sites have concentrations below this line
1 0% of sites have concentrations bel<
1 990 1991 1 9921 993 1 994 1995 1996 1 997 1 998 1 999 2000 2001 2002 2003 2004
Source: EPA air emission trends, www.epa.gov/airtrends/2005/
econ-emissions.html
concentrations, ambient sulfate concentrations have
decreased since the program was implemented,
with average concentrations decreasing approxi-
mately 30 percent in all regions of the East. Both
the size of the affected region and magnitude of
the highest concentrations have dramatically
declined, with the largest decreases observed along
the Ohio River Valley (see Figures 17a and 17b).
Although the Acid Rain Program has met its
NOX reduction targets, emissions from other sources
(such as motor vehicles and agriculture) have led to
increased ambient nitrate concentration in some areas
of the country (see Figure 13 on page 13). NOX lev-
els in some areas can also be affected by emissions
transported via air currents over wide regions.8 In
2004, reduced NOX emissions from power plants
under the NOX Budget Trading Program led to more
significant region-specific improvements in some
indicators than have been seen in previous years. For
instance, total annual mean ambient nitrate concen-
trations (nitric acid plus particulate nitrate) for 2002
through 2004 have decreased in the Mid-Atlantic
and Midwest by about 15 percent from the annual
mean concentration in 1989 through 1991 (see
Figures 18a and 18b on page 17). While these
improvements may be partly attributed to added
NOX controls installed for compliance with the NOX
SIP Call, the findings at this time are not conclusive.
7 It should be noted that there has not been a violation of the SO2 standard at any of the monitoring sites since 2000.
3 See the EPA Office of Transportation and Air Quality Web site at www.epa.gov/otaq for information on recent rules to reduce NOX emis-
sions from mobile sources. Additional NOX reductions are occurring as a result of the NOX Budget Trading Program. See EPA's August
2005 report, Evaluating Ozone Control Programs in the Eastern United States: Focus on the NOX Budget Trading Program, 2004, at
wwwepa.gov/airtrends/2005/ozonenbp.pdf, which discusses these NOX reduction efforts.
-------
16 -v- Acid Rain Program, 2004 Progress Report
Figure 16a: Annual Mean Ambient Sulfur
Dioxide Concentration, 1989 through 1991
Figure 16b: Annual Mean Ambient Sulfur
Dioxide Concentration, 2002 through 2004
Source: CASTNET
Figure 17a: Annual Mean Ambient Sulfate
Concentration, 1989 through 1991
Source: CASTNET
Figure 17b: Annual Mean Ambient Sulfate
Concentration, 2002 through 2004
Source: CASTNET
Source: CASTNET
-------
Acid Rain Program, 2004 Progress Report & 17
Figure 18a: Annual Mean Total Ambient Nitrate
Concentration, 1989 through 1991
- >6.0
Figure 18b: Annual Mean Total Ambient Nitrate
Concentration, 2002 through 2004
Source: CASTNET
Source: CASTNET
4.0
5.0
>6.0
The CASTNET maps in this report represent ambient concentrations for the eastern United States only. During the
early years of CASTNET (1 989 to 1 991), monitoring coverage was limited to the East with only a handful of sites in
the West, which were located primarily in National Park Service-Class I areas. Today, EPA, together with its partners
such as NPS, has added many sites to the network, which now consists of more than 80 sites across the country.
Acid Deposition
NADP/NTN monitoring data show significant
improvements in some deposition indicators. For
example, wet sulfate deposition—sulfate that falls
to the earth through rain, snow, and fog—has
decreased since the Acid Rain Program was imple-
mented with some of the greatest reductions
occurring in the Mid-Appalachian region, includ-
ing Maryland, New York, West Virginia, Virginia,
and most of Pennsylvania. Wet sulfate deposition
decreased throughout the early 1990s in much of
the Ohio River Valley and northeastern United
States. Other less dramatic reductions have been
observed across much of New England, portions of
the southern Appalachian Mountains and in some
areas of the Midwest. Average decreases in wet
deposition of sulfate range from 36 percent in the
Northeast to 19 percent in the Southeast (see
Figure 13 on page 13, and Figures 19a, and 19b on
page 18).
Since 1991, wet sulfate concentrations have
decreased significantly as well, with average levels
decreasing 35 percent in the Northeast, 33 percent
in the Mid-Atlantic, and 32 percent in the
Midwest. A strong correlation between large scale
SO2 emission reductions and large reductions in
sulfate concentrations in precipitation has been
noted in the Northeast, one of the areas most
affected by acid deposition.
A principal reason for reduced concentrations
of sulfate in precipitation in the Northeast is a
reduction in the long-range transport of sulfate
-------
18 -0" Acid Rain Program, 2004 Progress Report
from emission sources located in the Ohio River
Valley. The reductions in sulfate documented in the
Northeast, particularly across New England and
portions of New York, were also affected by SO2
emission reductions in eastern Canada. NADP data
indicate that similar reductions in precipitation
acidity, expressed as hydrogen ion (H+) concentra-
tions, occurred concurrently with sulfate reduc-
tions, but have not decreased as dramatically due to
a simultaneous decline in acid-neutralizing base
cations, which act to buffer acidity.
Reductions in nitrogen deposition recorded
since the early 1990s have been less dramatic than
those for sulfur. As noted earlier, emission trends
from source categories other than Acid Rain
Program sources significantly affect air concentra-
tions and deposition of nitrogen. Inorganic nitro-
gen deposition decreased modestly in the Mid-
Atlantic and Northeast (averaging 8 to 16 percent)
but remained virtually unchanged in other regions
(see Figures 20a and 20b).Wet nitrate concentra-
tions have dropped significantly in the Mid-
Atlantic and Northeast regions, but are not tied to
precipitation (see Figure 13 on page 13). Modest
reductions of about 10 percent have occurred in
the Midwest and Southeast.
Figure 19a: Annual Mean Wet Sulfate
Deposition 1989 through 1991
Figure 19b: Annual Mean Wet Sulfate
Deposition 2002 through 2004
>40
Source: National Atmospheric Deposition Program
Source: National Atmospheric Deposition Program
Figure 20a: Annual Mean Wet Inorganic
Nitrogen Deposition 1989 through 1991
Figure 20b: Annual Mean Wet Inorganic
Nitrogen Deposition 2002 through 2004
Source: National Atmospheric Deposition Program
Source: National Atmospheric Deposition Program
Note: Dots on maps represent monitoring sites
-------
Acid Rain Program, 2004 Progress Report -0- 19
Recovery of
Acidified Lakes
and Streams
Over the past 25 years, the
effect of acid deposition on lakes
and streams has been the focus
of much research, particularly in
areas of the eastern United States
that are both sensitive to acid
deposition and receiving signifi-
cant levels over time. These areas
encompass New England, the
Adirondack Mountains, the
northern Appalachian Plateau
(including the Catskill and
Pocono Mountains), and the
Blue Ridge region (including
streams in western Virginia) (see
Figure 21). As shown in the dep-
osition maps, above, implementa-
tion ofTitle IV has resulted in
decreased sulfate deposition
across the East, while changes in
nitrate deposition have been
small. Recent studies provide
data regarding the response of
lakes and streams to changes in
emissions.
A 2005 study9 examined
alterations in lake water chem-
istry as a result of deposition
changes at 130 monitoring sites
between 1984 and 2001. The
sites were chosen to allow gen-
eralizations regarding the effects
of decreases in acidic deposition
in 3,666 lakes throughout the
entire northeastern United
' Warby, R.A.F., Johnson, C.E., and DriscoU,
C.T. Chemical recovery of surface waters across
the northeastern United States from reduced
inputs of acidic deposition: 1984-2001.
Syracuse, New York: Syracuse University.
sulfate
ANC
base
cations
-3
-2 -1 0
Slope of Trend
Improvements in Surface Water
EPA's Temporally Figure 21: Regional Trends in Lake and
Integrated Monitoring of Stream Acidification, 1990-2000
Ecosystems (TIME) and
Long-Term Monitoring
(LTM) programs
(described in a text box
on page 20) provide
information on the chem-
istry of lakes and streams,
which allows researchers
to understand how water
bodies are responding to
changes in emissions. The
data presented here show
regional trends in acidifi-
cation from 1990 to 2000
in areas of the eastern
United States. For each
lake or stream in the net-
work, measurements of
various indicators of recov-
ery from acidification were
taken. These measurements
were plotted against time,
and trends for the given lake or stream during the 10-year period
were then calculated as the change in each of the measurements
per year (e.g., change in concentration of sulfate per year). Using
the trends calculated for each water body, median regional
changes were determined for each of the measures of recovery. A
negative value of the "slope of the trend" means that the measure
has been declining in the region, while a positive value means it
has been increasing. The greater the value of the trend, the
greater the yearly change in the measurement. Movement
toward recovery is indicated by positive trends in acid
neutralizing capacity (ANC) and negative trends
in sulfate, nitrate, hydrogen ion, and alu-
minum. Negative trends in base
cations can balance out the
decreasing trends in sulfate and
nitrate and hinder improve-
ments in ANC.
^^^1 Maine lakes (n=11)
Vermont lakes (n-11)
^^^1 Adirondack lakes (n=50
^^H Catskill streams (n-4)
^^^1 Pennsylvania streams (n=5)
^^^1 Virginia streams (n=74)
* = not significant
Source: Stoddard, J.L., Kahl, J.S., Deviney F.A.,
DeWalle, D.R., DriscoU, C.T., Herlihy A.T.,
Kellogg, J.H., Murdoch, P.S.,Webb, J.R., and
Webster, K.E. (2003) Response of surface water
chemistry to the Clean Air Act Amendments of 1990.
EPA620-R-03-001. Washington, DC: U.S.
Environmental Protection Agency.
-------
20 < Acid Rain Program, 2004 Progress Report
Long-Term Environmental
Monitoring at EPA
EPA's Temporally Integrated Monitoring
of Ecosystems (TIME) and Long-Term
Monitoring (LTM) programs are
designed to detect trends in the chem-
istry of regional populations of lakes or
streams and to determine whether emis-
sion reductions have had the intended
effect of reducing acidification.
These programs monitor a total of 145
lakes and 147 streams, representing all
of the major acid-sensitive regions of the
northern and eastern United States,
including the upper Midwest, New
England, Adirondack Mountains, north-
ern Appalachian Plateau (including the
Catskill Mountains), and the Blue Ridge
Mountain region of Virginia. TIME/LTM
measure a variety of important chemical
characteristics, including acid neutraliz-
ing capacity (ANC), pH, sulfate, nitrate,
major cations (e.g., calcium and magne-
sium), and aluminum. While the repre-
sentativeness of the TIME/LTM network
is somewhat limited, the TIME program
provides a coherent individual regional
dataset for this kind of analysis. In addi-
tion, the U.S. Geological Survey (USGS)
has been measuring surface water quali-
throughout the United States, where
sample collection during hydrologic
events and ancillary data on other water-
shed characteristics have been used to
assess the watershed processes control-
States. The overall decrease in acidic deposition has
resulted in some chemical recovery of surface
waters, with increases in pH and ANC and
decreases in strong acidic anions and inorganic
monomeric aluminum. The 2005 study reports a
systematic increase in ANC in lakes across the
Northeast:
• Approximately 4.5 percent of lakes in the
Northeast are chronically acidic (ANCXO),
down from 6 percent in 1984.
• Eleven percent of lakes have low ANC levels
(ANC 0-25), down from 13 percent in 1984.
• Approximately 84.5 percent of lakes have
moderate ANC levels (ANO25), up from 81
percent in 1984.
• Despite region-wide increases in ANC in
recent years, waters with ANC<50 remain sen-
sitive to acidic deposition and could experience
adverse biological response associated with
episodic acidification. It is also important to
note that estimates of the numbers of acidic
and low-ANC lakes would increase if smaller
lakes (<4 hectares) were considered.
Another recent study10 focused specifically on a
subset of northeastern lakes in the Adirondack
Mountain region from 1992 to 2004. This study
found trends similar to those for the northeastern
region for 48 lakes included in the Adirondack
Long-Term Monitoring Program:
• Forty-seven of 48 sites showed significant
decreases in combined concentrations of sulfate
and nitrate.
• The declines in sulfate concentrations have not
been uniform over the 1992 to 2004 period,
with greater declines in the 1990s and a level-
ing of sulfate concentrations over the last five
years as emissions of SO2 and wet sulfate dep-
osition have leveled off.
• Twenty-seven of the 48 lakes showed signifi-
cant decreases in nitrate concentrations, with
only three exhibiting increases. It is unclear
why nitrate concentrations have declined at
10 DriscoU, C.T., DriscoU, K.M., Roy, K.M., and Dukett, J. Changes
in the chemistry of lakes in the Adirondack region of New York
following declines in acidic deposition. Environmental
Geochemistry and Health, (in review)
-------
Acid Rain Program, 2004 Progress Report > 21
certain locations while there has not been any
appreciable change in emissions of NOX or
atmospheric nitrate deposition.
• Thirty-seven of the 48 lakes showed significant
trends of increasing ANC, attributed to
decreasing concentrations of both SO42~ and
NO3\ Rates of ANC increase are relatively
slow, however, and, at current rates, it will be
several decades before full chemical recovery is
approached.
Recent studies11 used data on Shenandoah
National Park -watershed ecosystems to determine
regional trends for streams in western Virginia:
• An analysis using data from 1988 to 2003
showed that sulfate concentrations were gener-
ally not decreasing and, in many cases, were
increasing. Decreases in nitrate concentrations
were generally greater than those for sulfate
and could account for much of the observed
increase in ANC concentrations. Changes in
nitrate concentrations were attributed to the
gypsy moth defoliation of watersheds during
the late 1980s and early 1990s; the same con-
clusion was reached in a 1998 to 2001 analysis.
Thus, the 1988 to 2003 trend analysis provides
less evidence for recovery from acidification
due to atmospheric deposition.
Implementation of the Acid Rain Program has
substantially reduced emissions of SO2 and NOX
from power generation sources. However, the
National Acid Precipitation Assessment Program
(NAPAP) 2005 Report to Congress,12 recent model-
ing, and many published articles indicate that SO2
and NOX emission reductions achieved under Title
IV are insufficient to achieve full recovery or to pre-
vent further acidification in some regions. The studies
described above support that conclusion, showing
that environmental improvements have been slow in
many sensitive areas, and signs of recovery still are not
evident in some areas. The NAPAP Report to
Congress concluded that additional SO2 and NOX
emission reductions from power plants and other
sources are necessary to decrease deposition and fur-
ther reduce the number of acidic lakes and streams in
many regions of the United States. Additional emis-
sion reductions will be achieved through implemen-
tation of existing or future regulations to address
transport of ozone and fine particles and mercury
deposition, including the NOX SIP Call in the
Eastern United States; Tier II and diesel rules affect-
ing mobile sources; state implementation plans to
achieve the ozone and fine particle National Ambient
Air Quality Standards (NAAQS); and the recent rules
to reduce interstate transport of fine particles and
ozone, mercury, and regional haze from power plants.
Quantifying Costs and Benefits of the Acid Rain Program
A new 2005 analysis13 of the annual benefits and
costs of the Acid Rain Program updates those of the
NAPAP 1990 Integrated Assessment and a 1995 EPA
report,14 and integrates scientific knowledge that has
emerged since the 1990s. An expanded list of impacts
increases the program's estimated benefits, while
newer implementation strategies—unforeseen in
1990—lower estimated costs. The estimated value of
the program's annual benefits in the year 2010 now
totals $122 billion (2000$).These benefits result
mostly from the prevention of health-related impacts
(such as premature deaths, illnesses, and work days
missed due to illness), but also include improved visi-
bility in parks, and other recreational and ecosystem
improvements. The paper indicates that these
benefits stem from the substantial difference that the
Acid Rain Program is expected to make in many
areas meeting NAAQS by 2010 for fine particles less
than 2.5 micrometers in diameter (PM2 5) and ozone
standards (see Figure 22 on page 22). Notably, some
11 Webb, J.R., Deviney, F.A., Jr., and Maben, S. Shenandoah Watershed Study (SWAS) Annual Report for 2003. University ofVirginia.
Webb, J.R., Cosby, B.J., Deviney, F.A., Jr., Galloway, J.N., Maben, S.W, and Bulger, AJ. (2004) Are brook trout streams in western Virginia
and Shenandoah National park recovering from acidification? Environmental Science and Technology, 38.
12 2005 National Acid Precipitation Assessment Program Report to Congress, wwwal.noaa.gov/AQRS/reports/napapreport05.pdf.
13 Chestnut, L.G. and Mills, D. A fresh look at the benefits and cost of the U.S. Acid Rain Program. Journal of Environmental Management.
(article in press)
14 Human Health Benefits from Sulfate Reduction under Title IV of the 1990 Clean Air Act Amendments. EPA-430-R-95-010.
-------
22 < Acid Rain Program, 2004 Progress Report
significant benefits are not quanti-
fied, such as the 20 percent reduc-
tion in mercury emissions from
power plants; improvements to
urban visibility, forest health, and
surface water quality; and increased
longevity and reduced soiling of
painted and stone surfaces.
The 2005 study finds that
the estimated annual cost of the
Acid Rain Program in 2010 is
$3 billion, with the SO2 program
accounting for about $2 billion per
year in 2010. These findings are
generally consistent with other
recent independent findings, and
are far less than the original
NAPAP estimates.15 EPA expects
NOX costs to be no more than $1
billion annually, and likely less, from
the limited analysis that has been
completed in this area. This leads to
a more than 40-to-l benefit-cost
ratio. Among the most important
factors in reducing SO2 program
costs was improved transportation
and production of coal, which
enabled sources to increase the use
of low-sulfur coal. The flexibility
offered by the SO2 program also
may have enabled technological
innovations that lowered compli-
ance costs. For instance, boiler
adaptations and lower than expect-
ed installation and operation costs
for flue gas desulfurization systems
(scrubbers) reduced costs below
original estimates.16
Figure 22: Human Health Benefits from Acid Rain Program
PIS/IT r and Ozone Reduction
'2.5
Avoided Health Effects Related to Title Number Monetary
IV's PM2 5 and Ozone Reductions of Cases Value— Millions
Avoided* (U.S. 2000$)
PM2 5 Reduction
Mortality (adults)
Infant mortality (children less than 1)
Chronic bronchitis (adults)
Nonfatal heart attacks (adults)
Respiratory hospital admissions (all ages)
Cardiovascular hospital admissions (adults)
Emergency room visits for asthma (children)
Acute bronchitis (children)
Asthma exacerbations (children with asthma)
Upper respiratory symptoms (children with asthma)
Lower respiratory symptoms (children)
Minor restricted activity days (adults)
Work loss days (adults)
Total related to PM2 5 reduction
Ozone Reduction
Mortality
Respiratory hospital admissions (age > 65)
Respiratory hospital admissions (age < 2)
Emergency room visits for respiratory illness
School loss days
Acute respiratory symptoms, minor restricted activity
Worker productivity loss
Total related to ozone reduction
Total related to PM2 5 and ozone reductions
18,000
100
11,000
24,000
8,700
11,400
14,700
27,700
29,400
353,400
299,500
12,766,400
2,200,000
700
1,500
1,800
400
785,500
1,612,100
n.a.
$106,171
$779
$4,274
$2,018
$130
$246
$4
$10
$1
$9
$5
$677
$240
$114,564
$4,101
$27
$14
$0.1
$59
$161
$22
$4,384
$118,949
Source: Chestnut, L.G. and Mills, D. A fresh look at the benefits and cost of the U.S. Acid Ram
Program. Journal of Environmental Management, (article in press)
* Rounded to the nearest hundred
15 See, for example:
Ellerman, D. (2003) Lessons from Phase 2 compliance with the U.S. Acid Rain Program. Cambridge, Massachusetts: MIT Center for Energy and
Environmental Policy Research
Carlson, C.P., Burtraw, D., Cropper, M., and Palmer, K. SO2 control by electric utilities: What are the gains from trade? Journal of Political
Economy, Vol. 108, No. 6: 1292-1326.
Informing Regulatory Decisions: 2003 Report to Congress on the Costs and Benefits of Federal Regulations and Unfunded Mandates on State,
Local, and Tribal Entities (2003) Office of Management and Budget, Office of Information and Regulatory Affairs:
\v\vvv.\vhitehouse.gov/ornb/inforeg/2003_cost-ben_final_rpt.pdf
16 EPA estimates recognize that some switching to lower-sulfur coal (and accompanying emission reductions) would have occurred in the
absence of Title IV as railroad deregulation lowered the cost of transporting coal from Wyoming's Powder River Basin electric power
plants in the Midwest and as plant operators adapted boilers to different types of coal.
-------
Acid Rain Program, 2004 Progress Report -0- 23
National Actions for Further Emission Reductions-
2005 Clean Air Rules
In the spring of 2005, in the absence of new
legislation, EPA promulgated a suite of air quality
rules designed to address additional reductions of
SO2, NOX, and mercury (Hg) from power plants.
These rules include the Clean Air Interstate Rule
(CAIR), the Clean Air Mercury Rule (CAMR),
and the Clean Air Visibility Rule (CAVR).17
CAIR will permanently lower and cap emissions
of SO2 and NOX in 28 eastern states and the District
of Columbia (see Figures 23 and 24), starting in
2009 for NOX and 2010 for SO2.The rule addresses
the transport of ozone and fine particles resulting
from these emissions. States have the option to adopt
a model cap and trade program administered by EPA
to achieve the cap. The CAIR SO2 trading program
is designed to work with the existing Acid Rain
Program. Sources turn in Acid Rain allowances at a
ratio of greater than 1-to-l to achieve reductions
beyond Title IV of the Clean Air Act. When fully
implemented, CAIR will reduce SO2 emissions by
over 70 percent and NOX emissions by over 60 per-
cent from 2003 levels, leading to decreased particu-
late matter, ozone concentrations, and acid deposi-
tion. According to EPA models, CAIR will provide
health and environmental benefits valued at more
than 25 times the expected costs of compliance.17
CAMR is the first-ever rule to permanently cap
and reduce mercury emissions from coal-fired power
plants in all 50 states and the District of Columbia.
CAMR establishes standards of performance limiting
mercury emissions from new and existing coal-fired
power plants and creates a cap and trade program to
reduce nation-wide utility emissions in two distinct
phases. By 2018, a 15-ton cap will be in place. Along
with the CAIR rule, this will result in a mercury
reduction from coal-fired power plants of nearly 70
percent from current levels.17
CAVR applies to non-CAIR states, primarily in
the West, and affects power plants and other major
sources with the potential to impact visibility, fine
particles, acid deposition, and ozone in certain areas
of the country. CAVR places Best Available Retrofit
Figure 23: States Covered by the Clean Air
Interstate Rule (CAIR)
Source: EPA
Note: EPA proposed in March 200S to add Delaware and Newjersey to
the states in CAIR covered for fine particles.
Figure 24: CAIR/CAMR Emission Caps
Air Emission CAIR (for 28 Eastern CAMR
Cap States and DC)
S02-Phase 1
SO2-Phase 2
NOx-Phase 1
NOx-Phase 2
Hg-Phase 1
Hg-Phase 2
3.6 million tons in 2010
2.5 million tons in 2015
1.5 million tons in 2009
(annual)
0.6 million tons 2009
(ozone season)
1.3 million tons in 2015
(annual)
0.5 million tons 2015
(ozone season)
38 tons in 2010
15 tons in 2018
Technology (BART), scrubbers for SO2, and
advanced low-NOx burners, on many coal-fired
units outside of the CAIR region in 2013/2014.17
Based on these three regulations, EPA estimates
that power plants will install pollution control tech-
nology, such as scrubbers for SO2 control and SCRs
for NOX control. By 2010, nearly half (46 percent) of
the units in the nation-wide coal-fired fleet totaling
roughly 146.3 GW of capacity will have installed
scrubbers, while about 39 percent, or 126.5 GW of
power plant capacity, -will have installed SCRs. By
2020, nearly two-thirds (72 percent) of units will
have scrubbers (230.5 GW of capacity) and over 56
17 CAIR (See www.epa.gov/cair/index.html), CAMR (See www.epa.gov/air/mercuryrule), CAVR (See www.epa.gov/oar/visibility/index.html)
-------
24 & Acid Rain Program, 2004 Progress Report
percent will have installed SCR (180.9 GW), according to
EPA's projections.17
EPA projects that these rules will result in significant
monetized health benefits (1999$).These estimates range
from $62 billion to $73 billion annually in 2010, and from
$120 billion to $140 billion annually in 2020. The vast
majority of these benefits result from the reduced levels of
fine particles in the ambient air that will occur from
reductions in SO2 and NOX emissions. Reductions in SO2
emissions from 1993 levels (by 4.3 million tons in 2010
and by 6.1 million tons in 2020) account for the largest
portion of improvements in ambient fine particle condi-
tions. The remaining benefits result from ozone improve-
ments associated with NOX emission reductions. Notably,
these rules also provide multiple unquantified benefits,
including the value of increased agricultural crop and
commercial forest yields, visibility improvements, reduc-
tions in nitrogen and acid deposition and the resulting
changes in ecosystem functions, and health and welfare
benefits associated with reduced mercury emissions.17'18
EPA expects that the air quality impacts of these reg-
ulations, coupled with recent rules to reduce fine parti-
cles and NOX from motor vehicles, will be extensive.
Figures 25, 26, and 27 show areas projected to exceed
NAAQS in 2010 and 2020, compared to today. Figure
25 shows ozone and PM2 5 nonattainment areas primari-
ly occurring in eastern states and California. As the new
rules are implemented, nonattainment is expected to
decline progressively, with 92 fewer areas by 2010 (see
Figure 26), and 106 fewer areas by 2020 (see Figure 27).
As these maps indicate, implementing these three new
regulations is an important step toward improving future air
quality in the United States and helping states and local
communities meet NAAQS for fine particles and ozone.
Future progress reports will begin to provide infor-
mation important to the transition to CAIR, CAMR,
and CAVR, while continuing to report on compliance
under the Acid Rain Program.
17 CAIR (See www.epa.gov/cair/index.html), CAMR (See
www.epa.gov/air/mercuryrule/), CAVR (See www.epa.gov/
oar/ visibility /index, html)
18 Multi-pollutant legislative analysis, October 2005, EPA
19 Current rules include Title IV of CAA, NOX SIP Call, and some
existing state rules.
20 Areas forecast to remain in nonattainment may need to adopt
additional local or regional controls to attain the standards by
dates set pursuant to the Clean Air Act. These additional local or
regional measures are not forecast here, and therefore this figure
overstates the extent of expected nonattainment.
Figure 25: Current Nonattainment Areas
Source: EPA
Legend Area Count
^H Both PM and Ozone Nonattainment 36
PM Only Nonattainment 3
Ozone Only Nonattainment 90
Note: Currently, 1 29 areas are designated as nonattainment for PM2 5
and/or 8-hour Ozone (April 1, 200S).
For further information on designations and related requirements, see
www.epa.gov/air/oaqps/glo/designations/mdex.htm and
www.epa.gov/pmdesignations.
Figure 26: PM2 5 and Ozone Attainment in 2010
Source: EPA
Legend Area c
^H Both PM and Ozone Nonattainment
^H PM Only Nonattainment
Ozone Only Nonattainment 15
^H Nonattainment areas projected to attain 92
Note: 92 areas are projected to meet the PM2 5 and 8-Hour Ozone
Standards In 2010 with CAIR/CAMR/CAVR and some current rules,
absent additional local controls.19'20
Figure 27: PM2 5 and Ozone Attainment in 2020
Source: EPA
Legend Area Count
^H Both PM and Ozone Nonattainment 3
Ozone Only Nonattainment 7
^^| Nonattainment areas projected to attain -|Q6
Note: 1 06 areas are projected to meet the PM2 5 and 8-Hour Ozone
Standards In 2020 with CAIR/CAMR/CAVR and some current rules,
absent additional local controls.19'20
-------
Online Information, Data, and Resources
About the Clean Air Markets Division
The availability and transparency of data—
from emission measurement to allowance
trading to deposition monitoring—is a
cornerstone of effective cap and trade
programs. The Clean Air Markets Division
in the Office of Air and Radiation's Office
of Atmospheric Programs manages programs
for collecting these data and assessing the
effectiveness of cap and trade programs,
including the Acid Rain Program.
www.epa.gov/airmarkets
Regulatory Information
To learn more about how emissions
cap and trade programs work, see:
www.epa.gov/airmarkets/arp
Acid Rain Program
www.epa.gov/airmarkets/progsregs/
noxview.html
NOX Trading Programs
www.epa.gov/airmarkets/capandtrade/
index.html
General Cap-and-Trade Information
Also see recent related rulemakings,
including:
www.epa.gov/cair
Clean Air Interstate Rule (CAIR)
www.epa.gov/CAMR/index.htm
Clean Air Mercury Rule (CAMR)
www.epa.gov/visibility
Clean Air Visibility Rule (CAVR)
Progress and Results
Several reports have assessed the progress
and results and projected future impacts of
the Acid Rain Program.
www.sciencedirect.com/science/
journal/03014797
A Fresh Look at the Benefits and Costs of the U.S.
Acid Rain Program
www.al.noaa.gov/AQRS/reports/
napapreport05.pdf
2005 National Acid Precipitation Assessment
Program Report to Congress
www.rff.org/Documents/
RFF-RPT-Adirondacks.pdf
Valuation of Natural Resource Improvements in the
Adirondacks
www.adirondacklakessurvey.org
Jenkins,]., Roy, K., Driscoll, C, Beurkett, C.
Add Rain and the Adirondacks: A Research
Summary. Adirondack Lakes Survey Corporation
Emission, Allowance, and
Environmental Data
For more information on emissions,
allowance, and environmental data, see:
cfpub.epa.gov/gdm
EPA Clean Air Markets Data and Maps
www.epa.gov/castnet
Clean Air Status and Trends Network
(CASTNET)
www.epa.gov/airmarkets
2005 Atlas: Atmosphere in Motion
nadp.sws.uiuc.edu
National Atmospheric Deposition Program/
National Trends Network
-------
A Histor
ofthe
Acid Rain Progra
1970
20 million people
celebrate the first
Earth Day.
1978
The National Atmospheric Deposition
Program/National Trends Network
(NADP/NTN) begins monitoring sulfur
and nitrogen and deposition to
ecosystems.
1980
Lake acidification
and fish loss in the
Adirondacks, Green
Mountains, and
Sierra Nevada make
national news.
1970
Clean Air
Act (CAA)
is passed.
1977
Congress strengthens the
CAA and includes require-
ments forSO2 pollution con-
trol at power plants.
1980
The National Acid
Precipitation Assessment
Program (NAPAP), mandated
by Congress, begins study on
acid rain.
1990
Congress strengthens the
CAA and establishes the Acid
Rain Program using a market
based approach to reduce
SO2 from power plants by
more than 50 percent.
1986
The United States and Canada
begin study of cross-border acid
rain transport. The United States
is called upon to reduce emis-
sions of SO2 and NOX, especially
from coal-burning power plants.
1987
The Clean Air
Status and Trends
Network (CAST-
NET) is established
to monitor dry
deposition.
1993
EPA publishes acid
rain regulations,
and Chicago Board
of Trade holds first
auction of SO2
allowances.
1994
Projected costs of compliance
re-estimated by the
Government Accountability
Office and the Electric Power
Research Institute at less than
half of original estimates.
-------
1995
Phase I of Acid Rain Program imple-
mentation begins. SO2 emissions fall
to 5 million tons below 1 980 levels.
Acidity of rainfall in the eastern United
States drops 10 to 25 percent.
1996
About 150 of the largest
coal-fired power plants
begin to implement Acid
Rain Program NOX
requirements.
2001
2000
Phase II of Acid Rain Program
begins, regulating additional
smaller/cleaner plants and
requiring further reductions in
NOxandSO2.
Introduction of the
On-line Allowance
Trackings/stem begins
an era of paperless
allowance transfer
recording.
2002
EPA begins electronic
audit process to
supplement existing
rigorous monitoring
program.
1997
More than 80
percent of affected
companies have
engaged in private
allowance transac-
tions.
1998
Regulatory revisions
enhance efficiencies
of compliance and
administration. Nearly
10 million economically
significant allowance
transfers take place.
1999
Allowance
banking peaks.
SO2 early
reductions
total over 11
million tons.
2003
Lakes and streams
in the Adirondacks,
Upper Midwest
and Northern
Appalachian
Plateau show
signs of recovery.
2004
Acid Rain Program
sources emit 34
percent less SO2 and
43 percent less NOX
than in 1990, despite
a 34 percent increase
in fuel usage.
2005
New study estimates 2010 annual Acid Rain
Program benefits at $1 22 billion and annual costs
at $3 billion. According to 2005 NAPAP report,
further emission reductions are necessary to
achieve broader environmental recovery. EPA
promulgates CAIR, CAMR, and CAVR.
-------
2L
o
it
8
.2 o Z
— E -X
U
LU
eft
o <
O U
O a. LU O
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
PLANT NAME
AMEA Sylacauga Plant
AMEA Sylacauga Plant
Barry
Barry
Barry
Barry
Barry
Barry
Barry
Barry
Barry
Barry
Calhoun Power Company 1, LLC
Calhoun Power Company 1, LLC
Calhoun Power Company 1, LLC
Calhoun Power Company 1, LLC
Charles R Lowman
Charles R Lowman
Charles R Lowman
Colbert
Colbert
Colbert
Colbert
Colbert
Colbert
Decatur Energy Center
Decatur Energy Center
Decatur Energy Center
E B Harris Generating Plant
E B Harris Generating Plant
E B Harris Generating Plant
E B Harris Generating Plant
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
Gadsden
Gadsden
General Electric Company
Gorgas
Gorgas
Gorgas
PLANT
CODE
56018
56018
3
3
3
3
3
3
3
3
3
3
55409
55409
55409
55409
56
56
56
47
47
47
47
47
47
55292
55292
55292
7897
7897
7897
7897
26
26
26
26
26
26
26
7
7
7698
8
8
8
STACK/UNIT ID*
1
2
CSOAAN (1 , 2, 3)
1
2
3
4
5
6A
6B
7A
7B
CT1
CT2
CT3
CT4
1
2
3
CSCO14(1,2, 3, 4)
1
2
3
4
5
CTG-1
CTG-2
CTG-3
1A
1B
2A
2B
CSOCAN (1 , 2)
1
2
CSOCBN (3,4)
3
4
5
1
2
CC1
10
CSODAN (6,7)
6
2004
ALLOWANCES
ALLOCATED
0
0
3,882
4,292
8,811
10,051
24,836
0
0
0
0
0
0
0
0
1,853
7,026
5,895
5,854
6,602
6,641
6,646
16,033
0
0
0
0
0
0
0
7,805
7,996
7,896
8,313
25,805
1,957
2,024
0
22,443
3,036
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
1
5,096
4,466
8,894
10,667
20,714
10
10
10
10
2
2
2
2
8,917
7,172
7,196
13,828
14,887
17,999
16,760
17,899
2
2
2
2
2
2
2
17,442
19,177
16,249
17,474
56,859
4,521
5,668
12
29,373
9,844
ALLOWANCES
DEDUCTED
0
0
4,852
4,253
8,470
10,159
19,728
2
2
2
2
0
0
0
0
3,056
6,488
6,799
5,972
5,741
4,980
4,313
12,434
0
0
0
1
1
1
1
16,611
18,263
15,474
16,642
54,151
4,306
5,398
2
27,974
9,375
ALLOWANCES
CARRIED OVER
TO 2005
0
1
244
213
424
508
986
8
8
8
8
2
2
2
2
5,861
684
397
7,856
9,146
13,019
12,447
5,465
2
2
2
1
1
1
1
831
914
775
832
2,708
215
270
10
1,399
469
A, 1
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
PLANT NAME
Gorgas
Gorgas
Gorgas
Greene County
Greene County
Greene County
Greene County
Greene County
Greene County
Greene County
Greene County
Greene County
Greene County
Greene County
Hillabee Energy Center
Hillabee Energy Center
Hog Bayou Energy Center
James H Miller Jr
James H Miller Jr
James H Miller Jr
James H Miller Jr
Mclntosh (7063)
Mclntosh (7063)
Mclntosh (7063)
McWilliams
McWilliams
McWilliams
Morgan Energy Center
Morgan Energy Center
Morgan Energy Center
Plant H. Allen Franklin
Plant H. Allen Franklin
Plant H. Allen Franklin
Plant H. Allen Franklin
Tenaska Central Alabama Gen Station
Tenaska Central Alabama Gen Station
Tenaska Central Alabama Gen Station
Tenaska Lindsay Hill
Tenaska Lindsay Hill
Tenaska Lindsay Hill
Theodore Cogeneration
Washington County Cogen (Olin)
Widows Creek
Widows Creek
Widows Creek
PLANT
CODE
8
8
8
10
10
10
10
10
10
10
10
10
10
10
55411
55411
55241
6002
6002
6002
6002
7063
7063
7063
533
533
533
55293
55293
55293
7710
7710
7710
7710
55440
55440
55440
55271
55271
55271
7721
7697
50
50
50
STACK/UNIT ID*
7
8
9
1
2
CT10
CT2
CT3
CT4
CT5
CT6
CT7
CT8
CT9
CT1
CT2
COG01
1
2
3
4
"1
"2
**3
**4
**V1
**V2
CT-1
CT-2
CT-3
1A
1B
2A
2B
CTGDB1
CTGDB2
CTGDB3
CT1
CT2
CT3
CC1
CC1
CSWC16(1,2, 3, 4, 5, 6)
1
2
2004
ALLOWANCES
ALLOCATED
3,139
4,759
4,747
8,488
7,923
0
0
0
0
0
0
0
0
0
0
0
0
14,217
17,769
17,422
8,049
938
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
3,340
3,212
HELD IN
ACCOUNTS AS
OF 3/1/2005
11,801
12,775
11,448
18,085
17,711
12
12
16
17
14
12
11
16
14
0
0
2
10,778
1 1 ,507
14,140
13,080
7
10
10
10
10
10
3
2
3
2
2
4
4
1
1
1
1
1
2
13
14
3,789
3,465
ALLOWANCES
DEDUCTED
11,239
12,167
10,903
17,224
16,868
1
1
5
5
1
1
1
3
3
0
0
0
10,265
10,959
13,467
12,457
0
0
0
0
1
1
1
1
1
2
1
1
1
0
0
1
1
1
2
4
2
3,482
3,011
ALLOWANCES
CARRIED OVER
TO 2005
562
608
545
861
843
11
11
11
12
13
11
10
13
11
0
0
2
513
548
673
623
7
10
10
10
9
9
2
1
2
0
1
3
3
1
1
0
0
0
0
9
12
307
454
A, 2
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
AL
AL
AL
AL
AL
AL
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
AR
PLANT NAME
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Carl Bailey
Cecil Lynch
Cecil Lynch
Flint Creek Power Plant
Fulton
Geneva Arkansas 1
Geneva Arkansas 1
Hamilton Moses
Hamilton Moses
Harvey Couch
Harvey Couch
Hot Spring Power Company
Hot Spring Power Company
Hot Spring Power Company
Hot Spring Power Company
Independence
Independence
KGen Hot Spring LLC
KGen Hot Spring LLC
Lake Catherine
Lake Catherine
Lake Catherine
Lake Catherine
McClellan
Pine Bluff Energy Center
Robert E Ritchie
Robert E Ritchie
Thomas Fitzhugh
TPS - Dell
TPS - Dell
Union Power Station
Union Power Station
Union Power Station
Union Power Station
Union Power Station
Union Power Station
Union Power Station
Union Power Station
White Bluff
PLANT
CODE
50
50
50
50
50
50
202
167
167
6138
7825
55869
55869
168
168
169
169
55714
55714
55714
55714
6641
6641
55418
55418
170
170
170
170
203
55075
173
173
201
55340
55340
55380
55380
55380
55380
55380
55380
55380
55380
6009
STACK/UNIT ID*
3
4
5
6
7
8
01
2
3
1
CT1
CTG-1
CTG-2
1
2
1
2
GT-1
GT-2
SN-01
SN-02
1
2
CT-1
CT-2
1
2
3
4
01
CT-1
1
2
2
SN01
SN02
CTG-1
CTG-2
CTG-3
CTG-4
CTG-5
CTG-6
CTG-7
CTG-8
1
2004
ALLOWANCES
ALLOCATED
3,356
3,454
3,565
3,279
7,805
7,460
10
0
3
15,192
0
0
0
0
0
7
112
0
0
0
0
18,155
18,401
0
0
0
0
8
156
15
0
53
2,148
0
0
0
0
0
0
0
0
0
0
0
20,940
HELD IN
ACCOUNTS AS
OF 3/1/2005
4,556
3,707
3,711
4,060
8,959
8,682
1,792
1
14
21 ,392
10
0
0
2
2
30
450
0
0
0
0
26,767
29,682
3
3
2
2
35
616
2,750
6
214
736
41
0
0
2
2
2
2
2
2
2
2
24,637
ALLOWANCES
DEDUCTED
4,240
3,509
3,252
3,852
6,726
3,324
1,194
0
0
10,099
0
0
0
0
0
0
0
0
0
0
0
11,761
1 1 ,827
1
1
0
0
0
1
2,090
6
0
0
0
0
0
1
1
0
0
1
1
1
1
21,519
ALLOWANCES
CARRIED OVER
TO 2005
316
198
459
208
2,233
5,358
598
1
14
1 1 ,293
10
0
0
2
2
30
450
0
0
0
0
15,006
17,855
2
2
2
2
35
615
660
0
214
736
41
0
0
1
1
2
2
1
1
1
1
3,118
A, 3
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
AR
AR
AR
AR
AR
AR
AR
AR
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
PLANT NAME
White Bluff
Wrightsville Power Facility
Wrightsville Power Facility
Wrightsville Power Facility
Wrightsville Power Facility
Wrightsville Power Facility
Wrightsville Power Facility
Wrightsville Power Facility
Agua Fria Generating Station
Agua Fria Generating Station
Agua Fria Generating Station
Apache Station
Apache Station
Apache Station
Apache Station
APS Saguaro Power Plant
APS Saguaro Power Plant
APS Saguaro Power Plant
APS West Phoenix Power Plant
APS West Phoenix Power Plant
APS West Phoenix Power Plant
Bowie Power Station
Bowie Power Station
Bowie Power Station
Bowie Power Station
Cholla
Cholla
Cholla
Cholla
Coronado Generating Station
Coronado Generating Station
De Moss Petrie Generating Station
Desert Basin Generating Station
Desert Basin Generating Station
Duke Energy Arlington Valley
Duke Energy Arlington Valley
Duke Energy Arlington Valley
Duke Energy Arlington Valley
Gila Bend Power Generation Station
Gila Bend Power Generation Station
Gila Bend Power Generation Station
Gila Bend Power Generation Station
Gila River Power Station
Gila River Power Station
Gila River Power Station
PLANT
CODE
6009
55221
55221
55221
55221
55221
55221
55221
141
141
141
160
160
160
160
118
118
118
117
117
117
55780
55780
55780
55780
113
113
113
113
6177
6177
124
55129
55129
55282
55282
55282
55282
55507
55507
55507
55507
55306
55306
55306
STACK/UNIT ID*
2
G1
G2
G3
G4
G5
G6
G7
1
2
3
1
2
3
4
1
2
CT3
CC4
CC5A
CC5B
CTG1
CTG2
CTG3
CTG4
1
2
3
4
U1B
U2B
GT1
DBG1
DBG2
CTG1
CTG2
CTG3
CTG4
1
2
3
4
1CTGA
1CTGB
2CTGA
2004
ALLOWANCES
ALLOCATED
23,900
0
0
0
0
0
0
0
54
65
77
331
1,609
3,011
0
204
25
0
0
0
0
0
0
0
0
2,223
5,443
5,147
8,334
5,733
5,903
0
0
0
0
0
0
0
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
31,754
2
2
2
2
2
2
2
0
0
1
7
1,749
1,711
5
265
252
4
3
4
4
0
0
0
0
1,713
2,452
17,928
8,606
6,731
7,215
8
3
3
6
6
0
0
0
0
0
0
3
3
3
ALLOWANCES
DEDUCTED
22,979
0
0
0
0
0
0
0
0
0
1
0
1,525
1,395
1
10
7
0
0
1
1
0
0
0
0
713
951
8,928
7,650
6,731
7,215
0
3
3
2
2
0
0
0
0
0
0
2
2
2
ALLOWANCES
CARRIED OVER
TO 2005
8,775
2
2
2
2
2
2
2
0
0
0
7
224
316
4
255
245
4
3
3
3
0
0
0
0
1,000
1,501
9,000
956
0
0
8
0
0
4
4
0
0
0
0
0
0
1
1
1
A, 4
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
PLANT NAME
Gila River Power Station
Gila River Power Station
Gila River Power Station
Gila River Power Station
Gila River Power Station
Griffith Energy LLC
Griffith Energy LLC
Griffith Energy LLC
Harquahala Generating Project
Harquahala Generating Project
Harquahala Generating Project
Irvington Generating Station
Irvington Generating Station
Irvington Generating Station
Irvington Generating Station
Kyrene Generating Station
Kyrene Generating Station
Kyrene Generating Station
Mesquite Generating Station
Mesquite Generating Station
Mesquite Generating Station
Mesquite Generating Station
Navajo Generating Station
Navajo Generating Station
Navajo Generating Station
Ocotillo Power Plant
Ocotillo Power Plant
PPL Sundance Energy, LLC
PPL Sundance Energy, LLC
PPL Sundance Energy, LLC
PPL Sundance Energy, LLC
PPL Sundance Energy, LLC
PPL Sundance Energy, LLC
PPL Sundance Energy, LLC
PPL Sundance Energy, LLC
PPL Sundance Energy, LLC
PPL Sundance Energy, LLC
Redhawk Generating Facility
Redhawk Generating Facility
Redhawk Generating Facility
Redhawk Generating Facility
Santa n
Santa n
Santa n
South Point Energy Center, LLC
PLANT
CODE
55306
55306
55306
55306
55306
55124
55124
55124
55372
55372
55372
126
126
126
126
147
147
147
55481
55481
55481
55481
4941
4941
4941
116
116
55522
55522
55522
55522
55522
55522
55522
55522
55522
55522
55455
55455
55455
55455
8068
8068
8068
55177
STACK/UNIT ID*
2CTGB
3CTGA
3CTGB
4CTGA
4CTGB
P1
P2
P3
CTG1
CTG2
CTG3
1
2
3
4
K-1
K-2
K-7
1
2
5
6
1
2
3
1
2
CT01
CT02
CT03
CT04
CT05
CT06
CT07
CT08
CT09
CT10
CC1A
CC1B
CC2A
CC2B
5A
5B
6
A
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
16
28
0
2,854
7
18
0
0
0
0
0
26,220
24,262
25,042
56
132
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
3
3
3
3
3
3
3
0
1
1
1
5
3
6
3,376
0
0
2
7
7
8
8
1,345
958
1,615
17
21
2
2
2
2
2
2
2
2
2
2
6
5
6
6
0
0
0
4
ALLOWANCES
DEDUCTED
2
2
2
2
2
1
1
0
0
0
0
0
0
1
3,296
0
0
2
3
3
3
3
1,345
958
1,615
1
1
0
0
0
0
0
0
0
0
0
0
1
1
1
1
0
0
0
3
ALLOWANCES
CARRIED OVER
TO 2005
1
1
1
1
1
2
2
0
1
1
1
5
3
5
80
0
0
0
4
4
5
5
0
0
0
16
20
2
2
2
2
2
2
2
2
2
2
5
4
5
5
0
0
0
1
A, 5
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
AZ
AZ
AZ
AZ
AZ
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
PLANT NAME
South Point Energy Center, LLC
Springerville Generating Station
Springerville Generating Station
Springerville Generating Station
Yuma Axis
AES Alamitos
AES Alamitos
AES Alamitos
AES Alamitos
AES Alamitos
AES Alamitos
AES Huntington Beach
AES Huntington Beach
AES Huntington Beach
AES Huntington Beach
AES Redondo Beach
AES Redondo Beach
AES Redondo Beach
AES Redondo Beach
AES Redondo Beach
Agua Mansa Power
Almond Power Plant
Anaheim Combustion Turbine
Blythe Energy
Blythe Energy
Broadway
Cabrillo Power 1 (Encina)
Cabrillo Power 1 (Encina)
Cabrillo Power 1 (Encina)
Cabrillo Power 1 (Encina)
Cabrillo Power 1 (Encina)
Cal Peak Power - Border LLC
Cal Peak Power - Border LLC
Cal Peak Power - El Cajon LLC
Cal Peak Power - El Cajon LLC
Cal Peak Power - Enterprise LLC
Cal Peak Power - Enterprise LLC
Cal Peak Power - Panoche LLC
Cal Peak Power - Panoche LLC
Cal Peak Power - Vaca Dixon LLC
Cal Peak Power - Vaca Dixon LLC
Calpine Sutler Energy Center
Calpine Sutler Energy Center
Carson Cogeneration
Carson Cogeneration
PLANT
CODE
55177
8223
8223
8223
120
315
315
315
315
315
315
335
335
335
335
356
356
356
356
356
55951
7315
7693
55295
55295
420
302
302
302
302
302
55510
55510
55512
55512
55513
55513
55508
55508
55499
55499
55112
55112
7527
7527
STACK/UNIT ID*
B
1
2
TS3
1
1
2
3
4
5
6
1
2
3A
4A
17
5
6
7
8
AMP-1
1
1
1
2
B3
1
2
3
4
5
GT-1
GT-2
GT-1
GT-2
GT-1
GT-2
GT-1
GT-2
GT-1
GT-2
CT01
CT02
1
2
2004
ALLOWANCES
ALLOCATED
0
6,566
5,756
0
42
2,775
105
290
819
4,227
1,484
1,325
1,134
0
0
0
80
105
554
597
0
0
0
0
0
74
491
1,131
737
1,946
2,495
0
0
0
0
0
0
0
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
4
8,403
9,776
0
193
10
7
11
18
32
19
100
80
21
16
0
7
8
36
49
0
18
0
4
5
126
2
2
3
7
7
0
0
0
0
0
0
0
0
0
0
5
5
9
4
ALLOWANCES
DEDUCTED
3
8,303
9,672
0
1
1
1
2
2
4
2
3
2
1
1
0
0
0
2
2
0
0
0
1
2
0
1
1
1
4
4
0
0
0
0
0
0
0
0
0
0
4
4
2
0
ALLOWANCES
CARRIED OVER
TO 2005
1
100
104
0
192
9
6
9
16
28
17
97
78
20
15
0
7
8
34
47
0
18
0
3
3
126
1
1
2
3
3
0
0
0
0
0
0
0
0
0
0
1
1
7
4
A, 6
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
PLANT NAME
Carson Cogeneration Company
Chula Vista Power Plant
Chula Vista Power Plant
Chula Vista Power Plant
Contra Costa Power Plant
Contra Costa Power Plant
Contra Costa Power Plant
Contra Costa Power Plant
Contra Costa Power Plant
Contra Costa Power Plant
Contra Costa Power Plant
Contra Costa Power Plant
Contra Costa Power Plant
Contra Costa Power Plant
Coolwater Generating Station
Coolwater Generating Station
Coolwater Generating Station
Coolwater Generating Station
Coolwater Generating Station
Coolwater Generating Station
Cosumnes Power Plant
Cosumnes Power Plant
Creed Energy Center
Delta Energy Center, LLC
Delta Energy Center, LLC
Delta Energy Center, LLC
Donald Von Raesfeld
Donald Von Raesfeld
Duke Energy South Bay Power Plant, LLC
Duke Energy South Bay Power Plant, LLC
Duke Energy South Bay Power Plant, LLC
Duke Energy South Bay Power Plant, LLC
El Centra
El Centra
El Centra
El Segundo
El Segundo
Elk Hills Power
Elk Hills Power
Escondido Power Plant
Escondido Power Plant
Escondido Power Plant
Etiwanda Generating Station
Etiwanda Generating Station
Feather River Energy Center
PLANT
CODE
10169
55540
55540
55540
228
228
228
228
228
228
228
228
228
228
329
329
329
329
329
329
55970
55970
55625
54001
54001
54001
8058
8058
310
310
310
310
389
389
389
330
330
55400
55400
55538
55538
55538
331
331
55847
STACK/UNIT ID*
D1
CP001 (1A, 1B)
1A
1B
1
10
2
3
4
5
6
7
8
9
1
2
31
32
41
42
2
3
UNIT1
1
2
3
PCT1
PCT2
1
2
3
4
2-2
3
4
3
4
CTG-1
CTG-2
CP001 (CT1A, CT1B)
CT1A
CT1B
3
4
UNIT1
2004
ALLOWANCES
ALLOCATED
0
0
0
125
4,286
2
0
0
0
0
28
53
356
10
6
0
0
0
0
0
0
0
0
0
0
0
0
2,492
1,775
2,177
603
0
614
586
182
370
0
0
0
0
1,372
261
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
2
1
1
0
103
0
0
0
0
0
0
0
41
28
20
2
2
2
2
0
0
0
5
5
5
45
45
45
45
15
45
199
1,028
1,171
14
26
7
7
1
1
103
11
0
ALLOWANCES
DEDUCTED
1
0
0
0
2
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
4
4
4
0
0
2
2
2
1
1
0
1
0
0
4
4
0
0
0
1
0
ALLOWANCES
CARRIED OVER
TO 2005
1
1
1
0
101
0
0
0
0
0
0
0
41
28
20
2
2
1
2
0
0
0
1
1
1
45
45
43
43
13
44
198
1,028
1,170
14
26
3
3
1
1
103
10
0
A, 7
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
PLANT NAME
Fresno Cogeneration Partners, LP
Gilroy Energy Center, LLC
Gilroy Energy Center, LLC
Gilroy Energy Center, LLC
Glenarm
Glenarm
Glenarm
Glenarm
Goose Haven Energy Center
Grayson
Grayson
Grayson
Hanford Energy Park Peaker
Hanford Energy Park Peaker
Harbor Generating Station
Harbor Generating Station
Harbor Generating Station
Harbor Generating Station
Harbor Generating Station
Harbor Generating Station
Harbor Generating Station
Haynes Generating Station
Haynes Generating Station
Haynes Generating Station
Haynes Generating Station
Haynes Generating Station
Haynes Generating Station
Haynes Generating Station
Henrietta Peaker Plant
Henrietta Peaker Plant
High Desert Power Project
High Desert Power Project
High Desert Power Project
Humboldt Bay
Humboldt Bay
Hunters Point
Indigo Energy Facility
Indigo Energy Facility
Indigo Energy Facility
Kern
Kern
Kern
Kern
King City Energy Center
La Paloma Generating Plant
PLANT
CODE
10156
55810
55810
55810
422
422
422
422
55627
377
377
377
55698
55698
399
399
399
399
399
399
399
400
400
400
400
400
400
400
55807
55807
55518
55518
55518
246
246
247
55541
55541
55541
251
251
251
251
10294
55151
STACK/UNIT ID*
GEN1
S-3
S-4
S-5
16
17
GTS
GT4
UNIT1
4
5
9
HEP1
HEP2
**10A
**10B
10
11
12
13
14
1
10
2
3
5
6
9
HPP1
HPP2
CTG1
CTG2
CTG3
1
2
7
1
2
3
1
2
3
4
2
CTG-1
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
102
36
0
0
0
699
699
0
0
0
0
0
681
0
338
1,244
1,401
1,527
0
0
0
0
0
0
358
24
192
0
0
0
3
0
13
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
0
0
0
0
0
135
135
0
506
177
0
2
2
2,757
1,406
29
30
28
30
30
7,316
43
1,006
1,325
2,112
1,782
44
2
2
6
6
6
289
352
30
0
1
1
0
0
0
0
0
9
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
2
0
2
0
1
1
0
0
0
3
3
3
1
1
2
0
0
0
0
0
0
0
0
3
ALLOWANCES
CARRIED OVER
TO 2005
0
0
0
0
0
0
135
135
0
505
177
0
2
2
2,757
1,406
29
30
28
30
30
7,314
43
1,004
1,325
2,111
1,781
44
2
2
3
3
3
288
351
28
0
1
1
0
0
0
0
0
6
A, 8
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
PLANT NAME
La Paloma Generating Plant
La Paloma Generating Plant
La Paloma Generating Plant
Lake
Lambie Energy Center
Larkspur Energy Faciity
Larkspur Energy Faciity
Los Esteros Critical Energy Fac
Los Esteros Critical Energy Fac
Los Esteros Critical Energy Fac
Los Esteros Critical Energy Fac
Los Medanos Energy Center, LLC
Los Medanos Energy Center, LLC
Mandalay Generating Station
Mandalay Generating Station
Metcalf Energy Center
Metcalf Energy Center
Miramar Energy Facility
Morro Bay Power Plant, LLC
Morro Bay Power Plant, LLC
Morro Bay Power Plant, LLC
Morro Bay Power Plant, LLC
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Moss Landing
Mountainview Power Company, LLC
Mountainview Power Company, LLC
Mountainview Power Company, LLC
Mountainview Power Company, LLC
NCPA Combustion Turbine Project #2
Olive
Olive
Ormond Beach Generating Station
Ormond Beach Generating Station
PLANT
CODE
55151
55151
55151
7987
55626
55542
55542
55748
55748
55748
55748
55217
55217
345
345
55393
55393
56232
259
259
259
259
260
260
260
260
260
260
260
260
260
260
260
260
260
260
358
358
358
358
7449
6013
6013
350
350
STACK/UNIT ID*
CTG-2
CTG-3
CTG-4
01
UNIT1
1
2
CTG1
CTG2
CTG3
CTG4
X724
X725
1
2
1
2
1
1
2
3
4
1
1A
2
2A
3
3A
4
4A
5
6
6-1
7
7-1
8
3-1
3-2
4-1
4-2
NA1
01
02
1
2
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
0
0
1,379
1,291
0
0
0
1,561
139
3,822
3,053
122
0
0
0
0
0
0
0
0
0
8,924
79
976
466
0
0
0
0
0
133
25
4,520
4,586
HELD IN
ACCOUNTS AS
OF 3/1/2005
9
9
9
16
0
1
1
0
0
0
0
5
5
111
95
0
0
0
38
13
85
96
3
6
0
9
0
10
0
10
0
0
126
0
67
12
0
0
0
0
23
59
0
366
380
ALLOWANCES
DEDUCTED
3
4
4
0
0
1
1
0
0
0
0
4
4
1
1
0
0
0
0
0
1
0
0
2
0
3
0
3
0
3
0
0
1
0
2
0
0
0
0
0
0
0
0
4
3
ALLOWANCES
CARRIED OVER
TO 2005
6
5
5
16
0
0
0
0
0
0
0
1
1
110
94
0
0
0
38
13
84
96
3
4
0
6
0
7
0
7
0
0
125
0
65
12
0
0
0
0
23
59
0
362
377
A, 9
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
CA
PLANT NAME
Otay Mesa Generating Project
Otay Mesa Generating Project
Palomar Energy
Palomar Energy
Pastoria Energy Facility
Pastoria Energy Facility
Pastoria Energy Facility
Pittsburg Power Plant (CA)
Pittsburg Power Plant (CA)
Pittsburg Power Plant (CA)
Potrero Power Plant
Redding Power Plant
Ripon Generation Station
Ripon Generation Station
Riverview Energy Center
Sacramento Power Authority Cogen
SCACogen II
SCA Cogen II
SCACogen II
Scattergood Generating Station
Scattergood Generating Station
Scattergood Generating Station
Silver Gate
Silver Gate
Silver Gate
Silver Gate
Silver Gate
Silver Gate
Sunrise Power Company
Sunrise Power Company
TESLA Power Project
TESLA Power Project
TESLA Power Project
TESLA Power Project
Tracy Peaker
Tracy Peaker
Valley Gen Station
Valley Gen Station
Valley Gen Station
Walnut Energy Center
Walnut Energy Center
Wellhead Power Gates, LLC
Western Msec Project
Western Msec Project
Western Msec Project
PLANT
CODE
55345
55345
55985
55985
55656
55656
55656
271
271
271
273
7307
56135
56135
55963
7552
7551
7551
7551
404
404
404
309
309
309
309
309
309
55182
55182
55937
55937
55937
55937
55933
55933
408
408
408
4256
4256
55875
52169
52169
52169
STACK/UNIT ID*
CTG-1
CTG-2
CTG1
CTG2
CT001
CT002
CT004
5
6
7
3-1
5
1
2
1
1
1A
1B
1C
1
2
3
1
2
3
4
5
6
CTG1
CTG2
GTG1
GTG2
GTG3
GTG4
TPP1
TPP2
5
6
7
3
4
GT1
1
2
3
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
285
3,754
740
321
0
0
0
0
0
0
0
0
752
658
262
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
0
0
0
0
0
0
30
109
50
14
9
0
0
0
18
11
11
5
825
1,314
3,892
0
0
0
0
0
0
5
5
0
0
0
0
4
4
18
4
9
0
0
0
0
0
0
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
2
2
2
3
1
0
0
0
3
1
1
0
8
5
3
0
0
0
0
0
0
4
3
0
0
0
0
0
0
0
2
2
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
0
0
0
0
0
0
0
28
107
48
11
8
0
0
0
15
10
10
5
817
1,309
3,889
0
0
0
0
0
0
1
2
0
0
0
0
4
4
18
2
7
0
0
0
0
0
0
A, 10
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CA
CA
CA
CA
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
PLANT NAME
Wolfskill Energy Center
Woodland Generation Station
Woodland Generation Station
Yuba City Energy Center
Arapahoe
Arapahoe
Arapahoe Combustion Turbine
Arapahoe Combustion Turbine
Blue Spruce Energy Center
Blue Spruce Energy Center
Brush 3
Brush 4
Brush 4
Cameo
Cherokee
Cherokee
Cherokee
Cherokee
Comanche (470)
Comanche (470)
Craig
Craig
Craig
Fort St. Vrain
Fort St. Vrain
Fort St. Vrain
Fountain Valley Combustion Turbine
Fountain Valley Combustion Turbine
Fountain Valley Combustion Turbine
Fountain Valley Combustion Turbine
Fountain Valley Combustion Turbine
Fountain Valley Combustion Turbine
Frank Knutson Station
Frank Knutson Station
Front Range Power Plant
Front Range Power Plant
Hayden
Hayden
Limon Generating Station
Limon Generating Station
Manchief Station
Manchief Station
Martin Drake
Martin Drake
Martin Drake
PLANT
CODE
55855
7266
7266
10349
465
465
55200
55200
55645
55645
10682
55209
55209
468
469
469
469
469
470
470
6021
6021
6021
6112
6112
6112
55453
55453
55453
55453
55453
55453
55505
55505
55283
55283
525
525
55504
55504
55127
55127
492
492
492
STACK/UNIT ID*
UNIT1
1
2
2
3
4
CT5
CT6
CT-01
CT-02
GT2
GT4
GTS
2
1
2
3
4
1
2
C1
C2
C3
2
3
4
1
2
3
4
5
6
BR1
BR2
1
2
H1
H2
L1
L2
CT1
CT2
5
6
7
2004
ALLOWANCES
ALLOCATED
0
0
0
0
181
1,927
0
0
0
0
0
0
0
904
2,138
2,838
3,761
7,535
7,698
6,914
8,218
7,845
2,602
0
0
0
0
0
0
0
0
0
0
0
0
0
6,063
9,230
0
0
0
0
1,149
2,030
3,219
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
13
5
0
714
2,115
12
12
1
4
7
4
3
1,955
2,251
3,393
6,707
14,413
5,951
8,980
2,560
3,251
6,524
8
8
8
30
30
30
30
30
30
50
49
5
5
4,932
4,387
50
49
4
2
2,145
3,430
5,721
ALLOWANCES
DEDUCTED
0
0
1
0
678
2,024
0
0
0
3
0
0
0
1,877
2,163
1,941
664
1,679
5,368
8,582
768
1,787
1,999
3
3
3
0
0
0
0
0
0
0
0
3
3
1,225
1,391
0
0
0
0
1,460
2,445
3,773
ALLOWANCES
CARRIED OVER
TO 2005
0
13
4
0
36
91
12
12
1
1
7
4
3
78
88
1,452
6,043
12,734
583
398
1,792
1,464
4,525
5
5
5
30
30
30
30
30
30
50
49
2
2
3,707
2,996
50
49
4
2
685
985
1,948
A, 11
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
CT
PLANT NAME
Nucla
Pawnee
Rawhide Energy Station
Rawhide Energy Station
Rawhide Energy Station
Rawhide Energy Station
Rawhide Energy Station
Ray D Nixon
Ray D Nixon
Ray D Nixon
Rocky Mountain Energy Center
Rocky Mountain Energy Center
Valmont
Valmont Combustion Turbine Facility
Valmont Combustion Turbine Facility
Zuni
Zuni
Zuni
Bridgeport Energy
Bridgeport Energy
Bridgeport Harbor Station
Bridgeport Harbor Station
Bridgeport Harbor Station
Capitol District Energy Center
Devon
Devon
Devon
Devon
Devon
Devon
Devon
English Station
English Station
Lake Road Generating Company
Lake Road Generating Company
Lake Road Generating Company
Meriden Combined Cycle Facility
Meriden Combined Cycle Facility
Middletown
Middletown
Middletown
Milford Power Project
Milford Power Project
Montville
Montville
PLANT
CODE
527
6248
6761
6761
6761
6761
6761
8219
8219
8219
55835
55835
477
55207
55207
478
478
478
55042
55042
568
568
568
50498
544
544
544
544
544
544
544
569
569
55149
55149
55149
55310
55310
562
562
562
55126
55126
546
546
STACK/UNIT ID*
1
1
101
A
B
C
D
1
2
3
1
2
5
CT7
CT8
1
2
3
BE1
BE2
BHB1
BHB2
BHB3
GT
11
12
13
14
CS0001 (7, 8)
7
8
EB13
EB14
LRG1
LRG2
LRG3
1
2
2
3
4
CT01
CT02
5
6
2004
ALLOWANCES
ALLOCATED
1,122
14,443
1,800
0
0
0
0
4,477
0
0
0
0
3,137
0
0
340
0
5
0
0
2,079
4,727
1 1 ,481
0
0
0
0
0
2,808
3,003
114
157
0
0
0
0
0
1,328
3,339
2,390
0
0
1,208
5,675
HELD IN
ACCOUNTS AS
OF 3/1/2005
1,485
15,224
3,999
3
3
3
0
6,103
1
1
3
3
5,802
30
30
654
2
11
6
5
0
102
2,810
4
1
3
1
1
150
0
0
0
8
7
8
0
0
1,312
3,490
2,035
3
4
1,168
4,993
ALLOWANCES
DEDUCTED
1,314
12,550
1,012
0
0
0
0
4,964
0
0
2
2
826
0
0
1
0
0
3
3
0
77
2,790
0
0
1
0
0
102
0
0
0
2
1
2
0
0
356
378
277
3
3
93
404
ALLOWANCES
CARRIED OVER
TO 2005
171
2,674
2,987
3
3
3
0
1,139
1
1
1
1
4,976
30
30
653
2
11
3
2
0
25
20
4
1
2
1
1
48
0
0
0
6
6
6
0
0
956
3,112
1,758
0
1
1,075
4,589
A, 12
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
CT
CT
CT
CT
CT
CT
CT
CT
CT
DC
DC
DE
DE
DE
DE
DE
DE
DE
DE
DE
DE
DE
DE
DE
DE
DE
DE
DE
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
PLANT NAME
New Haven Harbor
Norwalk Harbor Station
Norwalk Harbor Station
Norwalk Harbor Station
Wallingford Energy
Wallingford Energy
Wallingford Energy
Wallingford Energy
Wallingford Energy
Benning
Benning
Delaware City Refinery
Edge Moor
Edge Moor
Edge Moor
Hay Road
Hay Road
Hay Road
Hay Road
Indian River
Indian River
Indian River
Indian River
McKee Run
NRG Energy Center Dover
NRG Energy Center Dover
Van Sant
Warren F. Sam Beasley Pwr Station
Anclote
Anclote
Arvah B Hopkins
Arvah B Hopkins
Arvah B Hopkins
Arvah B Hopkins
Auburndale Cogeneration Facility
Auburndale Cogeneration Facility
Bayside Power Station
Bayside Power Station
Bayside Power Station
Bayside Power Station
Bayside Power Station
Bayside Power Station
Bayside Power Station
Belle Glade Energy Center
Belle Glade Energy Center
PLANT
CODE
6156
548
548
548
55517
55517
55517
55517
55517
603
603
52193
593
593
593
7153
7153
7153
7153
594
594
594
594
599
10030
10030
7318
7962
8048
8048
688
688
688
688
54658
54658
7873
7873
7873
7873
7873
7873
7873
55434
55434
STACK/UNIT ID*
NHB1
CS0001 (1 , 2)
1
2
CT01
CT02
CT03
CT04
CT05
15
16
DCPP4
3
4
5
"3
5
6
7
1
2
3
4
3
2
3
**11
1
1
2
1
2
HC3
HC4
1
6
CT1A
CT1B
CT1C
CT2A
CT2B
CT2C
CT2D
1
2
2004
ALLOWANCES
ALLOCATED
13,070
5,141
5,458
0
0
0
0
0
517
856
0
3,558
6,295
6,463
158
0
0
0
2,998
3,182
5,441
13,414
2,585
0
0
138
0
13,890
13,895
81
5,524
0
0
0
0
0
0
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
1,078
0
800
50
0
0
0
0
48
113
120
2,656
5,802
1,704
8
8
8
8
4,485
3,902
8,486
8,563
925
5
5
17
8
17,490
18,165
112
1,923
0
0
4
2
3
3
3
3
3
3
3
0
0
ALLOWANCES
DEDUCTED
866
0
746
0
0
0
0
0
42
108
74
2,523
5,665
1,596
5
1
1
1
4,271
3,716
8,060
8,155
489
0
0
2
2
16,942
16,069
105
1,493
0
0
2
0
2
2
2
2
2
2
2
0
0
ALLOWANCES
CARRIED OVER
TO 2005
212
0
54
50
0
0
0
0
6
5
46
133
137
108
3
7
7
7
214
186
426
408
436
5
5
15
6
548
2,096
7
430
0
0
2
2
1
1
1
1
1
1
1
0
0
A, 13
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
PLANT NAME
Belle Glade Energy Center
Big Bend
Big Bend
Big Bend
Big Bend
Big Bend
Big Bend
Brandy Branch
Brandy Branch
Brandy Branch
Broward Energy Center
Broward Energy Center
Broward Energy Center
Broward Energy Center
Broward Energy Center
C D Mclntosh
C D Mclntosh
C D Mclntosh
C D Mclntosh
Cane Island
Cane Island
Cane Island
Cape Canaveral
Cape Canaveral
CPV Cana
CPV Gulfcoast
CPV Pierce
Crist Electric Generating Plant
Crist Electric Generating Plant
Crist Electric Generating Plant
Crist Electric Generating Plant
Crist Electric Generating Plant
Crist Electric Generating Plant
Crystal River
Crystal River
Crystal River
Crystal River
Curtis H. Stanton Energy Center
Curtis H. Stanton Energy Center
Cutler
Cutler
Debary
Debary
Debary
Debary
PLANT
CODE
55434
645
645
645
645
645
645
7846
7846
7846
55436
55436
55436
55436
55436
676
676
676
676
7238
7238
7238
609
609
55727
55613
55688
641
641
641
641
641
641
628
628
628
628
564
564
610
610
6046
6046
6046
6046
STACK/UNIT ID*
3
XS12(BB01,BB02)
BB01
BB02
XS23 (BB03, BB04)
BB03
BB04
1
2
3
1
2
3
4
5
1
2
3
5
"1
2
3
PCC1
PCC2
CT01
CT01
CT01
2
3
4
5
6
7
1
2
4
5
1
2
PCU5
PCU6
"10
**7
"8
"9
2004
ALLOWANCES
ALLOCATED
0
12,136
12,200
1 1 ,448
8,783
0
0
0
0
0
0
0
0
907
1,029
9,931
0
0
0
0
4,225
4,963
0
0
0
3
4
2,468
2,431
8,399
12,526
12,429
14,295
23,659
25,257
1 1 ,294
0
0
0
705
705
705
705
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
28,170
26,896
29,351
20,930
100
100
100
0
0
0
0
0
1,258
3,123
15,000
12
8
20
17
5,889
6,383
0
0
0
15
20
15,783
26,454
20,688
18,670
21,910
26,824
37,603
27,423
17,991
2,931
10
7
336
210
210
663
ALLOWANCES
DEDUCTED
0
2,870
2,870
3,087
3,087
26
12
17
0
0
0
0
0
1,252
82
5,521
3
0
1
3
4,887
4,762
0
0
0
0
0
3,649
3,617
9,759
15,713
18,332
23,914
26,325
25,501
4,274
2,501
0
1
63
11
9
11
ALLOWANCES
CARRIED OVER
TO 2005
0
25,300
24,026
26,264
17,843
74
88
83
0
0
0
0
0
6
3,041
9,479
9
8
19
14
1,002
1,621
0
0
0
15
20
12,134
22,837
10,929
2,957
3,578
2,910
1 1 ,278
1,922
13,717
430
10
6
273
199
201
652
A, 14
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
PLANT NAME
Deerhaven
Deerhaven
Deerhaven
Desoto County Generating Co, LLC
Desoto County Generating Co, LLC
Fort Myers
Fort Myers
Fort Myers
Fort Myers
Fort Myers
Fort Myers
Fort Myers
Fort Myers
G E Turner
G E Turner
G E Turner
Hardee Power Station
Henry D King
Henry D King
Higgins
Higgins
Higgins
Hines Energy Complex
Hines Energy Complex
Hines Energy Complex
Hines Energy Complex
Hines Energy Complex
Hines Energy Complex
Indian River (5531 8)
Indian River (5531 8)
Indian River (5531 8)
Indian River (683)
Indian River (683)
Intercession City
Intercession City
Intercession City
Intercession City
Intercession City
Intercession City
Intercession City
Intercession City
J D Kennedy
J D Kennedy
J D Kennedy
J R Kelly
PLANT
CODE
663
663
663
55422
55422
612
612
612
612
612
612
612
612
629
629
629
50949
658
658
630
630
630
7302
7302
7302
7302
7302
7302
55318
55318
55318
683
683
8049
8049
8049
8049
8049
8049
8049
8049
666
666
666
664
STACK/UNIT ID*
B1
B2
CT3
CT1
CT2
FMCT2A
FMCT2B
FMCT2C
FMCT2D
FMCT2E
FMCT2F
PFM3A
PFM3B
2
3
4
CT2B
7
8
1
2
3
1A
1B
2A
2B
3A
3B
1
2
3
**C
**D
"10
"11
"12
"13
"14
"7
"8
"9
7
8
9
CC1
2004
ALLOWANCES
ALLOCATED
98
8,271
0
0
0
0
0
0
0
0
0
0
0
543
718
611
0
63
26
423
475
969
0
0
0
0
0
0
1,192
1,569
3,647
0
639
705
0
0
0
0
705
705
705
0
196
553
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
771
8,858
2
12
17
22
21
22
21
21
21
22
18
100
100
100
41
0
0
123
153
100
14
13
14
15
0
0
494
1,883
5,271
13
2,526
10
129
12
12
11
9
10
9
100
0
0
115
ALLOWANCES
DEDUCTED
761
6,952
0
2
7
3
3
3
3
3
4
4
10
0
0
0
1
0
0
0
0
0
3
2
3
3
0
0
426
1,817
5,204
4
2
4
29
1
1
1
3
4
3
2
0
0
1
ALLOWANCES
CARRIED OVER
TO 2005
10
1,906
2
10
10
19
18
19
18
18
17
18
8
100
100
100
40
0
0
123
153
100
11
11
11
12
0
0
68
66
67
9
2,524
6
100
11
11
10
6
6
6
98
0
0
114
A, 15
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
PLANT NAME
Lansing Smith Generating Plant
Lansing Smith Generating Plant
Lansing Smith Generating Plant
Lansing Smith Generating Plant
Larsen Memorial
Larsen Memorial
Lauderdale
Lauderdale
Lauderdale
Lauderdale
Manatee
Manatee
Manatee
Manatee
Manatee
Manatee
Manatee Energy Center
Manatee Energy Center
Manatee Energy Center
Manatee Energy Center
Martin
Martin
Martin
Martin
Martin
Martin
Martin
Martin
Martin
Martin
Mulberry Cogeneration Facility
Northside
Northside
Northside
Oleander Power Project
Oleander Power Project
Oleander Power Project
Oleander Power Project
Orange Cogeneration Facility
Orange Cogeneration Facility
Orlando CoGen
Osprey Energy Center
Osprey Energy Center
P L Bartow
P L Bartow
PLANT
CODE
643
643
643
643
675
675
613
613
613
613
6042
6042
6042
6042
6042
6042
55435
55435
55435
55435
6043
6043
6043
6043
6043
6043
6043
6043
6043
6043
54426
667
667
667
55286
55286
55286
55286
54365
54365
54466
55412
55412
634
634
STACK/UNIT ID*
1
2
4
5
"8
7
4GT1
4GT2
5GT1
5GT2
MTCT3A
MTCT3B
MTCT3C
MTCT3D
PMT1
PMT2
1
2
3
4
HRSG3A
HRSG3B
HRSG4A
HRSG4B
PMR1
PMR2
PMR8A
PMR8B
PMR8C
PMR8D
1
1A
2A
3
O-1
O-2
O-3
O-4
1
2
1
CT1
CT2
1
2
2004
ALLOWANCES
ALLOCATED
6,478
7,603
0
0
665
307
948
948
948
948
0
0
0
0
13,777
12,701
0
0
0
0
1,275
1,275
1,275
1,275
5,094
6,041
0
0
0
0
0
0
0
11,126
0
0
0
0
0
0
0
0
0
2,806
2,962
HELD IN
ACCOUNTS AS
OF 3/1/2005
13,529
16,975
40
49
1,455
210
1,908
2,297
2,848
2,843
0
0
0
0
22,202
16,413
0
0
0
0
2,570
2,570
2,570
2,570
11,689
12,403
36
29
0
0
1
1,610
1,468
9,103
16
15
15
15
1
2
3
3
3
7,274
5,890
ALLOWANCES
DEDUCTED
9,709
1 1 ,404
7
8
11
0
10
3
3
8
0
0
0
0
15,399
10,882
0
0
0
0
3
4
4
4
9,478
9,909
5
5
0
0
1
1,294
1,096
8,334
5
4
3
2
1
1
2
2
2
5,383
5,790
ALLOWANCES
CARRIED OVER
TO 2005
3,820
5,571
33
41
1,444
210
1,898
2,294
2,845
2,835
0
0
0
0
6,803
5,531
0
0
0
0
2,567
2,566
2,566
2,566
2,211
2,494
31
24
0
0
0
316
372
769
11
11
12
13
0
1
1
1
1
1,891
100
A, 16
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
PLANT NAME
P L Bartow
Payne Creek Generating Station
Payne Creek Generating Station
Polk
Polk
Polk
Polk
Port Everglades
Port Everglades
Port Everglades
Port Everglades
Putnam
Putnam
Putnam
Putnam
Reedy Creek
Reliant Energy Osceola
Reliant Energy Osceola
Reliant Energy Osceola
Riviera
Riviera
Riviera
S O Purdom
S O Purdom
Sanford
Sanford
Sanford
Sanford
Sanford
Sanford
Sanford
Sanford
Sanford
Santa Rosa Energy Center
Scholz Electric Generating Plant
Scholz Electric Generating Plant
Seminole (136)
Seminole (136)
Shady Hills Generating Station
Shady Hills Generating Station
Shady Hills Generating Station
St. Johns River Power
St. Johns River Power
Stanton A
Stanton A
PLANT
CODE
634
7380
7380
7242
7242
7242
7242
617
617
617
617
6246
6246
6246
6246
7254
55192
55192
55192
619
619
619
689
689
620
620
620
620
620
620
620
620
620
55242
642
642
136
136
55414
55414
55414
207
207
55821
55821
STACK/UNIT ID*
3
1
2
"1
"2
"3
**4
PPE1
PPE2
PPE3
PPE4
HRSG11
HRSG12
HRSG21
HRSG22
32432
OSC1
OSC2
OSC3
PRV2
PRV3
PRV4
7
8
PSN3
SNCT4A
SNCT4B
SNCT4C
SNCT4D
SNCT5A
SNCT5B
SNCT5C
SNCT5D
CT-1
1
2
1
2
GT101
GT201
GT301
1
2
25
26
2004
ALLOWANCES
ALLOCATED
5,430
0
0
0
0
0
0
2,340
2,414
5,882
5,964
1,644
1,644
1,568
1,568
60
0
0
0
94
3,574
3,546
443
0
1,085
0
0
0
0
0
0
0
0
0
1,959
2,051
18,388
18,388
0
0
0
1 1 ,586
1 1 ,374
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
9,398
85
92
1,161
1
1
0
3,706
3,787
7,745
8,853
4,946
4,943
4,705
4,709
298
4
4
5
188
7,289
8,104
16
80
1,843
49
49
49
49
45
45
45
45
2
20,693
23,021
21 ,708
18,441
10
7
9
12,407
10,206
11
11
ALLOWANCES
DEDUCTED
9,053
3
2
1,161
1
1
0
3,072
3,110
6,429
7,217
1
2
2
2
0
2
2
3
0
6,068
5,808
0
2
1,083
4
4
4
4
4
4
4
4
0
1,721
1,882
14,280
12,424
7
4
6
1 1 ,905
9,770
9
9
ALLOWANCES
CARRIED OVER
TO 2005
345
82
90
0
0
0
0
634
677
1,316
1,636
4,945
4,941
4,703
4,707
298
2
2
2
188
1,221
2,296
16
78
760
45
45
45
45
41
41
41
41
2
18,972
21,139
7,428
6,017
3
3
3
502
436
2
2
A, 17
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
PLANT NAME
Suwannee River
Suwannee River
Suwannee River
Tiger Bay
Tom G Smith
Tom G Smith
Turkey Point
Turkey Point
Turkey Point
Turkey Point
Turkey Point
Turkey Point
University of Florida
Vandolah Power Project
Vandolah Power Project
Vandolah Power Project
Vandolah Power Project
Vero Beach Municipal
Vero Beach Municipal
Vero Beach Municipal
Augusta Energy Center
Augusta Energy Center
Augusta Energy Center
Baconton
Baconton
Baconton
Baconton
Bo wen
Bo wen
Bo wen
Bo wen
Chattahoochee Energy Facility
Chattahoochee Energy Facility
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Dahlberg (Jackson County)
PLANT
CODE
638
638
638
7699
673
673
621
621
621
621
621
621
7345
55415
55415
55415
55415
693
693
693
55389
55389
55389
55304
55304
55304
55304
703
703
703
703
7917
7917
7765
7765
7765
7765
7765
7765
7765
7765
7765
7765
7765
7765
STACK/UNIT ID*
1
2
3
1
S-3
S-4
PTP1
PTP2
TPCT5A
TPCT5B
TPCT5C
TPCT5D
1
GT101
GT201
GT301
GT401
"5
3
4
CT-1
CT-2
CT-3
CT1
CT4
CT5
CT6
1BLR
2BLR
3BLR
4BLR
8A
8B
1
10
11
12
13
14
15
16
2
3
4
5
2004
ALLOWANCES
ALLOCATED
254
253
649
0
9
80
5,870
5,913
0
0
0
0
0
0
0
0
0
317
315
107
0
0
0
0
0
0
0
23,617
24,288
30,942
30,934
0
0
0
0
0
0
0
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
1,506
1,460
1,012
14
316
0
8,542
7,760
0
0
0
0
11
10
9
9
9
1,583
1,555
492
0
0
0
0
0
0
0
67,178
39,578
51,173
43,355
2
2
4
5
0
0
0
0
0
0
4
4
4
4
ALLOWANCES
DEDUCTED
1,106
1,360
877
3
0
0
6,375
6,459
0
0
0
0
1
4
4
4
2
0
1
1
0
0
0
0
0
0
0
34,447
38,494
50,603
42,370
1
1
0
0
0
0
0
0
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
400
100
135
11
316
0
2,167
1,301
0
0
0
0
10
6
5
5
7
1,583
1,554
491
0
0
0
0
0
0
0
32,731
1,084
570
985
1
1
4
5
0
0
0
0
0
0
4
4
4
4
A, 18
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
PLANT NAME
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Dahlberg (Jackson County)
Doyle Generating Facility
Doyle Generating Facility
Doyle Generating Facility
Doyle Generating Facility
Doyle Generating Facility
Duke Energy Murray, LLC
Duke Energy Murray, LLC
Duke Energy Murray, LLC
Duke Energy Murray, LLC
Effingham County Power, LLC
Effingham County Power, LLC
Genpower - Mclntosh
Genpower - Mclntosh
Georgia Energy Project 1 , LLC
Georgia Energy Project 1 , LLC
Hammond
Hammond
Hammond
Hammond
Hammond
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Hartwell Energy Facility
Hartwell Energy Facility
Heard County Power, LLC
Heard County Power, LLC
Heard County Power, LLC
Jack McDonough
Jack McDonough
Jack McDonough
KGen Sandersville LLC
KGen Sandersville LLC
KGen Sandersville LLC
KGen Sandersville LLC
KGen Sandersville LLC
KGen Sandersville LLC
KGen Sandersville LLC
PLANT
CODE
7765
7765
7765
7765
55244
55244
55244
55244
55244
55382
55382
55382
55382
55406
55406
55632
55632
55827
55827
708
708
708
708
708
709
709
709
709
709
709
70454
70454
55141
55141
55141
710
710
710
55672
55672
55672
55672
55672
55672
55672
STACK/UNIT ID*
6
7
8
9
CTG-1
CTG-2
CTG-3
CTG-4
CTG-5
CCCT1
CCCT2
CCCT3
CCCT4
1
2
GT1
GT2
TB1
TB2
CS001 (1 , 2, 3)
1
2
3
4
CS001 (1 , 2)
1
2
CS002 (3, 4)
3
4
MAG1
MAG2
CT1
CT2
CT3
CS001 (MB1, MB2)
MB1
MB2
CT1
CT2
CT3
CT4
CT5
CT6
CT7
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
3,786
3,975
3,842
16,232
9,859
1 1 ,661
16,044
15,921
0
0
0
0
0
8,584
8,885
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
4
5
4
5
10
10
10
10
10
3
3
3
4
15
15
0
0
0
0
18,869
21,097
19,529
80,742
22,556
45,136
22,468
22,662
3
2
0
0
0
28,104
32,296
1
1
1
1
1
1
1
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
0
1
1
1
1
1
1
0
0
0
0
4,837
4,837
4,836
23,186
13,387
13,387
21,681
21,681
1
0
0
0
0
1 1 ,358
1 1 ,358
0
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
4
5
4
5
10
10
10
10
10
2
2
2
3
14
14
0
0
0
0
14,032
16,260
14,693
57,556
9,169
31 ,749
787
981
2
2
0
0
0
16,746
20,938
1
1
1
1
1
1
1
A, 19
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
PLANT NAME
KGen Sandersville LLC
Kraft
Kraft
Kraft
Kraft
Kraft
Live Oaks Power Plant
Live Oaks Power Plant
Mclntosh(6124)
Mclntosh(6124)
Mclntosh(6124)
Mclntosh(6124)
Mclntosh(6124)
Mclntosh(6124)
Mclntosh(6124)
Mclntosh(6124)
Mclntosh(6124)
McManus
McManus
Mid-Georgia Cogeneration
Mid-Georgia Cogeneration
Mirant West Georgia Generating Co.
Mirant West Georgia Generating Co.
Mirant West Georgia Generating Co.
Mirant West Georgia Generating Co.
Mitchell (GA)
MPC Generating, LLC
MPC Generating, LLC
Peace Valley Generation Company, LLC
Peace Valley Generation Company, LLC
Peace Valley Generation Company, LLC
Peace Valley Generation Company, LLC
Peace Valley Generation Company, LLC
Peace Valley Generation Company, LLC
Riverside (734)
Robins
Robins
Rome Linerboard Mill
Rome Linerboard Mill
Scherer
Scherer
Scherer
Scherer
Sewell Creek Energy
Sewell Creek Energy
PLANT
CODE
55672
733
733
733
733
733
55800
55800
6124
6124
6124
6124
6124
6124
6124
6124
6124
715
715
55040
55040
55267
55267
55267
55267
727
7764
7764
55993
55993
55993
55993
55993
55993
734
7348
7348
10426
10426
6257
6257
6257
6257
7813
7813
STACK/UNIT ID*
CT8
CS001 (1 , 2, 3, 4)
1
2
3
4
CTG1
CTG2
1
CT1
CT2
CT3
CT4
CT5
CT6
CT7
CT8
1
2
1
2
1
2
3
4
3
1
2
CTG-1
CTG-2
CTG-3
CTG-4
CTG-5
CTG-6
12
CT1
CT2
CT1
CT2
1
2
3
4
1
2
2004
ALLOWANCES
ALLOCATED
0
1,530
1,510
2,964
436
0
0
5,556
0
0
0
0
0
0
0
0
844
1,279
0
0
0
0
0
0
5,463
0
0
0
0
0
0
0
0
5
0
0
0
0
21 ,083
21 ,232
21 ,266
21 ,242
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
1
2,127
2,087
4,640
0
0
0
8,349
22
31
30
34
29
28
33
32
2,152
3,085
4
7
2
1
1
1
38,495
15
15
0
0
0
0
0
0
0
6
6
0
0
22,828
20,984
22,245
20,782
2
2
ALLOWANCES
DEDUCTED
0
2,009
1,969
4,153
0
0
0
8,019
1
2
1
1
0
1
1
1
80
256
0
0
0
0
0
0
5,169
0
0
0
0
0
0
0
0
0
2
1
0
0
19,909
20,534
20,145
19,156
0
0
ALLOWANCES
CARRIED OVER
TO 2005
1
118
118
487
0
0
0
330
21
29
29
33
29
27
32
31
2,072
2,829
4
7
2
1
1
1
33,326
15
15
0
0
0
0
0
0
0
4
5
0
0
2,919
450
2,100
1,626
2
2
A, 20
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
PLANT NAME
Sewell Creek Energy
Sewell Creek Energy
Smarr Energy Facility
Smarr Energy Facility
Sowega Power Project
Sowega Power Project
Talbot Energy Facility
Talbot Energy Facility
Talbot Energy Facility
Talbot Energy Facility
Talbot Energy Facility
Talbot Energy Facility
Tenaska Georgia Generating Station
Tenaska Georgia Generating Station
Tenaska Georgia Generating Station
Tenaska Georgia Generating Station
Tenaska Georgia Generating Station
Tenaska Georgia Generating Station
W R Clayton Plant
W R Clayton Plant
W R Clayton Plant
Walton County Power, LLC
Walton County Power, LLC
Walton County Power, LLC
Wansley (6052)
Wansley (6052)
Wansley (6052)
Wansley (6052)
Wansley (6052)
Wansley (6052)
Wansley (7946)
Wansley (7946)
Washington County Power, LLC
Washington County Power, LLC
Washington County Power, LLC
Washington County Power, LLC
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yates
PLANT
CODE
7813
7813
7829
7829
7768
7768
7916
7916
7916
7916
7916
7916
55061
55061
55061
55061
55061
55061
7968
7968
7968
55128
55128
55128
6052
6052
6052
6052
6052
6052
7946
7946
55332
55332
55332
55332
728
728
728
728
728
728
728
728
728
STACK/UNIT ID*
3
4
1
2
CT2
CT3
1
2
3
4
5
6
CT1
CT2
CT3
CT4
CT5
CT6
CT1
CT2
CT3
T1
T2
T3
1
2
6A
6B
7A
7B
CT9A
CT9B
T1
T2
T3
T4
Y1BR
CS001 (Y2BR, Y3BR)
Y2BR
Y3BR
CS002 (Y4BR, Y5BR)
Y4BR
Y5BR
Y6BR
Y7BR
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
30,517
28,211
0
0
0
0
0
0
0
0
0
0
3,107
3,036
2,998
3,843
4,056
10,678
10,502
HELD IN
ACCOUNTS AS
OF 3/1/2005
2
2
2
2
0
0
2
2
2
2
19
19
1
2
1
0
1
0
0
0
0
15
15
15
104,415
88,517
2
2
2
2
1
1
5
5
5
5
46,518
18,742
18,199
22,696
25,706
61,470
50,690
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
0
0
1
1
0
0
0
0
0
0
0
0
0
0
0
0
50,769
48,206
1
1
1
1
1
1
0
0
0
0
384
4,896
4,896
7,088
7,087
15,132
11,068
ALLOWANCES
CARRIED OVER
TO 2005
2
2
2
2
0
0
2
2
2
2
18
18
1
2
1
0
1
0
0
0
0
15
15
15
53,646
40,311
1
1
1
1
0
0
5
5
5
5
46,134
13,846
13,303
15,608
18,619
46,338
39,622
A, 21
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
PLANT NAME
Ames
Ames
Burlington (IA)
Council Bluffs
Council Bluffs
Council Bluffs
Dayton Avenue Substation
Dubuque
Dubuque
Dubuque
Earl F Wisdom
Earl F Wisdom
Emery Station
Emery Station
Exira Station
Exira Station
Fair Station
George Neal North
George Neal North
George Neal North
George Neal South
Greater Des Moines Energy Center
Greater Des Moines Energy Center
Hawkeye Generating
Hawkeye Generating
Lansing
Lansing
Lansing
Lansing
Lansing
Lime Creek
Lime Creek
Louisa
Milton L Kapp
Muscatine
Muscatine
Ottumwa
Pella
Pella
Pella
Pella
Pleasant Hill Energy Center
Prairie Creek
Prairie Creek
Riverside (1081)
PLANT
CODE
1122
1122
1104
1082
1082
1082
6463
1046
1046
1046
1217
1217
8031
8031
56013
56013
1218
1091
1091
1091
7343
7985
7985
55725
55725
1047
1047
1047
1047
1047
7155
7155
6664
1048
1167
1167
6254
1175
1175
1175
1175
7145
1073
1073
1081
STACK/UNIT ID*
7
8
1
1
2
3
GT2
1
5
6
1
2
11
12
U-1
U-2
2
1
2
3
4
1
2
CTG1
CTG2
CS1 (1,2)
1
2
3
4
"1
**2
101
2
8
9
1
CS67 (6, 7)
6
7
8
3
3
4
9
2004
ALLOWANCES
ALLOCATED
403
1,834
4,499
1,110
1,651
15,956
0
1,120
305
0
379
0
0
0
0
0
5,575
2,310
9,082
12,296
15,144
0
0
0
0
0
0
478
4,629
255
255
15,593
5,795
1,362
2,027
19,095
757
978
68
0
725
3,434
1,745
HELD IN
ACCOUNTS AS
OF 3/1/2005
720
1,867
15,700
1,307
1,769
14,212
0
1,300
736
139
1,092
3
13
12
10
10
7,101
4,263
6,820
12,462
17,975
10
15
0
0
89
112
961
5,497
1,222
1,226
17,016
37,512
4,520
5,026
20,840
1,366
2,593
340
25
1,352
16,481
3,320
ALLOWANCES
DEDUCTED
196
792
4,634
1,253
1,635
12,653
0
950
646
129
818
0
3
2
1
1
7,085
3,568
6,093
1 1 ,459
14,950
0
0
0
0
32
68
890
4,633
10
7
16,725
4,973
2,527
547
16,093
285
285
0
1
1,298
3,100
3,086
ALLOWANCES
CARRIED OVER
TO 2005
524
1,075
1 1 ,066
54
134
1,559
0
350
90
10
274
3
10
10
9
9
16
695
727
1,003
3,025
10
15
0
0
57
44
71
864
1,212
1,219
291
32,539
1,993
4,479
4,747
1,081
2,308
340
24
54
13,381
234
A, 22
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IA
IA
IA
IA
IA
IA
IA
IA
ID
ID
ID
ID
ID
ID
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
PLANT NAME
Sixth Street
Sixth Street
Sixth Street
Sixth Street
Streeter Station
Sutherland
Sutherland
Sutherland
Bennett Mountain Power Project
Mountain Home Generation Station
Mountain Home Generation Station
Rathdrum Combustion Turbine Project
Rathdrum Combustion Turbine Project
Rathdrum Power, LLC
Baldwin Energy Complex
Baldwin Energy Complex
Baldwin Energy Complex
Calumet Energy Team
Calumet Energy Team
Coffeen
Coffeen
Coffeen
Collins Station
Collins Station
Collins Station
Collins Station
Collins Station
Collins Station
Collins Station
Cordova Energy Center
Cordova Energy Center
Crawford
Crawford
Crete Energy Park
Crete Energy Park
Crete Energy Park
Crete Energy Park
Dallman
Dallman
Dallman
Dallman
Duck Creek
E D Edwards
E D Edwards
E D Edwards
PLANT
CODE
1058
1058
1058
1058
1131
1077
1077
1077
55733
7953
7953
7456
7456
55179
889
889
889
55296
55296
861
861
861
6025
6025
6025
6025
6025
6025
6025
55188
55188
867
867
55253
55253
55253
55253
963
963
963
963
6016
856
856
856
STACK/UNIT ID*
2
3
4
5
7
1
2
3
CT01
CT2
CT3
1
2
CTGEN1
1
2
3
**1
**2
CS0001 (01 , 02)
01
02
031230(1,2,3)
1
2
3
CS0405 (4, 5)
4
5
1
2
7
8
GT1
GT2
GTS
GT4
033132(31,32)
31
32
33
1
1
2
3
2004
ALLOWANCES
ALLOCATED
177
154
77
308
554
199
376
2,191
0
0
0
0
0
0
18,116
19,154
18,350
0
0
5,085
15,381
1,327
1,133
2,001
1,633
1,810
0
0
7,236
9,850
0
0
0
0
1,385
1,568
5,199
1 1 ,201
2,899
6,916
9,125
HELD IN
ACCOUNTS AS
OF 3/1/2005
297
244
449
838
1,850
928
906
2,362
0
250
250
0
0
5
10,108
9,726
1 1 ,246
5
5
16,164
31,108
695
698
698
0
0
8
9
4,255
5,199
0
0
0
0
1,832
2,129
5,624
10,079
10,695
7,693
23,902
ALLOWANCES
DEDUCTED
242
220
405
791
1,712
835
865
2,302
0
0
0
0
0
3
8,788
8,456
9,777
0
0
15,736
30,629
675
675
675
0
0
0
1
4,090
5,047
0
0
0
0
772
772
2,322
9,999
10,617
7,616
23,826
ALLOWANCES
CARRIED OVER
TO 2005
55
24
44
47
138
93
41
60
0
250
250
0
0
2
1,320
1,270
1,469
5
5
428
479
20
23
23
0
0
8
8
165
152
0
0
0
0
1,060
1,357
3,302
80
78
77
76
A, 23
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
PLANT NAME
Elgin Energy Center
Elgin Energy Center
Elgin Energy Center
Elgin Energy Center
Elwood Energy Facility
Elwood Energy Facility
Elwood Energy Facility
Elwood Energy Facility
Elwood Energy Facility
Elwood Energy Facility
Elwood Energy Facility
Elwood Energy Facility
Elwood Energy Facility
Fisk
Freedom Power Project
Gibson City Power Plant
Gibson City Power Plant
Goose Creek Energy Center
Goose Creek Energy Center
Goose Creek Energy Center
Goose Creek Energy Center
Goose Creek Energy Center
Goose Creek Energy Center
Grand Tower
Grand Tower
Havana
Havana
Havana
Havana
Havana
Havana
Havana
Havana
Havana
Hennepin Power Station
Hennepin Power Station
Hennepin Power Station
Holland Energy Facility
Holland Energy Facility
Hutsonville
Hutsonville
Indeck-Elwood Energy Center
Indeck-Elwood Energy Center
Interstate
Joliet 29
PLANT
CODE
55438
55438
55438
55438
55199
55199
55199
55199
55199
55199
55199
55199
55199
886
7842
55201
55201
55496
55496
55496
55496
55496
55496
862
862
891
891
891
891
891
891
891
891
891
892
892
892
55334
55334
863
863
55823
55823
7425
384
STACK/UNIT ID*
CT01
CT02
CT03
CT04
1
2
3
4
5
6
7
8
9
19
CT1
GCTG1
GCTG2
CT-01
CT-02
CT-03
CT-04
CT-05
CT-06
CT01
CT02
1
2
3
4
5
6
7
8
9
CSS (1 , 2)
1
2
CTG1
CTG2
05
06
1
2
1
CS7172(71,72)
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
0
0
10,032
0
0
0
0
0
0
0
0
0
0
0
35
45
35
35
35
35
35
35
8,805
2,018
7,940
0
0
2,223
2,302
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
5
5
5
5
25
25
25
25
25
25
25
25
25
5,316
0
13
12
2
2
2
2
2
2
512
511
38
48
38
37
38
37
38
38
10,168
1,290
4,211
3
3
7,126
8,016
0
0
4
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
0
0
0
0
0
5,137
0
0
0
0
0
0
0
0
0
0
0
0
0
1
2
2
7
2
1
8,555
1,042
3,490
0
0
6,588
7,552
0
0
1
ALLOWANCES
CARRIED OVER
TO 2005
5
5
5
5
25
25
25
25
25
25
25
25
25
179
0
13
12
2
2
2
2
2
2
512
511
38
48
37
35
36
30
36
37
1,613
248
721
3
3
538
464
0
0
3
A, 24
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
PLANT NAME
Joliet 29
Joliet 29
Joliet 29
Joliet 29
Joliet 29
Joliet 9
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Kendall County Generating Facility
Kendall County Generating Facility
Kendall County Generating Facility
Kendall County Generating Facility
Kincaid Station
Kincaid Station
Kincaid Station
Kinmundy Power Plant
Kinmundy Power Plant
Lakeside
Lakeside
Lakeside
Lee Energy Facility
Lee Energy Facility
Lee Energy Facility
Lee Energy Facility
Lee Energy Facility
Lee Energy Facility
Lee Energy Facility
Lee Energy Facility
Lincoln Generating Facility
Lincoln Generating Facility
Lincoln Generating Facility
Lincoln Generating Facility
Lincoln Generating Facility
Lincoln Generating Facility
Lincoln Generating Facility
Lincoln Generating Facility
Marion
Marion
PLANT
CODE
384
384
384
384
384
874
887
887
887
887
887
887
887
887
887
55131
55131
55131
55131
876
876
876
55204
55204
964
964
964
55236
55236
55236
55236
55236
55236
55236
55236
55222
55222
55222
55222
55222
55222
55222
55222
976
976
STACK/UNIT ID*
71
72
CS8182(81,82)
81
82
5
CS1 (1,2)
1
2
CS2 (3, 4)
3
4
CSS (5, 6)
5
6
GTG-1
GTG-2
GTG-3
GTG-4
CS0102(1,2)
1
2
KCTG1
KCTG2
CS0078 (7, 8)
7
8
CT1
CT2
CT3
CT4
CT5
CT6
CT7
CT8
CTG-1
CTG-2
CTG-3
CTG-4
CTG-5
CTG-6
CTG-7
CTG-8
123
4
2004
ALLOWANCES
ALLOCATED
7,580
6,177
7,296
7,558
8,676
5,288
4,523
5,153
4,773
4,795
4,460
0
0
0
0
13,596
14,982
0
0
2,554
1,446
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
6,841
HELD IN
ACCOUNTS AS
OF 3/1/2005
4,331
4,331
4,063
4,063
5,033
4,725
4,721
4,616
4,605
4,739
4,731
1
1
1
2
11,071
1 1 ,074
10
10
3,325
3,325
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
6,547
9,377
ALLOWANCES
DEDUCTED
4,181
4,181
3,942
3,941
4,853
4,706
4,707
4,599
4,599
4,718
4,719
0
0
0
0
10,984
10,984
0
0
3,021
3,021
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
3,828
5,624
ALLOWANCES
CARRIED OVER
TO 2005
150
150
121
122
180
19
14
17
6
21
12
1
1
1
2
87
90
10
10
304
304
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2,719
3,753
A, 25
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
PLANT NAME
Marion
Marion
MEP Flora Power
MEP Flora Power
MEP Flora Power
MEP Flora Power
MEPI Gt Facility
MEPI Gt Facility
MEPI Gt Facility
MEPI Gt Facility
MEPI Gt Facility
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Nelson Energy Center
Nelson Energy Center
Nelson Energy Center
Nelson Energy Center
New Heights Recovery & Power
Newton
Newton
Nrg Bourbonnais Energy Center
Nrg Bourbonnais Energy Center
Nrg Bourbonnais Energy Center
Nrg Bourbonnais Energy Center
NRG Rockford Energy Center
NRG Rockford Energy Center
NRG Rockford II Energy Center
Pinckneyville Power Plant
Pinckneyville Power Plant
Pinckneyville Power Plant
Pinckneyville Power Plant
Pinckneyville Power Plant
Pinckneyville Power Plant
Pinckneyville Power Plant
Pinckneyville Power Plant
Powerton
Powerton
Powerton
Powerton
Powerton
PLANT
CODE
976
976
55417
55417
55417
55417
7858
7858
7858
7858
7858
864
864
864
864
864
864
864
55183
55183
55183
55183
55174
6017
6017
55330
55330
55330
55330
55238
55238
55936
55202
55202
55202
55202
55202
55202
55202
55202
879
879
879
879
879
STACK/UNIT ID*
5
6
CT-01
CT-02
CT-03
CT-04
1
2
3
4
5
CS0001 (01 , 02, 03, 04)
01
02
03
04
05
06
1
2
3
4
1
1
2
1
2
3
4
0001
0002
U1
CT01
CT02
CT03
CT04
CT05
CT06
CT07
CT08
CS0506 (51 , 52, 61 , 62)
51
52
61
62
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
298
322
280
255
5,991
46
0
0
0
0
0
15,625
13,932
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
10,704
10,574
10,516
10,599
HELD IN
ACCOUNTS AS
OF 3/1/2005
1,258
627
2
2
2
2
5
5
5
5
5
2,514
2,925
2,745
3,240
3,340
241
0
0
0
0
12
9,101
9,505
0
0
0
0
26
27
1
5
5
5
5
5
5
5
5
6,096
6,096
6,050
6,050
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
0
0
0
2,008
2,457
2,251
2,713
2,864
7
0
0
0
0
0
8,655
9,072
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
5,862
5,862
5,862
5,863
ALLOWANCES
CARRIED OVER
TO 2005
1,258
627
2
2
2
2
5
5
5
5
5
506
468
494
527
476
234
0
0
0
0
12
446
433
0
0
0
0
26
27
1
5
5
5
5
5
5
5
5
234
234
188
187
A, 26
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
PLANT NAME
PPL University Park Power Project
PPL University Park Power Project
PPL University Park Power Project
PPL University Park Power Project
PPL University Park Power Project
PPL University Park Power Project
PPL University Park Power Project
PPL University Park Power Project
PPL University Park Power Project
PPL University Park Power Project
PPL University Park Power Project
PPL University Park Power Project
Reliant Energy - Aurora
Reliant Energy - Aurora
Reliant Energy - Aurora
Reliant Energy - Aurora
Reliant Energy - Aurora
Reliant Energy - Aurora
Reliant Energy - Aurora
Reliant Energy - Aurora
Reliant Energy - Aurora
Reliant Energy - Aurora
Reliant Energy Shelby County
Reliant Energy Shelby County
Reliant Energy Shelby County
Reliant Energy Shelby County
Reliant Energy Shelby County
Reliant Energy Shelby County
Reliant Energy Shelby County
Reliant Energy Shelby County
Rocky Road Power, LLC
Rocky Road Power, LLC
Rocky Road Power, LLC
Rocky Road Power, LLC
Southeast Chicago Energy Project
Southeast Chicago Energy Project
Southeast Chicago Energy Project
Southeast Chicago Energy Project
Southeast Chicago Energy Project
Southeast Chicago Energy Project
Southeast Chicago Energy Project
Southeast Chicago Energy Project
Tilton Power Station
Tilton Power Station
Tilton Power Station
PLANT
CODE
55640
55640
55640
55640
55640
55640
55640
55640
55640
55640
55640
55640
55279
55279
55279
55279
55279
55279
55279
55279
55279
55279
55237
55237
55237
55237
55237
55237
55237
55237
55109
55109
55109
55109
55281
55281
55281
55281
55281
55281
55281
55281
7760
7760
7760
STACK/UNIT ID*
CT01
CT02
CT03
CT04
CT05
CT06
CT07
CT08
CT09
CT10
CT11
CT12
AGS01
AGS02
AGS03
AGS04
AGS05
AGS06
AGS07
AGS08
AGS09
AGS10
SCE1
SCE2
SCE3
SCE4
SCE5
SCE6
SCE7
SCE8
T1
T2
T3
T4
CTG10
CTG11
CTG12
CTG5
CTG6
CTG7
CTG8
CTG9
1
2
3
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
2
2
2
2
2
2
2
2
2
2
2
2
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
0
0
0
0
50
50
50
50
50
50
50
50
3
3
3
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
2
2
2
2
2
2
2
2
2
2
2
2
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
0
0
0
0
50
50
50
50
50
50
50
50
3
3
3
A, 27
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IN
IN
IN
IN
IN
IN
IN
IN
IN
PLANT NAME
Tilton Power Station
University Park Energy
University Park Energy
University Park Energy
University Park Energy
University Park Energy
University Park Energy
University Park Energy
University Park Energy
University Park Energy
University Park Energy
University Park Energy
University Park Energy
Venice
Venice
Venice
Venice
Venice
Vermilion Power Station
Vermilion Power Station
Vermilion Power Station
Waukegan
Waukegan
Waukegan
Will County
Will County
Will County
Will County
Wood River Power Station
Wood River Power Station
Wood River Power Station
Wood River Power Station
Wood River Power Station
Zion Energy Center
Zion Energy Center
Zion Energy Center
A B Brown Generating Station
A B Brown Generating Station
A B Brown Generating Station
A B Brown Generating Station
Anderson
Anderson
Anderson
Bailly Generating Station
Bailly Generating Station
PLANT
CODE
7760
55250
55250
55250
55250
55250
55250
55250
55250
55250
55250
55250
55250
913
913
913
913
913
897
897
897
883
883
883
884
884
884
884
898
898
898
898
898
55392
55392
55392
6137
6137
6137
6137
7336
7336
7336
995
995
STACK/UNIT ID*
4
UP1
UP10
UP11
UP12
UP2
UPS
UP4
UPS
UP6
UP7
UPS
UP9
CT03
CT04
CT05
CT2A
CT2B
CSS (1 , 2)
1
2
17
7
8
1
2
3
4
1
2
3
4
5
CT-1
CT-2
CT-3
1
2
3
4
ACT1
ACT2
ACTS
XS12(7, 8)
7
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
2,835
3,831
3,104
8,214
7,840
5,322
4,850
6,995
13,804
3
3
3
2,259
9,481
0
0
0
5,358
4,530
639
0
0
0
0
4,812
HELD IN
ACCOUNTS AS
OF 3/1/2005
3
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
5
5
7,332
9,975
1,976
7,257
5,822
555
560
5,493
9,251
6
12
12
2,346
4,816
0
0
0
6,045
12,183
3,087
5
4
4
5
1,904
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
6,319
8,727
1,893
7,037
5,615
209
293
5,251
8,963
0
0
0
1,547
4,105
0
0
0
5,157
3,077
0
0
0
0
0
1,804
ALLOWANCES
CARRIED OVER
TO 2005
3
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
5
5
1,013
1,248
83
220
207
346
267
242
288
6
12
12
799
711
0
0
0
888
9,106
3,087
5
4
4
5
100
A, 28
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
PLANT NAME
Bailly Generating Station
C. C. Perry K Steam Plant1
Cayuga
Cayuga
Cayuga
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Dean H Mitchell Generating Station
Dean H Mitchell Generating Station
Dean H Mitchell Generating Station
Dean H Mitchell Generating Station
Dean H Mitchell Generating Station
Dean H Mitchell Generating Station
Edwardsport
Edwardsport
Edwardsport
Edwardsport
F B Culley Generating Station
F B Culley Generating Station
F B Culley Generating Station
F B Culley Generating Station
Frank E Ratts
Frank E Ratts
Georgetown Substation
Georgetown Substation
Georgetown Substation
Georgetown Substation
Gibson
Gibson
Gibson
Gibson
Gibson
Gibson
Gibson
Harding Street Station (EW Stout)
Harding Street Station (EW Stout)
Harding Street Station (EW Stout)
Harding Street Station (EW Stout)
Harding Street Station (EW Stout)
PLANT
CODE
995
992
1001
1001
1001
983
983
983
983
983
983
983
983
996
996
996
996
996
996
1004
1004
1004
1004
1012
1012
1012
1012
1043
1043
7759
7759
7759
7759
6113
6113
6113
6113
6113
6113
6113
990
990
990
990
990
STACK/UNIT ID*
8
11
1
2
4
CS001 (1 , 2, 3)
1
2
3
CS002 (4, 5, 6)
4
5
6
11
CS45 (4, 5)
4
5
CS611 (6, 11)
6
6-1
7-1
7-2
8-1
1
XS23 (2, 3)
2
3
1SG1
2SG1
GT1
GT2
GTS
GT4
CS0003 (1 , 2)
1
2
XS34 (3, 4)
3
4
5
10
50
60
70
9
2004
ALLOWANCES
ALLOCATED
6,871
1,796
14,390
14,715
0
8,465
8,324
8,573
8,434
8,132
8,560
2,658
3,116
3,018
2,970
0
347
354
375
827
1,759
7,318
3,593
3,660
0
0
0
0
17,420
17,683
17,714
17,389
18,187
2
1,674
2,058
10,180
1
HELD IN
ACCOUNTS AS
OF 3/1/2005
1,904
367
38,777
35,559
4
9,632
9,632
9,632
9,080
9,080
9,080
0
0
0
0
2
3,687
3,912
3,645
3,118
6,138
8,270
10,383
10,247
0
0
0
0
43,109
48,533
56,322
9,614
18,976
4
9,308
7,645
29,955
3
ALLOWANCES
DEDUCTED
1,805
361
36,930
33,866
0
9,132
9,132
9,132
8,580
8,580
8,580
0
0
0
0
0
3,511
3,726
3,471
2,967
1,310
1,310
8,930
9,322
0
0
0
0
41 ,056
46,222
53,640
9,156
14,047
0
8,125
7,421
29,235
0
ALLOWANCES
CARRIED OVER
TO 2005
99
6
1,847
1,693
4
500
500
500
500
500
500
0
0
0
0
2
176
186
174
151
4,828
6,960
1,453
925
0
0
0
0
2,053
2,311
2,682
458
4,929
4
1,183
224
720
3
A, 29
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
PLANT NAME
Harding Street Station (EW Stout)
Harding Street Station (EW Stout)
Harding Street Station (EW Stout)
Henry County Generating Station
Henry County Generating Station
Henry County Generating Station
Hoosier Energy Lawrence Co Station
Hoosier Energy Lawrence Co Station
Hoosier Energy Lawrence Co Station
Hoosier Energy Lawrence Co Station
Hoosier Energy Lawrence Co Station
Hoosier Energy Lawrence Co Station
IPL Eagle Valley Generating Station
IPL Eagle Valley Generating Station
IPL Eagle Valley Generating Station
IPL Eagle Valley Generating Station
IPL Eagle Valley Generating Station
IPL Eagle Valley Generating Station
IPL Eagle Valley Generating Station
IPL Eagle Valley Generating Station
Merom
Merom
Michigan City Generating Station
Michigan City Generating Station
Michigan City Generating Station
Michigan City Generating Station
Mirant Sugar Creek, LLC
Mirant Sugar Creek, LLC
Mirant Sugar Creek, LLC
Mirant Sugar Creek, LLC
Montpelier Electric Gen Station
Montpelier Electric Gen Station
Montpelier Electric Gen Station
Montpelier Electric Gen Station
Montpelier Electric Gen Station
Montpelier Electric Gen Station
Montpelier Electric Gen Station
Montpelier Electric Gen Station
Noblesville
Noblesville
Noblesville
Petersburg
Petersburg
Petersburg
Petersburg
PLANT
CODE
990
990
990
7763
7763
7763
7948
7948
7948
7948
7948
7948
991
991
991
991
991
991
991
991
6213
6213
997
997
997
997
55364
55364
55364
55364
55229
55229
55229
55229
55229
55229
55229
55229
1007
1007
1007
994
994
994
994
STACK/UNIT ID*
GT4
GTS
GT6
1
2
3
1
2
3
4
5
6
1
2
CS592 (3, 4)
3
4
CS596 (5, 6)
5
6
1SG1
2SG1
12
4
5
6
CT11
CT12
CT21
CT22
G1CT1
G1CT2
G2CT1
G2CT2
G3CT1
G3CT2
G4CT1
G4CT2
CT3
CT4
CT5
1
2
3
4
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
0
0
1
240
533
596
2,488
14,925
14,823
10,052
909
1,010
1,019
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
7,088
13,965
16,886
16,155
HELD IN
ACCOUNTS AS
OF 3/1/2005
10
10
10
2
2
2
0
0
0
0
0
0
7
4
3,129
3,854
4,538
6,082
10,906
10,141
14,977
0
0
0
2
2
0
0
0
0
0
0
0
0
0
0
4
4
4
2,088
2,965
18,744
20,005
ALLOWANCES
DEDUCTED
1
1
0
0
0
0
0
0
0
0
0
0
1
1
3,038
3,712
4,404
5,605
6,499
9,157
14,877
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
912
1,928
17,677
18,222
ALLOWANCES
CARRIED OVER
TO 2005
9
9
10
2
2
2
0
0
0
0
0
0
6
3
91
142
134
477
4,407
984
100
0
0
0
2
2
0
0
0
0
0
0
0
0
0
0
4
4
4
1,176
1,037
1,067
1,783
A, 30
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
PLANT NAME
PSEG Lawrenceburg Energy Facility
PSEG Lawrenceburg Energy Facility
PSEG Lawrenceburg Energy Facility
PSEG Lawrenceburg Energy Facility
PSEG Morristown Energy Facility
PSEG Morristown Energy Facility
PSEG Morristown Energy Facility
PSEG Morristown Energy Facility
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R M Schahfer Generating Station
R M Schahfer Generating Station
R M Schahfer Generating Station
R M Schahfer Generating Station
Richmond (IN)
Richmond (IN)
Rockport
Rockport
Rockport
State Line Generating Station (IN)
State Line Generating Station (IN)
Tanners Creek
Tanners Creek
Tanners Creek
Tanners Creek
Tanners Creek
Vermillion Energy Facility
Vermillion Energy Facility
Vermillion Energy Facility
Vermillion Energy Facility
Vermillion Energy Facility
Vermillion Energy Facility
Vermillion Energy Facility
Vermillion Energy Facility
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
PLANT
CODE
55502
55502
55502
55502
55523
55523
55523
55523
1008
1008
1008
1008
1008
1008
6085
6085
6085
6085
7335
7335
6166
6166
6166
981
981
988
988
988
988
988
55111
55111
55111
55111
55111
55111
55111
55111
1010
1010
1010
1010
1010
1010
1010
STACK/UNIT ID*
1
2
3
4
1
2
3
4
CS0001 (1 , 2)
1
2
CS0002 (3, 4)
3
4
14
15
17
18
RCT1
RCT2
CS012(MB1, MB2)
MB1
MB2
3
4
CS013(U1, U2, U3)
U1
U2
U3
U4
1
2
3
4
5
6
7
8
1
CS0005 (2, 3, 4, 5, 6)
2
3
4
5
6
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
2,909
3,138
2,815
2,933
10,357
10,693
5,224
5,189
0
0
33,003
33,003
4,726
6,924
2,776
2,798
4,080
10,705
0
0
0
0
0
0
0
0
1,723
1,392
1,616
1,532
1,582
5,295
HELD IN
ACCOUNTS AS
OF 3/1/2005
1
1
1
1
0
0
0
0
14,918
17,173
16,967
16,728
9,652
10,441
7,134
5,397
5
4
43,287
46,782
3,952
5,908
6,482
7,481
10,063
51 ,840
4
4
4
4
4
4
4
4
153
8,275
8,626
9,217
9,875
31,505
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
14,208
16,355
16,159
15,931
9,552
10,341
7,034
5,297
0
0
25,401
19,225
3,876
5,826
3,631
4,581
5,845
50,330
0
0
0
0
0
0
0
0
147
7,881
8,215
8,778
9,405
30,004
ALLOWANCES
CARRIED OVER
TO 2005
1
1
1
1
0
0
0
0
710
818
808
797
100
100
100
100
5
4
17,886
27,557
76
82
2,851
2,900
4,218
1,510
4
4
4
4
4
4
4
4
6
394
411
439
470
1,501
A, 31
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
PLANT NAME
Warrick
Warrick
Warrick
Warrick
Warrick
Wheatland Generating Facility LLC
Wheatland Generating Facility LLC
Wheatland Generating Facility LLC
Wheatland Generating Facility LLC
Whitewater Valley
Whitewater Valley
Whitewater Valley
Whiting Clean Energy, Inc.
Whiting Clean Energy, Inc.
Worthington Generation
Worthington Generation
Worthington Generation
Worthington Generation
Arthur Mullergren
Chanute 2
Cimarron River
Coffeyville
East 12th Street
Garden City
Gordon Evans Energy Center
Gordon Evans Energy Center
Gordon Evans Energy Center
Gordon Evans Energy Center
Gordon Evans Energy Center
Holcomb
Hutchinson Energy Center
Hutchinson Energy Center
Hutchinson Energy Center
Hutchinson Energy Center
Jeffrey Energy Center
Jeffrey Energy Center
Jeffrey Energy Center
Judson Large
Kaw
Kaw
Kaw
La Cygne
La Cygne
Lawrence Energy Center
Lawrence Energy Center
PLANT
CODE
6705
6705
6705
6705
6705
55224
55224
55224
55224
1040
1040
1040
55259
55259
55148
55148
55148
55148
1235
1268
1230
1271
7013
1336
1240
1240
1240
1240
1240
108
1248
1248
1248
1248
6068
6068
6068
1233
1294
1294
1294
1241
1241
1250
1250
STACK/UNIT ID*
XS123(1,2, 3)
1
2
3
4
EU-01
EU-02
EU-03
EU-04
CS12(1,2)
1
2
CT1
CT2
1
2
3
4
3
14
1
4
4
S-2
1
2
E1CT
E2CT
E3CT
SGU1
1
2
3
4
1
2
3
4
1
2
3
1
2
3
4
2004
ALLOWANCES
ALLOCATED
30,372
30,732
27,668
10,509
0
0
0
0
2,237
6,695
0
0
0
0
0
0
1
0
12
11
10
0
64
25
0
0
0
4,011
0
0
0
18
17,113
18,087
20,635
39
787
619
516
17,946
15,061
2,148
1,819
HELD IN
ACCOUNTS AS
OF 3/1/2005
22,974
21,287
22,629
43,642
1
1
1
1
3,809
10,041
49
48
1
1
1
1
4
0
10
30
50
48
1,572
3,751
0
0
0
4,391
0
0
0
2,042
22,013
21,589
19,377
39
1
1
1
9,142
21,061
1,741
514
ALLOWANCES
DEDUCTED
22,033
20,437
21 ,779
41 ,876
0
0
0
0
3,663
9,658
1
1
0
0
0
0
0
0
0
0
0
0
1,429
3,410
0
0
0
2,131
0
0
0
1,856
20,965
20,561
18,454
1
0
0
0
6,495
20,695
1,583
439
ALLOWANCES
CARRIED OVER
TO 2005
941
850
850
1,766
1
1
1
1
146
383
48
47
1
1
1
1
4
0
10
30
50
48
143
341
0
0
0
2,260
0
0
0
186
1,048
1,028
923
38
1
1
1
2,647
366
158
75
A, 32
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
PLANT NAME
Lawrence Energy Center
McPherson 2
McPherson 3
Murray Gill Energy Center
Murray Gill Energy Center
Murray Gill Energy Center
Murray Gill Energy Center
Nearman Creek
Nearman Creek
Neosho Energy Center
Osawatomie Generating Station
Osawatomie Generating Station
Osawatomie Generating Station
Osawatomie Generating Station
Osawatomie Generating Station
Osawatomie Generating Station
Osawatomie Generating Station
Osawatomie Generating Station
Quindaro
Quindaro
Riverton
Riverton
Tecumseh Energy Center
Tecumseh Energy Center
West Gardner Generating Station
West Gardner Generating Station
West Gardner Generating Station
West Gardner Generating Station
Wyandotte County Generating, LLC
Wyandotte County Generating, LLC
Big Sandy
Big Sandy
Big Sandy
Bluegrass Generating Company, LLC
Bluegrass Generating Company, LLC
Bluegrass Generating Company, LLC
Cane Run
Cane Run
Cane Run
Coleman
Coleman
Coleman
D B Wilson
E W Brown
E W Brown
PLANT
CODE
1250
1305
7515
1242
1242
1242
1242
6064
6064
1243
7928
7928
7928
7928
7928
7928
7928
7928
1295
1295
1239
1239
1252
1252
7929
7929
7929
7929
55743
55743
1353
1353
1353
55164
55164
55164
1363
1363
1363
1381
1381
1381
6823
1355
1355
STACK/UNIT ID*
5
1
1
1
2
3
4
CT4
N1
7
1
2
3
4
5
6
7
8
1
2
39
40
10
9
1
2
3
4
GTG1
GTG2
CS012(BSU1,BSU2)
BSU1
BSU2
GTG1
GTG2
GTG3
4
5
6
C1
C2
C3
W1
1
10
2004
ALLOWANCES
ALLOCATED
5,377
1
0
1
5
50
62
0
6,930
13
0
0
0
0
0
0
0
0
2,032
2,079
1,039
1,764
3,916
2,256
0
0
0
0
0
0
6,430
19,718
0
0
0
4,522
4,341
5,500
4,854
5,536
5,324
12,465
3,066
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
2,203
73
38
0
39
1,409
1,274
0
1 1 ,926
0
3
0
0
0
0
0
0
0
5,671
6,892
2,698
3,077
3,491
2,242
3
3
3
3
0
0
10,792
38,659
0
0
0
4,685
5,045
7,349
20,501
20,318
21 ,548
10,696
10,088
98
ALLOWANCES
DEDUCTED
2,003
0
0
0
35
1,281
1,158
0
8,024
0
0
0
0
0
0
0
0
0
2,310
2,475
2,452
922
3,174
2,038
0
0
0
0
0
0
10,477
37,533
0
0
0
4,602
4,577
6,607
19,328
19,280
20,542
9,800
9,010
1
ALLOWANCES
CARRIED OVER
TO 2005
200
73
38
0
4
128
116
0
3,902
0
3
0
0
0
0
0
0
0
3,361
4,417
246
2,155
317
204
3
3
3
3
0
0
315
1,126
0
0
0
83
468
742
1,173
1,038
1,006
896
1,078
97
A, 33
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
PLANT NAME
E W Brown
E W Brown
E W Brown
E W Brown
E W Brown
E W Brown
E W Brown
E W Brown
E W Brown
East Bend
Elmer Smith
Elmer Smith
Elmer Smith
Ghent
Ghent
Ghent
Ghent
Ghent
Green River
Green River
Green River
Green River
Green River
Green River
H L Spurlock
H L Spurlock
Henderson 1
HMP&L Station 2
HMP&L Station 2
John S. Cooper
John S. Cooper
John S. Cooper
Kentucky Energy Project, LLC
Kentucky Energy Project, LLC
Kentucky Pioneer Energy
Kentucky Pioneer Energy
KGen Marshall LLC
KGen Marshall LLC
KGen Marshall LLC
KGen Marshall LLC
KGen Marshall LLC
KGen Marshall LLC
KGen Marshall LLC
KGen Marshall LLC
Mill Creek
PLANT
CODE
1355
1355
1355
1355
1355
1355
1355
1355
1355
6018
1374
1374
1374
1356
1356
1356
1356
1356
1357
1357
1357
1357
1357
1357
6041
6041
1372
1382
1382
1384
1384
1384
55828
55828
55266
55266
55232
55232
55232
55232
55232
55232
55232
55232
1364
STACK/UNIT ID*
11
CS003 (2, 3)
2
3
5
6
7
8
9
2
XS12(1,2)
1
2
1
2
CS002 (3, 4)
3
4
CS001 (1 , 2, 3)
1
2
3
4
5
1
2
6
H1
H2
CS1 (1,2)
1
2
TB1
TB2
GT1
GT2
CT1
CT2
CT3
CT4
CT5
CT6
CT7
CT8
1
2004
ALLOWANCES
ALLOCATED
0
5,807
1 1 ,254
0
0
0
0
0
18,322
2,805
6,213
12,252
12,737
13,960
13,717
130
851
744
2,826
3,372
9,824
16,591
810
5,758
5,936
3,210
6,608
0
0
0
0
0
0
0
0
0
0
0
0
8,082
HELD IN
ACCOUNTS AS
OF 3/1/2005
100
13,384
31,350
98
83
85
97
99
12,123
5,082
12,426
17,643
18,011
19,111
22,679
497
3,792
3,255
9,172
10,203
11,578
20,447
11,674
5,758
5,936
15,290
15,289
0
0
0
0
0
1
1
0
1
1
0
1
18,339
ALLOWANCES
DEDUCTED
1
13,285
29,970
0
1
0
0
0
1 1 ,546
3,384
3,384
5,592
15,034
14,939
15,942
0
0
0
7,842
9,970
1 1 ,527
20,395
0
2,300
2,264
15,264
15,265
0
0
0
0
0
0
0
0
0
0
0
0
3,760
ALLOWANCES
CARRIED OVER
TO 2005
99
99
1,380
98
82
85
97
99
577
1,698
9,042
12,051
2,977
4,172
6,737
497
3,792
3,255
1,330
233
51
52
1 1 ,674
3,458
3,672
26
24
0
0
0
0
0
1
1
0
1
1
0
1
14,579
A, 34
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
PLANT NAME
Mill Creek
Mill Creek
Mill Creek
Paddy's Run
Paradise
Paradise
Paradise
R D Green
R D Green
Riverside Generating Company
Riverside Generating Company
Riverside Generating Company
Riverside Generating Company
Riverside Generating Company
Robert Reid
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Smith Generating Facility
Smith Generating Facility
Smith Generating Facility
Smith Generating Facility
Smith Generating Facility
Thoroughbred Generating Station
Thoroughbred Generating Station
Trimble County
Trimble County
Trimble County
Trimble County
Trimble County
Trimble County
Trimble County
Tyrone
Tyrone
Tyrone
Tyrone
PLANT
CODE
1364
1364
1364
1366
1378
1378
1378
6639
6639
55198
55198
55198
55198
55198
1383
1379
1379
1379
1379
1379
1379
1379
1379
1379
1379
1379
1379
54
54
54
54
54
55462
55462
6071
6071
6071
6071
6071
6071
6071
1361
1361
1361
1361
STACK/UNIT ID*
2
3
4
13
1
2
3
G1
G2
GTG101
GTG201
GTG301
GTG401
GTG501
R1
CSSH15 (1,2,3, 4, 5)
1
10
2
3
4
5
CSSH60 (6, 7, 8, 9)
6
7
8
9
SCT1
SCT2
SCT3
SCT4
SCT5
01
02
1
10
5
6
7
8
9
1
2
3
4
2004
ALLOWANCES
ALLOCATED
8,142
10,982
13,622
0
10,821
12,304
25,513
5,294
6,378
0
0
0
0
0
942
3,644
4,895
3,673
3,708
3,594
3,826
3,712
3,640
3,571
3,666
0
0
0
0
0
0
0
9,634
0
0
0
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
18,978
24,064
28,160
87
18,145
17,218
59,785
3,411
2,136
0
0
0
0
0
5,953
4,299
14,800
4,990
4,437
4,421
5,148
6,233
4,482
4,338
4,689
16
16
18
18
10
0
0
18,032
50
100
150
50
50
50
50
50
50
50
ALLOWANCES
DEDUCTED
4,792
7,776
9,381
0
17,268
16,375
56,928
2,072
816
0
0
0
0
0
5,648
3,779
1,562
3,841
3,829
3,323
3,395
3,753
3,612
3,641
3,149
1
1
1
0
0
0
0
4,725
0
0
0
0
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
14,186
16,288
18,779
87
877
843
2,857
1,339
1,320
0
0
0
0
0
305
520
13,238
1,149
608
1,098
1,753
2,480
870
697
1,540
15
15
17
18
10
0
0
13,307
50
100
150
50
50
50
50
50
50
50
A, 35
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
KY
KY
KY
KY
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
PLANT NAME
Tyrone
William C. Dale
William C. Dale
William C. Dale
A B Paterson
A B Paterson
Acadia Power Station
Acadia Power Station
Acadia Power Station
Acadia Power Station
Arsenal Hill Power Plant
Bayou Cove Peaking Power Plant
Bayou Cove Peaking Power Plant
Bayou Cove Peaking Power Plant
Bayou Cove Peaking Power Plant
Big Cajun 1
Big Cajun 1
Big Cajun 1
Big Cajun 1
Big Cajun 2
Big Cajun 2
Big Cajun 2
Caddo Parish Energy
Caddo Parish Energy
Caddo Parish Energy
Calcasieu Power, LLC
Calcasieu Power, LLC
Carville Energy Center
Carville Energy Center
D G Hunter
D G Hunter
Doc Bonin
Doc Bonin
Doc Bonin
Dolet Hills Power Station
Evangeline Power Station (Coughlin)
Evangeline Power Station (Coughlin)
Evangeline Power Station (Coughlin)
Houma
Houma
Iberville Energy Center
Iberville Energy Center
Lieberman Power Plant
Lieberman Power Plant
Little Gypsy
PLANT
CODE
1361
1385
1385
1385
1407
1407
55173
55173
55173
55173
1416
55433
55433
55433
55433
1464
1464
1464
1464
6055
6055
6055
55724
55724
55724
55165
55165
55404
55404
6558
6558
1443
1443
1443
51
1396
1396
1396
1439
1439
55723
55723
1417
1417
1402
STACK/UNIT ID*
5
CS2 (3, 4)
3
4
3
4
CT1
CT2
CT3
CT4
5A
CTG-1
CTG-2
CTG-3
CTG-4
1B1
1B2
CTG1
CTG2
2B1
2B2
2B3
1
2
3
GTG1
GTG2
COG01
COG02
3
4
1
2
3
1
6-1
7-1
7-2
15
16
1
2
3
4
1
2004
ALLOWANCES
ALLOCATED
1,713
1,984
1,847
7
8
0
0
0
0
30
0
0
0
0
27
27
0
0
14,868
14,640
14,657
0
0
0
0
0
0
0
0
32
12
24
45
20,501
0
0
0
10
14
0
0
86
72
245
HELD IN
ACCOUNTS AS
OF 3/1/2005
3,447
3,905
3,905
21
24
2
1
1
1
128
1
1
1
1
55
56
3
3
18,775
16,092
18,445
0
0
0
0
0
3
2
0
145
59
119
221
25,393
215
303
304
50
70
0
0
272
242
1,218
ALLOWANCES
DEDUCTED
2,390
3,879
3,879
0
0
2
1
1
1
1
0
0
0
0
0
0
0
0
17,881
15,326
17,567
0
0
0
0
0
3
2
0
0
0
1
1
21 ,666
0
1
1
0
0
0
0
0
0
1
ALLOWANCES
CARRIED OVER
TO 2005
1,057
26
26
21
24
0
0
0
0
127
1
1
1
1
55
56
3
3
894
766
878
0
0
0
0
0
0
0
0
145
59
118
220
3,727
215
302
303
50
70
0
0
272
242
1,217
A, 36
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
PLANT NAME
Little Gypsy
Little Gypsy
Louisiana 1
Louisiana 1
Louisiana 1
Louisiana 1
Louisiana 1
Louisiana 2
Louisiana 2
Louisiana 2
Michoud
Michoud
Michoud
Monroe
Monroe
Morgan City Electrical Gen Facility
Natchitoches
Ninemile Point
Ninemile Point
Ninemile Point
Ninemile Point
Ninemile Point
Ouachita Power, LLC
Ouachita Power, LLC
Ouachita Power, LLC
Perryville Power Station
Perryville Power Station
Perryville Power Station
Placquemine Cogen Facility
Placquemine Cogen Facility
Placquemine Cogen Facility
Placquemine Cogen Facility
Pointe Coupee Energy Center
Pointe Coupee Energy Center
Pointe Coupee Energy Center
R S Cogen
R S Cogen
R S Nelson
R S Nelson
R S Nelson
Rodemacher Power Station (6190)
Rodemacher Power Station (6190)
Ruston
Ruston
Sterlington
PLANT
CODE
1402
1402
1391
1391
1391
1391
1391
1392
1392
1392
1409
1409
1409
1448
1448
1449
1450
1403
1403
1403
1403
1403
55467
55467
55467
55620
55620
55620
55419
55419
55419
55419
55722
55722
55722
55117
55117
1393
1393
1393
6190
6190
1458
1458
1404
STACK/UNIT ID*
2
3
1A
2A
3A
4A
5A
10
11
12
1
2
3
11
12
4
10
1
2
3
4
5
CTGEN1
CTGEN2
CTGEN3
1-1
1-2
2-1
500
600
700
800
1
2
3
RS-5
RS-6
3
4
6
1
2
2
3
10
2004
ALLOWANCES
ALLOCATED
378
543
116
2
2
0
0
0
0
0
71
106
491
13
45
5
0
62
112
96
691
930
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
39
123
19,569
3,249
18,909
4
5
174
HELD IN
ACCOUNTS AS
OF 3/1/2005
1,680
2,697
183
24
67
53
48
2
2
2
286
319
1,450
65
225
25
1
308
554
476
3,060
4,583
2
2
2
8
8
11
7
7
7
7
0
0
0
20
20
152
478
24,501
15,513
26,737
4
6
832
ALLOWANCES
DEDUCTED
2
2
42
21
38
6
34
0
0
0
1
1
17
0
0
0
0
1
1
1
22
31
0
0
0
2
2
0
3
2
3
3
0
0
0
5
5
1
4
13,179
283
13,530
0
0
1
ALLOWANCES
CARRIED OVER
TO 2005
1,678
2,695
141
3
29
47
14
2
2
2
285
318
1,433
65
225
25
1
307
553
475
3,038
4,552
2
2
2
6
6
11
4
5
4
4
0
0
0
15
15
151
474
1 1 ,322
15,230
13,207
4
6
831
A, 37
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
LA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
PLANT NAME
Sterlington
Sterlington
Taft Cogeneration Facility
Taft Cogeneration Facility
Taft Cogeneration Facility
Teche Power Station
Teche Power Station
Washington Parish Energy Center
Washington Parish Energy Center
Waterford 1 & 2
Waterford 1 & 2
Willow Glen
Willow Glen
Willow Glen
Willow Glen
Willow Glen
ANP Bellingham Energy Project
ANP Bellingham Energy Project
ANP Blackstone Energy Company
ANP Blackstone Energy Company
Bellingham
Bellingham
Berkshire Power
Brayton Point
Brayton Point
Brayton Point
Brayton Point
Canal Station
Canal Station
Cleary Flood
Cleary Flood
Dartmouth Power
Dighton
Fore River Station
Fore River Station
Indeck-Pepperell
Kendall Square
Kendall Square
Kendall Square
Kendall Square
Lowell Cogeneration Company
Lowell Power, LLC
Masspower
Masspower
PLANT
CODE
1404
1404
55089
55089
55089
1400
1400
55486
55486
8056
8056
1394
1394
1394
1394
1394
55211
55211
55212
55212
10307
10307
10307
55041
1619
1619
1619
1619
1599
1599
1682
1682
52026
55026
55317
55317
10522
1595
1595
1595
1595
10802
54586
10726
10726
STACK/UNIT ID*
7AB
7C
CT1
CT2
CT3
2
3
CTG01
CTG02
1
2
1
2
3
4
5
1
2
1
2
1
CP1
2
1
1
2
3
4
1
2
8
9
1
1
11
12
CC1
1
2
3
4
001
1
1
2
2004
ALLOWANCES
ALLOCATED
72
0
0
0
0
27
446
0
0
4,554
3,535
99
26
93
291
458
0
0
0
0
0
0
0
8,481
8,911
18,625
12,139
13,235
17,999
143
2,679
0
0
0
0
0
199
208
421
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
341
37
104
104
104
134
2,071
0
0
14,309
12,317
306
91
296
1,842
789
3
4
3
3
0
0
9
7,516
7,093
16,058
826
16,247
12,184
143
179
0
27
14
19
14
2
3
61
5
4
6
0
0
ALLOWANCES
DEDUCTED
0
0
3
4
4
0
3
0
0
4,586
5,208
0
1
0
0
597
1
2
1
1
0
0
3
6,833
6,448
15,218
751
16,121
12,060
48
171
0
2
2
2
0
0
0
53
1
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
341
37
101
100
100
134
2,068
0
0
9,723
7,109
306
90
296
1,842
192
2
2
2
2
0
0
6
683
645
840
75
126
124
95
8
0
25
12
17
14
2
3
8
4
4
6
0
0
A, 38
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MA
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
PLANT NAME
Millennium Power Partners
Mount Tom
Mystic
Mystic
Mystic
Mystic
Mystic
Mystic
Mystic
Mystic
New Boston
New Boston
Salem Harbor
Salem Harbor
Salem Harbor
Salem Harbor
Somerset
Somerset
West Springfield
West Springfield
West Springfield
Brandon Shores
Brandon Shores
C P Crane
C P Crane
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Dickerson
Dickerson
Dickerson
Dickerson
Dickerson
Dickerson
Dickerson
PLANT
CODE
55079
1606
1588
1588
1588
1588
1588
1588
1588
1588
1589
1589
1626
1626
1626
1626
1613
1613
1642
1642
1642
602
602
1552
1552
1571
1571
1571
1571
1571
1571
1571
1571
1571
1571
1571
1571
1571
1572
1572
1572
1572
1572
1572
1572
STACK/UNIT ID*
1
1
4
5
6
7
81
82
93
94
1
2
1
2
3
4
7
8
3
CTG1
CTG2
1
2
1
2
"GTS
**GT4
"GTS
"GT6
CSE12(1,2)
1
2
3
4
GT10
GT7
GTS
GT9
XS123(1,2, 3)
1
2
3
GT2
GTS
GT4
2004
ALLOWANCES
ALLOCATED
0
5,611
2,607
3,092
3,076
17,244
0
0
0
0
6,158
6,324
3,339
3,408
5,461
12,571
2,765
3,985
3,012
0
0
18,510
7,795
4,349
4,043
707
707
894
894
9,202
10,219
12,503
2,600
0
0
0
0
5,848
5,500
5,846
1,082
1,082
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
3
4,122
1,607
1,952
2,076
11,398
6
7
7
7
1,391
1,525
2,492
1,738
4,247
551
0
7,048
935
5
5
21 ,245
20,247
14,921
14,242
756
748
947
929
27,414
28,681
12,544
6,771
0
0
0
0
14,297
14,749
14,505
1,128
1,117
0
ALLOWANCES
DEDUCTED
2
3,929
0
0
0
5,040
5
5
5
5
1
0
2,265
1,580
3,861
501
0
4,417
558
0
0
21,144
20,147
14,860
14,182
27
28
44
37
27,181
27,332
5,458
4,541
0
0
0
0
12,817
13,125
12,858
151
87
0
ALLOWANCES
CARRIED OVER
TO 2005
1
193
1,607
1,952
2,076
6,358
1
2
2
2
1,390
1,525
227
158
386
50
0
2,631
377
5
5
101
100
61
60
729
720
903
892
233
1,349
7,086
2,230
0
0
0
0
1,480
1,624
1,647
977
1,030
0
A, 39
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
ME
Ml
Ml
Ml
Ml
Ml
PLANT NAME
Dickerson
Easton 2
Easton 2
Easton 2
Herbert A Wagner
Herbert A Wagner
Herbert A Wagner
Herbert A Wagner
Morgantown
Morgantown
Panda Brandywine
Panda Brandywine
Perryman
R. Paul Smith Power Station
R. Paul Smith Power Station
Riverside
Rock Springs Generating Facility
Rock Springs Generating Facility
Rock Springs Generating Facility
Rock Springs Generating Facility
Rock Springs Generating Facility
Rock Springs Generating Facility
Vienna
Androscoggin Cogeneration Center
Androscoggin Cogeneration Center
Androscoggin Cogeneration Center
Bucksport Clean Energy
Loring BioEnergy, LLC
Maine Independence Station
Maine Independence Station
Mason Steam
Mason Steam
Mason Steam
Rumford Power Associates
Westbrook Energy Center
Westbrook Energy Center
William F Wyman
William F Wyman
William F Wyman
William F Wyman
48th Street Peaking Station
48th Street Peaking Station
48th Street Peaking Station
Augusta Park Energy Facility
Augusta Park Energy Facility
PLANT
CODE
1572
4257
4257
4257
1554
1554
1554
1554
1573
1573
54832
54832
1556
1570
1570
1559
7835
7835
7835
7835
7835
7835
1564
55031
55031
55031
55180
56105
55068
55068
1496
1496
1496
55100
55294
55294
1507
1507
1507
1507
7258
7258
7258
55431
55431
STACK/UNIT ID*
GTS
"25
"26
"27
1
2
3
4
1
2
1
2
"51
11
9
4
1
2
3
4
5
6
8
CT01
CT02
CT03
GEN4
GTG1
1
2
3
4
5
1
1
2
1
2
3
4
"7
"8
9
1
2
2004
ALLOWANCES
ALLOCATED
0
0
0
0
1,291
1,299
8,381
1,520
16,932
16,189
0
0
0
2,314
634
455
0
0
0
0
0
0
3,645
0
0
0
0
0
0
0
2
1
1
0
0
0
1,159
1,161
2,946
6,274
298
298
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
0
0
0
1,102
7,670
12,754
1,873
41,197
42,440
2
2
38
2,567
433
1
5
5
5
5
0
0
588
1
3
2
81
0
5
5
6
3
2
24
4
4
217
233
1,396
2,447
303
294
50
0
0
ALLOWANCES
DEDUCTED
0
0
0
0
1,096
7,635
12,694
1,863
40,085
40,915
1
1
37
2,467
333
0
0
0
0
0
0
0
538
1
3
1
7
0
3
3
0
0
0
4
4
4
128
136
1,383
1,570
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
0
0
0
0
6
35
60
10
1,112
1,525
1
1
1
100
100
1
5
5
5
5
0
0
50
0
0
1
74
0
2
2
6
3
2
20
0
0
89
97
13
877
303
294
50
0
0
A, 40
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
PLANT NAME
Augusta Park Energy Facility
B C Cobb
B C Cobb
B C Cobb
B C Cobb
B C Cobb
Belle River
Belle River
Belle River
Belle River
Belle River
Conners Creek
Conners Creek
Conners Creek
Conners Creek
Dan E Karn
Dan E Karn
Dan E Karn
Dan E Karn
Dan E Karn
Dearborn Industrial Generation
Delray
Delray
DTE East China
DTE East China
DTE East China
DTE East China
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Endicott Generating
Erickson
Greenwood
Greenwood
Greenwood
Greenwood
Harbor Beach
Indeck-Niles Energy Center
Indeck-Niles Energy Center
Indeck-Niles Energy Center
Indeck-Niles Energy Center
J B Sims
PLANT
CODE
55431
1695
1695
1695
1695
1695
6034
6034
6034
6034
6034
1726
1726
1726
1726
1702
1702
1702
1702
1702
55088
1728
1728
55718
55718
55718
55718
1831
1831
1831
1831
1831
1831
4259
1832
6035
6035
6035
6035
1731
55460
55460
55460
55460
1825
STACK/UNIT ID*
3
1
2
3
4
5
1
2
CTG121
CTG122
CTG131
15
16
17
18
1
2
CS0009 (3, 4)
3
4
GTP1
CTG111
CTG121
1
2
3
4
1
2
3
4
5
6
1
1
1
CTG111
CTG112
CTG121
1
0001
0002
0003
0004
3
2004
ALLOWANCES
ALLOCATED
0
1,142
1,229
1,223
4,573
4,695
18,505
18,769
0
0
0
4,285
4,279
4,034
3,353
7,811
8,567
1,020
948
0
0
0
0
0
0
0
1,298
1,354
1,327
2,223
2,666
2,343
1,810
6,646
539
0
0
0
3,520
0
0
0
0
1,484
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
7,069
1,229
1,223
6,417
6,045
22,000
23,340
5
5
5
4,289
4,283
5,143
6,706
7,811
8,567
1,793
948
0
5
5
0
0
0
0
1,067
1,117
1,167
1,922
1,664
1,646
1,940
3,964
1,446
5
5
5
5,489
0
0
0
0
978
ALLOWANCES
DEDUCTED
0
0
0
0
6,111
5,757
14,383
14,938
0
0
0
0
0
0
0
5,732
7,364
1,708
643
0
0
0
0
0
0
0
715
767
797
1,631
1,516
1,427
1,124
2,628
1,422
0
0
0
1,725
0
0
0
0
733
ALLOWANCES
CARRIED OVER
TO 2005
0
7,069
1,229
1,223
306
288
7,617
8,402
5
5
5
4,289
4,283
5,143
6,706
2,079
1,203
85
305
0
5
5
0
0
0
0
352
350
370
291
148
219
816
1,336
24
5
5
5
3,764
0
0
0
0
245
A, 41
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
PLANT NAME
J C Weadock
J C Weadock
J C Weadock
J H Campbell
J H Campbell
J H Campbell
J H Campbell
J R Whiting
J R Whiting
J R Whiting
Jackson Ml Facility
Jackson Ml Facility
Jackson Ml Facility
Jackson Ml Facility
Jackson Ml Facility
Jackson Ml Facility
Jackson Ml Facility
James De Young
Kalamazoo River Generating Station
Kalkaska Ct Project #1
Kalkaska Ct Project #1
Livingston Generating Station
Livingston Generating Station
Livingston Generating Station
Livingston Generating Station
Marysville
Marysville
Marysville
Marysville
Marysville
Marysville
Michigan Power Limited Partnership
Mirant Wyandotte, LLC
Mirant Wyandotte, LLC
Mirant Zeeland, LLC
Mirant Zeeland, LLC
Mirant Zeeland, LLC
Mirant Zeeland, LLC
Mistersky
Mistersky
Mistersky
Monroe
Monroe
Monroe
Monroe
PLANT
CODE
1720
1720
1720
1710
1710
1710
1710
1723
1723
1723
55270
55270
55270
55270
55270
55270
55270
1830
55101
7984
7984
55102
55102
55102
55102
1732
1732
1732
1732
1732
1732
54915
55520
55520
55087
55087
55087
55087
1822
1822
1822
1733
1733
1733
1733
STACK/UNIT ID*
CS0009 (7, 8)
7
8
CS0009 (1 , 2)
1
2
3
1
2
3
7EA
LM1
LM2
LM3
LM4
LM5
LM6
5
1
1A
1B
1
2
3
4
10
CS0002(11, 12)
11
12
CS0001 (9, 10)
9
1
CT01
CT02
CC1
CC2
CCS
CC4
5
6
7
CS0012(1,2)
1
2
CS0034 (3, 4)
2004
ALLOWANCES
ALLOCATED
4,745
4,691
8,098
9,685
27,481
3,412
3,494
4,468
0
0
0
0
0
0
0
1,048
0
0
0
0
0
0
0
1,261
1,315
1,061
1,637
0
0
0
0
0
0
0
257
437
485
23,669
24,307
HELD IN
ACCOUNTS AS
OF 3/1/2005
4,745
5,450
8,098
10,937
47,988
3,479
3,494
4,468
0
0
0
0
0
0
0
1,861
0
0
0
0
0
0
0
1,659
2,630
2,122
1,637
6
0
0
4
4
4
4
1,281
2,180
2,418
26,035
26,360
ALLOWANCES
DEDUCTED
3,852
5,190
5,003
10,416
19,901
3,313
3,225
4,047
0
0
0
0
0
0
0
1,299
0
0
0
0
0
0
0
0
0
0
0
3
0
0
0
0
0
0
1
0
1
26,019
24,597
ALLOWANCES
CARRIED OVER
TO 2005
893
260
3,095
521
28,087
166
269
421
0
0
0
0
0
0
0
562
0
0
0
0
0
0
0
1,659
2,630
2,122
1,637
3
0
0
4
4
4
4
1,280
2,180
2,417
16
1,763
A, 42
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
PLANT NAME
Monroe
Monroe
New Covert Generating Project
New Covert Generating Project
New Covert Generating Project
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Renaissance Power
Renaissance Power
Renaissance Power
Renaissance Power
River Rouge
River Rouge
River Rouge
Shiras
St. Clair
St. Clair
St. Clair
St. Clair
St. Clair
St. Clair
St. Clair
Sumpter Plant
Sumpter Plant
Sumpter Plant
Sumpter Plant
Tallmadge Generation Station
Tallmadge Generation Station
Tallmadge Generation Station
Tallmadge Generation Station
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Wyandotte
Wyandotte
PLANT
CODE
1733
1733
55297
55297
55297
1769
1769
1769
1769
1769
1769
1769
1769
1769
55402
55402
55402
55402
1740
1740
1740
1843
1743
1743
1743
1743
1743
1743
1743
7972
7972
7972
7972
55808
55808
55808
55808
1745
1745
1745
1745
1745
1745
1866
1866
STACK/UNIT ID*
3
4
001
002
003
CS4 (2, 3, 4)
2
3
4
5
6
7
8
9
CT1
CT2
CT3
CT4
1
2
3
3
1
2
3
4
5
6
7
1
2
3
4
CT-1
CT-2
CT-3
CT-4
030006(16,17,18,19)
16
17
18
19
9A
5
7
2004
ALLOWANCES
ALLOCATED
22,771
24,617
0
0
0
637
1,907
1,677
2,934
2,941
2,216
2,192
2,346
0
0
0
0
79
6,323
9,103
500
3,666
3,543
3,525
3,396
0
7,342
13,459
0
0
0
0
0
0
0
0
3,292
767
3,563
698
14,507
960
953
HELD IN
ACCOUNTS AS
OF 3/1/2005
22,904
31,348
2
1
1
265
2,244
2,421
3,888
3,716
1,560
1,912
1,862
0
0
0
0
4
7,702
9,180
1,360
4,531
4,348
3,527
3,398
0
11,353
16,835
5
5
5
5
0
0
0
0
3,889
3,023
5,814
3,124
17,018
1,633
1,269
ALLOWANCES
DEDUCTED
17,847
31 ,272
0
0
0
249
2,115
2,282
3,821
3,652
1,533
1,879
1,829
0
0
0
0
0
7,698
7,906
219
4,526
4,340
3,267
3,066
0
11,301
16,804
0
0
0
0
0
0
0
0
3,246
3,022
3,112
3,120
16,972
0
1,090
ALLOWANCES
CARRIED OVER
TO 2005
5,057
76
2
1
1
16
129
139
67
64
27
33
33
0
0
0
0
4
4
1,274
1,141
5
8
260
332
0
52
31
5
5
5
5
0
0
0
0
643
1
2,702
4
46
1,633
179
A, 43
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
Ml
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
PLANT NAME
Wyandotte
Allen S King
Black Dog
Black Dog
Black Dog
Black Dog
Blue Lake Generating Plant
Blue Lake Generating Plant
Cascade Creek
Cascade Creek
Clay Boswell
Clay Boswell
Clay Boswell
Clay Boswell
Clay Boswell
Cottage Grove Cogeneration
Faribault Energy Park
Faribault Energy Park
Fibrominn Biomass Power Plant
Fox Lake
High Bridge
High Bridge
High Bridge
High Bridge
High Bridge
Hoot Lake
Hoot Lake
Hutchinson - Plant 2
Lakefield Junction Generating
Lakefield Junction Generating
Lakefield Junction Generating
Lakefield Junction Generating
Lakefield Junction Generating
Lakefield Junction Generating
M L Hibbard
M L Hibbard
M L Hibbard
Mankato Energy Center
Mankato Energy Center
Minnesota River Station
Minnesota Valley
Northeast Station
Pleasant Valley Station
Pleasant Valley Station
Pleasant Valley Station
PLANT
CODE
1866
1915
1904
1904
1904
1904
8027
8027
6058
6058
1893
1893
1893
1893
1893
55010
56164
56164
55867
1888
1912
1912
1912
1912
1912
1943
1943
6358
7925
7925
7925
7925
7925
7925
1897
1897
1897
56104
56104
7844
1918
1961
7843
7843
7843
STACK/UNIT ID*
8
1
CS1 (3, 4)
3
4
5
7
8
CT2
CT3
CS0003 (1 , 2, 3)
1
2
3
4
01
01
06
EU-001
3
CS0001 (3, 4, 5, 6)
3
4
5
6
2
3
1
CT01
CT02
CT03
CT04
CT05
CT06
CS0001 (3, 4)
3
4
CT-1
CT-2
U001
4
NEPP
11
12
13
2004
ALLOWANCES
ALLOCATED
0
15,628
2,275
4,056
0
0
0
0
0
1,827
1,800
9,866
10,324
0
0
0
0
2,069
2,118
1,458
2,194
1,852
1,242
1,978
0
0
0
0
0
0
0
987
1,094
0
0
0
938
1,052
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
513
28,645
6,880
12,937
348
0
0
52
52
0
0
18,741
5,906
4
0
0
0
9,877
12,932
7,687
6,892
9,097
2,081
3,314
5
10
10
10
10
10
9
1,054
1,162
0
0
0
483
2,755
8
8
10
ALLOWANCES
DEDUCTED
481
26,041
1,054
2,111
1
0
0
0
0
0
0
17,287
2,440
2
0
0
0
302
327
147
1,311
2,021
1,268
1,438
0
0
0
0
0
0
0
158
157
0
0
0
0
2,178
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
32
2,604
5,826
10,826
347
0
0
52
52
0
0
1,454
3,466
2
0
0
0
9,575
12,605
7,540
5,581
7,076
813
1,876
5
10
10
10
10
10
9
896
1,005
0
0
0
483
577
8
8
10
A, 44
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
PLANT NAME
Riverside (1927)
Riverside (1927)
Riverside (1927)
Riverside (1927)
Sherburne County
Sherburne County
Sherburne County
Sherburne County
Silver Lake
Solway Plant
Syl Laskin
Syl Laskin
Syl Laskin
Taconite Harbor Energy Center
Taconite Harbor Energy Center
Taconite Harbor Energy Center
Asbury
Audrain Generating Station
Audrain Generating Station
Audrain Generating Station
Audrain Generating Station
Audrain Generating Station
Audrain Generating Station
Audrain Generating Station
Audrain Generating Station
Blue Valley
Chamois Power Plant
Columbia
Columbia
Columbia
Columbia
Columbia Energy Center (MO)
Columbia Energy Center (MO)
Columbia Energy Center (MO)
Columbia Energy Center (MO)
Empire District Elec Co Energy Ctr
Empire District Elec Co Energy Ctr
Empire District Elec Co Energy Ctr
Empire District Elec Co Energy Ctr
Essex Power Plant
Hawthorn
Hawthorn
Hawthorn
Hawthorn
Hawthorn
PLANT
CODE
1927
1927
1927
1927
6090
6090
6090
6090
2008
7947
1891
1891
1891
10075
10075
10075
2076
55234
55234
55234
55234
55234
55234
55234
55234
2132
2169
2123
2123
2123
2123
55447
55447
55447
55447
6223
6223
6223
6223
7749
2079
2079
2079
2079
2079
STACK/UNIT ID*
XS67 (6, 7)
6
7
8
CS1 (1,2)
1
2
3
4
1
CS0001 (1 , 2)
1
2
1
2
3
1
CT1
CT2
CT3
CT4
CT5
CT6
CT7
CT8
3
2
CSS (6, 7)
6
7
8
CT01
CT02
CT03
CT04
3A
3B
4A
4B
1
5A
6
7
8
9
2004
ALLOWANCES
ALLOCATED
3,076
1,339
5,068
13,091
13,184
12,956
3,133
0
1,692
1,649
0
0
0
6,975
0
0
0
0
0
0
0
0
4,670
5,457
903
3,631
125
0
0
0
0
0
0
0
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
1,168
1,549
1 1 ,360
12,006
24,801
14,187
2,627
10
1,515
1,651
1,848
2,140
2,289
53,170
1
1
1
1
1
1
1
1
8,256
987
707
3,631
125
5
5
5
5
10
10
10
10
10
2,300
4
5
5
2
ALLOWANCES
DEDUCTED
1,016
1,017
10,328
6,678
6,904
11,291
2,202
0
808
807
1,639
1,901
2,034
7,599
0
0
0
0
0
0
0
0
6,978
982
614
229
0
0
0
0
0
0
0
0
0
0
2,181
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
152
532
1,032
5,328
17,897
2,896
425
10
707
844
209
239
255
45,571
1
1
1
1
1
1
1
1
1,278
5
93
3,402
125
5
5
5
5
10
10
10
10
10
119
4
5
5
2
A, 45
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
PLANT NAME
Holden Power Plant
Holden Power Plant
Holden Power Plant
latan
James River
James River
James River
James River
Labadie
Labadie
Labadie
Labadie
Lake Road
McCartney Generating Station
McCartney Generating Station
McCartney Generating Station
McCartney Generating Station
MEP Pleasant Hill-Aries Power Proj
MEP Pleasant Hill-Aries Power Proj
Meramec
Meramec
Meramec
Meramec
Montrose
Montrose
Montrose
Montrose
New Madrid Power Plant
New Madrid Power Plant
Nodaway Power Plant
Nodaway Power Plant
Peno Creek Energy Center
Peno Creek Energy Center
Peno Creek Energy Center
Peno Creek Energy Center
Peno Creek Energy Center
Peno Creek Energy Center
Peno Creek Energy Center
Peno Creek Energy Center
Rush Island
Rush Island
Sibley
Sibley
Sibley
Sibley
PLANT
CODE
7848
7848
7848
6065
2161
2161
2161
2161
2103
2103
2103
2103
2098
7903
7903
7903
7903
55178
55178
2104
2104
2104
2104
2080
2080
2080
2080
2167
2167
7754
7754
7964
7964
7964
7964
7964
7964
7964
7964
6155
6155
2094
2094
2094
2094
STACK/UNIT ID*
1
2
3
1
**GT2
3
4
5
1
2
3
4
6
MGS1A
MGS1B
MGS2A
MGS2B
CT-1
CT-2
1
2
3
4
1
CS023 (2, 3)
2
3
1
2
1
2
CT1A
CT1B
CT2A
CT2B
CT3A
CT3B
CT4A
CT4B
1
2
CS0001 (1 , 2, 3)
1
2
3
2004
ALLOWANCES
ALLOCATED
0
0
0
16,208
604
3,327
5,975
2,133
17,553
16,363
17,487
15,584
605
0
0
0
0
0
0
2,745
2,778
6,058
7,175
3,189
3,535
4,349
12,178
14,009
0
0
0
0
0
0
0
0
0
0
14,960
15,652
519
638
7,634
HELD IN
ACCOUNTS AS
OF 3/1/2005
31
31
36
20,164
380
10,598
7,352
2,697
15,019
13,463
18,102
16,358
5,041
10
10
10
10
1
1
5,045
4,223
10,125
12,487
5,301
6,498
5,495
7,895
7,220
10
10
5
5
5
5
5
5
5
5
12,298
11,792
1,957
2,132
13,278
ALLOWANCES
DEDUCTED
0
0
0
19,219
0
875
1,181
2,154
14,467
12,895
17,540
15,809
2,390
0
0
0
0
1
1
4,493
3,668
9,559
1 1 ,966
5,171
6,373
5,303
7,890
7,215
0
0
0
0
0
0
0
0
0
0
1 1 ,725
11,193
1,830
1,899
9,130
ALLOWANCES
CARRIED OVER
TO 2005
31
31
36
945
380
9,723
6,171
543
552
568
562
549
2,651
10
10
10
10
0
0
552
555
566
521
130
125
192
5
5
10
10
5
5
5
5
5
5
5
5
573
599
127
233
4,148
A, 46
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
PLANT NAME
Sikeston
Sioux
Sioux
South Harper Peaking Facility
South Harper Peaking Facility
South Harper Peaking Facility
Southwest
St. Francis Power Plant
St. Francis Power Plant
State Line (MO)
State Line (MO)
State Line (MO)
Thomas Hill Energy Center
Thomas Hill Energy Center
Thomas Hill Energy Center
Attala Generating Plant
Attala Generating Plant
Batesville Generation Facility
Batesville Generation Facility
Batesville Generation Facility
Baxter Wilson
Baxter Wilson
Caledonia Power 1, LLC
Caledonia Power 1, LLC
Caledonia Power 1, LLC
Caledonia Power 1, LLC
Caledonia Power 1, LLC
Caledonia Power 1, LLC
Caledonia Power, LLC
Caledonia Power, LLC
Caledonia Power, LLC
Chevron Cogenerating Station
Choctaw Gas Power Plant
Choctaw Gas Power Plant
Crossroads Energy Center
Crossroads Energy Center
Crossroads Energy Center (CPU)
Crossroads Energy Center (CPU)
Crossroads Energy Center (CPU)
Crossroads Energy Center (CPU)
Daniel Electric Generating Plant
Daniel Electric Generating Plant
Daniel Electric Generating Plant
Daniel Electric Generating Plant
Daniel Electric Generating Plant
PLANT
CODE
6768
2107
2107
56151
56151
56151
6195
7604
7604
7296
7296
7296
2168
2168
2168
55220
55220
55063
55063
55063
2050
2050
55082
55082
55082
55082
55082
55082
55197
55197
55197
2047
55694
55694
55432
55432
55395
55395
55395
55395
6073
6073
6073
6073
6073
STACK/UNIT ID*
1
1
2
1
2
3
1
1
2
1
2-1
2-2
MB1
MB2
MBS
A01
A02
1
2
3
1
2
AA-001
AA-002
AA-003
AA-004
AA-005
AA-006
AA-001
AA-002
AA-003
5
AA-001
AA-002
1
2
CT01
CT02
CT03
CT04
1
2
3A
3B
4A
2004
ALLOWANCES
ALLOCATED
6,791
10,823
9,492
0
0
0
4,184
0
0
0
0
0
4,421
7,432
18,257
0
0
0
0
0
360
3,564
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1 1 ,228
14,277
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
8,024
22,758
18,542
0
0
0
7,497
27
23
28
107
105
2,930
4,524
9,547
3
3
4
4
5
886
3,259
3
3
3
3
3
3
3
3
3
25
0
0
0
0
2
2
2
2
14,831
17,966
13
13
13
ALLOWANCES
DEDUCTED
6,251
22,168
17,948
0
0
0
3,412
0
0
0
1
2
2,925
4,519
9,542
1
1
1
1
2
886
3,259
0
0
0
0
0
0
1
1
1
10
0
0
0
0
0
0
0
0
14,125
17,110
2
2
2
ALLOWANCES
CARRIED OVER
TO 2005
1,773
590
594
0
0
0
4,085
27
23
28
106
103
5
5
5
2
2
3
3
3
0
0
3
3
3
3
3
3
2
2
2
15
0
0
0
0
2
2
2
2
706
856
11
11
11
A, 47
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
PLANT NAME
Daniel Electric Generating Plant
Delta
Delta
Gerald Andrus
Kemper
Kemper
Kemper
Kemper
KGen Enterprise LLC
KGen Enterprise LLC
KGen Enterprise LLC
KGen Enterprise LLC
KGen Enterprise LLC
KGen Enterprise LLC
KGen Enterprise LLC
KGen Enterprise LLC
KGen Hinds LLC
KGen Hinds LLC
KGen New Albany LLC
KGen New Albany LLC
KGen New Albany LLC
KGen New Albany LLC
KGen New Albany LLC
KGen New Albany LLC
KGen Southaven LLC
KGen Southaven LLC
KGen Southaven LLC
KGen Southaven LLC
KGen Southaven LLC
KGen Southaven LLC
KGen Southaven LLC
KGen Southaven LLC
Lee Power Partners
Lee Power Partners
Lone Oak Energy Center
Lone Oak Energy Center
Lone Oak Energy Center
Magnolia Facility
Magnolia Facility
Magnolia Facility
Moselle
Moselle
Moselle
Moselle
Moselle
PLANT
CODE
6073
2051
2051
8054
7960
7960
7960
7960
55373
55373
55373
55373
55373
55373
55373
55373
55218
55218
13213
13213
13213
13213
13213
13213
55219
55219
55219
55219
55219
55219
55219
55219
55663
55663
55410
55410
55410
55451
55451
55451
2070
2070
2070
2070
2070
STACK/UNIT ID*
4B
1
2
1
KCT1
KCT2
KCT3
KCT4
CT1
CT2
CT3
CT4
CT5
CT6
CT7
CT8
H01
H02
AA-001
AA-002
AA-003
AA-004
AA-005
AA-006
S01
S02
SOS
S04
SOS
S06
S07
SOS
CTG-1
CTG-2
CT1
CT2
CIS
CTG-1
CTG-2
CTG-3
**4
1
2
3
5
2004
ALLOWANCES
ALLOCATED
0
26
50
3,282
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
35
76
42
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
13
101
133
12,309
49
48
49
49
1
1
1
1
1
1
1
1
3
3
0
0
2
2
2
2
1
1
1
1
1
1
1
1
0
0
0
0
0
0
1
1
10
170
367
205
0
ALLOWANCES
DEDUCTED
2
14
101
12,258
0
0
0
1
0
0
0
0
0
0
0
0
1
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
1
1
0
0
ALLOWANCES
CARRIED OVER
TO 2005
11
87
32
51
49
48
49
48
1
1
1
1
1
1
1
1
2
2
0
0
2
2
2
2
1
1
1
1
1
1
1
1
0
0
0
0
0
0
0
1
10
169
366
205
0
A, 48
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MS
MT
MT
MT
MT
MT
MT
MT
MT
MT
MT
MT
PLANT NAME
Natchez
R D Morrow
R D Morrow
Red Hills Generation Facility
Red Hills Generation Facility
Reliant Energy Choctaw County Gen
Reliant Energy Choctaw County Gen
Reliant Energy Choctaw County Gen
Rex Brown
Rex Brown
Rex Brown
Rex Brown
Silver Creek Generating Plant
Silver Creek Generating Plant
Silver Creek Generating Plant
Southaven Power, LLC
Southaven Power, LLC
Southaven Power, LLC
Sweatt Electric Generating Plant
Sweatt Electric Generating Plant
Sylvarena Generating Plant
Sylvarena Generating Plant
Sylvarena Generating Plant
TPS - McAdams
TPS - McAdams
Warren Peaking Power Facility
Warren Peaking Power Facility
Warren Peaking Power Facility
Warren Peaking Power Facility
Watson Electric Generating Plant
Watson Electric Generating Plant
Watson Electric Generating Plant
Watson Electric Generating Plant
Watson Electric Generating Plant
Basin Creek
Basin Creek
Basin Creek
Basin Creek
Basin Creek
Basin Creek
Basin Creek
Basin Creek
Basin Creek
Colstrip
Colstrip
PLANT
CODE
2052
6061
6061
55076
55076
55706
55706
55706
2053
2053
2053
2053
7988
7988
7988
55269
55269
55269
2048
2048
7989
7989
7989
55341
55341
55303
55303
55303
55303
2049
2049
2049
2049
2049
55866
55866
55866
55866
55866
55866
55866
55866
55866
6076
6076
STACK/UNIT ID*
1
1
2
AA001
AA002
CTG1
CTG2
CTG3
1A
1B
3
4
1
2
3
AA-001
AA-002
AA-003
1
2
1
2
3
CT01
CT02
AA-001
AA-002
AA-003
AA-004
1
2
3
4
5
EU1
EU2
EU3
EU4
EU5
EU6
EU7
EU8
EU9
1
2
2004
ALLOWANCES
ALLOCATED
2
4,800
5,254
0
0
0
0
0
6
6
41
159
0
0
0
0
0
0
78
86
0
0
0
0
0
0
0
0
0
172
180
273
7,525
15,415
0
0
0
0
0
0
0
0
0
7,859
7,870
HELD IN
ACCOUNTS AS
OF 3/1/2005
10
7,631
10,054
1,757
1,623
5
5
5
25
25
135
483
0
0
0
2
2
2
25
25
0
0
0
0
0
0
0
0
0
25
25
25
9,279
16,062
0
0
0
0
0
0
0
0
0
5,082
4,987
ALLOWANCES
DEDUCTED
0
5,146
5,648
1,530
1,399
0
0
0
0
0
0
1
0
0
0
1
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
8,838
14,998
0
0
0
0
0
0
0
0
0
5,057
4,933
ALLOWANCES
CARRIED OVER
TO 2005
10
2,485
4,406
227
224
5
5
5
25
25
135
482
0
0
0
1
1
2
25
25
0
0
0
0
0
0
0
0
0
25
25
25
441
1,064
0
0
0
0
0
0
0
0
0
25
54
A, 49
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
MT
MT
MT
MT
MT
MT
MT
MT
MT
MT
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
PLANT NAME
Colstrip
Colstrip
Glendive Generating Station
Hardin
J E Corette
Lewis & Clark
Northwestern Mt First Megawatts LLC
Northwestern Mt First Megawatts LLC
Silver Bow Generation Plant
Silver Bow Generation Plant
Asheville
Asheville
Asheville
Asheville
Belews Creek
Belews Creek
Buck
Buck
Buck
Buck
Buck
Cape Fear
Cape Fear
Cliffside
Cliffside
Cliffside
Cliffside
Cliffside
Dan River
Dan River
Dan River
Elizabethtown Power
Elizabethtown Power
Elizabethtown Power
G G Allen
G G Allen
G G Allen
G G Allen
G G Allen
L V Sutton
L V Sutton
L V Sutton
L V Sutton
Lee
Lee
PLANT
CODE
6076
6076
2176
55749
2187
6089
55781
55781
55797
55797
2706
2706
2706
2706
8042
8042
2720
2720
2720
2720
2720
2708
2708
2721
2721
2721
2721
2721
2723
2723
2723
10380
10380
10380
2718
2718
2718
2718
2718
2713
2713
2713
2713
2709
2709
STACK/UNIT ID*
3
4
GT-2
1
2
B1
EU1
EU2
EU1
EU2
1
2
3
4
1
2
5
6
7
8
9
5
6
1
2
3
4
5
1
2
3
CS1 (UNIT1.UNIT2)
UNIT1
UNIT2
1
2
3
4
5
CS0002 (1 , 2)
1
2
3
1
10
2004
ALLOWANCES
ALLOCATED
4,405
2,917
0
0
5,062
1,444
0
0
0
0
6,622
5,261
0
0
30,911
32,560
1,031
589
1,058
2,322
2,871
3,382
3,913
898
872
1,291
1,305
14,040
1,909
2,779
2,792
0
0
2,427
2,813
6,121
5,744
5,971
2,051
2,270
8,298
1,636
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
2,898
3,048
0
0
5,017
3,084
0
0
0
0
6,841
7,650
11
10
45,452
48,534
1,274
667
1,179
4,378
4,726
6,178
10,459
1,111
1,109
1,480
1,574
24,825
2,278
3,919
3,197
20
19
4,819
5,662
11,019
11,374
12,561
2,814
2,809
30,198
3,667
9
ALLOWANCES
DEDUCTED
2,586
3,023
0
0
3,584
1,166
0
0
0
0
6,741
7,550
2
2
42,321
45,982
147
137
793
3,920
4,283
6,078
6,992
666
926
1,263
1,270
23,558
890
990
2,529
20
19
4,579
5,331
10,465
10,781
8,932
2,708
2,709
13,533
2,031
2
ALLOWANCES
CARRIED OVER
TO 2005
312
25
0
0
1,433
1,918
0
0
0
0
100
100
9
8
3,131
2,552
1,127
530
386
458
443
100
3,467
445
183
217
304
1,267
1,388
2,929
668
0
0
240
331
554
593
3,629
106
100
16,665
1,636
7
A, 50
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
PLANT NAME
Lee
Lee
Lee
Lee
Lee
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lincoln
Lumberton Power
Lumberton Power
Lumberton Power
Marshall
Marshall
Marshall
Marshall
Mayo
Mayo
Mayo
Richmond County Plant
Richmond County Plant
Richmond County Plant
Richmond County Plant
Richmond County Plant
Richmond County Plant
Richmond County Plant
Richmond County Plant
Riverbend
Riverbend
Riverbend
Riverbend
Rocking ham Power
Rocking ham Power
PLANT
CODE
2709
2709
2709
2709
2709
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
7277
10382
10382
10382
2727
2727
2727
2727
6250
6250
6250
7805
7805
7805
7805
7805
7805
7805
7805
2732
2732
2732
2732
55116
55116
STACK/UNIT ID*
11
12
13
2
3
1
10
11
12
13
14
15
16
2
3
4
5
6
7
8
9
CS1 (UNIT1.UNIT2)
UNIT1
UNIT2
1
2
3
4
CS0005(1A, 1B)
1A
1B
1
2
3
4
5
6
7
8
10
7
8
9
CT1
CT2
2004
ALLOWANCES
ALLOCATED
0
0
0
1,685
5,764
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
8,765
9,265
15,864
15,136
12,785
12,785
0
0
0
0
0
0
0
0
2,626
2,152
2,113
2,267
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
10
10
10
2,424
8,814
13
18
17
18
17
18
12
13
13
13
14
14
17
17
17
17
18
23
16,352
20,025
32,729
44,500
13,880
13,880
13
13
13
13
0
14
13
13
3,361
2,592
2,977
4,531
2
2
ALLOWANCES
DEDUCTED
1
2
2
2,100
8,714
1
1
1
2
2
1
1
1
1
1
1
1
1
1
1
1
18
23
14,980
18,845
30,370
29,395
13,780
13,779
1
0
0
0
0
0
1
1
3,186
2,462
2,825
4,260
0
0
ALLOWANCES
CARRIED OVER
TO 2005
9
8
8
324
100
12
17
16
16
15
17
11
12
12
12
13
13
16
16
16
16
0
0
1,372
1,180
2,359
15,105
100
101
12
13
13
13
0
14
12
12
175
130
152
271
2
2
A, 51
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
PLANT NAME
Rocking ham Power
Rocking ham Power
Rocking ham Power
Rosemary Power Station
Rosemary Power Station
Rowan County Power, LLC
Rowan County Power, LLC
Rowan County Power, LLC
Rowan County Power, LLC
Rowan County Power, LLC
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
W H Weatherspoon
W H Weatherspoon
W H Weatherspoon
W H Weatherspoon
Antelope Valley
Antelope Valley
Coal Creek
Coal Creek
Coyote
Leland Olds
Leland Olds
Milton R Young
Milton R Young
R M Heskett
Stanton
Stanton
Beatrice
Beatrice
C W Burdick
C W Burdick
C W Burdick
Canaday
Cass County Station
Cass County Station
Gerald Gentleman Station
Gerald Gentleman Station
Gerald Whelan Energy Center
PLANT
CODE
55116
55116
55116
50555
50555
7826
7826
7826
7826
7826
2712
2712
2712
2712
2712
2712
2712
2712
2716
2716
2716
2716
6469
6469
6030
6030
8222
2817
2817
2823
2823
2790
2824
2824
8000
8000
2241
2241
2241
2226
55972
55972
6077
6077
60
STACK/UNIT ID*
CT3
CT4
CT5
1
2
1
2
3
4
5
1
2
CS0003 (3A, 3B)
3A
3B
CS0004 (4A, 4BO
4A
4B
CS0001 (1 , 2)
1
2
3
B1
B2
1
2
B1
1
2
B1
B2
B2
1
10
1
2
B-3
GT-2
GT-3
1
CT1
CT2
1
2
1
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
1 1 ,088
19,642
9,096
9,096
10,407
10,407
1,122
1,125
1,626
1 1 ,947
11,131
23,310
21,187
16,182
9,105
26,401
12,951
15,885
3,202
7,447
1,334
0
0
0
0
0
627
0
0
10,805
17,572
2,335
HELD IN
ACCOUNTS AS
OF 3/1/2005
2
2
3
0
0
14
15
15
9
5
41 ,095
43,236
18,951
17,308
1 1 ,034
21 ,255
1,739
1,737
2,505
12,320
10,517
15,742
1 1 ,469
21,478
15,532
35,359
25,651
10,621
6,728
7,870
926
10
10
9
9
9
107
0
0
19,797
21 ,302
3,344
ALLOWANCES
DEDUCTED
0
0
1
0
0
0
0
0
3
0
17,977
29,000
17,208
17,208
10,934
10,935
1,637
1,637
2,405
8,858
5,276
15,742
1 1 ,469
16,015
15,448
32,990
21 ,586
9,795
2,754
7,869
926
0
0
0
0
0
6
0
0
15,453
16,582
2,352
ALLOWANCES
CARRIED OVER
TO 2005
2
2
2
0
0
14
15
15
6
5
23,118
14,236
1,743
100
100
10,320
102
100
100
3,462
5,241
0
0
5,463
84
2,369
4,065
826
3,974
1
0
10
10
9
9
9
101
0
0
4,344
4,720
992
A, 52
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NE
NH
NH
NH
NH
NH
NH
NH
NH
NH
NH
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
PLANT NAME
Lon D Wright Power Plant
Lon D Wright Power Plant
Nebraska City
North Omaha
North Omaha
North Omaha
North Omaha
North Omaha
North Omaha
Platte
Rokeby
Rokeby
Salt Valley Generating Station
Salt Valley Generating Station
Salt Valley Generating Station
Sarpy County Station
Sarpy County Station
Sarpy County Station
Sarpy County Station
Sarpy County Station
Sheldon
Sheldon
Granite Ridge Energy
Granite Ridge Energy
Merrimack
Merrimack
Newington
Newington Power Facility
Newington Power Facility
Schiller
Schiller
Schiller
AES Red Oak
AES Red Oak
AES Red Oak
B L England
B L England
B L England
Bayonne Plant Holding, LLC
Bayonne Plant Holding, LLC
Bayonne Plant Holding, LLC
Bergen
Bergen
Bergen
Bergen
PLANT
CODE
2240
2240
6096
2291
2291
2291
2291
2291
2291
59
6373
6373
7887
7887
7887
2292
2292
2292
2292
2292
2277
2277
55170
55170
2364
2364
8002
55661
55661
2367
2367
2367
55239
55239
55239
2378
2378
2378
50497
50497
50497
2398
2398
2398
2398
STACK/UNIT ID*
SOT
8
1
CSOOOA (1 , 2, 3)
1
2
3
4
5
1
2
3
SVGS2
SVGS3
SVGS4
CT3
CT4A
CT4B
CT5A
CT5B
1
2
0001
0002
1
2
1
1
2
4
5
6
1
2
3
1
2
3
001001
002001
004001
1101
1201
1301
1401
2004
ALLOWANCES
ALLOCATED
0
2,044
13,194
2,388
3,287
3,208
3,849
4,647
2,927
0
0
0
0
0
0
0
0
0
0
2,168
2,280
0
0
4,288
9,242
1 1 ,663
0
0
1,514
1,457
1,643
0
0
0
3,811
4,931
2,420
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
10
5,536
15,805
5,594
8,019
8,263
8,554
8,786
5,228
5
5
5
5
5
8
0
0
0
0
3,209
3,312
3
3
9,508
21,570
19,302
61
48
2,522
2,791
2,707
3
3
3
12,627
1,700
5,078
3
2
3
5
3
13
4
ALLOWANCES
DEDUCTED
2
1,181
15,593
1,946
2,612
2,777
3,314
5,476
2,159
0
0
0
0
0
0
0
0
0
0
2,311
2,457
3
3
9,154
20,582
16,783
3
10
2,416
2,593
2,443
1
1
1
12,093
1,069
372
0
0
1
5
2
13
4
ALLOWANCES
CARRIED OVER
TO 2005
8
4,355
212
3,648
5,407
5,486
5,240
3,310
3,069
5
5
5
5
5
8
0
0
0
0
898
855
0
0
354
988
2,519
58
38
106
198
264
2
2
2
534
631
4,706
3
2
2
0
1
0
0
A, 53
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
PLANT NAME
Bergen
Bergen
Burlington Generating Station
Burlington Generating Station
Burlington Generating Station
Burlington Generating Station
Burlington Generating Station
Burlington Generating Station
Burlington Generating Station
Burlington Generating Station
Calpine Newark Cogeneration
Calpine Parlin
Calpine Parlin
Camden Plant Holding, LLC
Commonwealth Shore Power, LLC
Commonwealth Shore Power, LLC
Commonwealth Shore Power, LLC
Deepwater
Deepwater
Deepwater
Deepwater
Gilbert Generating Station
Gilbert Generating Station
Gilbert Generating Station
Gilbert Generating Station
Gilbert Generating Station
Hudson Generating Station
Hudson Generating Station
Kearny Generating Station
Kearny Generating Station
Kearny Generating Station
Kearny Generating Station
Kearny Generating Station
Kearny Generating Station
Liberty Generating Station
Liberty Generating Station
Liberty Generating Station
Linden Cogeneration Facility
Linden Generating Station
Linden Generating Station
Linden Generating Station
Linden Generating Station
Linden Generating Station
Linden Generating Station
Linden Generating Station
PLANT
CODE
2398
2398
2399
2399
2399
2399
2399
2399
2399
2399
50797
50799
50799
10751
56109
56109
56109
2384
2384
2384
2384
2393
2393
2393
2393
2393
2403
2403
2404
2404
2404
2404
2404
2404
55469
55469
55469
50006
2406
2406
2406
2406
2406
2406
2406
STACK/UNIT ID*
2101
2201
101
102
103
104
121
122
123
124
001001
001001
003001
002001
CT1
CT2
CT3
1
4
6
8
04
05
06
07
9
1
2
121
122
123
124
7
8
GT-1
GT-2
GT-3
004001
11
1101
12
1201
13
2
2101
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1,164
59
59
2,744
600
596
593
605
0
1,197
15,972
0
0
0
0
145
153
0
0
0
0
968
0
665
0
877
644
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
4
4
0
0
0
0
1
1
1
1
0
0
0
5
0
0
0
24
0
0
2,837
7
7
7
7
7
58
21 ,489
3
3
3
4
7
7
0
0
0
10
0
0
0
0
0
0
0
ALLOWANCES
DEDUCTED
4
4
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
18
0
0
2,781
2
2
2
2
2
45
21 ,467
0
0
0
0
4
3
0
0
0
7
0
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
0
0
0
0
0
0
1
1
1
1
0
0
0
5
0
0
0
6
0
0
56
5
5
5
5
5
13
22
3
3
3
4
3
4
0
0
0
3
0
0
0
0
0
0
0
A, 54
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NJ
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
PLANT NAME
Linden Generating Station
Linden Generating Station
Linden Generating Station
Linden Generating Station
Linden Generating Station
Mantua Creek Generating Project
Mantua Creek Generating Project
Mantua Creek Generating Project
Mercer Generating Station
Mercer Generating Station
Newark Bay Cogen
Newark Bay Cogen
North Jersey Energy Associates
North Jersey Energy Associates
Ocean Peaking Power, LP
Ocean Peaking Power, LP
Ocean Peaking Power, LP
Sayreville
Sewaren Generating Station
Sewaren Generating Station
Sewaren Generating Station
Sewaren Generating Station
Sherman Avenue
Sunoco Power Generation, LLC
Sunoco Power Generation, LLC
TXU Pedricktown Cogeneration Plant
Afton Generating Station
Bloomfield Generation
Bloomfield Generation
Cunningham
Cunningham
Cunningham
Cunningham
Deming Energy Facility
Deming Energy Facility
Eddy County Generating Station
Eddy County Generating Station
Evergreen Energy Facility
Evergreen Energy Facility
Four Corners Steam Elec Station
Four Corners Steam Elec Station
Four Corners Steam Elec Station
Four Corners Steam Elec Station
Four Corners Steam Elec Station
Lordsburg Generating Station
PLANT
CODE
2406
2406
2406
2406
2406
55291
55291
55291
2408
2408
50385
50385
10308
10308
55938
55938
55938
2390
2411
2411
2411
2411
7288
50561
50561
10099
55210
55458
55458
2454
2454
2454
2454
55343
55343
55252
55252
55705
55705
2442
2442
2442
2442
2442
7967
STACK/UNIT ID*
2201
5
6
7
8
01
02
03
1
2
1001
2001
1001
1002
OPP3
OPP4
OPP5
07
1
2
3
4
1
0001
0002
001001
0001
GT01
GT02
121B
122B
123T
124T
CTG1
CTG2
0001
0002
CTG-1
CTG-2
1
2
3
4
5
1
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
7,683
7,439
0
0
0
0
0
0
0
766
117
340
254
574
0
0
0
0
0
0
0
42
269
0
0
0
0
0
0
0
0
3,593
3,589
4,478
12,507
13,275
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
9
10
1
7
0
0
0
5,192
6,361
4
4
2
2
5
5
0
2
91
142
226
190
12
1
1
4
0
0
0
206
541
2
2
0
0
0
0
0
0
4,399
4,846
6,723
10,772
13,263
0
ALLOWANCES
DEDUCTED
0
9
10
0
7
0
0
0
5,168
6,341
0
0
1
1
0
0
0
1
69
137
168
169
1
0
0
1
0
0
0
1
3
0
0
0
0
0
0
0
0
1,399
1,345
2,223
6,198
9,607
0
ALLOWANCES
CARRIED OVER
TO 2005
0
0
0
1
0
0
0
0
24
20
4
4
1
1
5
5
0
1
22
5
58
21
11
1
1
3
0
0
0
205
538
2
2
0
0
0
0
0
0
3,000
3,501
4,500
4,574
3,656
0
A, 55
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
PLANT NAME
Lordsburg Generating Station
Maddox
Milagro
Milagro
Person Generating Project
Prewitt Escalante Generating Static
Pyramid Generating Station
Pyramid Generating Station
Pyramid Generating Station
Pyramid Generating Station
Reeves Generating Station
Reeves Generating Station
Reeves Generating Station
Rio Grande
Rio Grande
Rio Grande
San Juan
San Juan
San Juan
San Juan
Valencia Energy Facility
Valencia Energy Facility
Valencia Energy Facility
Valencia Energy Facility
Apex Generating Station
Apex Generating Station
Chuck Lenzie Generating Station
Chuck Lenzie Generating Station
Chuck Lenzie Generating Station
Chuck Lenzie Generating Station
Clark
Clark
Clark
Copper Mountain Power
Copper Mountain Power
El Dorado Energy
El Dorado Energy
El Dorado Energy
Fort Churchill
Fort Churchill
Harry Allen
Harry Allen
Harry Allen
Harry Allen
Las Vegas Cogeneration II, LLC
PLANT
CODE
7967
2446
54814
54814
55039
87
7975
7975
7975
7975
2450
2450
2450
2444
2444
2444
2451
2451
2451
2451
55802
55802
55802
55802
55514
55514
55322
55322
55322
55322
2322
2322
2322
55493
55493
55077
55077
55077
2330
2330
7082
7082
7082
7082
10761
STACK/UNIT ID*
2
051 B
1
2
GT-1
1
1
2
3
4
1
2
3
6
7
8
1
2
3
4
CTG1
CTG2
CTG3
CTG4
CTG01
CTG02
CTG-1
CTG-2
CTG-3
CTG-4
1
2
3
A01
A02
CP1 (EDE1.EDE2)
EDE1
EDE2
1
2
**3
**4
"5
**6
2
2004
ALLOWANCES
ALLOCATED
0
170
0
0
0
1,874
0
0
0
0
4
7
104
3
1
80
7,941
5,922
13,878
13,047
0
0
0
0
0
0
0
0
0
0
20
273
18
0
0
0
0
371
577
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
415
2
2
48
1,874
10
10
10
10
20
35
2,219
11
2
394
2,704
2,982
11,184
25,918
0
0
0
0
4
4
0
0
0
0
97
1,239
86
0
0
7
6
1,116
1,725
3
0
0
0
6
ALLOWANCES
DEDUCTED
0
2
1
1
0
1,228
0
0
0
0
0
0
0
1
1
1
2,449
2,980
4,811
5,940
0
0
0
0
2
2
0
0
0
0
0
0
0
0
0
4
3
9
6
0
0
0
0
1
ALLOWANCES
CARRIED OVER
TO 2005
0
413
1
1
48
646
10
10
10
10
20
35
2,219
10
1
393
255
2
6,373
19,978
0
0
0
0
2
2
0
0
0
0
97
1,239
86
0
0
3
3
1,107
1,719
3
0
0
0
5
A, 56
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NV
NY
NY
NY
NY
NY
NY
NY
NY
NY
PLANT NAME
Las Vegas Cogeneration II, LLC
Las Vegas Cogeneration II, LLC
Las Vegas Cogeneration II, LLC
Moapa Paiute Energy Center
Moapa Paiute Energy Center
Moapa Paiute Energy Center
Mohave
Mohave
North Valmy
North Valmy
REI Bighorn
REI Bighorn
Reid Gardner
Reid Gardner
Reid Gardner
Reid Gardner
Silverhawk
Silverhawk
Sunrise
Tracy
Tracy
Tracy
Tracy
Tracy
Tracy
Tri-Center Naniwa Energy
Tri-Center Naniwa Energy
Tri-Center Naniwa Energy
Tri-Center Naniwa Energy
Tri-Center Naniwa Energy
Tri-Center Naniwa Energy
TS Power Plant
TS Power Plant
TS Power Plant
TS Power Plant
TS Power Plant
23rd and 3rd
23rd and 3rd
74th Street
74th Street
74th Street
74th Street
AES Cayuga (Milliken)
AES Cayuga (Milliken)
AES Cayuga (Milliken)
PLANT
CODE
10761
10761
10761
55642
55642
55642
2341
2341
8224
8224
55687
55687
2324
2324
2324
2324
55841
55841
2326
2336
2336
2336
2336
2336
2336
55494
55494
55494
55494
55494
55494
56224
56224
56224
56224
56224
7910
7910
2504
2504
2504
2504
2535
2535
2535
STACK/UNIT ID*
3
4
5
1
2
3
1
2
1
2
BHG1
BHG2
1
2
3
4
A01
A03
1
1
2
3
4
5
6
CT1
CT2
CT3
CT4
CT5
CT6
001
002
003
004
005
2301
2302
030002(120,121, 122)
120
121
122
XS12(1,2)
1
2
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
26,660
26,556
6,960
4,262
0
0
2,173
2,202
2,125
2,814
0
0
50
15
46
314
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
447
449
447
4,928
5,215
HELD IN
ACCOUNTS AS
OF 3/1/2005
6
6
6
0
0
0
40,787
39,234
9,799
8,612
5
5
1,809
2,841
2,132
1,324
3
3
225
84
144
917
5
3
7
6
5
5
5
5
5
0
0
0
0
0
0
0
447
449
447
1,197
1,907
ALLOWANCES
DEDUCTED
1
1
1
0
0
0
21,613
21 ,967
7,196
1,851
3
3
215
269
235
1,017
1
1
0
1
1
161
0
0
2
0
0
0
0
0
0
0
0
0
0
0
0
0
101
101
102
1,167
1,877
ALLOWANCES
CARRIED OVER
TO 2005
5
5
5
0
0
0
19,174
17,267
2,603
6,761
2
2
1,594
2,572
1,897
307
2
2
225
83
143
756
5
3
5
6
5
5
5
5
5
0
0
0
0
0
0
0
346
348
345
30
30
A, 57
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
PLANT NAME
AES Greenidge
AES Greenidge
AES Greenidge
AES Greenidge
AES Hickling
AES Hickling
AES Hickling
AES Hickling
AES Hickling
AES Hickling
AES Jennison
AES Jennison
AES Jennison
AES Jennison
AES Jennison
AES Jennison
AES Somerset (Kintigh )
AES Westover (Goudey)
AES Westover (Goudey)
AES Westover (Goudey)
AES Westover (Goudey)
AG - Energy
AG - Energy
Allegany Station No. 133
Arthur Kill
Arthur Kill
Astoria Energy
Astoria Energy
Astoria Energy
Astoria Energy
Astoria Generating Station
Astoria Generating Station
Astoria Generating Station
Astoria Generating Station
Athens Generating Company
Athens Generating Company
Athens Generating Company
Batavia Energy
Bayswater Peaking Facility
Bayswater Peaking Facility
Bethlehem Energy Center (Albany)
Bethlehem Energy Center (Albany)
Bethlehem Energy Center (Albany)
Bethlehem Energy Center (Albany)
Bethlehem Energy Center (Albany)
PLANT
CODE
2527
2527
2527
2527
2529
2529
2529
2529
2529
2529
2531
2531
2531
2531
2531
2531
6082
2526
2526
2526
2526
10803
10803
10619
2490
2490
55375
55375
55375
55375
8906
8906
8906
8906
55405
55405
55405
54593
55699
55699
2539
2539
2539
2539
2539
STACK/UNIT ID*
CSG003 (4, 5)
4
5
6
CSH001 (1,2)
1
2
CSH002 (3, 4)
3
4
CSJ001 (1 , 2)
1
2
CSJ002 (3, 4)
3
4
1
CSW003(11, 12, 13)
11
12
13
1
2
00001
20
30
CT1
CT2
CT3
CT4
20
30
40
50
1
2
3
1
1
2
1
10001
10002
10003
2
2004
ALLOWANCES
ALLOCATED
982
980
3,185
725
725
895
933
650
676
724
724
13,889
792
780
3,288
0
0
0
1,478
2,367
0
0
0
0
1,554
3,024
2,376
2,700
0
0
0
0
0
0
1,801
0
0
0
1,556
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
3,767
14,326
0
0
0
0
0
0
0
0
4,803
0
0
11,621
2
2
3
3
5
0
0
0
0
2
820
1,020
1,420
3
3
3
0
2
6
490
0
0
0
545
ALLOWANCES
DEDUCTED
0
3,737
13,661
0
0
0
0
0
0
0
0
4,744
0
0
11,591
2
1
0
2
2
0
0
0
0
0
711
887
1,234
2
2
2
0
0
4
475
0
0
0
542
ALLOWANCES
CARRIED OVER
TO 2005
0
30
665
0
0
0
0
0
0
0
0
59
0
0
30
0
1
3
1
3
0
0
0
0
2
109
133
186
1
1
1
0
2
2
15
0
0
0
3
A, 58
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
PLANT NAME
Bethlehem Energy Center (Albany)
Bethlehem Energy Center (Albany)
Bethpage Energy Center
Bethpage Energy Center
Bethpage Energy Center
Binghamton Cogen Plant
Black Rock Facility
Bowline Generating Station
Bowline Generating Station
Bowline Generating Station
Bowline Generating Station
Bowline Generating Station
Brentwood
Brooklyn Navy Yard Cogeneration
Brooklyn Navy Yard Cogeneration
Caithness Bellport Energy Center
Carr Street Generating Station
Carr Street Generating Station
Carthage Energy
Castleton
Charles Poletti
CRN Bethpage 3rd Turbine, Inc.
Dunkirk
Dunkirk
Dunkirk
Dunkirk
Dunkirk
Dynegy Danskammer
Dynegy Danskammer
Dynegy Danskammer
Dynegy Danskammer
Dynegy Roseton
Dynegy Roseton
E F Barrett
E F Barrett
East River
East River
East River
East River
Equus Freeport Power Generating Station
Far Rockaway
Freeport Power Plant No. 2
Fulton Cogeneration Associates
Glenwood
Glenwood
PLANT
CODE
2539
2539
50292
50292
50292
55600
10331
2625
2625
2625
2625
2625
7912
54914
54914
56234
50978
50978
10620
10190
2491
50292
2554
2554
2554
2554
2554
2480
2480
2480
2480
8006
8006
2511
2511
2493
2493
2493
2493
56032
2513
2679
54138
2514
2514
STACK/UNIT ID*
3
4
GT2
GTS
GT4
1
1
1
2
3A
3B
3C
BW01
1
2
0001
A
B
1
1
001
GT1
1
2
CS0003 (3, 4)
3
4
1
2
3
4
1
2
10
20
1
2
60
70
0001
40
5
01GTDB
40
50
2004
ALLOWANCES
ALLOCATED
1,593
1,687
0
0
0
0
0
4,240
4,241
0
0
0
0
0
0
0
0
0
0
0
6,438
0
2,843
3,229
5,292
5,906
948
920
3,129
6,030
15,584
14,912
2,372
2,337
0
0
1,430
1,033
0
469
0
0
939
903
HELD IN
ACCOUNTS AS
OF 3/1/2005
476
655
0
0
0
0
0
1,972
373
0
0
0
0
15
12
0
2
3
4
15
3,312
1
6,019
6,175
0
19,961
53
120
3,908
6,226
12,000
1 1 ,838
272
312
0
0
4,290
3,227
0
5
0
1
16
9
ALLOWANCES
DEDUCTED
471
650
0
0
0
0
0
1,904
306
0
0
0
0
14
11
0
2
2
1
5
1,275
1
5,732
5,881
0
19,011
19
86
3,830
6,092
11,661
1 1 ,500
193
193
0
0
403
167
0
1
0
0
1
1
ALLOWANCES
CARRIED OVER
TO 2005
5
5
0
0
0
0
0
68
67
0
0
0
0
1
1
0
0
1
3
10
2,037
0
287
294
0
950
34
34
78
134
339
338
79
119
0
0
3,887
3,060
0
4
0
1
15
8
A, 59
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
PLANT NAME
Glenwood Landing Energy Center
Glenwood Landing Energy Center
Harlem River Yard
Harlem River Yard
Hawkeye Energy Greenport, LLC
Hell Gate
Hell Gate
Huntley Power
Huntley Power
Huntley Power
Huntley Power
Huntley Power
Huntley Power
Huntley Power
Huntley Power
Ilion Energy Center
Indeck-Corinth Energy Center
Indeck-Olean Energy Center
Indeck-Oswego Energy Center
Indeck-Silver Springs Energy Center
Indeck-Yerkes Energy Center
Independence
Independence
Independence
Independence
KIAC Cogeneration
Lockport
Lockport
Lockport
Lockport Merchant Facility
Lockport Merchant Facility
Lovett Generating Station
Lovett Generating Station
Lovett Generating Station
Massena Energy Facility
Medford Power Project
North 1st
Northport
Northport
Northport
Northport
Onondaga Cogeneration
Onondaga Cogeneration
Oswego Harbor Power
Oswego Harbor Power
PLANT
CODE
7869
7869
7914
7914
55969
7913
7913
2549
2549
2549
2549
2549
2549
2549
2549
50459
50458
54076
50450
50449
50451
54547
54547
54547
54547
54114
54041
54041
54041
55531
55531
2629
2629
2629
54592
56101
7915
2516
2516
2516
2516
50855
50855
2594
2594
STACK/UNIT ID*
UGT012
UGT013
HR01
HR02
U-01
HG01
HG02
CS0002 (63, 64, 65, 66)
63
64
65
66
CS0001 (67, 68)
67
68
1
1
1
1
1
1
1
2
3
4
03
011854
011855
011856
1
2
3
4
5
001
CTG-01
NO1
1
2
3
4
1
2
3
4
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
2,657
2,664
2,693
2,729
5,775
5,381
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
225
4,569
4,988
0
0
0
8,323
10,130
11,122
5,794
0
0
90
398
HELD IN
ACCOUNTS AS
OF 3/1/2005
4
4
0
0
13
0
0
0
0
0
12,488
20,623
0
1
11
63
67
15
27
2
2
2
2
0
0
0
0
0
0
5
5,054
5,132
0
0
0
7,871
8,360
6,372
5,970
4
2
0
0
ALLOWANCES
DEDUCTED
1
1
0
0
7
0
0
0
0
0
1 1 ,893
19,641
0
0
4
6
0
0
0
1
1
1
1
0
0
0
0
0
0
1
4,751
4,530
0
0
0
7,768
8,221
6,333
5,777
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
3
3
0
0
6
0
0
0
0
0
595
982
0
1
7
57
67
15
27
1
1
1
1
0
0
0
0
0
0
4
303
602
0
0
0
103
139
39
193
4
2
0
0
A, 60
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
PLANT NAME
Oswego Harbor Power
Oswego Harbor Power
Port Jefferson Energy Center
Port Jefferson Energy Center
Port Jefferson Energy Center
Port Jefferson Energy Center
Port Jefferson Energy Center
Port Jefferson Energy Center
Pouch Terminal
PPL Edgewood Energy
PPL Edgewood Energy
PPL Shoreham Energy
PPL Shoreham Energy
Project Orange Facility
Project Orange Facility
Ravenswood Generating Station
Ravenswood Generating Station
Ravenswood Generating Station
Ravenswood Generating Station
Rensselaer Cogen
Richard M Flynn (Holtsville)
Rochester 7 - Russell Station
Rochester 7 - Russell Station
Rochester 7 - Russell Station
Rochester 7 - Russell Station
Rochester 7 - Russell Station
Rochester 7 - Russell Station
S A Carlson
S A Carlson
S A Carlson
S A Carlson
S A Carlson
S A Carlson
S A Carlson
South Glens Falls Energy
Sterling Energy Facility
Vernon Boulevard
Vernon Boulevard
Waterside
Waterside
Waterside
Waterside
Waterside
Waterside
WPS Empire State, Inc-Syracuse
PLANT
CODE
2594
2594
2517
2517
2517
2517
2517
2517
7911
55786
55786
55787
55787
54425
54425
2500
2500
2500
2500
54034
7314
2642
2642
2642
2642
2642
2642
2682
2682
2682
2682
2682
2682
2682
10618
50744
7909
7909
2502
2502
2502
2502
2502
2502
10621
STACK/UNIT ID*
5
6
1
2
3
4
UGT002
UGT003
PT01
CT01
CT02
CT01
CT02
001
002
10
20
30
UCC001
1GTDBS
001
CS1 (1,2)
1
2
CS2 (3, 4)
3
4
CS0002(10, 11)
10
11
12
20
CS0001 (9,12)
9
1
00001
VB01
VB02
CS0002 (61 , 62)
61
62
CS0003 (80, 90)
80
90
1
2004
ALLOWANCES
ALLOCATED
17,242
4,808
475
498
4,397
5,181
0
0
0
0
0
0
0
0
0
3,165
2,678
4,992
0
0
0
1,093
1,626
1,586
2,213
673
424
1,276
0
664
0
0
0
0
431
507
1,128
1,234
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
1,926
467
0
0
3,993
5,169
4
4
0
0
0
2
2
1
1
1,541
1,374
3,668
5
4
149
5,958
5,882
7,635
7,711
971
0
2,050
10
1,162
4
0
0
0
431
507
1,128
1,234
3
ALLOWANCES
DEDUCTED
1,834
445
0
0
3,901
5,128
1
1
0
0
0
1
1
0
0
1,538
1,369
3,662
4
0
94
5,865
5,865
7,588
7,588
969
0
1,918
0
1,159
1
0
0
0
1
1
2
1
0
ALLOWANCES
CARRIED OVER
TO 2005
92
22
0
0
92
41
3
3
0
0
0
1
1
1
1
3
5
6
1
4
55
93
17
47
123
2
0
132
10
3
3
0
0
0
430
506
1,126
1,233
3
A, 61
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
NY
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
PLANT NAME
WPS Niagara Generation, LLC
AMP-Ohio Gas Turbines Bowling Green
AMP-Ohio Gas Turbines Galion
AMP-Ohio Gas Turbines Napoleon
Ashtabula
Avon Lake Power Plant
Avon Lake Power Plant
Bay Shore
Bay Shore
Bay Shore
Bay Shore
Bay Shore
Cardinal
Cardinal
Cardinal
Conesville
Conesville
Conesville
Conesville
Conesville
Conesville
Conesville
Conesville
Darby Electric Generating Station
Darby Electric Generating Station
Darby Electric Generating Station
Darby Electric Generating Station
Darby Electric Generating Station
Darby Electric Generating Station
Dresden Energy Facility
Dresden Energy Facility
Eastlake
Eastlake
Eastlake
Eastlake
Eastlake
Edgewater (2857)
Frank M Tait Station
Frank M Tait Station
Frank M Tait Station
Fremont Energy Center
Fremont Energy Center
Gen J M Gavin
Gen J M Gavin
Greenville Electric Gen Station
PLANT
CODE
50202
55262
55263
55264
2835
2836
2836
2878
2878
2878
2878
2878
2828
2828
2828
2840
2840
2840
2840
2840
2840
2840
2840
55247
55247
55247
55247
55247
55247
55350
55350
2837
2837
2837
2837
2837
2857
2847
2847
2847
55701
55701
8102
8102
55228
STACK/UNIT ID*
1
CT1
CT1
CT1
7
10
12
1
CSS (2, 3, 4)
2
3
4
1
2
3
CS012(1,2)
1
2
3
4
CS056 (5, 6)
5
6
CT1
CT2
CT3
CT4
CT5
CT6
1A
1B
1
2
3
4
5
13
1
2
3
CT01
CT02
1
2
G1CT1
2004
ALLOWANCES
ALLOCATED
0
0
0
0
7,220
2,254
15,199
4,719
4,495
4,277
7,038
14,778
16,526
17,301
1,814
2,110
2,370
21 ,031
9,025
9,394
0
0
0
0
0
0
0
0
3,366
3,725
4,319
6,258
16,605
2,179
0
0
0
0
0
34,099
34,738
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
1,027
1
1
1
3,608
3,765
26,600
2,857
2,025
2,436
3,147
45,623
30,503
51,116
7,083
6,829
13,468
48,377
7,123
7,420
0
0
0
0
0
0
0
0
4,665
4,472
4,592
6,649
43,861
0
4
4
4
0
0
17,272
33,865
0
ALLOWANCES
DEDUCTED
978
0
0
0
3,558
2,765
25,594
2,807
1,976
2,387
3,095
44,294
28,733
27,107
6,876
6,630
13,075
47,874
6,781
7,014
0
0
0
0
0
0
0
0
4,615
4,422
4,542
6,549
43,71 1
0
0
0
0
0
0
16,439
17,277
0
ALLOWANCES
CARRIED OVER
TO 2005
49
1
1
1
50
1,000
1,006
50
49
49
52
1,329
1,770
24,009
207
199
393
503
342
406
0
0
0
0
0
0
0
0
50
50
50
100
150
0
4
4
4
0
0
833
16,588
0
A, 62
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
PLANT NAME
Greenville Electric Gen Station
Greenville Electric Gen Station
Greenville Electric Gen Station
Greenville Electric Gen Station
Greenville Electric Gen Station
Greenville Electric Gen Station
Greenville Electric Gen Station
Hamilton Municipal Power Plant
Hanging Rock Energy Facility
Hanging Rock Energy Facility
Hanging Rock Energy Facility
Hanging Rock Energy Facility
J M Stuart
J M Stuart
J M Stuart
J M Stuart
Killen Station
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Lake Road
Lake Shore
Lima Energy Company
Lima Energy Company
Madison Generating Station
Madison Generating Station
Madison Generating Station
Madison Generating Station
Madison Generating Station
Madison Generating Station
Madison Generating Station
Madison Generating Station
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Muskingum River
Muskingum River
Muskingum River
Muskingum River
PLANT
CODE
55228
55228
55228
55228
55228
55228
55228
2917
55736
55736
55736
55736
2850
2850
2850
2850
6031
2876
2876
2876
2876
2876
2876
2908
2838
55635
55635
55110
55110
55110
55110
55110
55110
55110
55110
2832
2832
2832
2832
2832
2832
2872
2872
2872
2872
STACK/UNIT ID*
G1CT2
G2CT1
G2CT2
G3CT1
G3CT2
G4CT1
G4CT2
9
CTG1
CTG2
CTG3
CTG4
1
2
3
4
2
CS001 (1 , 2, 3, 4, 5)
1
2
3
4
5
6
18
GT1
GT2
1
2
3
4
5
6
7
8
CS056 (5-1 , 5-2, 6)
5-1
5-2
6
7
8
03014(1,2,3,4)
1
2
3
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
1,665
0
0
0
0
19,632
18,611
18,454
19,503
16,928
8,100
7,797
7,524
7,860
7,874
1,340
6,033
0
0
0
0
0
0
0
0
0
0
144
144
4,908
16,607
18,233
6,414
6,108
6,018
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
0
0
0
0
0
0
1,688
4
4
3
3
34,762
35,353
35,737
30,549
23,279
15,070
15,070
15,070
15,070
15,070
6,700
2,538
0
0
4
4
4
4
4
4
4
4
2,293
2,293
17,624
67,377
16,018
30,649
26,327
25,206
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
1,071
0
0
0
0
29,537
30,215
30,513
25,301
23,049
14,570
14,570
14,570
14,570
14,570
0
2,488
0
0
0
0
0
0
0
0
0
0
2,184
2,184
16,785
64,169
15,256
24,360
19,677
24,470
ALLOWANCES
CARRIED OVER
TO 2005
0
0
0
0
0
0
0
617
4
4
3
3
5,225
5,138
5,224
5,248
230
500
500
500
500
500
6,700
50
0
0
4
4
4
4
4
4
4
4
109
109
839
3,208
762
6,289
6,650
736
A, 63
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
PLANT NAME
Muskingum River
Muskingum River
Niles
Niles
Niles
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
O H Hutchings
Omega JV2 Bowling Green
Omega JV2 Hamilton
Picway
PSEG Waterford Energy Facility
PSEG Waterford Energy Facility
PSEG Waterford Energy Facility
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
Richard Gorsuch
Richard Gorsuch
Richard Gorsuch
Richard Gorsuch
Richard Gorsuch
Richland Peaking Station
Richland Peaking Station
Richland Peaking Station
Robert P Mone
Robert P Mone
Robert P Mone
Rolling Hills Generating LLC
Rolling Hills Generating LLC
Rolling Hills Generating LLC
Rolling Hills Generating LLC
Rolling Hills Generating LLC
PLANT
CODE
2872
2872
2861
2861
2861
2848
2848
2848
2848
2848
2848
2848
2848
2848
7783
7782
2843
55503
55503
55503
2864
2864
2864
2864
2864
2864
2864
2864
2864
7253
7253
7253
7253
7253
2880
2880
2880
7872
7872
7872
55401
55401
55401
55401
55401
STACK/UNIT ID*
4
5
XS12(1,2)
1
2
CS0001 (H-1 , H-2)
H-1
H-2
CS0002 (H-3, H-4)
H-3
H-4
CS0003 (H-5, H-6)
H-5
H-6
P001
P001
9
1
2
3
CS0001 (1 , 2, 3, 4, 5, 6, 7, 8)
1
2
3
4
5
6
7
8
CS0001 (1 , 2, 3, 4)
1
2
3
4
CTG4
CTG5
CTG6
1
2
3
CT-1
CT-2
CT-3
CT-4
CT-5
2004
ALLOWANCES
ALLOCATED
5,080
17,450
2,995
3,924
1,736
1,671
1,603
1,623
1,630
1,660
0
0
2,128
0
0
0
1,233
1,206
1,246
1,275
1,327
1,325
4,648
5,361
6,152
5,064
6,880
1,404
0
0
0
0
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
23,833
51 ,742
6,824
9,216
204
166
658
954
788
1,046
1
1
9,717
1
1
1
0
0
0
0
191
363
15,503
11,118
7,598
7,598
7,598
7,598
5
5
5
5
5
5
0
0
0
0
0
ALLOWANCES
DEDUCTED
22,410
50,234
5,824
8,216
194
156
642
931
769
1,020
0
0
9,378
0
0
0
0
0
0
0
134
321
15,342
10,978
7,416
7,416
7,416
7,416
0
0
0
0
0
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
1,423
1,508
1,000
1,000
10
10
16
23
19
26
1
1
339
1
1
1
0
0
0
0
57
42
161
140
182
182
182
182
5
5
5
5
5
5
0
0
0
0
0
A, 64
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OK
OK
OK
OK
OK
OK
OK
OK
PLANT NAME
Tait Electric Generating Station
Tait Electric Generating Station
Tait Electric Generating Station
Tait Electric Generating Station
Troy Energy, LLC
Troy Energy, LLC
Troy Energy, LLC
Troy Energy, LLC
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Zimmer
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Walter C Beckjord
Washington Energy Facility
Washington Energy Facility
West Lorain
West Lorain
West Lorain
West Lorain
West Lorain
Woodsdale
Woodsdale
Woodsdale
Woodsdale
Woodsdale
Woodsdale
Anadarko
Anadarko
Anadarko
Arbuckle
Chouteau Power Plant
Chouteau Power Plant
Comanche (8059)
Comanche (8059)
PLANT
CODE
55248
55248
55248
55248
55348
55348
55348
55348
2866
2866
2866
2866
2866
2866
2866
2866
2866
6019
2830
2830
2830
2830
2830
2830
55397
55397
2869
2869
2869
2869
2869
7158
7158
7158
7158
7158
7158
3006
3006
3006
2947
7757
7757
8059
8059
STACK/UNIT ID*
CT4
CT5
CT6
CT7
1
2
3
4
CS0001 (1 , 2)
1
2
CS0002 (3, 4)
3
4
5
6
7
1
1
2
3
4
5
6
CT1
CT2
2
3
4
5
6
**GT1
**GT2
"GTS
**GT4
"GTS
"GT6
3
7
8
ARB
1
2
CP001 (7251 , 7252)
7251
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
6,239
5,472
6,238
5,529
10,422
19,953
18,639
16,154
1,834
1,859
2,530
3,262
3,858
9,925
0
0
0
0
0
0
0
294
294
294
294
294
294
0
0
0
45
0
0
333
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
0
0
0
7
7
8
8
9,392
10,891
7,138
8,947
14,396
38,936
38,314
27,890
3,618
3,819
6,076
6,392
19,280
41,941
7
8
3
3
3
3
3
2
2
2
2
2
2
5
4
4
135
22
22
1,647
ALLOWANCES
DEDUCTED
0
0
0
0
1
0
1
1
9,295
10,738
7,037
8,849
14,246
38,786
38,164
21,638
3,446
3,637
5,787
6,088
18,363
36,998
0
0
1
1
1
1
1
0
0
0
0
0
0
0
0
0
0
1
1
3
ALLOWANCES
CARRIED OVER
TO 2005
0
0
0
0
6
7
7
7
97
153
101
98
150
150
150
6,252
172
182
289
304
917
4,943
7
8
2
2
2
2
2
2
2
2
2
2
2
5
4
4
135
21
21
1,644
A, 65
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
PLANT NAME
Comanche (8059)
Conoco
Conoco
Geneva Oklahoma 1
Geneva Oklahoma 1
Grand River Dam Authority
Grand River Dam Authority
Green Country Energy, LLC
Green Country Energy, LLC
Green Country Energy, LLC
Horseshoe Lake
Horseshoe Lake
Horseshoe Lake
Horseshoe Lake
Horseshoe Lake
Hugo
McClain Energy Facility
McClain Energy Facility
Mooreland
Mooreland
Mooreland
Muskogee
Muskogee
Muskogee
Muskogee
Mustang
Mustang
Mustang
Mustang
Northeastern
Northeastern
Northeastern
Northeastern
Northeastern
Northeastern
Oneta Energy Center
Oneta Energy Center (Panda Oneta)
Oneta Energy Center (Panda Oneta)
Oneta Energy Center (Panda Oneta)
Ponca
Ponca
Ponca
Redbud Power Plant
Redbud Power Plant
Redbud Power Plant
PLANT
CODE
8059
7185
7185
55868
55868
165
165
55146
55146
55146
2951
2951
2951
2951
2951
6772
55457
55457
3008
3008
3008
2952
2952
2952
2952
2953
2953
2953
2953
2963
2963
2963
2963
2963
2963
55225
55225
55225
55225
762
762
762
55463
55463
55463
STACK/UNIT ID*
7252
**1
**2
CTG-1
CTG-2
1
2
CTGEN1
CTGEN2
CTGEN3
10
6
7
8
9
1
CT1
CT2
1
2
3
3
4
5
6
1
2
3
4
3301 A
3301 B
3302
CS1 00 (331 3, 3314)
3313
3314
CTG-2
CTG-1
CTG-3
CTG-4
2
3
4
CT-01
CT-02
CT-03
2004
ALLOWANCES
ALLOCATED
2
222
222
0
0
14,642
8,396
0
0
0
0
173
231
313
0
1 1 ,877
0
0
0
44
7
141
9,311
8,277
14,425
32
26
1
163
0
0
5,935
13,833
14,884
0
0
0
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
11
1,076
1,070
0
0
17,535
8,512
4
4
4
30
858
1,090
1,500
30
13,355
46
46
5
199
33
703
11,054
9,516
25,014
160
130
1
807
1,720
1,721
2,679
19,389
16,616
0
0
1
1
0
0
0
0
0
1
ALLOWANCES
DEDUCTED
0
9
9
0
0
12,423
3,995
1
1
2
0
1
1
1
0
9,171
3
3
0
0
0
0
9,704
8,386
7,750
0
0
1
1
2
2
1
14,547
15,284
0
0
1
1
0
0
0
0
0
1
ALLOWANCES
CARRIED OVER
TO 2005
11
1,067
1,061
0
0
5,112
4,517
3
3
2
30
857
1,089
1,499
30
4,184
43
43
5
199
33
703
1,350
1,130
17,264
160
130
0
806
1,718
1,719
2,678
4,842
1,332
0
0
0
0
0
0
0
0
0
0
A, 66
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OK
OR
OR
OR
OR
OR
OR
OR
OR
OR
OR
OR
OR
OR
OR
OR
OR
OR
OR
PA
PA
PLANT NAME
Redbud Power Plant
Riverside (4940)
Riverside (4940)
Seminole (2956)
Seminole (2956)
Seminole (2956)
Sooner
Sooner
Southwestern
Southwestern
Southwestern
Southwestern
Southwestern
Spring Creek Power Plant
Spring Creek Power Plant
Spring Creek Power Plant
Spring Creek Power Plant
Tenaska Kiamichi Generating Station
Tenaska Kiamichi Generating Station
Tenaska Kiamichi Generating Station
Tenaska Kiamichi Generating Station
Tulsa
Tulsa
Tulsa
Tulsa
Boardman
Cob Energy Facility
Cob Energy Facility
Cob Energy Facility
Cob Energy Facility
Coyote Springs
Coyote Springs
Hermiston
Hermiston
Hermiston Power Plant
Hermiston Power Plant
Klamath Cogeneration Project
Klamath Cogeneration Project
Klamath Energy LLC
Klamath Energy LLC
Klamath Energy LLC
Klamath Energy LLC
Morrow Power Project
AES Hoytdale
AES Hoytdale
PLANT
CODE
55463
4940
4940
2956
2956
2956
6095
6095
2964
2964
2964
2964
2964
55651
55651
55651
55651
55501
55501
55501
55501
2965
2965
2965
2965
6106
55962
55962
55962
55962
7350
7350
54761
54761
55328
55328
55103
55103
55544
55544
55544
55544
55683
55631
55631
STACK/UNIT ID*
CT-04
1501
1502
1
2
3
1
2
8002
8003
CP001 801 N, 801 S, 8002, 8003)
801 N
801 S
CT-01
CT-02
CT-03
CT-04
CTGDB1
CTGDB2
CTGDB3
CTGDB4
CP001 (1402,1403, 1404)
1402
1403
1404
1SG
1
2
3
4
CTG1
CTG2
1
2
CTG-1
CTG-2
CT1
CT2
GT1
GT2
GTS
GT4
1
1
2
2004
ALLOWANCES
ALLOCATED
0
519
285
412
453
494
10,471
9,979
15
164
3
0
0
0
0
0
0
0
0
0
98
4
58
13,377
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
1,636
1,132
2,044
2,249
2,351
13,762
13,503
74
738
14
5
10
10
9
9
2
2
2
2
488
19
288
12,404
0
0
0
0
4
1
5
5
5
5
3
3
2
2
2
2
0
0
0
ALLOWANCES
DEDUCTED
0
1
4
4
5
4
10,189
8,573
0
1
0
0
0
0
0
0
2
2
2
2
1
0
0
12,390
0
0
0
0
3
1
4
4
4
4
1
2
0
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
0
1,635
1,128
2,040
2,244
2,347
3,573
4,930
74
737
14
5
10
10
9
9
0
0
0
0
487
19
288
14
0
0
0
0
1
0
1
1
1
1
2
1
2
2
2
2
0
0
0
A, 67
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PLANT NAME
AES Hoytdale
AES Ironwood
AES Ironwood
Allegheny Energy Unit 1 and Unit 2
Allegheny Energy Unit 1 and Unit 2
Allegheny Energy Unit 8 and Unit 9
Allegheny Energy Unit 8 and Unit 9
Allegheny Energy Units 3, 4 & 5
Allegheny Energy Units 3, 4 & 5
Armstrong Energy Ltd Part
Armstrong Energy Ltd Part
Armstrong Energy Ltd Part
Armstrong Energy Ltd Part
Armstrong Power Station
Armstrong Power Station
Bethlehem Power Plant
Bethlehem Power Plant
Bethlehem Power Plant
Bethlehem Power Plant
Bethlehem Power Plant
Bethlehem Power Plant
Bruce Mansfield
Bruce Mansfield
Bruce Mansfield
Brunner Island
Brunner Island
Brunner Island
Brunner Island
Brunot Island Power Station
Brunot Island Power Station
Brunot Island Power Station
Chambersburg Units 12 and 13
Chambersburg Units 12 and 13
Cheswick
Conemaugh
Conemaugh
Cromby
Cromby
Delaware
Delaware
Delta Power Plant
Delta Power Plant
Delta Power Plant
Delta Power Plant
Delta Power Plant
PLANT
CODE
55631
55337
55337
55196
55196
55377
55377
55710
55710
55347
55347
55347
55347
3178
3178
55690
55690
55690
55690
55690
55690
6094
6094
6094
3140
3140
3140
3140
3096
3096
3096
55654
55654
8226
3118
3118
3159
3159
3160
3160
55524
55524
55524
55524
55524
STACK/UNIT ID*
3
0001
0002
1
2
8
9
3
4
1
2
3
4
1
2
1
2
3
5
6
7
1
2
3
CS102(1,2)
1
2
3
2A
2B
3
12
13
1
1
2
1
2
71
81
1
2
3
5
6
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
0
0
6,215
6,654
0
0
0
0
0
0
12,717
14,069
14,473
1 1 ,972
13,414
23,209
0
0
0
0
0
16,891
25,938
28,752
2,203
2,110
743
537
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
2
2
1
1
1
1
2
3
2
3
2
3
16,575
16,770
12
11
13
12
12
13
12,867
15,221
14,081
19,641
21 ,820
50,614
10
11
10
1
1
41 ,982
4,464
3,918
6,007
1,073
0
80
0
0
0
0
0
ALLOWANCES
DEDUCTED
0
1
1
0
0
0
0
0
1
0
0
1
1
16,375
16,570
5
5
6
5
5
6
1 1 ,973
12,084
13,931
19,641
21,819
50,613
0
0
0
0
0
40,982
3,865
3,339
5,824
1,041
0
71
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
0
1
1
1
1
1
1
2
2
2
3
1
2
200
200
7
6
7
7
7
7
894
3,137
150
0
1
1
10
11
10
1
1
1,000
599
579
183
32
0
9
0
0
0
0
0
A, 68
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PLANT NAME
Delta Power Plant
Eddystone
Eddystone
Eddystone
Eddystone
Eddystone
Elrama
Elrama
Elrama
Elrama
Elrama
Fairless Energy, LLC
Fairless Energy, LLC
Fairless Energy, LLC
Fairless Energy, LLC
Fayette Energy Facility
Fayette Energy Facility
FPL Energy Marcus Hook, LP
FPL Energy Marcus Hook, LP
FPL Energy Marcus Hook, LP
Grays Ferry Cogen Partnership
Handsome Lake Energy
Handsome Lake Energy
Handsome Lake Energy
Handsome Lake Energy
Handsome Lake Energy
Handsome Lake Energy
Handsome Lake Energy
Handsome Lake Energy
Handsome Lake Energy
Handsome Lake Energy
Hatfields Ferry Power Station
Hatfields Ferry Power Station
Hatfields Ferry Power Station
Hatfields Ferry Power Station
Homer City
Homer City
Homer City
Hunlock Power Station
Hunlock Power Station
Hunterstown
Hunterstown
Hunterstown
Keystone
Keystone
PLANT
CODE
55524
3161
3161
3161
3161
3161
3098
3098
3098
3098
3098
55298
55298
55298
55298
55516
55516
55801
55801
55801
54785
55233
55233
55233
55233
55233
55233
55233
55233
55233
55233
3179
3179
3179
3179
3122
3122
3122
3176
3176
3110
3110
3110
3136
3136
STACK/UNIT ID*
7
1
2
CS034 (3, 4)
3
4
CS001 (1 , 2, 3, 4)
1
2
3
4
1A
1B
2A
2B
CTG1
CTG2
0001
0002
0003
2
EU-1A
EU-1B
EU-2A
EU-2B
EU-3A
EU-3B
EU-4A
EU-4B
EU-5A
EU-5B
XS123(1,2, 3)
1
2
3
1
2
3
4
6
CT101
CT201
CT301
1
2
2004
ALLOWANCES
ALLOCATED
0
2,845
3,005
1,895
2,011
1,650
1,616
1,568
2,580
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
16,313
16,094
17,365
17,759
16,314
27,629
0
2,257
0
0
0
28,219
30,045
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
3,500
3,098
1,048
843
1,565
1,921
1,748
2,410
2
2
2
2
3
3
2
2
2
2
0
0
0
0
0
0
0
0
0
0
63,161
32,026
55,063
72,034
77,944
4,292
0
3,832
5
5
5
91,143
80,952
ALLOWANCES
DEDUCTED
0
3,397
3,008
993
843
565
921
749
1,410
1
1
1
1
1
0
1
1
1
2
0
0
0
0
0
0
0
0
0
0
62,565
31 ,428
54,466
70,040
75,747
4,170
0
3,831
0
0
0
90,781
80,528
ALLOWANCES
CARRIED OVER
TO 2005
0
103
90
55
0
1,000
1,000
999
1,000
1
1
1
1
2
3
1
1
1
0
0
0
0
0
0
0
0
0
0
0
596
598
597
1,994
2,197
122
0
1
5
5
5
362
424
A, 69
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PLANT NAME
Liberty Electric Power Plant
Liberty Electric Power Plant
Lower Mount Bethel Energy
Lower Mount Bethel Energy
Martins Creek
Martins Creek
Martins Creek
Martins Creek
Martins Creek
Mitchell Power Station
Mitchell Power Station
Mitchell Power Station
Mitchell Power Station
Montour
Montour
Mt. Carmel Cogeneration
New Castle
New Castle
New Castle
North East Cogeneration Plant
North East Cogeneration Plant
Ontelaunee Energy Center
Ontelaunee Energy Center
PEI Power Power Corporation
Portland
Portland
Portland
Schuylkill
Seward
Seward
Seward
Shawville
Shawville
Shawville
Shawville
Shawville
Springdale Power Station
Springdale Power Station
Sunbury
Sunbury
Sunbury
Sunbury
Sunbury
Sunbury
Sunbury
PLANT
CODE
55231
55231
55667
55667
3148
3148
3148
3148
3148
3181
3181
3181
3181
3149
3149
10343
3138
3138
3138
54571
54571
55193
55193
50279
3113
3113
3113
3169
3130
3130
3130
3131
3131
3131
3131
3131
3182
3182
3152
3152
3152
3152
3152
3152
3152
STACK/UNIT ID*
0001
0002
CT01
CT02
CS102(1,2)
1
2
3
4
1
2
3
33
1
2
SG-101
3
4
5
001
002
CT1
CT2
2
1
2
5
1
CS1 (1,2)
1
2
1
2
CS1 (3, 4)
3
4
77
88
CS1 (1A, 1B)
1A
1B
CS2 (2A, 2B)
2A
2B
3
2004
ALLOWANCES
ALLOCATED
0
0
0
0
5,457
5,528
13,183
12,127
0
1
0
3,529
24,191
24,680
0
2,843
2,817
4,514
0
0
0
0
0
2,560
4,413
0
572
0
0
4,430
4,456
6,111
6,070
0
0
1,818
1,817
1,818
1,818
4,029
HELD IN
ACCOUNTS AS
OF 3/1/2005
11
11
1
1
7,644
8,078
4,203
2,759
25
27
25
1,366
64,484
62,496
504
7,724
6,303
11,564
0
0
1
1
0
12,359
18,436
19
499
1,314
1,885
9,282
10,480
14,003
10,715
0
0
3,638
2,290
3,224
3,563
8,121
ALLOWANCES
DEDUCTED
2
2
1
1
7,643
8,077
4,202
2,758
2
1
0
1,266
64,483
62,495
504
6,724
5,303
10,564
0
0
1
1
0
12,317
18,395
9
184
1,113
1,688
9,242
10,440
13,963
10,675
0
0
3,420
2,175
3,061
3,376
7,707
ALLOWANCES
CARRIED OVER
TO 2005
9
9
0
0
1
1
1
1
23
26
25
100
1
1
0
1,000
1,000
1,000
0
0
0
0
0
42
41
10
315
201
197
40
40
40
40
0
0
218
115
163
187
414
A, 70
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
PA
PA
PA
PA
PA
PA
PA
PA
PA
Rl
Rl
Rl
Rl
Rl
Rl
Rl
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
SC
PLANT NAME
Sunbury
Titus
Titus
Titus
Titus
Westwood
Williams Generation Co (Hazleton)
Williams Generation Co (Hazleton)
Williams Generation Co (Hazleton)
Manchester Street
Manchester Street
Manchester Street
Pawtucket Power Associates, LP
Rhode Island State Energy Partners
Rhode Island State Energy Partners
Tiverton Power Associates
Broad River Energy Center
Broad River Energy Center
Broad River Energy Center
Broad River Energy Center
Broad River Energy Center
Canadys Steam
Canadys Steam
Canadys Steam
Cherokee County Cogen
Columbia Energy Center (SC)
Columbia Energy Center (SC)
Cope Station
Cross
Cross
Cross
Cross
Darlington County
Darlington County
Dolphus M Grainger
Dolphus M Grainger
Genpower - Anderson
Genpower - Anderson
H B Robinson
Hagood
Jasper County Generating Facility
Jasper County Generating Facility
Jasper County Generating Facility
Jefferies
Jefferies
PLANT
CODE
3152
3115
3115
3115
3115
50611
10870
10870
10870
3236
3236
3236
54056
55107
55107
55048
55166
55166
55166
55166
55166
3280
3280
3280
55043
55386
55386
7210
130
130
130
130
3250
3250
3317
3317
55476
55476
3251
3285
7996
7996
7996
3319
3319
STACK/UNIT ID*
4
CS1 (1,2,3)
1
2
3
031
TURB2
TURB3
TURB4
10
11
9
1
RISEP1
RISEP2
1
CT-1
CT-2
CT-3
CT-4
CT-5
CAN1
CAN2
CANS
CCCP1
CT-1
CT-2
COP1
1
2
3
4
12
13
1
2
CTG-1
CTG-2
1
HAG4
CT01
CT02
CT03
1
2
2004
ALLOWANCES
ALLOCATED
5,250
2,150
2,272
2,195
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
3,248
2,979
4,223
0
0
0
2,616
5,603
8,941
0
0
0
0
3,114
277
0
0
3,815
948
0
0
0
0
1
HELD IN
ACCOUNTS AS
OF 3/1/2005
8,303
4,618
4,341
4,805
383
4
4
4
13
15
19
2
8
8
20
3
2
3
2
3
12,312
10,225
13,292
10
5
3
1 1 ,845
4,550
10,434
0
0
13
14
6,919
5,863
0
0
33,136
4,733
63
125
62
140
112
ALLOWANCES
DEDUCTED
7,996
4,558
4,280
4,740
363
0
0
0
1
1
1
1
1
1
4
0
0
0
1
1
7,948
8,008
11,132
1
4
1
2,689
4,500
10,377
0
0
0
1
6,839
5,773
0
0
13,120
4
1
1
1
110
104
ALLOWANCES
CARRIED OVER
TO 2005
307
60
61
65
20
4
4
4
12
14
18
1
7
7
16
3
2
3
1
2
4,364
2,217
2,160
9
1
2
9,156
50
57
0
0
13
13
80
90
0
0
20,016
4,729
62
124
61
30
8
A, 71
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
SC
sc
SC
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
SD
SD
SD
SD
SD
SD
SD
TN
TN
TN
TN
TN
PLANT NAME
Jefferies
Jefferies
John S. Rainey Generating Station
John S. Rainey Generating Station
John S. Rainey Generating Station
John S. Rainey Generating Station
John S. Rainey Generating Station
John S. Rainey Generating Station
John S. Rainey Generating Station
McMeekin
McMeekin
Mill Creek Combustion Turbine Sta
Mill Creek Combustion Turbine Sta
Mill Creek Combustion Turbine Sta
Mill Creek Combustion Turbine Sta
Mill Creek Combustion Turbine Sta
Mill Creek Combustion Turbine Sta
Mill Creek Combustion Turbine Sta
Mill Creek Combustion Turbine Sta
Urquhart
Urquhart
Urquhart
Urquhart
WSLee
WSLee
WSLee
Wateree
Wateree
Williams
Winyah
Winyah
Winyah
Winyah
Angus Anson
Angus Anson
Angus Anson
Big Stone
Huron
Huron
Lange
Allen
Allen
Allen
Brownsville Power 1, LLC
Brownsville Power 1, LLC
PLANT
CODE
3319
3319
7834
7834
7834
7834
7834
7834
7834
3287
3287
7981
7981
7981
7981
7981
7981
7981
7981
3295
3295
3295
3295
3264
3264
3264
3297
3297
3298
6249
6249
6249
6249
7237
7237
7237
6098
3344
3344
55478
3393
3393
3393
55081
55081
STACK/UNIT ID*
3
4
CT1A
CT1B
CT2A
CT2B
CT3
CT4
CT5
MCM1
MCM2
1
2
3
4
5
6
7
8
URQ3
URQ4
URQ5
URQ6
1
2
3
WAT1
WAT2
WIL1
1
2
3
4
2
3
4
1
**2A
**2B
CT1
1
2
3
AA-001
AA-002
2004
ALLOWANCES
ALLOCATED
3,886
3,743
0
0
0
0
0
0
0
4,080
4,038
0
0
0
0
0
0
0
0
2,914
0
0
0
2,133
2,277
3,444
9,717
9,270
15,821
7,574
6,234
3,610
3,427
851
1,020
0
13,715
80
103
0
6,608
7,231
6,756
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
11,572
11,236
4
7
4
3
0
0
0
20,949
10,184
12
11
11
16
17
18
19
18
7,218
833
805
829
4,099
2,827
5,120
24,370
20,644
23,321
19,985
11,041
4,024
3,822
4,250
5,096
0
17,425
2
4
7
12,147
10,709
11,555
3
3
ALLOWANCES
DEDUCTED
11,551
11,145
2
2
1
0
0
0
0
5,733
5,777
1
1
1
1
1
1
1
1
5,764
0
10
5
2,463
2,566
4,872
21,354
18,067
20,718
19,985
1 1 ,037
4,024
3,672
2
3
0
14,293
0
0
0
7,918
8,168
7,410
0
0
ALLOWANCES
CARRIED OVER
TO 2005
21
91
2
5
3
3
0
0
0
15,216
4,407
11
10
10
15
16
17
18
17
1,454
833
795
824
1,636
261
248
3,016
2,577
2,603
0
4
0
150
4,248
5,093
0
3,132
2
4
7
4,229
2,541
4,145
3
3
A, 72
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
PLANT NAME
Brownsville Power 1, LLC
Brownsville Power 1, LLC
Bull Run
Cumberland
Cumberland
Dupont Johnsonville
Dupont Johnsonville
Dupont Johnsonville
Dupont Johnsonville
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gleason Generating Facility
Gleason Generating Facility
Gleason Generating Facility
Haywood Energy Center
Haywood Energy Center
Haywood Energy Center
John Sevier
John Sevier
John Sevier
John Sevier
John Sevier
John Sevier
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
PLANT
CODE
55081
55081
3396
3399
3399
880001
880001
880001
880001
3403
3403
3403
3403
3403
3403
3403
3403
3403
3403
55251
55251
55251
55729
55729
55729
3405
3405
3405
3405
3405
3405
3406
3406
3406
3406
3406
3406
3406
3406
3406
3406
3406
3406
3406
3406
STACK/UNIT ID*
AA-003
AA-004
1
1
2
JVD1
JVD2
JVD3
JVD4
CSGA12(1,2)
1
2
CSGA34 (3, 4)
3
4
GCT5
GCT6
GCT7
GCT8
CTG-1
CTG-2
CTG-3
CT-1
CT-2
CT-3
CSJS12(1,2)
1
2
CSJS34 (3, 4)
3
4
CSJO10(1,2, 3, 4, 5, 6, 7, 8, 9, 10)
1
10
2
3
4
5
6
7
8
9
JCT17
JCT18
JCT19
2004
ALLOWANCES
ALLOCATED
0
0
25,047
37,386
40,896
1,778
1,778
1,777
1,777
7,605
7,464
8,635
9,168
0
0
0
0
0
0
0
0
0
0
6,361
6,358
6,519
6,669
3,358
3,256
3,465
3,628
3,443
3,553
3,404
3,871
3,753
3,052
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
3
3
38,876
31 ,692
42,606
0
0
0
0
9,733
10,114
12,719
13,543
46
47
62
48
2
2
2
0
0
0
9,365
9,805
8,406
9,344
10,572
11,618
10,186
8,537
10,354
8,715
9,629
10,737
10,213
10,344
42
43
42
ALLOWANCES
DEDUCTED
0
0
28,606
8,262
10,264
0
0
0
0
5,305
6,168
7,009
8,316
0
0
0
0
0
0
0
0
0
0
8,916
9,334
8,005
8,891
10,068
10,956
9,698
8,127
9,860
8,300
9,168
10,153
9,596
9,749
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
3
3
10,270
23,430
32,342
0
0
0
0
4,428
3,946
5,710
5,227
46
47
62
48
2
2
2
0
0
0
449
471
401
453
504
662
488
410
494
415
461
584
617
595
42
43
42
A, 73
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Johnsonville
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Lagoon Creek
Lagoon Creek
Lagoon Creek
Lagoon Creek
Lagoon Creek
Lagoon Creek
Lagoon Creek
Lagoon Creek
Lagoon Creek
Lagoon Creek
Lagoon Creek
Lagoon Creek
Memphis Refinery
AES Deepwater, Inc.
Alex Ty Cooke Generating Station
Alex Ty Cooke Generating Station
Alex Ty Cooke Generating Station
Barney M. Davis
Barney M. Davis
Bastrop Clean Energy Center
Bastrop Clean Energy Center
Baytown Energy Center
Baytown Energy Center
Baytown Energy Center
Big Brown
Big Brown
Blackhawk Station
Blackhawk Station
Bosque County Power Plant
Bosque County Power Plant
Bosque County Power Plant
Brazos Valley Energy, LP
Brazos Valley Energy, LP
PLANT
CODE
3406
3407
3407
3407
3407
3407
3407
3407
3407
3407
3407
3407
7845
7845
7845
7845
7845
7845
7845
7845
7845
7845
7845
7845
55703
10670
3602
3602
3602
4939
4939
55168
55168
55327
55327
55327
3497
3497
55064
55064
55172
55172
55172
55357
55357
STACK/UNIT ID*
JCT20
CSKI15(1,2, 3, 4, 5)
1
2
3
4
5
CSKI69 (6, 7, 8, 9)
6
7
8
9
LCT1
LCT10
LCT11
LCT12
LCT2
LCT3
LCT4
LCT5
LCT6
LCT7
LCT8
LCT9
P036
01001
1
2
3
1
2
CTG-1A
CTG-1 B
CTG-1
CTG-2
CTG-3
1
2
001
002
GT-1
GT-2
GT-3
CTG1
CTG2
2004
ALLOWANCES
ALLOCATED
0
4,152
3,992
4,751
5,041
6,194
6,347
6,189
5,784
6,405
0
0
0
0
0
0
0
0
0
0
0
0
0
0
59
71
0
496
398
0
0
0
0
0
20,985
19,878
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
187
8,352
8,331
8,566
8,321
7,741
9,059
9,643
9,303
9,762
97
99
98
99
98
97
97
99
99
98
99
98
1
1,957
2
2
0
20
75
6
6
5
4
4
38,644
43,979
5
4
2
2
6
5
5
ALLOWANCES
DEDUCTED
0
7,950
7,903
8,122
7,924
7,351
8,595
9,152
8,860
9,204
1
0
0
0
1
0
0
0
0
0
0
0
1
1,930
0
0
0
0
4
2
2
4
4
3
38,344
43,679
2
4
0
0
3
3
3
ALLOWANCES
CARRIED OVER
TO 2005
187
402
428
444
397
390
464
491
443
558
96
99
98
99
97
97
97
99
99
98
99
98
0
27
2
2
0
20
71
4
4
1
0
1
300
300
3
0
2
2
3
2
2
A, 74
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Brazos Valley Energy, LP
Brazos Valley Energy, LP
Bryan
C E Newman
C. R. Wing Cogeneration Plant
C. R. Wing Cogeneration Plant
Cedar Bayou
Cedar Bayou
Cedar Bayou
Cedar Bluff Power Project
Cedar Bluff Power Project
Channel Energy Center
Channel Energy Center
Channel Energy Center
Cleburne Cogeneration Facility
Cogen Lyondell, Inc.
Cogen Lyondell, Inc.
Cogen Lyondell, Inc.
Cogen Lyondell, Inc.
Cogen Lyondell, Inc.
Cogen Lyondell, Inc.
Coleto Creek
Collin
Corpus Christ! Energy Center
Corpus Christ! Energy Center
Cottonwood Energy Project
Cottonwood Energy Project
Cottonwood Energy Project
Cottonwood Energy Project
Dansby
Dansby
Decker Creek
Decker Creek
Decordova
Deepwater
Deer Park Energy Center
Deer Park Energy Center
Deer Park Energy Center
Deer Park Energy Center
Eagle Mountain
Eagle Mountain
Eagle Mountain
Eastman Cogeneration Facility
Eastman Cogeneration Facility
Edinburg Energy Project
PLANT
CODE
55357
55357
3561
3574
52176
52176
3460
3460
3460
55426
55426
55299
55299
55299
54817
50815
50815
50815
50815
50815
50815
6178
3500
55206
55206
55358
55358
55358
55358
6243
6243
3548
3548
8063
3461
55464
55464
55464
55464
3489
3489
3489
55176
55176
55145
STACK/UNIT ID*
CTG3
CTG4
6
BW5
1
2
CBY1
CBY2
CBY3
GT1
GT2
CTG1
CTG2
CTG3
EAST
ENG101
ENG201
ENG301
ENG401
ENG501
ENG601
1
1
CU1
CU2
CT1
CT2
CT3
CT4
1
2
1
2
1
DWP9
CTG1
CTG2
CTG3
CTG4
1
2
3
1
2
STK1
2004
ALLOWANCES
ALLOCATED
0
0
19
3
0
0
814
921
725
0
0
0
0
0
0
0
0
0
0
0
0
14,721
92
0
0
0
0
0
0
94
0
128
195
1,018
28
0
0
0
0
52
140
100
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
0
92
13
10
10
3,818
3,930
3,232
0
0
5
5
0
7
3
3
3
4
3
4
17,196
112
4
5
2
2
1
2
451
2
1,593
930
3
139
6
5
6
5
69
5
102
57
54
0
ALLOWANCES
DEDUCTED
0
0
0
0
1
1
4
5
4
0
0
4
4
0
4
2
2
1
2
1
2
15,063
0
3
4
1
2
1
2
1
0
3
2
1
0
5
4
5
4
0
0
1
3
3
0
ALLOWANCES
CARRIED OVER
TO 2005
0
0
92
13
9
9
3,814
3,925
3,228
0
0
1
1
0
3
1
1
2
2
2
2
2,133
112
1
1
1
0
0
0
450
2
1,590
928
2
139
1
1
1
1
69
5
101
54
51
0
A, 75
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Edinburg Energy Project
Edinburg Energy Project
Edinburg Energy Project
Ennis-Tractebel Power Company
Exelon Laporte Generating Station
Exelon Laporte Generating Station
Exelon Laporte Generating Station
Exelon Laporte Generating Station
Exxonmobil Beaumont Refinery
Exxonmobil Beaumont Refinery
Exxonmobil Beaumont Refinery
Forney Power Plant
Forney Power Plant
Forney Power Plant
Forney Power Plant
Forney Power Plant
Forney Power Plant
Fort Phantom Power Station
Fort Phantom Power Station
Freestone Power Generation
Freestone Power Generation
Freestone Power Generation
Freestone Power Generation
Frontera Generation Facility
Frontera Generation Facility
Gateway Power Project
Gateway Power Project
Gateway Power Project
Gibbons Creek Steam Electric Station
Graham
Graham
Greens Bayou
Gregory Power Facility
Gregory Power Facility
Guadalupe Generating Station
Guadalupe Generating Station
Guadalupe Generating Station
Guadalupe Generating Station
H W Pirkey Power Plant
Handley Generating Station
Handley Generating Station
Handley Generating Station
Handley Generating Station
Handley Generating Station
Handley Generating Station
PLANT
CODE
55145
55145
55145
55223
55365
55365
55365
55365
50625
50625
50625
55480
55480
55480
55480
55480
55480
4938
4938
55226
55226
55226
55226
55098
55098
55194
55194
55194
6136
3490
3490
3464
55086
55086
55153
55153
55153
55153
7902
3491
3491
3491
3491
3491
3491
STACK/UNIT ID*
STK2
STK3
STK4
GT-1
GT-1
GT-2
GT-3
GT-4
61 STK1
61 STK2
61 STK3
U1
U2
U3
U4
U5
U6
1
2
GT1
GT2
GTS
GT4
1
2
CTG-1
CTG-2
CTG-3
1
1
2
GBY5
101
102
CTG-1
CTG-2
CTG-3
CTG-4
1
1A
1B
2
3
4
5
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
126
187
0
0
0
0
0
0
0
0
0
14,414
235
496
352
0
0
0
0
0
0
20,532
7
0
21
423
118
136
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
0
0
5
8
10
8
9
0
0
0
9
9
9
7
8
7
465
826
4
3
4
4
20
12
0
0
0
15,041
7
371
1,657
13
13
4
4
3
3
21,455
32
10
75
1,275
360
415
ALLOWANCES
DEDUCTED
0
0
0
3
1
2
2
2
0
0
0
3
3
3
2
3
2
61
1
3
2
3
3
1
2
0
0
0
10,588
1
4
1
5
5
3
3
2
3
18,785
0
0
0
1
2
2
ALLOWANCES
CARRIED OVER
TO 2005
0
0
0
2
7
8
6
7
0
0
0
6
6
6
5
5
5
404
825
1
1
1
1
19
10
0
0
0
4,453
6
367
1,656
8
8
1
1
1
0
2,670
32
10
75
1,274
358
413
A, 76
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Harrington Station
Harrington Station
Harrington Station
Harrison County Power Project
Harrison County Power Project
Hays Energy Project
Hays Energy Project
Hays Energy Project
Hays Energy Project
Hidalgo Energy Facility
Hidalgo Energy Facility
Holly Street
Holly Street
Holly Street
Holly Street
J K Spruce
J K Spruce
J L Bates
J L Bates
J Robert Massengale Generating Station
J T Deely
J T Deely
J T Deely
Jack County Power Plant
Jack County Power Plant
Jones Station
Jones Station
Knox Lee Power Plant
Knox Lee Power Plant
Knox Lee Power Plant
Knox Lee Power Plant
La Palma
Lake Creek
Lake Creek
Lake Hubbard
Lake Hubbard
Lamar Power (Paris)
Lamar Power (Paris)
Lamar Power (Paris)
Lamar Power (Paris)
Laredo
Laredo
Laredo
Leon Creek
Leon Creek
PLANT
CODE
6193
6193
6193
55664
55664
55144
55144
55144
55144
7762
7762
3549
3549
3549
3549
7097
7097
3438
3438
3604
6181
6181
6181
55230
55230
3482
3482
3476
3476
3476
3476
3442
3502
3502
3452
3452
55097
55097
55097
55097
3439
3439
3439
3609
3609
STACK/UNIT ID*
061 B
062B
063B
GT-1
GT-2
STK1
STK2
STK3
STK4
HRSG1
HRSG2
1
2
3
4
"1
"2
1
2
GT1
CS012(1,2)
1
2
CT-1
CT-2
151B
152B
2
3
4
5
7
1
2
1
2
1
2
3
4
1
2
3
3
4
2004
ALLOWANCES
ALLOCATED
8,234
8,721
9,269
0
0
0
0
0
0
0
0
49
31
68
43
6,692
0
48
124
0
13,136
13,705
0
0
125
93
0
5
29
251
178
39
191
170
604
0
0
0
0
15
14
85
2
10
HELD IN
ACCOUNTS AS
OF 3/1/2005
8,392
10,039
10,276
2
2
3
3
3
2
3
3
245
155
335
209
5,052
0
25
25
1
11,603
11,963
0
0
609
395
5
25
140
929
50
44
196
181
545
4
4
4
4
20
20
40
10
50
ALLOWANCES
DEDUCTED
8,016
9,629
9,863
1
1
0
0
0
0
2
2
0
0
1
1
4,133
0
1
1
0
11,216
11,215
0
0
3
4
0
0
0
47
2
0
0
1
3
2
2
2
2
0
0
2
0
0
ALLOWANCES
CARRIED OVER
TO 2005
376
410
413
1
1
3
3
3
2
1
1
245
155
334
208
919
0
24
24
1
387
748
0
0
606
391
5
25
140
882
48
44
196
180
542
2
2
2
2
20
20
38
10
50
A, 77
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Leon Creek
Leon Creek
Leon Creek
Leon Creek
Lewis Creek
Lewis Creek
Limestone
Limestone
Lon C Hill
Lon C Hill
Lon C Hill
Lon C Hill
Lone Star Power Plant
Lost Pines 1
Lost Pines 1
Magic Valley Generating Station
Magic Valley Generating Station
Martin Lake
Martin Lake
Martin Lake
Midlothian Energy
Midlothian Energy
Midlothian Energy
Midlothian Energy
Midlothian Energy
Midlothian Energy
Mirant Texas - Weatherford
Mirant Texas - Weatherford
Mirant Texas - Weatherford
Mirant Texas - Weatherford
Mission Road
Montgomery County Power Project
Montgomery County Power Project
Monticello
Monticello
Monticello
Moore County Station
Morgan Creek
Morgan Creek
Morgan Creek
Morgan Creek
Mountain Creek Steam Electric Sta
Mountain Creek Steam Electric Sta
Mountain Creek Steam Electric Sta
Mountain Creek Steam Electric Sta
PLANT
CODE
3609
3609
3609
3609
3457
3457
298
298
3440
3440
3440
3440
3477
55154
55154
55123
55123
6146
6146
6146
55091
55091
55091
55091
55091
55091
55171
55171
55171
55171
3610
55423
55423
6147
6147
6147
3483
3492
3492
3492
3492
3453
3453
3453
3453
STACK/UNIT ID*
CGT1
CGT2
CGT3
CGT4
1
2
LIM1
LIM2
1
2
3
4
1
1
2
CTG-1
CTG-2
1
2
3
STK1
STK2
STK3
STK4
STK5
STK6
GT-1
GT-2
GT-3
GT-4
3
GT1
GT2
1
2
3
3
3
4
5
6
2
3A
3B
6
2004
ALLOWANCES
ALLOCATED
0
0
0
0
317
271
23,787
14,158
9
10
179
197
0
0
0
0
0
33,231
32,266
33,436
0
0
0
0
0
0
0
0
0
0
3
0
0
23,641
22,938
35,232
0
8
72
154
836
4
11
2
63
HELD IN
ACCOUNTS AS
OF 3/1/2005
51
51
51
51
948
810
55,762
17,410
0
0
0
0
5
41
40
4
4
25,043
23,735
31,295
3
4
3
4
3
3
0
0
0
0
15
0
0
27,575
28,974
21 ,439
1
8
73
16
439
22
43
16
239
ALLOWANCES
DEDUCTED
0
0
0
0
3
3
12,535
10,036
0
0
0
0
0
4
4
3
3
24,743
1 1 ,986
19,748
1
1
1
2
1
1
0
0
0
0
0
0
0
27,276
28,674
19,703
0
0
0
5
0
0
0
0
1
ALLOWANCES
CARRIED OVER
TO 2005
51
51
51
51
945
807
43,227
7,374
0
0
0
0
5
37
36
1
1
300
1 1 ,749
1 1 ,547
2
3
2
2
2
2
0
0
0
0
15
0
0
299
300
1,736
1
8
73
11
439
22
43
16
238
A, 78
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Mountain Creek Steam Electric Sta
Mountain Creek Steam Electric Sta
Mustang Station
Mustang Station
Neches
Neches
Neches
Neches
Newgulf
Newman
Newman
Newman
Newman
Newman
Nichols Station
Nichols Station
Nichols Station
North Lake
North Lake
North Lake
North Main
North Texas
Nueces Bay
Nueces Bay
Nueces Bay
O W Sommers
O W Sommers
Oak Creek Power Station
Odessa-Ector Generating Station
Odessa-Ector Generating Station
Odessa-Ector Generating Station
Odessa-Ector Generating Station
Oklaunion Power Station
P H Robinson
P H Robinson
P H Robinson
P H Robinson
Paint Creek Power Station
Paint Creek Power Station
Paint Creek Power Station
Paint Creek Power Station
Parkdale
Parkdale
Parkdale
Pasadena Power Plant
PLANT
CODE
3453
3453
55065
55065
3458
3458
3458
3458
50137
3456
3456
3456
3456
3456
3484
3484
3484
3454
3454
3454
3493
3627
3441
3441
3441
3611
3611
3523
55215
55215
55215
55215
127
3466
3466
3466
3466
3524
3524
3524
3524
3455
3455
3455
55047
STACK/UNIT ID*
7
8
1
2
11
13
15
18
1
**4
**5
1
2
3
141B
142B
143B
1
2
3
4
3
5
6
7
1
2
1
GT1
GT2
GTS
GT4
1
PHR1
PHR2
PHR3
PHR4
1
2
3
4
1
2
3
CG-1
2004
ALLOWANCES
ALLOCATED
62
527
0
0
0
0
0
0
0
99
0
14
29
88
77
86
50
131
150
294
42
13
1
140
496
478
188
106
0
0
0
0
7,859
645
494
685
796
11
11
28
105
34
62
61
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
234
1,675
10
10
0
0
0
0
4
240
244
66
141
284
381
426
242
133
152
296
44
1
0
0
0
982
925
514
4
4
5
4
9,638
3,211
2,455
3,413
3,962
49
43
132
359
1
0
4
4
ALLOWANCES
DEDUCTED
2
1
4
4
0
0
0
0
0
1
1
1
1
1
1
1
2
0
0
1
0
0
0
0
0
50
1
0
2
3
3
3
4,015
0
0
0
0
0
0
0
0
0
0
0
3
ALLOWANCES
CARRIED OVER
TO 2005
232
1,674
6
6
0
0
0
0
4
239
243
65
140
283
380
425
240
133
152
295
44
1
0
0
0
932
924
514
2
1
2
1
5,623
3,211
2,455
3,413
3,962
49
43
132
359
1
0
4
1
A, 79
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Pasadena Power Plant
Pasadena Power Plant
Permian Basin
Permian Basin
Plant X
Plant X
Plant X
Plant X
Power Lane Steam Plant
Power Lane Steam Plant
RW Miller
RW Miller
RW Miller
RW Miller
RW Miller
Ray Olinger
Ray Olinger
Ray Olinger
Ray Olinger
Reliant Energy Channelview Cogen
Reliant Energy Channelview Cogen
Reliant Energy Channelview Cogen
Reliant Energy Channelview Cogen
Rio Nogales Power Project, LP
Rio Nogales Power Project, LP
Rio Nogales Power Project, LP
Rio Pecos Power Station
Rio Pecos Power Station
River Crest
Sabine
Sabine
Sabine
Sabine
Sabine
Sabine Cogeneration Facility
Sabine Cogeneration Facility
Sam Bertron
Sam Bertron
Sam Bertron
Sam Bertron
Sam Rayburn Plant
Sam Rayburn Plant
Sam Rayburn Plant
Sam Seymour
Sam Seymour
PLANT
CODE
55047
55047
3494
3494
3485
3485
3485
3485
4195
4195
3628
3628
3628
3628
3628
3576
3576
3576
3576
55187
55187
55187
55187
55137
55137
55137
3526
3526
3503
3459
3459
3459
3459
3459
55104
55104
3468
3468
3468
3468
3631
3631
3631
6179
6179
STACK/UNIT ID*
CG-2
CG-3
5
6
111B
112B
113B
114B
2
3
**4
"5
1
2
3
BW2
BW3
CE1
GE4
CHV1
CHV2
CHV3
CHV4
CTG-1
CTG-2
CTG-3
5
6
1
1
2
3
4
5
SAB-1
SAB-2
SRB1
SRB2
SRB3
SRB4
CT7
CT8
CT9
1
2
2004
ALLOWANCES
ALLOCATED
0
0
103
804
0
2
89
0
459
37
851
851
55
98
218
60
79
42
0
0
0
0
0
0
0
0
64
179
61
152
164
576
504
323
0
0
57
18
120
79
0
0
0
15,910
17,396
HELD IN
ACCOUNTS AS
OF 3/1/2005
5
4
4
904
1
12
413
7
1,295
182
0
32
0
0
1
285
390
207
0
7
6
8
7
5
4
4
275
851
61
459
498
1,730
1,505
982
2
2
275
77
552
328
0
1
0
17,580
20,290
ALLOWANCES
DEDUCTED
3
3
0
244
0
1
1
3
0
0
0
0
0
0
1
1
1
1
0
4
3
5
4
1
1
1
0
0
0
2
2
4
6
3
1
1
0
0
0
0
0
1
0
14,034
14,102
ALLOWANCES
CARRIED OVER
TO 2005
2
1
4
660
1
11
412
4
1,295
182
0
32
0
0
0
284
389
206
0
3
3
3
3
4
3
3
275
851
61
457
496
1,726
1,499
979
1
1
275
77
552
328
0
0
0
3,546
6,188
A, 80
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Sam Seymour
San Angelo Power Station
San Jacinto Steam Electric Station
San Jacinto Steam Electric Station
San Jacinto Steam Electric Station
San Miguel
Sand Hill Energy Center
Sand Hill Energy Center
Sand Hill Energy Center
Sand Hill Energy Center
Sand Hill Energy Center
Sandow
Silas Ray
Silas Ray
Sim Gideon
Sim Gideon
Sim Gideon
South Houston Green Power Site
South Houston Green Power Site
South Houston Green Power Site
Spencer
Spencer
SRWCogen Limited Partnership
SRWCogen Limited Partnership
Sterne Electric Generating Facility
Sterne Electric Generating Facility
Sterne Electric Generating Facility
Stryker Creek
Stryker Creek
Sweeny Cogeneration Facility
Sweeny Cogeneration Facility
Sweeny Cogeneration Facility
Sweeny Cogeneration Facility
Sweetwater Generating Plant
Sweetwater Generating Plant
Sweetwater Generating Plant
T C Ferguson
T H Wharton
Tenaska Frontier Generation Station
Tenaska Frontier Generation Station
Tenaska Frontier Generation Station
Tenaska Gateway Generating Station
Tenaska Gateway Generating Station
Tenaska Gateway Generating Station
Tolk Station
PLANT
CODE
6179
3527
7325
7325
7325
6183
7900
7900
7900
7900
7900
6648
3559
3559
3601
3601
3601
55470
55470
55470
4266
4266
55120
55120
55708
55708
55708
3504
3504
55015
55015
55015
55015
50615
50615
50615
4937
3469
55062
55062
55062
55132
55132
55132
6194
STACK/UNIT ID*
3
2
CP1 (SJS1.SJS2)
SJS1
SJS2
SM-1
SH1
SH2
SH3
SH4
SH5
4
10
9
1
2
3
EPN801
EPN802
EPN803
4
5
CTG-1
CTG-2
HRSG-1
HRSG-2
HRSG-3
1
2
1
2
3
4
GT01
GT02
GT03
1
THW2
1
2
3
OGTDB1
OGTDB2
OGTDB3
171B
2004
ALLOWANCES
ALLOCATED
10,494
161
0
0
17,216
0
0
0
0
0
25,698
0
0
47
56
277
0
0
0
19
23
0
0
0
0
0
170
525
0
0
0
0
0
0
0
253
97
0
0
0
0
0
0
14,781
HELD IN
ACCOUNTS AS
OF 3/1/2005
2,538
785
33
28
1 1 ,230
1
1
1
1
20
33,231
0
1,508
185
221
372
37
37
36
93
101
6
6
0
0
0
6
551
51
51
50
52
1
2
1
1,236
471
3
3
3
3
3
3
17,647
ALLOWANCES
DEDUCTED
1,702
1
2
3
8,524
0
0
0
0
1
26,583
0
0
0
1
3
21
19
19
0
1
5
3
0
0
0
0
8
3
3
3
3
0
0
0
2
0
3
3
3
3
3
3
1 1 ,397
ALLOWANCES
CARRIED OVER
TO 2005
836
784
31
25
2,706
1
1
1
1
19
6,648
0
1,508
185
220
369
16
18
17
93
100
1
3
0
0
0
6
543
48
48
47
49
1
2
1
1,234
471
0
0
0
0
0
0
6,250
A, 81
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
PLANT NAME
Tolk Station
Tradinghouse
Tradinghouse
Trinidad
Twin Oak
Twin Oak
Twin Oaks Power, LP
Twin Oaks Power, LP
V H Braunig
V H Braunig
V H Braunig
V H Braunig
V H Braunig
V H Braunig
Valley (TXU)
Valley (TXU)
Valley (TXU)
Victoria
Victoria
Victoria
Victoria
W A Parish
W A Parish
W A Parish
W A Parish
W A Parish
W A Parish
W A Parish
W A Parish
W B Tuttle
W B Tuttle
W B Tuttle
W B Tuttle
Webster
Welsh Power Plant
Welsh Power Plant
Welsh Power Plant
West Texas Energy Facility
West Texas Energy Facility
Wilkes Power Plant
Wilkes Power Plant
Wilkes Power Plant
Wise County Power Company
Wise County Power Company
Wolf Hollow 1, LP
PLANT
CODE
6194
3506
3506
3507
6180
6180
7030
7030
3612
3612
3612
3612
3612
3612
3508
3508
3508
3443
3443
3443
3443
3470
3470
3470
3470
3470
3470
3470
3470
3613
3613
3613
3613
3471
6139
6139
6139
55240
55240
3478
3478
3478
55320
55320
55139
STACK/UNIT ID*
172B
1
2
9
1
2
U1
U2
1
2
3
CP01 (CT01 , CT02)
CT01
CT02
1
2
3
5
6
7
8
WAP1
WAP2
WAP3
WAP4
WAP5
WAP6
WAP7
WAP8
1
2
3
4
WEBS
1
2
3
STK1
STK2
1
2
3
GT-1
GT-2
CTG1
2004
ALLOWANCES
ALLOCATED
14,444
593
995
135
8,015
1,540
2,123
3,500
78
121
416
0
0
77
518
124
6
8
110
238
57
56
245
558
22,878
20,761
15,142
7,287
2
19
11
48
343
13,329
12,846
15,220
0
0
30
118
129
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
18,446
599
206
179
0
0
4,106
3,500
347
583
2,020
61
61
83
522
126
0
0
0
0
282
278
1,220
2,775
38,907
28,498
18,266
15,107
10
95
55
240
1,710
16,291
16,617
25,213
0
0
111
580
634
5
5
4
ALLOWANCES
DEDUCTED
10,951
0
1
92
0
0
2,700
2,440
1
0
1
2
2
0
0
0
0
0
0
0
0
0
0
2
19,175
16,505
15,881
3,774
0
0
0
0
0
1 1 ,743
11,113
1 1 ,685
0
0
0
1
2
3
3
3
ALLOWANCES
CARRIED OVER
TO 2005
7,495
599
205
87
0
0
1,406
1,060
346
583
2,019
59
59
83
522
126
0
0
0
0
282
278
1,220
2,773
19,732
1 1 ,993
2,385
1 1 ,333
10
95
55
240
1,710
4,548
5,504
13,528
0
0
111
579
632
2
2
1
A, 82
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
TX
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
PLANT NAME
Wolf Hollow 1, LP
Bonanza
Carbon
Carbon
Currant Creek Power Project
Currant Creek Power Project
Desert Power Plant
Desert Power Plant
Gadsby
Gadsby
Gadsby
Gadsby
Gadsby
Gadsby
Hunter (Emery)
Hunter (Emery)
Hunter (Emery)
Huntington
Huntington
Intermountain
Intermountain
Nebo Power Station
West Valley Generation Project
West Valley Generation Project
West Valley Generation Project
West Valley Generation Project
West Valley Generation Project
Altavista Power Station
Altavista Power Station
Altavista Power Station
Bellemeade Power Station
Bellemeade Power Station
Bremo Power Station
Bremo Power Station
Buchanan — Units 1 and 2
Buchanan - Units 1 and 2
Chesapeake Energy Center
Chesapeake Energy Center
Chesapeake Energy Center
Chesapeake Energy Center
Chesterfield Power Station
Chesterfield Power Station
Chesterfield Power Station
Chesterfield Power Station
Chesterfield Power Station
PLANT
CODE
55139
7790
3644
3644
56102
56102
55848
55848
3648
3648
3648
3648
3648
3648
6165
6165
6165
8069
8069
6481
6481
56177
55622
55622
55622
55622
55622
10773
10773
10773
50966
50966
3796
3796
55738
55738
3803
3803
3803
3803
3797
3797
3797
3797
3797
STACK/UNIT ID*
CTG2
1-1
1
2
CTG1A
CTG1B
UNT1
UNT2
1
2
3
4
5
6
1
2
3
1
2
1SGA
2SGA
U1
U1
U2
U3
U4
U5
CSO (1 , 2)
1
2
1
2
3
4
1
2
1
2
3
4
**8A
3
4
5
6
2004
ALLOWANCES
ALLOCATED
0
10,785
1,913
2,499
0
0
0
0
24
1,690
2,265
0
0
0
7,454
7,960
1 1 ,254
7,925
9,753
2,875
2,895
0
0
0
0
0
0
0
0
0
0
2,029
5,160
0
0
2,117
2,210
4,560
5,872
1,387
2,561
4,670
9,166
17,139
HELD IN
ACCOUNTS AS
OF 3/1/2005
4
1,525
2,160
3,681
0
0
2
2
10
10
10
10
10
10
4,006
3,894
1,087
2,446
14,481
7,094
7,034
0
10
10
11
10
10
72
96
13
40
4,034
7,755
1
1
5,462
5,247
9,891
14,208
51
6,537
11,271
22,420
28,653
ALLOWANCES
DEDUCTED
3
1,199
2,060
3,581
0
0
0
0
0
0
0
0
0
0
2,338
2,402
987
2,346
14,381
1,993
1,856
0
0
0
1
0
0
42
39
3
27
3,667
7,050
0
0
4,965
4,770
8,992
12,916
46
5,943
10,246
20,382
26,048
ALLOWANCES
CARRIED OVER
TO 2005
1
326
100
100
0
0
2
2
10
10
10
10
10
10
1,668
1,492
100
100
100
5,101
5,178
0
10
10
10
10
10
30
57
10
13
367
705
1
1
497
477
899
1,292
5
594
1,025
2,038
2,605
A, 83
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
PLANT NAME
Clinch River
Clinch River
Clinch River
Clinch River
Clover Power Station
Clover Power Station
Commonwealth Chesapeake
Commonwealth Chesapeake
Commonwealth Chesapeake
Commonwealth Chesapeake
Commonwealth Chesapeake
Commonwealth Chesapeake
Commonwealth Chesapeake
CPV Cunningham Creek Power Gen Fac
CPV Cunningham Creek Power Gen Fac
Doswell Limited Partnership
Elizabeth River Combustion Turbine Sta
Elizabeth River Combustion Turbine Sta
Elizabeth River Combustion Turbine Sta
Glen Lyn
Glen Lyn
Glen Lyn
Gordonsville Power Station
Gordonsville Power Station
Hopewell Power Station
Hopewell Power Station
Hopewell Power Station
Ladysmith Combustion Turbine Sta
Ladysmith Combustion Turbine Sta
Louisa Generation Facility
Louisa Generation Facility
Louisa Generation Facility
Louisa Generation Facility
Louisa Generation Facility
Marsh Run Generation Facility
Marsh Run Generation Facility
Marsh Run Generation Facility
Marsh Run Generation Facility
Mecklenburg Power Station
Mecklenburg Power Station
Possum Point Power Station
Possum Point Power Station
Possum Point Power Station
Possum Point Power Station
Possum Point Power Station
PLANT
CODE
3775
3775
3775
3775
7213
7213
55381
55381
55381
55381
55381
55381
55381
55814
55814
52019
52087
52087
52087
3776
3776
3776
54844
54844
10771
10771
10771
7838
7838
7837
7837
7837
7837
7837
7836
7836
7836
7836
52007
52007
3804
3804
3804
3804
3804
STACK/UNIT ID*
CS012(1,2)
1
2
3
1
2
CT-001
CT-002
CT-003
CT-004
CT-005
CT-006
CT-007
CT01
CT02
CT1
CT-1
CT-2
CT-3
51
52
6
1
2
CSO (1 , 2)
1
2
1
2
EU1
EU2
EU3
EU4
EU5
EU1
EU2
EU3
EU4
1
2
3
4
5
6A
6B
2004
ALLOWANCES
ALLOCATED
5,348
6,113
5,651
2,938
2,938
0
0
0
0
0
0
0
0
0
0
0
0
0
1,152
1,113
5,535
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
2,647
6,725
4,336
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
7,904
7,609
8,152
1,790
1,790
11
9
10
4
4
4
5
0
0
6
0
0
0
2,959
1,954
6,318
3
3
20
20
17
13
7
6
6
5
8
6
5
6
0
226
229
5
6
5,670
17
17
ALLOWANCES
DEDUCTED
7,673
7,387
7,914
1,107
1,221
7
7
8
2
2
2
2
0
0
2
0
0
0
1,762
1,898
6,006
2
2
0
0
6
5
1
1
1
1
4
2
1
2
0
205
208
0
0
4,646
3
4
ALLOWANCES
CARRIED OVER
TO 2005
231
222
238
683
569
4
2
2
2
2
2
3
0
0
4
0
0
0
1,197
56
312
1
1
20
20
11
8
6
5
5
4
4
4
4
4
0
21
21
5
6
1,024
14
13
A, 84
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VT
WA
WA
WA
WA
WA
WA
WA
WA
WA
WA
WA
WA
WA
WA
WA
PLANT NAME
Potomac River
Potomac River
Potomac River
Potomac River
Potomac River
Remington Combustion Turbine Station
Remington Combustion Turbine Station
Remington Combustion Turbine Station
Remington Combustion Turbine Station
Southampton Power Station
Southampton Power Station
Southampton Power Station
Tenaska Virginia Generating Station
Tenaska Virginia Generating Station
Tenaska Virginia Generating Station
Wolf Hills Energy
Wolf Hills Energy
Wolf Hills Energy
Wolf Hills Energy
Wolf Hills Energy
Wolf Hills Energy
Wolf Hills Energy
Wolf Hills Energy
Wolf Hills Energy
Wolf Hills Energy
Yorktown Power Station
Yorktown Power Station
Yorktown Power Station
Yorktown Power Station
J C McNeil
AES Columbia Power
AES Columbia Power
Centralia
Centralia
Centralia
Centralia
Centralia
Centralia
Chehalis Generation Facility
Chehalis Generation Facility
Finley Combustion Turbine
Frederickson Power LP
Fredonia Plant
Fredonia Plant
Goldendale Energy Project
PLANT
CODE
3788
3788
3788
3788
3788
7839
7839
7839
7839
10774
10774
10774
55439
55439
55439
55285
55285
55285
55285
55285
55285
55285
55285
55285
55285
3809
3809
3809
3809
589
55676
55676
3845
3845
3845
3845
3845
3845
55662
55662
7945
55818
607
607
55482
STACK/UNIT ID*
1
2
3
4
5
1
2
3
4
CSO (1 , 2)
1
2
CTGDB1
CTGDB2
CTGDB3
WH01
WH02
WH03
WH04
WH05
WH06
WH07
WH08
WH09
WH10
CSO (1 , 2)
1
2
3
1
GT-1
GT-2
30
40
50
60
BW21
BW22
CT1
CT2
1
F1CT
CT3
CT4
CT-1
2004
ALLOWANCES
ALLOCATED
2,334
2,309
2,756
3,037
2,913
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
4,671
4,674
6,305
104
0
0
0
0
0
0
19,076
20,337
0
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
2,421
2,618
3,319
3,681
3,284
22
24
22
22
88
52
0
0
0
0
0
0
0
0
0
0
0
0
0
13,525
13,495
14,990
497
0
0
24
24
24
24
4,509
2,503
9
8
0
7
16
5
1
ALLOWANCES
DEDUCTED
1,849
2,064
2,858
3,242
2,940
1
1
1
1
80
47
0
0
0
0
0
0
0
0
0
0
0
0
0
12,295
12,268
13,627
8
0
0
0
0
0
0
4,429
2,455
3
3
0
2
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
572
554
461
439
344
21
23
21
21
8
5
0
0
0
0
0
0
0
0
0
0
0
0
0
1,230
1,227
1,363
489
0
0
24
24
24
24
80
48
6
5
0
5
16
5
1
A, 85
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
WA
WA
WA
WA
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
PLANT NAME
Longview Energy Development
Mint Farm Generation, LLC
Plymouth Generation Facility
River Road
Alma
Alma
Alma
Alma
Alma
Alma
Appleton Coated Locks Mill
Bay Front
Bay Front
Bay Front
Blount Street
Blount Street
Blount Street
Blount Street
Blount Street
Blount Street
Blount Street
Columbia
Columbia
Concord
Concord
Concord
Concord
Depere Energy Center
Edgewater (4050)
Edgewater (4050)
Edgewater (4050)
Elk Mound Generating Station
Elk Mound Generating Station
Fond Du Lac Energy Center
Fond Du Lac Energy Center
Fox Energy Center
Fox Energy Center
Genoa
Germantown Power Plant
Island Street Peaking Plant
Island Street Peaking Plant
J P Madgett
Manitowoc
Manitowoc
Manitowoc
PLANT
CODE
55634
55700
55870
7605
4140
4140
4140
4140
4140
4140
55558
3982
3982
3982
3992
3992
3992
3992
3992
3992
3992
8023
8023
7159
7159
7159
7159
55029
4050
4050
4050
7863
7863
55498
55498
56031
56031
4143
6253
55836
55836
4271
4125
4125
4125
STACK/UNIT ID*
CT1
CTG1
PGF1
1
CS1 (B1 , B2, B3, B4, B5)
B1
B2
B3
B4
B5
B06
1
2
5
11
3
5
6
7
8
9
1
2
**1
**2
"3
**4
B01
3
4
5
1
2
CT10
CT20
CTG-1
CTG-2
1
"5
1A
1B
B1
CS0020 (6, 7, 8)
6
7
2004
ALLOWANCES
ALLOCATED
0
0
0
0
537
518
455
1,193
1,906
0
1,046
529
281
1
6
7
7
1,476
1,130
1,183
15,484
8,758
126
126
126
126
0
1,237
10,396
1 1 ,459
0
0
0
0
0
0
8,019
0
0
0
7,436
672
814
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
0
0
10
794
881
771
4,483
13,575
19
3,564
2,092
673
9
29
35
35
3,393
3,196
4,503
17,323
16,266
3
3
3
3
19
21 ,052
44,459
15,977
10
10
0
0
0
0
12,038
4
45
8
21,115
1,226
1,254
ALLOWANCES
DEDUCTED
0
0
0
6
704
795
676
2,000
3,500
0
278
140
611
0
0
0
0
1,809
2,289
3,855
14,844
14,399
0
0
0
0
0
1,606
6,105
10,881
0
0
0
0
0
0
10,944
0
0
0
4,687
1,226
1,254
ALLOWANCES
CARRIED OVER
TO 2005
0
0
0
4
90
86
95
2,483
10,075
19
3,286
1,952
62
9
29
35
35
1,584
907
648
2,479
1,867
3
3
3
3
19
19,446
38,354
5,096
10
10
0
0
0
0
1,094
4
45
8
16,428
0
0
A, 86
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
PLANT NAME
Manitowoc
Manitowoc
Mirant Portage County
Mirant Portage County
Mirant Portage County
Mirant Portage County
Mirant Portage County
Mirant Portage County
Muskego Energy Center
Muskego Energy Center
Muskego Energy Center
Muskego Energy Center
Neenah Energy Facility
Neenah Energy Facility
Nelson Dewey
Nelson Dewey
Nelson Dewey
Paris
Paris
Paris
Paris
Pleasant Prairie
Pleasant Prairie
Pleasant Prairie
Port Washington Generating Station
Port Washington Generating Station
Port Washington Generating Station
Port Washington Generating Station
Port Washington Generating Station
Port Washington Generating Station
Port Washington Generating Station
Port Washington Generating Station
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Riverside Energy Center, LLC
Riverside Energy Center, LLC
Rock River
Rock River
PLANT
CODE
4125
4125
55697
55697
55697
55697
55697
55697
55670
55670
55670
55670
55135
55135
4054
4054
4054
7270
7270
7270
7270
6170
6170
6170
4040
4040
4040
4040
4040
4040
4040
4040
4072
4072
4072
4072
4072
4072
4072
4072
4072
55641
55641
4057
4057
STACK/UNIT ID*
8
9
1A
1B
2A
2B
2C
2D
1
2
3
4
CT01
CT02
CS1 (1,2)
1
2
**1
**2
"3
**4
CS1 (1,2)
1
2
CS7 (1 , 2, 3)
1
11
12
2
21
22
3
CS34 (3, 4)
3
32
4
CS56 (5, 6)
5
6
7
8
CT-01
CT-02
1
2
2004
ALLOWANCES
ALLOCATED
238
0
0
0
0
0
0
0
0
0
0
0
0
0
2,524
2,808
124
124
124
124
1 1 ,802
16,680
529
0
0
1,031
0
0
858
140
0
208
607
791
2,036
3,153
0
0
1,560
1,482
HELD IN
ACCOUNTS AS
OF 3/1/2005
323
0
0
0
0
0
0
0
0
0
0
0
4
4
8,733
8,954
3
2
3
3
17,492
16,809
2,917
0
0
2,213
0
0
2,698
493
26
592
1,024
1,085
1,658
2,592
2
3
7,817
4,236
ALLOWANCES
DEDUCTED
287
0
0
0
0
0
0
0
0
0
0
0
0
0
8,426
8,769
0
0
0
0
17,191
16,517
2,865
0
0
2,174
0
0
2,650
450
0
541
935
1,017
1,526
2,385
2
3
4
4
ALLOWANCES
CARRIED OVER
TO 2005
36
0
0
0
0
0
0
0
0
0
0
0
4
4
307
185
3
2
3
3
301
292
52
0
0
39
0
0
48
43
26
51
89
68
132
207
0
0
7,813
4,232
A, 87
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
wv
wv
wv
wv
wv
wv
wv
wv
wv
PLANT NAME
Rockgen Energy Center
Rockgen Energy Center
Rockgen Energy Center
Sheboygan Falls Energy Facility
Sheboygan Falls Energy Facility
Sheboygan Falls Energy Facility
South Fond Du Lac
South Fond Du Lac
South Fond Du Lac
South Fond Du Lac
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
Stoneman
Stoneman
Stoneman
Tenaska Talladega Gen Station
Tenaska Talladega Gen Station
Tenaska Talladega Gen Station
Valley (WEPCO)
Valley (WEPCO)
Valley (WEPCO)
Valley (WEPCO)
Valley (WEPCO)
Valley (WEPCO)
West Campus Cogeneration Facility
West Campus Cogeneration Facility
West Marinette
West Marinette
Weston
Weston
Weston
Whitewater Cogeneration Facility
Albright Power Station
Albright Power Station
Albright Power Station
Big Sandy Peaker Plant
Big Sandy Peaker Plant
Big Sandy Peaker Plant
Big Sandy Peaker Plant
Big Sandy Peaker Plant
Big Sandy Peaker Plant
PLANT
CODE
55391
55391
55391
56186
56186
56186
7203
7203
7203
7203
4041
4041
4041
4041
4041
4041
4146
4146
4146
55547
55547
55547
4042
4042
4042
4042
4042
4042
7991
7991
4076
4076
4078
4078
4078
55011
3942
3942
3942
55284
55284
55284
55284
55284
55284
STACK/UNIT ID*
CT-1
CT-2
CT-3
1
2
3
**CT1
**CT2
**CT3
**CT4
CSS (5, 6)
5
6
CS4 (7, 8)
7
8
CS12(B1,B2)
B1
B2
CTGDB1
CTGDB2
CTGDB3
CS1 (1,2)
1
2
CS2 (3, 4)
3
4
U1
U2
"33
"34
1
2
3
01
1
2
3
GS01
GS02
GS03
GS04
GS05
GS06
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
639
39
39
0
3,885
4,861
6,504
6,392
177
223
0
0
0
1,805
1,824
1,954
1,900
0
0
765
0
762
1,810
9,704
0
1,974
2,054
4,598
0
0
0
0
0
0
HELD IN
ACCOUNTS AS
OF 3/1/2005
2
2
4
0
0
0
639
195
195
2
3,310
3,399
4,660
4,677
393
436
0
0
0
1,855
1,732
1,924
1,956
0
0
1,225
4
1,656
2,720
9,783
3
3,696
3,967
8,722
0
0
0
0
0
0
ALLOWANCES
DEDUCTED
1
2
2
0
0
0
0
0
0
0
3,252
3,339
4,578
4,596
297
347
0
0
0
1,822
1,701
1,889
1,922
0
0
0
0
1,510
2,489
8,908
1
3,596
3,867
8,522
0
0
0
0
0
0
ALLOWANCES
CARRIED OVER
TO 2005
1
0
2
0
0
0
639
195
195
2
58
60
82
81
96
89
0
0
0
33
31
35
34
0
0
1,225
4
146
231
875
2
100
100
200
0
0
0
0
0
0
A, 88
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
WV
wv
WV
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
PLANT NAME
Big Sandy Peaker Plant
Big Sandy Peaker Plant
Big Sandy Peaker Plant
Big Sandy Peaker Plant
Big Sandy Peaker Plant
Big Sandy Peaker Plant
Ceredo Electric Generating Station
Ceredo Electric Generating Station
Ceredo Electric Generating Station
Ceredo Electric Generating Station
Ceredo Electric Generating Station
Ceredo Electric Generating Station
Fort Martin Power Station
Fort Martin Power Station
Harrison Power Station
Harrison Power Station
Harrison Power Station
Harrison Power Station
John E Amos
John E Amos
John E Amos
John E Amos
Kammer
Kammer
Kammer
Kammer
Kanawha River
Kanawha River
Kanawha River
Mitchell (WV)
Mitchell (WV)
Mitchell (WV)
Mount Storm Power Station
Mount Storm Power Station
Mount Storm Power Station
Mount Storm Power Station
Mountaineer (1301)
North Branch Power Station
North Branch Power Station
North Branch Power Station
Phil Sporn
Phil Sporn
Phil Sporn
Phil Sporn
Phil Sporn
PLANT
CODE
55284
55284
55284
55284
55284
55284
55276
55276
55276
55276
55276
55276
3943
3943
3944
3944
3944
3944
3935
3935
3935
3935
3947
3947
3947
3947
3936
3936
3936
3948
3948
3948
3954
3954
3954
3954
6264
7537
7537
7537
3938
3938
3938
3938
3938
STACK/UNIT ID*
GS07
GS08
GS09
GS10
GS11
GS12
01
02
03
04
05
06
1
2
XS123(1,2, 3)
1
2
3
CS012(1,2)
1
2
3
03013(1,2,3)
1
2
3
03012(1,2)
1
2
03012(1,2)
1
2
CSO (1 , 2)
1
2
3
1
CS1 (1A, 1B)
1A
1B
03014(11,21,31,41)
11
21
31
41
2004
ALLOWANCES
ALLOCATED
0
0
0
0
0
0
0
0
0
0
0
0
17,935
17,767
20,966
19,902
17,898
22,589
25,899
41,512
8,082
8,390
7,499
4,462
4,291
18,963
19,622
18,855
17,688
18,296
35,223
0
0
3,130
2,965
3,313
3,053
HELD IN
ACCOUNTS AS
OF 3/1/2005
0
0
0
0
0
0
2
2
2
2
2
3
49,628
51,241
3,833
3,574
3,962
34,400
24,897
47,907
29,863
20,104
29,657
9,980
6,985
33,120
31,377
2,348
2,557
1,440
38,959
549
537
9,147
9,321
8,391
9,738
ALLOWANCES
DEDUCTED
0
0
0
0
0
0
0
0
0
0
0
0
49,128
50,741
3,333
3,074
3,462
33,396
24,169
42,588
13,828
11,435
14,753
5,390
6,781
32,154
30,463
2,032
2,222
1,309
37,823
499
488
6,659
6,153
5,876
6,251
ALLOWANCES
CARRIED OVER
TO 2005
0
0
0
0
0
0
2
2
2
2
2
3
500
500
500
500
500
1,004
728
5,319
16,035
8,669
14,904
4,590
204
966
914
316
335
131
1,136
50
49
2,488
3,168
2,515
3,487
A, 89
-------
APPENDIX A: ACID RAIN PROGRAM - YEAR 2004 SO2 ALLOWANCE HOLDINGS AND DEDUCTIONS
STATE
WV
wv
WV
wv
wv
wv
wv
wv
wv
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
PLANT NAME
Phil Sporn
Pleasants Energy, LLC
Pleasants Energy, LLC
Pleasants Power Station
Pleasants Power Station
Rivesville Power Station
Rivesville Power Station
Willow Island Power Station
Willow Island Power Station
Dave Johnston
Dave Johnston
Dave Johnston
Dave Johnston
Jim Bridger
Jim Bridger
Jim Bridger
Jim Bridger
Laramie River
Laramie River
Laramie River
Naughton
Naughton
Naughton
Neil Simpson II
Neil Simpson II
Neil Simpson II (CT2)
Wygen
Wyodak
PLANT
CODE
3938
55349
55349
6004
6004
3945
3945
3946
3946
4158
4158
4158
4158
8066
8066
8066
8066
6204
6204
6204
4162
4162
4162
7504
7504
55477
55479
6101
STACK/UNIT ID*
51
1
2
1
2
7
8
1
2
BW41
BW42
BW43
BW44
BW71
BW72
BW73
BW74
1
2
3
1
2
3
001
CT1
CT2
001
BW91
2004
ALLOWANCES
ALLOCATED
10,617
0
0
17,603
20,194
1,237
2,529
1,496
4,684
4,706
4,572
8,830
6,804
20,913
20,470
19,590
4,065
5,113
4,303
3,823
5,203
6,743
5,216
0
0
0
0
18,317
HELD IN
ACCOUNTS AS
OF 3/1/2005
25,991
10
10
18,846
20,336
244
1,877
2,227
3,600
3,171
3,102
8,533
4,410
6,975
6,716
6,139
3,364
5,567
5,848
4,837
6,718
8,932
5,823
1,081
13
12
774
9,885
ALLOWANCES
DEDUCTED
17,535
1
1
18,646
20,136
144
1,777
2,127
3,400
3,071
3,002
8,433
4,310
6,875
6,616
6,039
3,264
4,178
3,833
4,456
6,618
8,832
5,723
532
0
0
532
7,862
* CS stands for Common Stack, which includes emissions from more than one unit. XS stands for Complex Stack, which includes emissions from one or more
Common Stacks and/or Multiple Stacks (MS).
1 Perry K Steam unit 1 1 had 149 allowances deducted for SO2 emissions and 212 allowances deducted for reduced utilization under the Opt-in program regulations.
ALLOWANCES
CARRIED OVER
TO 2005
8,456
9
9
200
200
100
100
100
200
100
100
100
100
100
100
100
100
1,389
2,015
381
100
100
100
549
13
12
242
2,023
A, 90
-------
2004 Compliance Results for NOx Affected Units
Date of NOx Compliance Assessment: 06/08/2005
ST Plant Name
AL Barry
AL Barry
AL Barry
AL Barry
AL Barry
AL Charles R Lowman
AL Charles R Lowman
AL Charles R Lowman
AL Colbert
AL Colbert
AL Colbert
AL Colbert
AL Colbert
AL E C Gaston
AL EC Gaston
AL EC Gaston
AL E C Gaston
AL E C Gaston
AL Gadsden
AL Gadsden
AL Gorgas
AL Gorgas
AL Gorgas
AL Gorgas
AL Gorgas
AL Greene County
AL Greene County
AL James H Miller Jr
AL James H Miller Jr
AL James H Miller Jr
AL James H Miller Jr
AL Widows Creek
AL Widows Creek
Operating Utility
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Electric Cooperative, Inc.
Alabama Electric Cooperative, Inc.
Alabama Electric Cooperative, Inc.
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Tennessee Valley Authority
Tennessee Valley Authority
ORIS
Code
3
3
3
3
3
56
56
56
47
47
47
47
47
26
26
26
26
26
7
7
8
8
8
8
8
10
10
6002
6002
6002
6002
50
50
Boiler
1
2
3
4
5
1
2
3
1
2
3
4
5
1
2
3
4
5
1
2
10
6
7
8
9
1
2
1
2
3
4
1
2
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emission
Limit
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.46
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.40
0.46
0.46
0.40
0.40
0.68
0.46
0.46
0.46
0.46
0.46
0.46
0.46
Actual Early Election
Emission
Rate
0.42
0.42
0.42
0.27
0.33
0.43
0.49
0.46
0.44
0.44
0.44
0.44
0.23
0.44
0.44
0.47
0.47
0.42
0.55
0.53
0.23
0.43
0.43
0.38
0.39
0.34
0.36
0.27
0.26
0.19
0.18
0.50
0.50
Limit Avg. Plan Limit
AEL
0.46
0.46
0.46
0.46
0.46
0.50
0.50
0.58
0.58
0.58
0.58
0.58
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.58
0.58
Actual
Avg. Plan
Rate
0.29
0.29
0.29
0.29
0.29
0.39
0.39
0.39
0.39
0.39
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.39
0.39
1990
Emission Rate
Not Oper.
0.54
0.54
0.65
0.68
0.69
0.62
0.66
0.80
0.67
0.83
0.86
0.78
0.90
0.78
0.80
0.80
0.78
0.51
0.56
0.73
0.83
0.83
0.55
0.57
0.92
0.82
0.73
0.54
0.44
0.58
0.76
0.76
Change
from 1990
to 2004
-22%
-22%
-58%
-51%
-38%
-21%
-30%
-45%
-34%
-47%
-49%
-71%
-51%
-44%
-41%
-41%
-46%
8%
-5%
-68%
-48%
-48%
-31%
-32%
-63%
-56%
-63%
-52%
-57%
-69%
-34%
-34%
-------
AL Widows Creek
AL Widows Creek
AL Widows Creek
AL Widows Creek
AL Widows Creek
AL Widows Creek
AR Flint Creek Power Plant
AR Independence
AR Independence
AR White Bluff
AR White Bluff
AZ Apache Station
AZ Apache Station
AZ Cholla
AZ Cholla
AZ Cholla
AZ Cholla
AZ Coronado Generating Station
AZ Coronado Generating Station
AZ Irvington Generating Station
AZ Navajo Generating Station
AZ Navajo Generating Station
AZ Navajo Generating Station
AZ Springerville Generating Station
AZ Springerville Generating Station
CO Arapahoe
CO Arapahoe
CO Cameo
CO Cherokee
CO Cherokee
CO Cherokee
CO Cherokee
CO Comanche (470)
CO Comanche (470)
CO Craig
CO Craig
CO Craig
CO Hayden
CO Hayden
CO Martin Drake
CO Martin Drake
CO Martin Drake
CO Pawnee
CO Rawhide Energy Station
CO Ray D Nixon
CO Valmont
CT Bridgeport Harbor Station
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Southwestern Electric Power Company
Entergy Corporation
Entergy Corporation
Entergy Corporation
Entergy Corporation
Arizona Electric Power Cooperative
Arizona Electric Power Cooperative
Arizona Public Service Company
Arizona Public Service Company
Arizona Public Service Company
Arizona Public Service Company
Salt River Project
Salt River Project
Tucson Electric Power Company
Salt River Project
Salt River Project
Salt River Project
Tucson Electric Power Company
Tucson Electric Power Company
Public Service Company of Colorado
Public Service Company of Colorado
Public Service Company of Colorado
Public Service Company of Colorado
Public Service Company of Colorado
Public Service Company of Colorado
Public Service Company of Colorado
Public Service Company of Colorado
Public Service Company of Colorado
Tri-State Generation & Transmission
Tri-State Generation & Transmission
Tri-State Generation & Transmission
Public Service Company of Colorado
Public Service Company of Colorado
Colorado Springs Utilities
Colorado Springs Utilities
Colorado Springs Utilities
Public Service Company of Colorado
Platte River Power Authority
Colorado Springs Utilities
Public Service Company of Colorado
PSEG Power Connecticut, LLC
50
50
50
50
50
50
6138
6641
6641
6009
6009
160
160
113
113
113
113
6177
6177
126
4941
4941
4941
8223
8223
465
465
468
469
469
469
469
470
470
6021
6021
6021
525
525
492
492
492
6248
6761
8219
477
568
3
4
5
6
7
8
1
1
2
1
2
2
3
1
2
3
4
U1B
U2B
4
1
2
3
1
2
3
4
2
1
2
3
4
1
2
Cl
C2
C3
HI
H2
5
6
7
1
101
1
5
BHB3
Averaging Plan 0.46 0.50
Averaging Plan 0.46 0.50
Averaging Plan 0.46 0.50
Averaging Plan 0.46 0.50
Averaging Plan 0.40 0.35
Averaging Plan 0.40 0.30
Early Election 0.46 0.25 0.50
Early Election 0.40 0.25 0.45
Early Election 0.40 0.26 0.45
Early Election 0.40 0.31 0.45
Early Election 0.40 0.29 0.45
Early Election 0.46 0.48 0.50
Early Election 0.46 0.43 0.50
Early Election 0.40 0.36 0.45
Early Election 0.40 0.30 0.45
Early Election 0.40 0.31 0.45
Early Election 0.40 0.32 0.45
Early Election 0.46 0.40 0.50
Early Election 0.46 0.45 0.50
Standard Limitation 0.46 0.43
Early Election 0.40 0.36 0.45
Early Election 0.40 0.36 0.45
Early Election 0.40 0.31 0.45
Early Election 0.40 0.32 0.45
Early Election 0.40 0.37 0.45
Averaging Plan 0.80 0.79
Averaging Plan 0.80 0.25
Standard Limitation 0.46 0.35
Averaging Plan 0.80 0.34
Averaging Plan 0.80 0.62
Early Election 0.46 0.30 0.50
Early Election 0.40 0.33 0.45
Early Election 0.40 0.32 0.45
Early Election 0.46 0.27 0.50
Early Election 0.46 0.26 0.50
Early Election 0.46 0.31 0.50
Early Election 0.46 0.37 0.50
Standard Limitation 0.46 0.43
Standard Limitation 0.40 0.33
Averaging Plan 0.46 0.42
Averaging Plan 0.46 0.40
Averaging Plan 0.46 0.37
Early Election 0.46 0.22 0.50
Early Election 0.40 0.32 0.45
Early Election 0.46 0.26 0.50
Early Election 0.40 0.33 0.45
Early Election 0.40 0.14 0.45
0.58
0.58
0.58
0.58
0.58
0.58
0.39
0.39
0.39
0.39
0.39
0.39
0.80
0.80
0.46
0.46
0.46
0.36
0.36
0.48
0.48
0.39
0.39
0.39
0.76
0.76
0.76
0.76
0.78
0.63
0.31
0.34
0.35
0.29
0.34
0.58
0.58
0.46
0.42
0.36
0.38
0.51
0.51
0.71
0.41
0.41
0.37
0.34
0.33
1.12
1.10
0.96
1.38
1.67
0.73
0.51
0.24
0.31
0.39
0.40
0.28
0.89
0.45
1.09
0.83
0.93
0.62
0.43
0.54
0.17
0.56
-34%
-34%
-34%
-34%
-55%
-52%
-19%
-26%
-26%
7%
-15%
-17%
-26%
-22%
-29%
-14%
-16%
-22%
-12%
-39%
-12%
-12%
-16%
-6%
12%
-29%
-77%
-64%
-75%
-63%
-59%
-35%
33%
-13%
-33%
-23%
32%
-52%
-27%
-61%
-52%
-60%
-65%
-26%
-52%
94%
-75%
-------
DE Edge Moor
DE Edge Moor
DE Indian River
DE Indian River
DE Indian River
DE Indian River
FL Big Bend
FL Big Bend
FL Big Bend
FL Big Bend
FL CDMcIntoshJr Power Plant
FL Crist Electric Generating Plant
FL Crist Electric Generating Plant
FL Crist Electric Generating Plant
FL Crist Electric Generating Plant
FL Crystal River
FL Crystal River
FL Crystal River
FL Crystal River
FL Curtis H. Stanton Energy Center
FL Deerhaven
FL Lansing Smith Generating Plant
FL Lansing Smith Generating Plant
FL Scholz Electric Generating Plant
FL Scholz Electric Generating Plant
FL Seminole(136)
FL Seminole(136)
FL St. Johns River Power
FL St. Johns River Power
GA Bowen
GA Bowen
GA Bowen
GA Bowen
GA Hammond
GA Hammond
GA Hammond
GA Hammond
GA Harllee Branch
GA Harllee Branch
GA Harllee Branch
GA Harllee Branch
GA Jack McDonough
GA Jack McDonough
GA Kraft
GA Kraft
GA Kraft
GA Mclntosh (6124)
Conectiv Delmarva Generation, LLC
Conectiv Delmarva Generation, LLC
Indian River Power, LLC
Indian River Power, LLC
Indian River Power, LLC
Indian River Power, LLC
Tampa Electric Company
Tampa Electric Company
Tampa Electric Company
Tampa Electric Company
City of Lakeland
Gulf Power Company
Gulf Power Company
Gulf Power Company
Gulf Power Company
Progress Energy Corporation
Progress Energy Corporation
Progress Energy Corporation
Progress Energy Corporation
Orlando Utilities Commission
Gainesville Regional Utilities
Gulf Power Company
Gulf Power Company
Gulf Power Company
Gulf Power Company
Seminole Electric Cooperative, Inc.
Seminole Electric Cooperative, Inc.
JEA
JEA
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Savannah Electric & Power Company
Savannah Electric & Power Company
Savannah Electric & Power Company
Savannah Electric & Power Company
593
593
594
594
594
594
645
645
645
645
676
641
641
641
641
628
628
628
628
564
663
643
643
642
642
136
136
207
207
703
703
703
703
708
708
708
708
709
709
709
709
710
710
733
733
733
6124
3
4
1
2
3
4
BB01
BB02
BB03
BB04
3
4
5
6
7
1
2
4
5
1
B2
1
2
1
2
1
2
1
2
1BLR
2BLR
3BLR
4BLR
1
2
3
4
1
2
3
4
MB1
MB2
1
2
3
1
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Early Election
Early Election
Standard Limitation
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.40
0.40
0.46
0.46
0.46
0.46
0.84
0.84
0.84
0.45
0.46
0.45
0.45
0.50
0.50
0.40
0.40
0.46
0.46
0.46
0.46
0.40
0.40
0.50
0.50
0.46
0.46
0.46
0.46
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.50
0.68
0.50
0.68
0.68
0.45
0.45
0.45
0.45
0.45
0.50
0.22
0.25
0.36
0.34
0.32
0.33
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.43
0.36
0.35
0.49
0.34
0.38
0.40
0.47
0.46
0.40
0.49
0.48
0.39
0.54
0.55
0.48
0.46
0.48
0.42
0.25
0.25
0.25
0.24
0.40
0.40
0.40
0.24
0.43
0.43
0.37
0.37
0.26
0.26
0.54
0.54
0.54
0.54
0.50
0.45
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.72
0.72
0.72
0.72
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.00
0.00
0.00
0.00
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.74
0.55
0.81
0.81
0.97
0.57
1.24
1.26
0.64
0.46
0.46
0.43
0.49
1.04
1.16
0.79
0.38
0.50
0.47
0.43
0.53
0.71
0.63
0.69
0.80
0.43
0.36
0.50
0.59
0.67
0.65
0.56
0.58
0.84
0.84
0.84
1.20
1.18
0.99
1.04
1.04
0.66
0.60
0.40
0.40
0.40
0.83
-70%
-55%
-56%
-58%
-67%
-42%
-7%
-16%
-29%
-53%
-71%
-52%
5%
-6%
-2%
-7%
-8%
-32%
-38%
-22%
-31%
12%
28%
-4%
-29%
-63%
-62%
-55%
-59%
-52%
-52%
-52%
-80%
-64%
-57%
-64%
-64%
-61%
-57%
35%
35%
35%
-35%
-------
GA Mitchell (GA)
GA Scherer
GA Scherer
GA Scherer
GA Scherer
GA Wansley (6052)
GA Wansley (6052)
GA Yates
GA Yates
GA Yates
GA Yates
GA Yates
GA Yates
GA Yates
IA Ames
IA Ames
IA Burlington (IA)
IA Council Bluffs
IA Council Bluffs
IA Council Bluffs
IA Dubuque
IA Dubuque
IA Earl F Wisdom
IA Fair Station
IA George Neal North
IA George Neal North
IA George Neal South
IA Lansing
IA Lansing
IA Lansing
IA Lansing
IA Louisa
IA Milton L Kapp
IA Muscatine
IA Ottumwa
IA Prairie Creek
IA Prairie Creek
IA Riverside (1081)
IA Sixth Street
IA Sixth Street
IA Sixth Street
IA Sixth Street
IA Sutherland
IA Sutherland
IL Baldwin Energy Complex
IL Baldwin Energy Complex
IL Baldwin Energy Complex
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
City of Ames
City of Ames
IES Utilities, Inc
MidAmerican Energy Company
MidAmerican Energy Company
MidAmerican Energy Company
Interstate Power & Light Company
Interstate Power & Light Company
Corn Belt Power Cooperative
Central Iowa Power Cooperative
MidAmerican Energy Company
MidAmerican Energy Company
MidAmerican Energy Company
Interstate Power & Light Company
Interstate Power & Light Company
Interstate Power & Light Company
Interstate Power & Light Company
MidAmerican Energy Company
Interstate Power & Light Company
City of Muscatine
Interstate Power & Light Company
IES Utilities, Inc
IES Utilities, Inc
MidAmerican Energy Company
IES Utilities, Inc
IES Utilities, Inc
IES Utilities, Inc
IES Utilities, Inc
IES Utilities, Inc
IES Utilities, Inc
Dynegy Power Corporation
Dynegy Power Corporation
Dynegy Power Corporation
111
6257
6257
6257
6257
6052
6052
728
728
728
728
728
728
728
1122
1122
1104
1082
1082
1082
1046
1046
1217
1218
1091
1091
7343
1047
1047
1047
1047
6664
1048
1167
6254
1073
1073
1081
1058
1058
1058
1058
1077
1077
889
889
889
3
1
2
3
4
1
2
Y1BR
Y2BR
Y3BR
Y4BR
Y5BR
Y6BR
Y7BR
7
8
1
1
2
3
1
5
1
2
2
3
4
1
2
3
4
101
2
9
1
3
4
9
2
3
4
5
1
2
1
2
3
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Averaging Plan
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
AEL
Standard Limitation
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Averaging Plan
Standard Limitation
Early Election
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.45
0.40
0.40
0.45
0.40
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.40
0.46
0.45
0.46
0.40
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.45
0.40
0.40
0.46
0.50
0.45
0.46
0.46
0.46
0.46
0.46
0.46
0.86
0.86
0.45
0.67
0.16
0.16
0.14
0.13
0.24
0.23
0.42
0.45
0.45
0.40
0.40
0.28
0.26
0.38
0.36
0.17
0.47
0.36
0.43
0.65
0.85
0.57
0.41
0.41
0.46
0.34
0.64
0.64
0.68
0.43
0.32
0.14
0.30
0.33
0.52
0.37
0.27
0.54
0.64
0.35
0.21
0.32
0.28
0.30
0.29
0.10
0.45
0.45
0.50
0.50
0.45
0.50
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.59
0.50
0.50
0.50
0.50
0.50
0.45
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.62
0.62
0.62
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.29
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.22
0.22
0.22
0.61
0.52
0.35
0.20
0.21
0.73
0.67
0.56
0.62
0.62
0.56
0.65
0.67
0.61
0.60
0.55
0.63
0.56
0.33
0.37
0.69
0.80
1.11
0.97
1.06
0.39
0.64
0.80
0.80
1.03
0.50
0.25
0.80
0.35
0.69
0.83
1.05
0.82
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.48
0.48
1.70
1.47
0.67
10%
-69%
-54%
-30%
-38%
-67%
-66%
-25%
-27%
-27%
-29%
-38%
-58%
-57%
-37%
-35%
-73%
-16%
9%
16%
-6%
6%
-49%
-58%
-61%
18%
-47%
-20%
-20%
-34%
-14%
28%
-83%
-14%
-52%
-37%
-65%
-67%
-33%
-42%
-82%
-80%
-85%
-------
IL Coffeen
IL Coffeen
IL Crawford
IL Crawford
IL Dallman
IL Duck Creek
IL ED Edwards
IL ED Edwards
IL ED Edwards
IL Fisk
IL Havana
IL Hennepin Power Station
IL Hennepin Power Station
IL Hutsonville
IL Hutsonville
IL Joliet 29
IL Joliet 29
IL Joliet 29
IL Joliet 29
IL Joliet 9
IL Joppa Steam
IL Joppa Steam
IL Joppa Steam
IL Joppa Steam
IL Joppa Steam
IL Joppa Steam
IL Kincaid Station
IL Kincaid Station
IL Marion
IL Meredosia
IL Meredosia
IL Meredosia
IL Meredosia
IL Meredosia
IL Newton
IL Newton
IL Powerton
IL Powerton
IL Powerton
IL Powerton
IL Vermilion Power Station
IL Vermilion Power Station
IL Waukegan
IL Waukegan
IL Will County
IL Will County
IL Will County
Ameren Energy Generating Company 861 01
Ameren Energy Generating Company 861 02
Midwest Generation EME, LLC 867 7
Midwest Generation EME, LLC 867 8
City of Springfield, IL 963 33
AmerenEnergy Resources Generating Company 6016 1
AmerenEnergy Resources Generating Company 856 1
AmerenEnergy Resources Generating Company 856 2
AmerenEnergy Resources Generating Company 856 3
Midwest Generation EME, LLC 886 19
Dynegy Power Corporation 891 9
Dynegy Power Corporation 892 1
Dynegy Power Corporation 892 2
Ameren Energy Generating Company 863 05
Ameren Energy Generating Company 863 06
Midwest Generation EME, LLC 384 71
Midwest Generation EME, LLC 384 72
Midwest Generation EME, LLC 384 81
Midwest Generation EME, LLC 384 82
Midwest Generation EME, LLC 874 5
Electric Energy, Inc. 887 1
Electric Energy, Inc. 887 2
Electric Energy, Inc. 887 3
Electric Energy, Inc. 887 4
Electric Energy, Inc. 887 5
Electric Energy, Inc. 887 6
Dominion Energy Services Company 876 1
Dominion Energy Services Company 876 2
Southern Illinois Power Cooperative 976 4
Ameren Energy Generating Company 864 01
Ameren Energy Generating Company 864 02
Ameren Energy Generating Company 864 03
Ameren Energy Generating Company 864 04
Ameren Energy Generating Company 864 05
Ameren Energy Generating Company 6017 1
Ameren Energy Generating Company 6017 2
Midwest Generation EME, LLC 879 51
Midwest Generation EME, LLC 879 52
Midwest Generation EME, LLC 879 61
Midwest Generation EME, LLC 879 62
Dynegy Midwest Generation, Inc. 897 1
Dynegy Midwest Generation, Inc. 897 2
Midwest Generation EME, LLC 883 7
Midwest Generation EME, LLC 883 8
Midwest Generation EME, LLC 884 1
Midwest Generation EME, LLC 884 2
Midwest Generation EME, LLC 884 3
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Averaging Plan/AEL
Averaging Plan
Averaging Plan
Averaging Plan/AEL
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Early Election
Early Election
Standard Limitation
Standard Limitation
Early Election
0.86
0.86
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.40
0.46
0.40
0.45
0.45
0.45
0.40
0.40
0.40
0.40
0.86
0.45
0.45
0.45
0.45
0.45
0.45
0.86
0.86
0.86
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.86
0.86
0.86
0.86
0.45
0.45
0.40
0.40
0.86
0.86
0.40
0.36
0.36
0.13
0.14
0.28
0.27
0.43
0.32
0.31
0.13
0.20
0.14
0.14
0.37
0.36
0.12
0.12
0.13
0.13
0.44
0.12
0.12
0.13
0.13
0.13
0.13
0.47
0.47
0.71
0.49
0.49
0.49
0.49
0.29
0.13
0.12
0.53
0.53
0.53
0.53
0.39
0.39
0.14
0.15
0.76
0.79
0.14
0.45
0.45
0.45
0.58
0.53
0.45
0.86
0.86
0.46
0.46
0.46
0.46
0.62
0.62
0.62
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.62
0.62
0.36
0.36
0.31
0.31
0.31
0.31
0.22
0.22
0.22
0.18
0.18
0.18
0.18
0.18
0.18
0.18
0.18
0.18
0.22
0.22
0.45
0.45
0.45
1.23
1.23
0.33
0.48
0.55
0.90
0.98
1.00
1.25
0.39
0.46
0.57
0.59
0.70
0.67
0.32
0.32
0.46
0.46
0.91
0.56
0.56
0.56
0.56
0.56
0.56
1.47
1.47
1.15
0.50
0.50
0.50
0.50
0.67
0.47
0.39
0.92
0.92
0.92
0.92
0.94
0.74
0.26
0.41
0.89
0.87
0.39
-71%
-71%
-61%
-71%
-49%
-70%
-56%
-68%
-75%
-67%
-57%
-75%
-76%
-47%
-46%
-63%
-63%
-72%
-72%
-52%
-79%
-79%
-77%
-77%
-77%
-77%
-68%
-68%
-38%
-2%
-2%
-2%
-2%
-57%
-72%
-69%
-42%
-42%
-42%
-42%
-59%
-47%
-46%
-63%
-15%
-9%
-64%
-------
IL Will County
IL Wood River Power Station
IL Wood River Power Station
IN A B Brown Generating Station
IN A B Brown Generating Station
IN Bailly Generating Station
IN Bailly Generating Station
IN Cayuga
IN Cayuga
IN Clifty Creek
IN Clifty Creek
IN Clifty Creek
IN Clifty Creek
IN Clifty Creek
IN Clifty Creek
IN Dean H Mitchell Generating Station
IN Dean H Mitchell Generating Station
IN Dean H Mitchell Generating Station
IN Dean H Mitchell Generating Station
IN Edwardsport
IN Edwardsport
IN Edwardsport
IN F B Culley Generating Station
IN F B Culley Generating Station
IN F B Culley Generating Station
IN Frank E Ratts
IN Frank E Ratts
IN Gibson
IN Gibson
IN Gibson
IN Gibson
IN Gibson
IN Harding Street Station (EW Stout)
IN Harding Street Station (EW Stout)
IN Harding Street Station (EW Stout)
IN IPL Eagle Valley Generating Station
IN IPL Eagle Valley Generating Station
IN IPL Eagle Valley Generating Station
IN IPL Eagle Valley Generating Station
IN Merom
IN Merom
IN Michigan City Generating Station
IN Petersburg
IN Petersburg
IN Petersburg
IN Petersburg
IN R Gallagher
Midwest Generation EME, LLC
Dynegy Power Corporation
Dynegy Power Corporation
Southern Indiana Gas and Electric Company
Southern Indiana Gas and Electric Company
Northern Indiana Public Service Company
Northern Indiana Public Service Company
PSI Energy, Inc.
PSI Energy, Inc.
Indiana Kentucky Electric Corp
Indiana Kentucky Electric Corp
Indiana Kentucky Electric Corp
Indiana Kentucky Electric Corp
Indiana Kentucky Electric Corp
Indiana Kentucky Electric Corp
Northern Indiana Public Service Company
Northern Indiana Public Service Company
Northern Indiana Public Service Company
Northern Indiana Public Service Company
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
Southern Indiana Gas and Electric Company
Southern Indiana Gas and Electric Company
Southern Indiana Gas and Electric Company
Hoosier Energy REC, Inc.
Hoosier Energy REC, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
Indianapolis Power & Light Company
Indianapolis Power & Light Company
Indianapolis Power & Light Company
Indianapolis Power & Light Company
Indianapolis Power & Light Company
Indianapolis Power & Light Company
Indianapolis Power & Light Company
Hoosier Energy REC, Inc.
Hoosier Energy REC, Inc.
Northern Indiana Public Service Company
Indianapolis Power & Light Company
Indianapolis Power & Light Company
Indianapolis Power & Light Company
Indianapolis Power & Light Company
PSI Energy, Inc.
884
898
898
6137
6137
995
995
1001
1001
983
983
983
983
983
983
996
996
996
996
1004
1004
1004
1012
1012
1012
1043
1043
6113
6113
6113
6113
6113
990
990
990
991
991
991
991
6213
6213
997
994
994
994
994
1008
4
4
5
1
2
7
8
1
2
1
2
3
4
5
6
11
4
5
6
7-1
7-2
8-1
1
2
3
1SG1
2SG1
1
2
3
4
5
50
60
70
3
4
5
6
1SG1
2SG1
12
1
2
3
4
1
Early Election
Averaging Plan
Averaging Plan
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.40
0.40
0.40
0.46
0.46
0.86
0.86
0.45
0.45
0.84
0.84
0.84
0.84
0.84
0.84
0.46
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.46
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.46
0.46
0.86
0.45
0.45
0.45
0.45
0.50
0.14
0.14
0.16
0.40
0.31
0.75
0.75
0.32
0.36
0.55
0.55
0.55
0.58
0.58
0.58
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.77
0.72
0.75
0.66
0.17
0.17
0.47
0.47
0.38
0.38
0.33
0.38
0.35
0.31
0.30
0.32
0.66
0.66
0.42
0.42
0.27
0.31
0.45
0.27
0.21
0.24
0.24
0.39
0.45
0.50
0.50
0.50
0.45
0.45
0.45
0.50
0.50
0.62
0.62
0.75
0.75
0.49
0.49
0.84
0.84
0.84
0.84
0.84
0.84
0.22
0.22
0.46
0.46
0.39
0.39
0.54
0.54
0.54
0.54
0.54
0.54
0.49
0.49
0.49
0.50
0.50
0.50
0.47
0.47
0.49
0.49
0.49
0.49
0.49
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.47
0.47
0.75
0.45
0.45
0.45
0.45
0.49
0.39
0.39
0.39
0.21
0.21
0.21
0.33
0.33
0.39
0.39
0.39
0.39
0.39
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.33
0.33
0.46
0.28
0.28
0.28
0.28
0.39
0.31
0.70
0.61
0.61
0.39
1.51
1.51
0.42
0.47
1.68
1.68
1.68
1.88
1.88
1.88
0.58
0.43
0.43
0.58
0.77
0.98
0.76
0.79
1.05
1.23
1.08
1.09
1.03
1.12
0.52
0.66
0.50
0.63
0.65
0.71
0.74
0.74
0.67
0.47
0.23
0.63
1.32
0.56
0.63
0.37
0.37
0.74
-55%
-80%
-74%
-34%
-21%
-50%
-50%
-24%
-23%
-67%
-67%
-67%
-69%
-69%
-69%
0%
-27%
-1%
-16%
-84%
-86%
-56%
-57%
-63%
-66%
-37%
-42%
-30%
-51%
-54%
-55%
-11%
-11%
-37%
-11%
17%
-51%
-66%
-52%
-67%
-35%
-35%
-47%
-------
IN R Gallagher
IN R Gallagher
IN R Gallagher
IN R M Schahfer Generating Station
IN R M Schahfer Generating Station
IN R M Schahfer Generating Station
IN R M Schahfer Generating Station
IN Rockport
IN Rockport
IN State Line Generating Station (IN)
IN State Line Generating Station (IN)
IN Tanners Creek
IN Tanners Creek
IN Tanners Creek
IN Tanners Creek
IN Wabash River
IN Wabash River
IN Wabash River
IN Wabash River
IN Wabash River
IN Wabash River
IN Warrick
IN Whitewater Valley
IN Whitewater Valley
KS Holcomb
KS Jeffrey Energy Center
KS Jeffrey Energy Center
KS Jeffrey Energy Center
KS LaCygne
KS LaCygne
KS Lawrence Energy Center
KS Lawrence Energy Center
KS Lawrence Energy Center
KS Nearman Creek
KS Quindaro
KS Quindaro
KS Riverton
KS Riverton
KS Tecumseh Energy Center
KS Tecumseh Energy Center
KY Big Sandy
KY Big Sandy
KY Cane Run
KY Cane Run
KY Cane Run
KY Coleman
KY Coleman
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
Northern Indiana Public Service Company
Northern Indiana Public Service Company
Northern Indiana Public Service Company
Northern Indiana Public Service Company
Indiana Michigan Power Company
Indiana Michigan Power Company
State Line Energy, LLC
State Line Energy, LLC
Indiana Michigan Power Company
Indiana Michigan Power Company
Indiana Michigan Power Company
Indiana Michigan Power Company
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
Alco, Inc.
City of Richmond
City of Richmond
Southwestern Electric Power Company
Westar Energy, Inc.
Westar Energy, Inc.
Westar Energy, Inc.
Kansas City Power & Light Company
Kansas City Power & Light Company
Westar Energy, Inc.
Westar Energy, Inc.
Westar Energy, Inc.
Kansas City Bd. of Public Utilities
Kansas City Bd. of Public Utilities
Kansas City Bd. of Public Utilities
Empire District Electric Company
Empire District Electric Company
Westar Energy, Inc.
Westar Energy, Inc.
Kentucky Power Company
Kentucky Power Company
Louisville Gas and Electric Company
Louisville Gas and Electric Company
Louisville Gas and Electric Company
Western Kentucky Energy Corporation
Western Kentucky Energy Corporation
1008
1008
1008
6085
6085
6085
6085
6166
6166
981
981
988
988
988
988
1010
1010
1010
1010
1010
1010
6705
1040
1040
108
6068
6068
6068
1241
1241
1250
1250
1250
6064
1295
1295
1239
1239
1252
1252
1353
1353
1363
1363
1363
1381
1381
2
3
4
14
15
17
18
MB1
MB2
3
4
Ul
U2
U3
U4
1
2
3
4
5
6
4
1
2
SGU1
1
2
3
1
2
3
4
5
Nl
1
2
39
40
10
9
BSU1
BSU2
4
5
6
Cl
C2
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Early Election
Early Election
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Early Election
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Standard Limitation
Standard Limitation
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/AEL
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
0.50
0.50
0.50
0.86
0.46
0.40
0.40
0.46
0.46
0.40
0.86
0.80
0.80
0.80
0.86
0.50
0.50
0.50
0.46
0.50
0.45
0.68
0.46
0.40
0.46
0.40
0.40
0.40
0.86
0.50
0.40
0.40
0.40
0.46
0.86
0.50
0.46
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.40
0.50
0.50
0.39
0.36
0.36
0.42
0.17
0.21
0.22
0.22
0.22
0.19
0.66
0.41
0.41
0.41
0.41
0.08
0.42
0.42
0.42
0.42
0.42
0.32
0.33
0.33
0.32
0.32
0.30
0.40
0.98
0.34
0.32
0.32
0.19
0.42
0.81
0.29
0.44
0.43
0.32
0.37
0.36
0.36
0.32
0.38
0.31
0.34
0.30
0.50
0.45
0.45
0.50
0.50
0.45
0.49
0.49
0.49
0.75
0.75
0.59
0.59
0.70
0.70
0.59
0.59
0.59
0.59
0.49
0.49
0.49
0.49
0.49
0.49
0.50
0.45
0.40
0.40
0.40
0.68
0.68
0.40
0.40
0.40
0.50
0.50
0.45
0.57
0.50
0.50
0.45
0.40
0.40
0.59
0.59
0.49
0.49
0.39
0.39
0.39
0.46
0.46
0.40
0.40
0.49
0.49
0.40
0.40
0.40
0.40
0.39
0.39
0.39
0.39
0.39
0.39
0.31
0.31
0.31
0.65
0.65
0.31
0.31
0.31
0.31
0.31
0.40
0.40
0.33
0.33
0.95
0.95
0.95
1.33
0.42
0.46
0.44
0.32
0.32
0.32
0.75
1.14
1.14
1.14
1.91
0.95
0.95
0.92
Not Oper.
0.85
0.37
1.00
0.71
0.71
0.32
0.36
0.47
0.46
1.09
0.29
0.45
0.51
0.34
0.46
0.97
0.64
0.83
0.55
0.44
0.42
1.33
1.33
0.84
1.15
1.02
1.41
1.29
-59%
-62%
-62%
-68%
-60%
-54%
-50%
-31%
-31%
-41%
-12%
-64%
-64%
-64%
-79%
-92%
-56%
-54%
-51%
14%
-68%
-54%
-54%
0%
-11%
-36%
-13%
-10%
17%
-29%
-37%
-44%
-9%
-16%
-55%
-47%
-22%
-27%
-12%
-73%
-73%
-62%
-67%
-70%
-76%
-77%
-------
KY Coleman
KY DB Wilson
KY EW Brown
KY EW Brown
KY EW Brown
KY East Bend
KY Elmer Smith
KY Ghent
KY Ghent
KY Ghent
KY Ghent
KY Green River
KY Green River
KY Green River
KY Green River
KY Green River
KY HLSpurlock
KY HLSpurlock
KY HMP&L Station 2
KY HMP&L Station 2
KY JohnS. Cooper
KY JohnS. Cooper
KY Mill Creek
KY Mill Creek
KY Mill Creek
KY Mill Creek
KY Paradise
KY Paradise
KY Paradise
KY RD Green
KY RD Green
KY Robert Reid
KY Shawnee
KY Shawnee
KY Shawnee
KY Shawnee
KY Shawnee
KY Shawnee
KY Shawnee
KY Shawnee
KY Shawnee
KY Trimble County
KY Tyrone
KY William C. Dale
KY William C. Dale
LA Big Cajun 2
LA Big Cajun 2
Western Kentucky Energy Corporation
Western Kentucky Energy Corporation
Louisville Gas and Electric Company
Louisville Gas and Electric Company
Louisville Gas and Electric Company
Cincinnati Gas & Electric Company
Owensboro Municipal Utilities
Kentucky Utilities Company
Kentucky Utilities Company
Kentucky Utilities Company
Kentucky Utilities Company
Kentucky Utilities Company
Kentucky Utilities Company
Kentucky Utilities Company
Kentucky Utilities Company
Kentucky Utilities Company
East Kentucky Power Cooperative
East Kentucky Power Cooperative
WKE Station Two, Inc.
WKE Station Two, Inc.
East Kentucky Power Cooperative
East Kentucky Power Cooperative
Louisville Gas and Electric Company
Louisville Gas and Electric Company
Louisville Gas and Electric Company
Louisville Gas and Electric Company
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Western Kentucky Energy Corporation
Western Kentucky Energy Corporation
WKE Station Two, Inc.
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Louisville Gas and Electric Company
Kentucky Utilities Company
East Kentucky Power Cooperative
East Kentucky Power Cooperative
Louisiana Generating, LLC
Louisiana Generating, LLC
1381
6823
1355
1355
1355
6018
1374
1356
1356
1356
1356
1357
1357
1357
1357
1357
6041
6041
1382
1382
1384
1384
1364
1364
1364
1364
1378
1378
1378
6639
6639
1383
1379
1379
1379
1379
1379
1379
1379
1379
1379
6071
1361
1385
1385
6055
6055
C3
Wl
1
2
3
2
2
1
2
3
4
1
2
3
4
5
1
2
HI
H2
1
2
1
2
3
4
1
2
3
Gl
G2
Rl
1
2
3
4
5
6
7
8
9
1
5
3
4
2B1
2B2
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Early Election
Early Election
Early Election
Early Election
0.50
0.46
0.50
0.45
0.45
0.50
0.45
0.45
0.40
0.46
0.46
0.46
0.46
0.46
0.46
0.50
0.50
0.40
0.50
0.50
0.50
0.50
0.40
0.40
0.46
0.46
0.86
0.86
0.86
0.50
0.50
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.40
0.46
0.46
0.46
0.46
0.46
0.33
0.34
0.47
0.32
0.32
0.29
0.28
0.26
0.27
0.21
0.21
Not Oper.
Not Oper.
Not Oper.
0.38
0.37
0.44
0.23
0.36
0.35
0.46
0.46
0.27
0.27
0.22
0.24
0.54
0.50
0.53
0.33
0.29
0.42
0.36
0.36
0.36
0.36
0.36
0.38
0.38
0.38
0.38
0.22
0.35
0.44
0.44
0.32
0.25
0.50
0.45
0.45
0.45
0.50
0.50
0.45
0.50
0.50
0.50
0.50
0.49
0.49
0.45
0.45
0.45
0.49
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.49
0.49
0.58
0.58
0.58
0.49
0.49
0.49
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.45
0.33
0.33
0.27
0.27
0.27
0.39
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.33
0.33
0.39
0.39
0.39
0.33
0.33
0.33
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.27
1.14
0.56
1.00
0.59
0.57
0.31
0.86
0.56
0.54
0.55
0.55
0.65
0.65
0.65
0.99
0.84
0.90
0.47
1.34
1.34
0.90
0.90
0.76
0.79
0.62
0.57
1.83
1.72
1.94
0.41
0.45
0.78
0.71
0.71
0.71
0.71
0.71
0.67
0.67
0.67
0.67
0.62
0.90
0.73
0.73
0.28
0.25
-71%
-39%
-53%
-46%
-44%
-6%
-67%
-54%
-50%
-62%
-62%
-62%
-56%
-51%
-51%
-73%
-74%
-49%
-49%
-64%
-66%
-65%
-58%
-70%
-71%
-73%
-20%
-36%
-46%
-49%
-49%
-49%
-49%
-49%
-43%
-43%
-43%
-43%
-65%
-61%
-40%
-40%
14%
0%
-------
LA Big Cajun 2
LA Dolet Hills Power Station
LA RS Nelson
LA Rodemacher Power Station (6190)
MA Brayton Point
MA Brayton Point
MA Brayton Point
MA Mount Tom
MA Salem Harbor
MA Salem Harbor
MA Salem Harbor
MA Somerset
MA Somerset
MD Brandon Shores
MD Brandon Shores
MD CP Crane
MD CP Crane
MD Chalk Point
MD Chalk Point
MD Dickerson
MD Dickerson
MD Dickerson
MD Herbert A Wagner
MD Herbert A Wagner
MD Morgantown
MD Morgantown
MD R. Paul Smith Power Station
MD R. Paul Smith Power Station
MI BCCobb
MI BCCobb
MI B C Cobb
MI B C Cobb
MI BCCobb
MI Belle River
MI Belle River
MI Dan E Kam
MI Dan E Kam
MI Eckert Station
MI Eckert Station
MI Eckert Station
MI Eckert Station
MI Eckert Station
MI Eckert Station
MI Endicott Generating
MI Erickson
MI Harbor Beach
MI J B Sims
Louisiana Generating, LLC
CLECO Power, LLC
Entergy Corporation
CLECO Power, LLC
Dominion Energy Brayton Point, LLC
Dominion Energy Brayton Point, LLC
Dominion Energy Brayton Point, LLC
Northeast Generation Services
Dominion Energy Salem Harbor, LLC
Dominion Energy Salem Harbor, LLC
Dominion Energy Salem Harbor, LLC
NRG Somerset Operations, Inc.
NRG Somerset Operations, Inc.
Constellation Energy Commodities Group, Inc.
Constellation Energy Commodities Group, Inc.
Constellation Energy Commodities Group, Inc.
Constellation Energy Commodities Group, Inc.
Mirant Chalk Point, LLC
Mirant Chalk Point, LLC
Mirant Mid-Atlantic, LLC
Mirant Mid-Atlantic, LLC
Mirant Mid-Atlantic, LLC
Constellation Energy Commodities Group, Inc.
Constellation Energy Commodities Group, Inc.
Mirant Mid-Atlantic, LLC
Mirant Mid-Atlantic, LLC
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
Consumers Energy Company
Consumers Energy Company
Consumers Energy Company
Consumers Energy Company
Consumers Energy Company
Detroit Edison Company
Detroit Edison Company
Consumers Energy Company
Consumers Energy Company
Lansing Board of Water and Light
Lansing Board of Water and Light
Lansing Board of Water and Light
Lansing Board of Water and Light
Lansing Board of Water and Light
Lansing Board of Water and Light
Michigan South Central Power Agency
Lansing Board of Water and Light
Detroit Edison Company
Grand Haven Board of Light and Power
6055
51
1393
6190
1619
1619
1619
1606
1626
1626
1626
1613
1613
602
602
1552
1552
1571
1571
1572
1572
1572
1554
1554
1573
1573
1570
1570
1695
1695
1695
1695
1695
6034
6034
1702
1702
1831
1831
1831
1831
1831
1831
4259
1832
1731
1825
2B3
1
6
2
1
2
3
1
1
2
3
7
8
1
2
1
2
1
2
1
2
3
2
3
1
2
11
9
1
2
3
4
5
1
2
1
2
1
2
3
4
5
6
1
1
1
3
Early Election
Early Election
Early Election
Early Election
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
AEL
AEL
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
AEL
AEL
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Early Election
0.46
0.46
0.40
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.46
0.40
0.40
0.46
0.46
0.86
0.86
0.50
0.50
0.40
0.40
0.40
0.46
0.68
0.45
0.45
0.45
0.50
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.40
0.46
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.16
0.46
0.24
0.39
0.23
0.24
0.34
0.28
0.22
0.24
0.25
Not Oper.
0.22
0.33
0.31
0.71
0.70
0.47
0.47
0.37
0.37
0.37
0.44
0.23
0.45
0.41
0.36
0.37
0.07
0.02
0.02
0.41
0.16
0.20
0.17
0.28
0.20
0.23
0.28
0.20
0.21
0.21
0.21
0.24
0.25
0.50
0.29
0.50
0.50
0.45
0.50
0.45
0.45
0.50
0.56
0.56
0.56
0.56
0.86
1.20
0.70
0.70
0.56
0.56
0.55
0.55
0.46
0.46
0.46
0.46
0.46
0.53
0.53
0.46
0.46
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.53
0.38
0.38
0.38
0.38
0.38
0.38
0.34
0.34
0.28
0.28
0.28
0.28
0.28
0.32
0.32
0.28
0.28
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.32
0.24
0.62
0.20
0.38
0.70
0.70
1.43
1.00
1.10
1.10
1.10
1.00
0.67
0.47
0.45
1.27
1.46
1.35
1.35
0.65
0.65
0.65
0.83
1.11
0.95
0.95
0.78
0.87
1.10
1.10
1.10
0.38
0.36
0.26
0.16
0.64
0.91
0.77
0.57
0.44
0.62
0.63
0.70
0.58
0.93
0.90
0.51
-33%
-26%
20%
3%
-67%
-66%
-76%
-72%
-80%
-78%
-77%
-67%
-30%
-31%
-44%
-52%
-65%
-65%
-43%
-43%
-43%
-47%
-79%
-53%
-57%
-54%
-57%
-94%
-98%
-98%
8%
-56%
-23%
6%
-56%
-78%
-70%
-51%
-55%
-66%
-67%
-70%
-59%
-73%
-44%
-43%
-------
MI JCWeadock
MI JCWeadock
MI J H Campbell
MI J H Campbell
MI JH Campbell
MI J R Whiting
MI J R Whiting
MI J R Whiting
MI James De Young
MI Marysville
MI Marysville
MI Marysville
MI Marysville
MI Monroe
MI Monroe
MI Monroe
MI Monroe
MI Presque Isle
MI Presque Isle
MI Presque Isle
MI Presque Isle
MI Presque Isle
MI Presque Isle
MI Presque Isle
MI Presque Isle
MI River Rouge
MI River Rouge
MI Shiras
MI St. Clair
MI St. Clair
MI St. Clair
MI St. Clair
MI St. Clair
MI St. Clair
MI Trenton Channel
MI Trenton Channel
MI Trenton Channel
MI Trenton Channel
MI Trenton Channel
MI Wyandotte
MN AllenS King
MN Black Dog
MN Black Dog
MN Boswell Energy Center
MN Boswell Energy Center
MN Boswell Energy Center
MN Boswell Energy Center
Consumers Energy Company
Consumers Energy Company
Consumers Energy Company
Consumers Energy Company
Consumers Energy Company
Consumers Energy Company
Consumers Energy Company
Consumers Energy Company
City of Holland
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Detroit Edison Company
Detroit Edison Company
Marquette Board of Light and Power
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
Detroit Edison Company
City of Wyandotte
NSP (Xcel Energy)
NSP (Xcel Energy)
NSP (Xcel Energy)
Minnesota Power and Light Company
Minnesota Power and Light Company
Minnesota Power and Light Company
Minnesota Power and Light Company
1720
1720
1710
1710
1710
1723
1723
1723
1830
1732
1732
1732
1732
1733
1733
1733
1733
1769
1769
1769
1769
1769
1769
1769
1769
1740
1740
1843
1743
1743
1743
1743
1743
1743
1745
1745
1745
1745
1745
1866
1915
1904
1904
1893
1893
1893
1893
7
8
1
2
3
1
2
3
5
10
11
12
9
1
2
3
4
2
3
4
5
6
7
8
9
2
3
3
1
2
3
4
6
7
16
17
18
19
9A
7
1
3
4
1
2
3
4
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan
Averaging Plan/EE
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan
0.40
0.40
0.45
0.68
0.46
0.46
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.68
0.68
0.68
0.68
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.46
0.40
0.46
0.40
0.46
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.46
0.86
0.46
0.46
0.46
0.46
0.40
0.40
0.29
0.32
0.16
0.29
0.34
0.23
0.25
0.24
0.42
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.43
0.43
0.44
0.44
0.37
0.37
0.37
0.37
0.38
0.48
0.39
0.48
0.28
0.30
0.13
0.64
0.37
0.34
0.57
0.17
0.17
0.43
0.43
0.43
0.43
0.17
0.38
0.70
0.77
0.77
0.40
0.40
0.38
0.33
0.45
0.45
0.50
0.50
0.50
0.50
0.50
0.45
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.41
0.41
0.41
0.41
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.32
0.32
0.32
0.32
0.32
0.32
0.32
0.32
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.32
0.32
0.32
0.32
0.32
0.32
0.32
0.32
0.32
0.32
0.32
0.32
0.32
0.44
0.44
0.44
0.38
0.38
0.38
0.38
0.44
0.44
0.69
1.00
0.69
0.82
0.96
1.04
0.99
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.86
0.86
0.78
0.78
0.75
0.75
0.75
0.91
0.88
0.49
0.53
0.66
0.44
0.83
0.22
0.54
0.58
0.63
0.57
0.39
0.31
0.47
0.47
0.47
0.47
0.33
0.69
1.22
0.95
0.95
0.42
0.42
0.42
0.38
-34%
-27%
-77%
-71%
-51%
-72%
-74%
-77%
-58%
-50%
-50%
-44%
-44%
-51%
-51%
-51%
-59%
-57%
-2%
-26%
-27%
-36%
-64%
-41%
19%
-36%
-46%
0%
-56%
-45%
-9%
-9%
-9%
-9%
-48%
-45%
-43%
-19%
-19%
-5%
-5%
-10%
-13%
-------
MN High Bridge
MN High Bridge
MN High Bridge
MN High Bridge
MN Hoot Lake
MN Hoot Lake
MN Laskin Energy Center
MN Laskin Energy Center
MN Minnesota Valley
MN Northeast Station
MN Riverside (1927)
MN Riverside (1927)
MN Riverside (1927)
MN Sherburne County
MN Sherburne County
MN Sherburne County
MN Silver Lake
MN Taconite Harbor Energy Center
MN Taconite Harbor Energy Center
MN Taconite Harbor Energy Center
MO Asbury
MO Blue Valley
MO Man
MO James River
MO James River
MO James River
MO Labadie
MO Labadie
MO Labadie
MO Labadie
MO Meramec
MO Meramec
MO Meramec
MO Meramec
MO Montrose
MO Montrose
MO Montrose
MO New Madrid Power Plant
MO New Madrid Power Plant
MO Rush Island
MO Rush Island
MO Sibley
MO Sikeston
MO Sioux
MO Sioux
MO Southwest
MO Thomas Hill Energy Center
NSP (Xcel Energy)
NSP (Xcel Energy)
NSP (Xcel Energy)
NSP (Xcel Energy)
Otter Tail Power Company
Otter Tail Power Company
Minnesota Power and Light Company
Minnesota Power and Light Company
NSP (Xcel Energy)
City of Austin
NSP (Xcel Energy)
NSP (Xcel Energy)
NSP (Xcel Energy)
NSP (Xcel Energy)
NSP (Xcel Energy)
NSP (Xcel Energy)
Rochester Public Utilities
Minnesota Power and Light Company
Minnesota Power and Light Company
Minnesota Power and Light Company
Empire District Electric Company
City of Independence
Kansas City Power & Light Company
City Utilities of Springfield, MO
City Utilities of Springfield, MO
City Utilities of Springfield, MO
Union Electric Company
Union Electric Company
Union Electric Company
Union Electric Company
Union Electric Company
Union Electric Company
Union Electric Company
Union Electric Company
Kansas City Power & Light Company
Kansas City Power & Light Company
Kansas City Power & Light Company
Associated Electric Cooperative, Inc.
Associated Electric Cooperative, Inc.
Union Electric Company
Union Electric Company
Aquila, Inc.
Sikeston Bd. of Municipal Utilities
Union Electric Company
Union Electric Company
City Utilities of Springfield, MO
Associated Electric Cooperative, Inc.
1912
1912
1912
1912
1943
1943
1891
1891
1918
1961
1927
1927
1927
6090
6090
6090
2008
10075
10075
10075
2076
2132
6065
2161
2161
2161
2103
2103
2103
2103
2104
2104
2104
2104
2080
2080
2080
2167
2167
6155
6155
2094
6768
2107
2107
6195
2168
3
4
5
6
2
3
1
2
4
NEPP
6
7
8
1
2
3
4
1
2
3
1
3
1
3
4
5
1
2
3
4
1
2
3
4
1
2
3
1
2
1
2
3
1
1
2
1
MB1
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.50
0.50
0.50
0.50
0.40
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.86
0.45
0.45
0.46
0.46
0.40
0.40
0.40
0.86
0.40
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.45
0.86
0.86
0.45
0.45
0.86
0.46
0.86
0.86
0.50
0.86
0.60
0.60
0.60
0.60
0.45
0.30
0.49
0.49
Not Oper.
0.45
0.76
0.76
0.95
0.22
0.22
0.35
0.40
0.39
0.39
0.41
0.72
0.29
0.35
0.35
0.37
0.39
0.12
0.12
0.11
0.12
0.20
0.17
0.39
0.18
0.29
0.33
0.33
0.75
0.74
0.10
0.11
0.63
0.22
0.36
0.31
0.34
0.71
0.45
0.50
0.53
0.53
0.53
0.53
0.41
0.41
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.41
0.41
0.41
0.50
0.50
0.50
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.53
0.75
0.75
0.53
0.53
0.53
0.53
0.50
0.75
0.44
0.44
0.44
0.44
0.38
0.38
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.38
0.38
0.38
0.36
0.36
0.36
0.18
0.18
0.18
0.18
0.18
0.18
0.18
0.18
0.57
0.57
0.18
0.18
0.18
0.18
0.36
0.57
0.48
0.48
0.48
0.48
0.58
0.67
0.64
0.64
0.52
0.78
Not Oper.
0.70
0.98
0.45
0.45
0.28
0.82
Not Oper.
Not Oper.
Not Oper.
1.09
0.79
0.31
1.02
0.87
0.93
0.62
0.62
0.62
0.62
0.82
0.63
0.96
1.17
0.32
0.34
0.34
1.47
1.32
0.63
0.63
1.37
0.51
1.07
1.21
0.47
0.90
25%
25%
25%
25%
-22%
-55%
-23%
-23%
-42%
9%
-3%
-51%
-51%
25%
-51%
-34%
-63%
13%
-66%
-57%
-58%
-81%
-81%
-82%
-81%
-76%
-73%
-59%
-85%
-9%
-3%
-3%
-49%
-44%
-84%
-83%
-54%
-57%
-66%
-74%
-28%
-21%
-------
MO Thomas Hill Energy Center
MO Thomas Hill Energy Center
MS Daniel Electric Generating Plant
MS Daniel Electric Generating Plant
MS RD Morrow
MS RD Morrow
MS Watson Electric Generating Plant
MS Watson Electric Generating Plant
MT Colstrip
MT Colstrip
MT Colstrip
MT Colstrip
MT JECorette
MT Lewis & Clark
NC Asheville
NC Asheville
NC Belews Creek
NC Belews Creek
NC Buck
NC Buck
NC Buck
NC Buck
NC Buck
NC Cape Fear
NC Cape Fear
NC Cliffside
NC Cliffside
NC Cliffside
NC Cliffside
NC Cliffside
NC Dan River
NC Dan River
NC Dan River
NC GG Allen
NC GG Allen
NC GG Allen
NC GG Allen
NC GG Allen
NC LVSutton
NC LVSutton
NC LVSutton
NC Lee
NC Lee
NC Lee
NC Marshall
NC Marshall
NC Marshall
Associated Electric Cooperative, Inc.
Associated Electric Cooperative, Inc.
Mississippi Power Company
Mississippi Power Company
South Missisippi Elec. Power Assoc.
South Missisippi Elec. Power Assoc.
Mississippi Power Company
Mississippi Power Company
P P & L Montana, LLC
P P & L Montana, LLC
P P & L Montana, LLC
P P & L Montana, LLC
P P & L Montana, LLC
Montana Dakota Utilities Company
Carolina Power & Light Company
Carolina Power & Light Company
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Carolina Power & Light Company
Carolina Power & Light Company
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Carolina Power & Light Company
Carolina Power & Light Company
Carolina Power & Light Company
Carolina Power & Light Company
Carolina Power & Light Company
Carolina Power & Light Company
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
2168
2168
6073
6073
6061
6061
2049
2049
6076
6076
6076
6076
2187
6089
2706
2706
8042
8042
2720
2720
2720
2720
2720
2708
2708
2721
2721
2721
2721
2721
2723
2723
2723
2718
2718
2718
2718
2718
2713
2713
2713
2709
2709
2709
2727
2727
2727
MB2
MB3
1
2
1
2
4
5
1
2
3
4
2
Bl
1
2
1
2
5
6
7
8
9
5
6
1
2
3
4
5
1
2
3
1
2
3
4
5
1
2
3
1
2
3
1
2
3
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Standard Limitation
Early Election
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Early Election
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
0.86
0.50
0.45
0.45
0.50
0.50
0.50
0.50
0.40
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.68
0.68
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.40
0.46
0.46
0.40
0.40
0.40
0.56
0.24
0.30
0.28
0.46
0.47
0.50
0.57
0.34
0.40
0.40
0.39
0.28
0.37
0.43
0.34
0.41
0.38
0.34
0.36
0.41
0.22
0.23
0.26
0.32
0.34
0.34
0.40
0.41
0.20
0.37
0.38
0.42
0.26
0.28
0.34
0.31
0.32
0.61
0.61
0.51
0.53
0.54
0.38
0.30
0.28
0.31
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.75
0.75
0.46
0.46
0.50
0.50
0.46
0.46
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.57
0.57
0.29
0.29
0.47
0.47
0.29
0.29
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.90
0.31
0.27
0.28
0.42
0.43
1.10
1.22
0.42
0.43
0.34
0.35
0.65
0.57
1.08
0.86
1.46
1.36
0.59
0.54
0.57
0.45
0.51
0.47
0.66
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.51
0.52
0.55
0.56
0.65
0.61
0.64
0.68
0.68
0.63
0.63
1.19
0.82
0.73
0.90
0.48
0.61
0.52
-38%
-23%
11%
0%
10%
9%
-55%
-53%
-19%
-7%
18%
11%
-57%
-35%
-60%
-60%
-72%
-72%
-42%
-33%
-28%
-51%
-55%
-45%
-52%
-61%
-29%
-31%
-25%
-60%
-54%
-47%
-54%
-53%
-3%
-3%
-57%
-35%
-26%
-58%
-38%
-54%
-40%
-------
NC Marshall
NC Mayo
NC Mayo
NC Riverbend
NC Riverbend
NC Riverbend
NC Riverbend
NC Roxboro
NC Roxboro
NC Roxboro
NC Roxboro
NC Roxboro
NC Roxboro
NC W H Weatherspoon
NC W H Weatherspoon
NC W H Weatherspoon
NO Antelope Valley
NO Antelope Valley
NO Coal Creek
NO Coal Creek
NO Coyote
NO LelandOlds
NO LelandOlds
NO Milton R Young
NO Milton R Young
NO Stanton
NO Stanton
NE Gerald Gentleman Station
NE Gerald Gentleman Station
NE Gerald Whelan Energy Center
NE Lon D Wright Power Plant
NE Nebraska City
NE North Omaha
NE North Omaha
NE North Omaha
NE North Omaha
NE North Omaha
NE Platte
NH Merrimack
NH Schiller
NH Schiller
NH Schiller
NJ B L England
NJ Deepwater
NJ Hudson Generating Station
NJ Mercer Generating Station
NJ Mercer Generating Station
Duke Energy Corporation
Carolina Power & Light Company
Carolina Power & Light Company
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Carolina Power & Light Company
Carolina Power & Light Company
Carolina Power & Light Company
Carolina Power & Light Company
Carolina Power & Light Company
Carolina Power & Light Company
Carolina Power & Light Company
Carolina Power & Light Company
Carolina Power & Light Company
Basin Electric Power Cooperative
Basin Electric Power Cooperative
Great River Energy
Great River Energy
Otter Tail Power Company
Basin Electric Power Cooperative
Basin Electric Power Cooperative
Minnkota Power Cooperative, Inc.
Minnkota Power Cooperative, Inc.
Great River Energy
Great River Energy
Nebraska Public Power District
Nebraska Public Power District
Nebraska Municipal Energy Agency
City of Freemont
Omaha Public Power District
Omaha Public Power District
Omaha Public Power District
Omaha Public Power District
Omaha Public Power District
Omaha Public Power District
City of Grand Island
Public Service of New Hampshire
Public Service of New Hampshire
Public Service of New Hampshire
Public Service of New Hampshire
Atlantic City Electric Company
Conectiv Atlantic Generation, LLC
PSEG Fossil LLC
PSEG Fossil LLC
PSEG Fossil LLC
2727
6250
6250
2732
2732
2732
2732
2712
2712
2712
2712
2712
2712
2716
2716
2716
6469
6469
6030
6030
8222
2817
2817
2823
2823
2824
2824
6077
6077
60
2240
6096
2291
2291
2291
2291
2291
59
2364
2367
2367
2367
2378
2384
2403
2408
2408
4
1A
IB
10
7
8
9
1
2
3A
3B
4A
4B
1
2
3
Bl
B2
1
2
Bl
1
2
Bl
B2
1
10
1
2
1
8
1
1
2
3
4
5
1
2
4
5
6
2
8
2
1
2
Early Election
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Standard Limitation
Standard Limitation
Standard Limitation
Early Election
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Early Election
Early Election
Early Election
Early Election
Standard Limitation
Early Election
Standard Limitation
Standard Limitation
Standard Limitation
Early Election
Standard Limitation
Early Election
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
0.40
0.46
0.46
0.40
0.40
0.40
0.40
0.46
0.40
0.46
0.46
0.46
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.40
0.86
0.46
0.86
0.86
0.86
0.46
0.40
0.46
0.46
0.40
0.46
0.46
0.40
0.40
0.40
0.40
0.46
0.40
0.86
0.46
0.46
0.46
0.86
0.46
0.46
0.84
0.84
0.28
0.25
0.25
0.23
0.24
0.42
0.42
0.30
0.28
0.32
0.32
0.26
0.26
0.86
0.86
0.46
0.33
0.33
0.22
0.24
0.73
0.29
0.58
0.84
0.81
0.40
0.37
0.45
0.34
0.30
0.20
0.41
0.31
0.31
0.31
0.33
0.31
0.32
0.28
0.32
0.27
0.28
0.45
0.37
0.44
0.39
0.56
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.45
0.50
0.50
0.45
0.50
0.45
0.45
0.62
0.62
0.62
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.46
0.46
0.46
0.70
0.64
Not Oper.
0.70
0.58
0.58
0.58
1.30
0.76
1.31
Not Oper.
0.57
Not Oper.
0.73
0.73
0.72
0.43
0.27
0.55
0.82
0.81
0.74
1.03
0.81
1.05
0.84
0.47
0.40
0.35
0.30
0.19
0.48
0.41
0.41
0.41
0.38
0.95
0.48
1.96
1.00
1.26
1.07
1.19
0.71
1.34
1.35
1.90
-60%
-61%
-67%
-59%
-28%
-28%
-77%
-63%
-76%
-54%
18%
18%
-36%
-23%
22%
-60%
-71%
-10%
-61%
-44%
4%
-23%
-52%
-21%
13%
-3%
0%
5%
-15%
-24%
-24%
-24%
-13%
-67%
-33%
-86%
-68%
-79%
-74%
-62%
-48%
-67%
-71%
-71%
-------
NM Four Comers Steam Elec Station
NM Four Comers Steam Elec Station
NM Four Comers Steam Elec Station
NM Four Comers Steam Elec Station
NM Four Comers Steam Elec Station
NM Prewitt Escalante Generating Static
NM San Juan
NM San Juan
NM San Juan
NM San Juan
NV Mohave
NV Mohave
NV North Valmy
NV North Valmy
NV Reid Gardner
NV Reid Gardner
NV Reid Gardner
NV Reid Gardner
NY AES Cayuga (Milliken)
NY AES Cayuga (Milliken)
NY AESGreenidge
NY AESGreenidge
NY AESGreenidge
NY AES Somerset (Kintigh )
NY AES Westover (Goudey)
NY AES Westover (Goudey)
NY AES Westover (Goudey)
NY Dunkirk
NY Dunkirk
NY Dunkirk
NY Dunkirk
NY Dynegy Danskammer
NY Dynegy Danskammer
NY Huntley Power
NY Huntley Power
NY Huntley Power
NY Huntley Power
NY Huntley Power
NY Huntley Power
NY Lovett Generating Station
NY Lovett Generating Station
NY Rochester 7 - Russell Station
NY Rochester 7 - Russell Station
NY Rochester 7 - Russell Station
NY Rochester 7 - Russell Station
NY S A Carlson
NY S A Carlson
Arizona Public Service Company
Arizona Public Service Company
Arizona Public Service Company
Arizona Public Service Company
Arizona Public Service Company
Tri-State Generation & Transmission
PNM Resources
PNM Resources
PNM Resources
PNM Resources
Southern California Edison Company
Southern California Edison Company
Sierra Pacific Power Company
Sierra Pacific Power Company
Nevada Power Company
Nevada Power Company
Nevada Power Company
Nevada Power Company
AES Cayuga, LLC
AES Cayuga, LLC
AES Greenidge, LLC
AES Greenidge, LLC
AES Greenidge, LLC
AES Somerset, LLC
AES Westover, LLC
AES Westover, LLC
AES Westover, LLC
NRG Dunkirk Operations, Inc.
NRG Dunkirk Operations, Inc.
NRG Dunkirk Operations, Inc.
NRG Dunkirk Operations, Inc.
Dynegy Power Corporation
Dynegy Power Corporation
NRG Huntley Operations, Inc.
NRG Huntley Operations, Inc.
NRG Huntley Operations, Inc.
NRG Huntley Operations, Inc.
NRG Huntley Operations, Inc.
NRG Huntley Operations, Inc.
Mirant Lovett, LLC
Mirant Lovett, LLC
Rochester Gas & Electric Corporation
Rochester Gas & Electric Corporation
Rochester Gas & Electric Corporation
Rochester Gas & Electric Corporation
City of Jamestown
City of Jamestown
2442
2442
2442
2442
2442
87
2451
2451
2451
2451
2341
2341
8224
8224
2324
2324
2324
2324
2535
2535
2527
2527
2527
6082
2526
2526
2526
2554
2554
2554
2554
2480
2480
2549
2549
2549
2549
2549
2549
2629
2629
2642
2642
2642
2642
2682
2682
1
2
3
4
5
1
1
2
3
4
1
2
1
2
1
2
3
4
1
2
4
5
6
1
11
12
13
1
2
3
4
3
4
63
64
65
66
67
68
4
5
1
2
3
4
10
11
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Early Election
Early Election
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
0.46
0.46
0.46
0.68
0.68
0.40
0.46
0.46
0.46
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.46
0.46
0.45
0.45
0.46
0.46
0.45
0.46
0.46
0.46
0.40
0.40
0.40
0.45
0.45
0.40
0.40
0.84
0.84
0.84
0.84
0.40
0.40
0.46
0.46
0.40
0.40
0.40
0.40
0.46
0.46
0.79
0.66
0.60
0.46
0.49
0.40
0.42
0.46
0.40
0.42
0.42
0.38
0.36
0.44
0.38
0.40
0.32
0.29
0.24
0.24
0.69
0.69
0.34
0.14
0.37
0.37
0.37
0.22
0.20
0.23
0.23
0.25
0.24
Not Oper.
0.54
0.54
0.54
0.22
0.22
0.34
0.40
0.38
0.38
0.31
0.31
0.43
Not Oper.
0.45
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.50
0.50
0.61
0.61
0.61
0.61
0.61
0.46
0.46
0.46
0.46
0.54
0.54
0.54
0.54
0.54
0.42
0.42
0.42
0.42
0.46
0.46
0.46
0.46
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.34
0.34
0.34
0.34
0.21
0.21
0.21
0.21
0.21
0.21
0.21
0.21
0.21
0.40
0.40
0.24
0.24
0.40
0.40
0.40
0.40
0.34
0.34
0.34
0.34
0.82
0.78
1.00
0.51
1.10
0.35
0.42
0.65
0.39
0.42
0.38
0.46
0.51
0.40
1.12
1.13
0.53
0.38
0.66
0.59
0.69
0.69
0.55
0.62
0.62
0.62
0.68
0.48
0.48
0.48
0.48
0.54
0.62
0.91
0.91
0.91
0.91
0.64
0.64
0.57
0.59
0.62
0.65
0.44
0.59
0.90
1.05
-4%
-15%
-40%
-10%
-55%
14%
0%
-29%
3%
0%
11%
-17%
-29%
10%
-66%
-65%
-40%
-24%
-64%
-59%
0%
0%
-38%
-77%
-40%
-40%
-46%
-54%
-58%
-52%
-52%
-54%
-61%
-41%
-41%
-41%
-66%
-66%
-40%
-32%
-39%
-42%
-30%
-47%
-52%
-------
NY S A Carlson
NY S A Carlson
OH Ashtabula
OH Avon Lake Power Plant
OH Avon Lake Power Plant
OH Bay Shore
OH Bay Shore
OH Bay Shore
OH Bay Shore
OH Cardinal
OH Cardinal
OH Cardinal
OH Conesville
OH Conesville
OH Conesville
OH Conesville
OH Eastlake
OH Eastlake
OH Eastlake
OH Eastlake
OH Eastlake
OH Edgewater (2857)
OH Gen JM Gavin
OH Gen JM Gavin
OH Hamilton Municipal Power Plant
OH JM Stuart
OH JM Stuart
OH JM Stuart
OH JM Stuart
OH Killen Station
OH Kyger Creek
OH Kyger Creek
OH Kyger Creek
OH Kyger Creek
OH Kyger Creek
OH Lake Shore
OH Miami Fort
OH Miami Fort
OH Miami Fort
OH Miami Fort
OH Miami Fort
OH Muskingum River
OH Muskingum River
OH Muskingum River
OH Muskingum River
OH Muskingum River
OH OHHutchings
City of Jamestown
City of Jamestown
FirstEnergy Generation Corporation
Orion Power Operating Services - Midwest,
Orion Power Operating Services - Midwest,
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
Cardinal Operating Company
Cardinal Operating Company
Cardinal Operating Company
Columbus Southern Power Company
Columbus Southern Power Company
Columbus Southern Power Company
Columbus Southern Power Company
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
Ohio Edison Company
Ohio Power Company
Ohio Power Company
City of Hamilton
Dayton Power and Light Company
Dayton Power and Light Company
Dayton Power and Light Company
Dayton Power and Light Company
Dayton Power and Light Company
Ohio Valley Electric Corporation
Ohio Valley Electric Corporation
Ohio Valley Electric Corporation
Ohio Valley Electric Corporation
Ohio Valley Electric Corporation
FirstEnergy Generation Corporation
Cincinnati Gas & Electric Company
Cincinnati Gas & Electric Company
Cincinnati Gas & Electric Company
Cincinnati Gas & Electric Company
Cincinnati Gas & Electric Company
Ohio Power Company
Ohio Power Company
Ohio Power Company
Ohio Power Company
Ohio Power Company
Dayton Power and Light Company
2682
2682
2835
Inc. 2836
Inc. 2836
2878
2878
2878
2878
2828
2828
2828
2840
2840
2840
2840
2837
2837
2837
2837
2837
2857
8102
8102
2917
2850
2850
2850
2850
6031
2876
2876
2876
2876
2876
2838
2832
2832
2832
2832
2832
2872
2872
2872
2872
2872
2848
12
9
7
10
12
1
2
3
4
1
2
3
3
4
5
6
1
2
3
4
5
13
1
2
9
1
2
3
4
2
1
2
3
4
5
18
5-1
5-2
6
7
8
1
2
3
4
5
H-l
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.46
0.46
0.45
0.40
0.68
0.80
0.80
0.46
0.46
0.68
0.68
0.46
0.50
0.45
0.40
0.40
0.45
0.45
0.45
0.45
0.68
0.80
0.68
0.68
0.40
0.68
0.68
0.68
0.68
0.46
0.84
0.84
0.84
0.84
0.84
0.40
0.80
0.80
0.45
0.68
0.46
0.84
0.84
0.86
0.86
0.68
0.40
0.41
0.41
0.25
0.31
0.45
0.08
0.36
0.36
0.36
0.38
0.33
0.34
0.47
0.43
0.38
0.38
0.33
0.24
0.23
0.29
0.29
Not Oper.
0.43
0.42
0.33
0.37
0.49
0.45
0.36
0.34
0.52
0.52
0.52
0.52
0.52
0.31
0.66
0.66
0.66
0.43
0.37
0.58
0.58
0.58
0.58
0.51
0.68
0.50
0.50
0.45
0.45
0.57
0.56
0.56
0.57
0.57
0.57
0.57
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.57
0.57
0.57
0.57
0.57
0.51
0.59
0.59
0.28
0.38
0.38
0.28
0.28
0.28
0.28
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.28
0.28
0.28
0.28
0.28
0.34
0.40
0.40
0.62
0.62
0.62
0.62
0.62
0.84
0.84
0.84
0.84
0.84
0.57
0.49
0.49
0.49
0.49
0.49
0.59
0.59
0.59
0.59
0.59
0.62
0.41
0.41
0.41
0.41
0.41
0.54
0.54
0.54
0.54
0.54
0.28
0.39
0.39
0.39
0.39
0.39
0.40
0.40
0.40
0.40
0.40
0.41
0.83
0.90
0.61
0.58
0.96
1.08
1.08
1.08
1.08
0.90
1.02
0.74
0.93
0.55
0.44
0.44
0.49
0.68
0.54
0.51
0.67
1.16
1.16
1.16
0.60
1.11
1.05
0.95
1.16
0.51
1.34
1.34
1.34
1.34
1.34
0.67
0.71
0.71
0.73
1.07
0.62
1.09
1.09
1.09
1.09
1.20
0.67
-51%
-54%
-59%
-47%
-53%
-93%
-67%
-67%
-67%
-58%
-68%
-54%
-49%
-22%
-14%
-14%
-33%
-65%
-57%
-43%
-57%
-63%
-64%
-45%
-67%
-53%
-53%
-69%
-33%
-61%
-61%
-61%
-61%
-61%
-54%
-7%
-7%
-10%
-60%
-40%
-47%
-47%
-47%
-47%
-58%
1%
-------
OH OHHutchings
OH OHHutchings
OH OHHutchings
OH OHHutchings
OH OHHutchings
OH Picway
OH RE Burger
OH RE Burger
OH RE Burger
OH RE Burger
OH Richard Gorsuch
OH Richard Gorsuch
OH Richard Gorsuch
OH Richard Gorsuch
OH WHSammis
OH WHSammis
OH WHSammis
OH WHSammis
OH WHSammis
OH WHSammis
OH WHSammis
OH WHZimmer
OH Walter C Beckjord
OH Walter C Beckjord
OH Walter C Beckjord
OH Walter C Beckjord
OH Walter C Beckjord
OH Walter C Beckjord
OK Grand River Dam Authority
OK Grand River Dam Authority
OK Hugo
OK Muskogee
OK Muskogee
OK Muskogee
OK Northeastern
OK Northeastern
OK Sooner
OK Sooner
OR Boardman
PA Armstrong Power Station
PA Armstrong Power Station
PA Bruce Mansfield
PA Bruce Mansfield
PA Bruce Mansfield
PA Brunner Island
PA Brunner Island
PA Brunner Island
Dayton Power and Light Company
Dayton Power and Light Company
Dayton Power and Light Company
Dayton Power and Light Company
Dayton Power and Light Company
Columbus Southern Power Company
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
American Municipal Power - Ohio
American Municipal Power - Ohio
American Municipal Power - Ohio
American Municipal Power - Ohio
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
Cincinnati Gas & Electric Company
Cincinnati Gas & Electric Company
Cincinnati Gas & Electric Company
Cincinnati Gas & Electric Company
Cincinnati Gas & Electric Company
Cincinnati Gas & Electric Company
Cincinnati Gas & Electric Company
Grand River Dam Authority
Grand River Dam Authority
Western Farmers Electric Cooperative, Inc.
Oklahoma Gas & Electric Company
Oklahoma Gas & Electric Company
Oklahoma Gas & Electric Company
Public Service Company of Oklahoma
Public Service Company of Oklahoma
Oklahoma Gas & Electric Company
Oklahoma Gas & Electric Company
Portland General Electric Company
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
FirstEnergy Generation Corporation
PPL Brunner Island, LLC
PPL Brunner Island, LLC
PPL Brunner Island, LLC
2848
2848
2848
2848
2848
2843
2864
2864
2864
2864
7253
7253
7253
7253
2866
2866
2866
2866
2866
2866
2866
6019
2830
2830
2830
2830
2830
2830
165
165
6772
2952
2952
2952
2963
2963
6095
6095
6106
3178
3178
6094
6094
6094
3140
3140
3140
H-2
H-3
H-4
H-5
H-6
9
5
6
7
8
1
2
3
4
1
2
3
4
5
6
7
1
1
2
3
4
5
6
1
2
1
4
5
6
3313
3314
1
2
1SG
1
2
1
2
3
1
2
3
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Standard Limitation
Standard Limitation
Standard Limitation
0.40
0.40
0.40
0.40
0.40
0.50
0.84
0.84
0.50
0.50
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.50
0.50
0.68
0.46
0.40
0.40
0.46
0.40
0.45
0.45
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.46
0.50
0.50
0.50
0.50
0.46
0.45
0.45
0.45
0.68
0.61
0.61
0.62
0.62
0.40
0.38
0.38
0.38
0.38
0.33
0.33
0.33
0.33
0.37
0.37
0.63
0.63
0.43
0.40
0.36
0.36
0.63
0.67
0.59
0.57
0.46
0.33
0.38
0.35
0.23
0.30
0.34
0.32
0.39
0.39
0.39
0.34
0.39
0.36
0.36
0.28
0.29
0.26
0.34
0.34
0.37
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.62
0.62
0.62
0.62
0.62
0.59
0.51
0.51
0.51
0.51
0.51
0.51
0.51
0.51
0.51
0.51
0.51
0.49
0.49
0.49
0.49
0.49
0.49
0.46
0.46
0.50
0.55
0.55
0.51
0.51
0.51
0.41
0.41
0.41
0.41
0.41
0.40
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.39
0.39
0.39
0.39
0.39
0.39
0.36
0.36
0.34
0.34
0.34
0.34
0.34
0.67
0.63
0.63
0.51
0.51
0.87
0.75
0.73
0.66
0.72
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.87
0.85
0.86
0.81
0.52
1.10
1.06
Not Oper.
0.58
0.65
1.21
0.51
0.72
0.71
0.41
0.27
0.27
0.44
0.41
0.44
0.53
0.53
0.33
0.42
0.40
0.90
1.04
0.98
1.13
0.57
0.65
0.71
0.83
1%
-3%
-3%
22%
22%
-54%
-49%
-48%
-42%
-47%
-57%
-56%
-27%
-22%
-17%
-64%
-66%
9%
3%
-51%
12%
-36%
-54%
-7%
30%
-15%
-32%
-17%
-27%
-26%
-26%
18%
-19%
-3%
-60%
-65%
-71%
-74%
-54%
-48%
-52%
-55%
-------
PA Cheswick
PA Conemaugh
PA Conemaugh
PA Cromby
PA Eddy stone Generating Station
PA Eddy stone Generating Station
PA Ekama
PA Ekama
PA Ekama
PA Ekama
PA Hatfields Ferry Power Station
PA Hatfields Ferry Power Station
PA Hatfields Ferry Power Station
PA Homer City
PA Homer City
PA Homer City
PA Keystone
PA Keystone
PA Martins Creek
PA Martins Creek
PA Mitchell Power Station
PA Montour
PA Montour
PA New Castle
PA New Castle
PA New Castle
PA Portland
PA Portland
PA Shawville
PA Shawville
PA Shawville
PA Shawville
PA Sunbury
PA Sunbury
PA Titus
PA Titus
PA Titus
SC Canadys Steam
SC Canadys Steam
SC Canadys Steam
SC Cope Station
SC Cross
SC Cross
SC Dolphus M Grainger
SC Dolphus M Grainger
SC H B Robinson
SC Jefferies
Orion Power Midwest, LP 8226
Reliant Energy Northeast Management Compan; 3118
Reliant Energy Northeast Management Compan' 3118
Exelon Generation Company 3159
Exelon Generation Company 3161
Exelon Generation Company 3161
Orion Power Midwest, LP 3098
Orion Power Midwest, LP 3098
Orion Power Midwest, LP 3098
Orion Power Midwest, LP 3098
Allegheny Energy Supply Company, LLC 3179
Allegheny Energy Supply Company, LLC 3179
Allegheny Energy Supply Company, LLC 3179
EME Homer City Generation, LP 3122
EME Homer City Generation, LP 3122
EME Homer City Generation, LP 3122
Reliant Energy Northeast Management Compan; 3136
Reliant Energy Northeast Management Compan; 3136
PPL Martins Creek, LLC 3148
PPL Martins Creek, LLC 3148
Allegheny Energy Supply Company, LLC 3181
PPL Montour, LLC 3149
PPL Montour, LLC 3149
Orion Power Midwest, LP 3138
Orion Power Midwest, LP 3138
Orion Power Midwest, LP 3138
Reliant Energy Mid-Atlantic Power Holdings, L 3113
Reliant Energy Mid-Atlantic Power Holdings, L 3113
Reliant Energy Mid-Atlantic Power Holdings, L 3131
Reliant Energy Mid-Atlantic Power Holdings, L 3131
Reliant Energy Mid-Atlantic Power Holdings, L 3131
Reliant Energy Mid-Atlantic Power Holdings, L 3131
Sunbury Generation, LLC 3152
Sunbury Generation, LLC 3152
Reliant Energy Mid-Atlantic Power Holdings, L 3115
Reliant Energy Mid-Atlantic Power Holdings, L 3115
Reliant Energy Mid-Atlantic Power Holdings, L 3115
South Carolina Electric & Gas Company 3280
South Carolina Electric & Gas Company 3280
South Carolina Electric & Gas Company 3280
South Carolina Electric & Gas Company 7210
Santee Cooper 130
Santee Cooper 130
Santee Cooper 3317
Santee Cooper 3317
Carolina Power & Light Company 3251
Santee Cooper 3319
1 Averaging Plan
1 Standard Limitation
2 Standard Limitation
1 Early Election
1 Early Election
2 Early Election
1 Averaging Plan
2 Averaging Plan
3 Averaging Plan
4 Averaging Plan
1 Averaging Plan
2 Averaging Plan
3 Averaging Plan
1 Early Election
2 Early Election
3 Early Election
1 Early Election
2 Early Election
1 Standard Limitation
2 Standard Limitation
33 Averaging Plan
1 Early Election
2 Early Election
3 Averaging Plan/EE
4 Averaging Plan/EE
5 Averaging Plan/EE
1 Averaging Plan
2 Averaging Plan
1 Averaging Plan
2 Averaging Plan
3 Averaging Plan
4 Averaging Plan
3 Standard Limitation
4 Standard Limitation
1 Early Election
2 Early Election
3 Early Election
CAN1 Averaging Plan
CAN2 Averaging Plan
CAN3 Averaging Plan
COP1 Averaging Plan
1 Averaging Plan/EE
2 Early Election
1 Averaging Plan
2 Averaging Plan
1 Averaging Plan
3 Averaging Plan
0.45
0.45
0.45
0.46
0.40
0.40
0.80
0.80
0.80
0.46
0.68
0.68
0.68
0.46
0.46
0.46
0.40
0.40
0.50
0.50
0.45
0.40
0.40
0.46
0.46
0.46
0.45
0.45
0.50
0.50
0.45
0.45
0.50
0.50
0.40
0.40
0.40
0.40
0.40
0.46
0.40
0.46
0.40
0.46
0.46
0.40
0.46
0.31
0.34
0.32
0.34
0.26
0.27
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.32
0.35
0.27
0.24
0.23
0.43
0.43
0.25
0.27
0.25
0.32
0.36
0.41
0.26
0.33
0.46
0.46
0.41
0.41
0.31
0.31
0.37
0.42
0.40
0.39
0.40
0.42
0.26
0.15
0.18
0.45
0.42
0.46
0.43
0.56
0.50
0.45
0.45
0.56
0.56
0.56
0.56
0.55
0.55
0.55
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.55
0.56
0.56
0.56
0.46
0.46
0.46
0.46
0.46
0.46
0.45
0.45
0.45
0.50
0.45
0.42
0.42
0.42
0.42
0.46
0.46
0.46
0.45
0.46
0.38
0.38
0.38
0.38
0.38
0.34
0.34
0.34
0.34
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.33
0.33
0.33
0.33
0.26
0.26
0.26
0.34
0.26
0.71
0.65
0.71
0.60
0.42
0.50
0.80
0.80
0.80
0.85
1.13
1.17
0.90
1.09
1.04
0.62
0.79
0.79
1.03
0.93
0.68
0.95
0.46
0.63
0.57
0.73
0.46
0.66
0.99
1.02
0.83
0.82
0.93
1.29
0.73
0.68
0.77
0.45
0.60
1.00
Not Oper.
Not Oper.
0.46
0.90
1.07
0.63
1.01
-56%
-48%
-55%
-43%
-38%
-46%
-46%
-46%
-46%
-49%
-62%
-63%
-52%
-71%
-66%
-56%
-70%
-71%
-58%
-54%
-63%
-72%
-46%
-49%
-37%
-44%
-43%
-50%
-54%
-55%
-51%
-50%
-67%
-76%
-49%
-38%
-48%
-13%
-33%
-58%
-61%
-50%
-61%
-27%
-57%
-------
sc
sc
SC Jefferies
SC McMeekin
SC McMeekin
SC Urquhart
SC WSLee
WSLee
WSLee
SC Wateree
SC Wateree
SC Williams
SC Winyah
SC Winyah
SC Winyah
SC Winyah
SD Big Stone
TN Allen
TN Allen
TN Allen
TN Bull Run
TN Cumberland
TN Cumberland
TN Gallatin
TN Gallatin
TN Gallatin
TN Gallatin
TN John Sevier
TN John Sevier
TN John Sevier
TN John Sevier
TN Johnsonville
TN Johnsonville
TN Johnsonville
TN Johnsonville
TN Johnsonville
TN Johnsonville
TN Johnsonville
TN Johnsonville
TN Johnsonville
TN Johnsonville
TN Kingston
TN Kingston
TN Kingston
TN Kingston
TN Kingston
TN Kingston
TN Kingston
TN Kingston
Santee Cooper
South Carolina Electric & Gas Company
South Carolina Electric & Gas Company
South Carolina Electric & Gas Company
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
South Carolina Electric & Gas Company
South Carolina Electric & Gas Company
South Carolina Generating Company
Santee Cooper
Santee Cooper
Santee Cooper
Santee Cooper
Otter Tail Power Company
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
3319
3287
3287
3295
3264
3264
3264
3297
3297
3298
6249
6249
6249
6249
6098
3393
3393
3393
3396
3399
3399
3403
3403
3403
3403
3405
3405
3405
3405
3406
3406
3406
3406
3406
3406
3406
3406
3406
3406
3407
3407
3407
3407
3407
3407
3407
3407
4
MCM1
MCM2
URQ3
1
2
3
WAT1
WAT2
WIL1
1
2
3
4
1
1
2
3
1
1
2
1
2
3
4
1
2
3
4
1
10
2
3
4
5
6
7
8
9
1
2
3
4
5
6
7
8
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Averaging Plan/AEL
Averaging Plan/AEL
Averaging Plan/AEL
Averaging Plan
AEL
AEL
AEL
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.46
0.40
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.40
0.46
0.46
0.46
0.46
0.86
0.86
0.86
0.86
0.40
0.68
0.68
0.45
0.45
0.45
0.45
0.40
0.40
0.40
0.40
0.45
0.50
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.45
0.42
0.40
0.33
0.40
0.39
0.23
0.33
0.28
0.32
0.22
0.26
0.53
0.55
0.82
0.46
0.46
0.46
0.35
0.31
0.39
0.25
0.25
0.31
0.31
0.41
0.41
0.43
0.43
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.28
0.28
0.28
0.28
0.28
0.32
0.32
0.32
0.46
0.42
0.42
0.42
0.45
0.45
0.45
0.59 0.42
0.59 0.42
0.48 0.42
0.46
0.61
0.60
0.60
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.45
0.45
0.45
0.45
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.58
0.26
0.33
0.33
0.33
0.33
0.33
0.33
0.26
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
0.39
1.15
0.61
0.59
0.51
0.64
0.61
0.50
1.30
1.47
0.87
1.03
0.65
0.63
0.50
1.29
1.95
1.91
1.87
0.67
1.57
1.33
0.59
0.63
0.59
0.55
0.62
0.62
0.64
0.64
0.45
1.07
0.48
0.46
0.54
0.45
0.50
1.00
0.97
1.10
0.60
0.60
0.60
0.60
0.60
0.63
0.63
0.63
-61%
-31%
-32%
-35%
-38%
-36%
-54%
-75%
-81%
-63%
-79%
-60%
-16%
10%
-36%
-76%
-76%
-75%
-48%
-80%
-71%
-58%
-60%
-47%
-44%
-34%
-34%
-33%
-33%
11%
-53%
4%
9%
-7%
11%
0%
-50%
-48%
-55%
-53%
-53%
-53%
-53%
-53%
-49%
-49%
-49%
-------
TN Kingston
TX Big Brown
TX Big Brown
TX Coleto Creek
TX Gibbons Creek Steam Electric Station
TX HWPirkey Power Plant
TX Harrington Station
TX Harrington Station
TX Harrington Station
TX JK Spruce
TX JTDeely
TX JTDeely
TX Limestone
TX Limestone
TX Martin Lake
TX Martin Lake
TX Martin Lake
TX Monticello
TX Monticello
TX Monticello
TX Oklaunion Power Station
TX Sam Seymour
TX Sam Seymour
TX Sam Seymour
TX San Miguel
TX Sandow
TX Tolk Station
TX Tolk Station
TX W A Parish
TX W A Parish
TX W A Parish
TX W A Parish
TX Welsh Power Plant
TX Welsh Power Plant
TX Welsh Power Plant
UT Bonanza
UT Carbon
UT Carbon
UT Hunter (Emery)
UT Hunter (Emery)
UT Hunter (Emery)
UT Huntington
UT Huntington
UT Intermountain
UT Intermountain
VA Bremo Power Station
VA Bremo Power Station
Tennessee Valley Authority
TXU Generation Company, LP
TXU Generation Company, LP
Coleto Creek WLE, LP
Texas Municipal Power Agency
Southwestern Electric Power Company
Southwestern Public Service Company
Southwestern Public Service Company
Southwestern Public Service Company
City of San Antonio
City of San Antonio
City of San Antonio
Texas Genco Operating Services, LLC
Texas Genco Operating Services, LLC
TXU Generation Company, LP
TXU Generation Company, LP
TXU Generation Company, LP
TXU Generation Company, LP
TXU Generation Company, LP
TXU Generation Company, LP
West Texas Utilities Company
Lower Colorado River Authority
Lower Colorado River Authority
Lower Colorado River Authority
San Miguel Electric Cooperative
TXU Generation Company, LP
Southwestern Public Service Company
Southwestern Public Service Company
Texas Genco Operating Services, LLC
Texas Genco Operating Services, LLC
Texas Genco Operating Services, LLC
Texas Genco Operating Services, LLC
Southwestern Electric Power Company
Southwestern Electric Power Company
Southwestern Electric Power Company
Deseret Generation & Transmission
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
Intermountain Power Service Corporation
Intermountain Power Service Corporation
Dominion Generation
Dominion Generation
3407
3497
3497
6178
6136
7902
6193
6193
6193
7097
6181
6181
298
298
6146
6146
6146
6147
6147
6147
127
6179
6179
6179
6183
6648
6194
6194
3470
3470
3470
3470
6139
6139
6139
7790
3644
3644
6165
6165
6165
8069
8069
6481
6481
3796
3796
9
1
2
1
1
1
061B
062B
063B
**j
1
2
LIM1
LIM2
1
2
3
1
2
3
1
1
2
3
SM-1
4
171B
172B
WAP5
WAP6
WAP7
WAP8
1
2
3
1-1
1
2
1
2
3
1
2
1SGA
2SGA
3
4
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Averaging Plan/EE
Averaging Plan/EE
Early Election
Early Election
Averaging Plan
Early Election
Averaging Plan
Early Election
Early Election
Averaging Plan
Averaging Plan
0.40
0.40
0.40
0.40
0.40
0.46
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.40
0.40
0.40
0.46
0.40
0.40
0.40
0.46
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.32
0.14
0.14
0.16
0.12
0.18
0.29
0.31
0.33
0.17
0.14
0.14
0.19
0.19
0.17
0.17
0.16
0.15
0.15
0.19
0.33
0.10
0.15
0.32
0.19
0.20
0.32
0.29
0.03
0.03
0.05
0.04
0.17
0.33
0.20
0.35
0.43
0.45
0.35
0.35
0.37
0.34
0.36
0.36
0.34
0.54
0.36
0.45
0.45
0.45
0.45
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.45
0.50
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.58
0.45
0.45
0.45
0.45
0.41
0.41
0.39
0.42
0.42
0.42
0.42
0.28
0.28
0.63
0.40
0.34
0.38
0.47
0.34
0.27
0.36
0.36
Not Oper.
0.31
0.31
0.50
0.48
0.36
0.35
0.42
0.31
0.40
0.21
0.54
0.34
0.29
0.25
0.41
0.43
0.38
0.24
0.47
0.53
0.35
0.31
0.27
0.36
0.37
0.42
0.50
0.58
0.50
0.55
0.34
0.52
0.43
0.45
0.38
0.78
0.93
-49%
-65%
-59%
-58%
-74%
-47%
7%
-14%
-8%
-55%
-55%
-62%
-60%
-53%
-51%
-62%
-52%
-63%
-10%
-39%
-71%
-48%
28%
-54%
-53%
-16%
21%
-94%
-94%
-86%
-87%
-37%
-8%
-46%
-17%
-14%
-22%
-30%
-36%
9%
-35%
-16%
-20%
-11%
-31%
-61%
-------
VA Chesapeake Energy Center
VA Chesapeake Energy Center
VA Chesapeake Energy Center
VA Chesapeake Energy Center
VA Chesterfield Power Station
VA Chesterfield Power Station
VA Chesterfield Power Station
VA Chesterfield Power Station
VA Clinch River
VA Clinch River
VA Clinch River
VA Clover Power Station
VA Clover Power Station
VA GlenLyn
VA GlenLyn
VA GlenLyn
VA Possum Point Power Station
VA Possum Point Power Station
VA Potomac River
VA Potomac River
VA Potomac River
VA Potomac River
VA Potomac River
VA Yorktown Power Station
VA Yorktown Power Station
WA Centralia
WA Centralia
WI Alma
WI Alma
WI Blount Street
WI Blount Street
WI Blount Street
WI Columbia
WI Columbia
WI Edgewater (4050)
WI Edgewater (4050)
WI Genoa
WI J P Madgett
WI Pleasant Prairie
WI Pleasant Prairie
WI Port Washington Generating Station
WI Port Washington Generating Station
WI Port Washington Generating Station
WI Pulliam
WI Pulliam
WI Pulliam
WI Pulliam
Dominion Generation
Dominion Generation
Dominion Generation
Dominion Generation
Dominion Generation
Dominion Generation
Dominion Generation
Dominion Generation
Appalachian Power Company
Appalachian Power Company
Appalachian Power Company
Dominion Generation
Dominion Generation
Appalachian Power Company
Appalachian Power Company
Appalachian Power Company
Dominion Generation
Dominion Generation
Mirant Potomac River, LLC
Mirant Potomac River, LLC
Mirant Potomac River, LLC
Mirant Potomac River, LLC
Mirant Potomac River, LLC
Dominion Generation
Dominion Generation
TransAlta Centralia Generation, LLC
TransAlta Centralia Generation, LLC
Dairy land Power Cooperative
Dairy land Power Cooperative
Madison Gas & Electric Company
Madison Gas & Electric Company
Madison Gas & Electric Company
Wisconsin Power & Light Company
Wisconsin Power & Light Company
Wisconsin Power & Light Company
Wisconsin Power & Light Company
Dairy land Power Cooperative
Dairy land Power Cooperative
Wisconsin Electric Power Company
Wisconsin Electric Power Company
We Energies
We Energies
We Energies
Wisconsin Public Service Corporation
Wisconsin Public Service Corporation
Wisconsin Public Service Corporation
Wisconsin Public Service Corporation
3803
3803
3803
3803
3797
3797
3797
3797
3775
3775
3775
7213
7213
3776
3776
3776
3804
3804
3788
3788
3788
3788
3788
3809
3809
3845
3845
4140
4140
3992
3992
3992
8023
8023
4050
4050
4143
4271
6170
6170
4040
4040
4040
4072
4072
4072
4072
1
2
3
4
3
4
5
6
1
2
3
1
2
51
52
6
3
4
1
2
3
4
5
1
2
BW21
BW22
B4
B5
7
8
9
1
2
4
5
1
Bl
1
2
1
2
3
3
4
5
6
Early Election
Early Election
Averaging Plan
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/EE
Averaging Plan
Early Election
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Standard Limitation
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.40
0.40
0.46
0.40
0.40
0.40
0.40
0.40
0.80
0.80
0.80
0.40
0.40
0.40
0.40
0.46
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.50
0.50
0.68
0.46
0.46
0.40
0.40
0.86
0.46
0.45
0.50
0.46
0.46
0.50
0.50
0.50
0.46
0.46
0.46
0.46
0.43
0.38
0.30
0.35
0.42
0.30
0.24
0.20
0.46
0.46
0.38
0.28
0.29
0.40
0.36
0.45
0.10
0.10
0.40
0.37
0.36
0.37
0.38
0.36
0.36
0.27
0.26
0.82
0.82
0.52
0.39
0.44
0.14
0.35
0.38
0.20
0.37
0.32
0.26
0.26
0.31
0.31
0.31
0.76
0.76
0.81
0.81
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.50
0.41
0.41
0.41
0.59
0.59
0.59
0.41
0.41
0.59
0.59
0.59
0.41
0.48
0.48
0.63
0.63
0.48
0.48
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.28
0.28
0.28
0.40
0.40
0.40
0.28
0.28
0.40
0.40
0.40
0.28
0.41
0.41
0.28
0.28
0.41
0.41
0.26
0.26
0.26
0.26
0.26
0.41
0.41
0.41
0.41
0.42
0.48
1.07
0.54
0.52
0.49
0.62
0.73
1.34
1.34
1.42
Not Oper.
Not Oper.
0.46
Not Oper.
0.76
0.60
0.61
0.51
0.44
0.64
0.46
0.72
0.57
0.57
0.40
0.45
0.85
0.85
0.89
0.71
0.61
0.46
0.49
1.17
0.21
0.75
0.30
0.45
0.45
0.32
0.32
0.32
0.76
0.76
0.94
0.94
2%
-21%
-72%
-35%
-19%
-39%
-61%
-73%
-66%
-66%
-73%
-13%
-41%
-83%
-84%
-22%
-16%
-44%
-20%
-47%
-37%
-37%
-33%
-42%
-4%
-4%
-42%
-45%
-28%
-70%
-29%
-68%
-5%
-51%
7%
-42%
-42%
-3%
-3%
-3%
0%
0%
-14%
-14%
-------
WI Pulliam
WI Pulliam
WI South Oak Creek
WI South Oak Creek
WI South Oak Creek
WI South Oak Creek
WI Stoneman
WI Stoneman
WI Valley (WEPCO)
WI Valley (WEPCO)
WI Valley (WEPCO)
WI Valley (WEPCO)
WI Weston
WI Weston
WI Weston
WV Albright Power Station
WV Albright Power Station
WV Albright Power Station
WV Fort Martin Power Station
WV Fort Martin Power Station
WV Harrison Power Station
WV Harrison Power Station
WV Harrison Power Station
WV John E Amos
WV John E Amos
WV John E Amos
WV Kammer
WV Kammer
WV Kammer
WV Kanawha River
WV Kanawha River
WV Mitchell (WV)
WV Mitchell (WV)
WV Mount Storm Power Station
WV Mount Storm Power Station
WV Mount Storm Power Station
WV Mountaineer (1301)
WV Phil Sporn
WV Phil Sporn
WV Phil Sporn
WV Phil Sporn
WV Phil Sporn
WV Pleasants Power Station
WV Pleasants Power Station
WV Rivesville Power Station
WV Rivesville Power Station
WV Willow Island Power Station
Wisconsin Public Service Corporation
Wisconsin Public Service Corporation
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Mid-American Power, LLC
Mid-American Power, LLC
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Wisconsin Electric Power Company
Wisconsin Public Service Corporation
Wisconsin Public Service Corporation
Wisconsin Public Service Corporation
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
Appalachian Power Company
Appalachian Power Company
Appalachian Power Company
Ohio Power Company
Ohio Power Company
Ohio Power Company
Appalachian Power Company
Appalachian Power Company
Ohio Power Company
Ohio Power Company
Dominion Generation
Dominion Generation
Dominion Generation
Appalachian Power Company
Appalachian Power Company
Central Operating Company
Appalachian Power Company
Central Operating Company
Central Operating Company
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
Allegheny Energy Supply Company, LLC
4072
4072
4041
4041
4041
4041
4146
4146
4042
4042
4042
4042
4078
4078
4078
3942
3942
3942
3943
3943
3944
3944
3944
3935
3935
3935
3947
3947
3947
3936
3936
3948
3948
3954
3954
3954
6264
3938
3938
3938
3938
3938
6004
6004
3945
3945
3946
7
8
5
6
7
8
Bl
B2
1
2
3
4
1
2
3
1
2
3
1
2
1
2
3
1
2
3
1
2
3
1
2
1
2
1
2
3
1
11
21
31
41
51
1
2
7
8
1
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/AEL
Averaging Plan/AEL
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan/AEL
Averaging Plan/AEL
AEL
AEL
AEL
Averaging Plan/EE
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.50
0.50
0.50
0.50
0.45
0.45
0.46
0.46
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.50
0.50
0.45
0.45
0.68
0.50
0.50
0.50
0.46
0.46
0.68
0.86
0.86
0.86
0.80
0.80
0.50
0.50
0.45
0.45
0.45
0.46
0.80
0.80
0.80
0.80
0.46
0.50
0.50
0.80
0.80
0.80
0.34
0.29
0.17
0.17
0.14
0.14
0.36
0.36
0.36
0.36
0.38
0.38
0.73
0.40
0.25
0.61
0.57
0.31
0.30
0.30
0.33
0.33
0.33
0.46
0.46
0.49
0.66
0.66
0.66
0.38
0.38
0.53
0.53
0.37
0.42
0.45
0.33
0.37
0.37
0.37
0.37
0.38
0.19
0.20
0.89
0.61
0.50
0.59
0.52
0.56
0.56
0.76
0.69
0.74
0.50
0.47
0.47
0.47
0.47
0.47
0.47
0.46
0.46
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.59
0.55
0.55
0.55
0.55
0.55
0.41
0.41
0.26
0.26
0.26
0.26
0.36
0.36
0.26
0.26
0.26
0.26
0.41
0.41
0.41
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.34
0.34
0.34
0.34
0.34
0.69
0.57
0.28
0.28
0.66
0.67
0.75
0.75
1.10
1.10
1.05
0.93
0.90
1.08
0.26
1.10
1.10
0.71
0.62
1.07
0.99
1.13
1.06
1.00
1.00
1.05
1.21
1.21
1.21
1.23
1.23
0.77
0.77
0.88
0.76
1.27
0.47
1.21
1.21
1.21
1.21
0.90
0.52
0.35
0.86
0.77
0.88
-51%
-49%
-39%
-39%
-79%
-79%
-52%
-52%
-67%
-67%
-64%
-59%
-19%
-63%
-4%
-45%
-48%
-56%
-52%
-72%
-67%
-71%
-69%
-54%
-54%
-53%
-45%
-45%
-45%
-69%
-69%
-31%
-31%
-58%
-45%
-65%
-30%
-69%
-69%
-69%
-69%
-58%
-63%
-43%
3%
-21%
-43%
-------
WV Willow Island Power Station
WY Dave Johnston
WY Dave Johnston
WY Dave Johnston
WY Dave Johnston
WY JimBridger
WY JimBridger
WY JimBridger
WY JimBridger
WY Laramie River
WY Laramie River
WY Laramie River
WY Naughton
WY Naughton
WY Naughton
WY Wyodak
Allegheny Energy Supply Company, LLC
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
Basin Electric Power Cooperative
Basin Electric Power Cooperative
Basin Electric Power Cooperative
PacifiCorp
PacifiCorp
PacifiCorp
PacifiCorp
3946
4158
4158
4158
4158
8066
8066
8066
8066
6204
6204
6204
4162
4162
4162
6101
2
BW41
BW42
BW43
BW44
BW71
BW72
BW73
BW74
1
2
3
1
2
3
BW91
Averaging Plan
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.86
0.46
0.46
0.68
0.40
0.45
0.45
0.45
0.40
0.46
0.46
0.46
0.40
0.40
0.40
0.50
1.04
0.44
0.45
0.50
0.35
0.43
0.45
0.45
0.44
0.26
0.24
0.28
0.58
0.56
0.41
0.29
0.50
0.50
0.45
0.50
0.50
0.50
0.55
0.45
0.45
0.45
0.45
0.45
0.34
0.42
0.42
0.42
0.42
0.42
0.45
0.45
0.45
0.45
0.42
0.42
0.42
0.42
1.26
0.48
0.54
0.71
0.55
0.63
0.51
0.42
0.41
0.35
0.32
0.42
0.42
0.55
0.62
0.37
-17%
-8%
-17%
-30%
-36%
-32%
-12%
7%
7%
-26%
-25%
-33%
38%
2%
-34%
-22%
-------
Company
Indiana Kentucky Electric Corp.
Year 2004 Averaging Plan Summary
Date of NOx Compliance Assessment: 06/08/2005
ORISCode Plant Name
983 Cliffy Creek
2876
Kyger Creek
Units
1
2
3
4
5
6
1
2
3
4
5
Plan Limit Plan Rate
0.84 0.54
Company
Allegheny Energy Supply Co., LLC
ORIS Code Plant Name
3942 Albright Power Station
3178 Armstrong Power Station
3943 Fort Martin Power Station
3944 Harrison Power Station
3179 Hatfields Ferry Power Station
3181 Mitchell Power Station
6004 Pleasants Power Station
1570 R. Paul Smith Power Station
3945 Rivesville Power Station
Units
1
2
3
1
2
1
2
1
2
3
1
2
3
33
1
2
11
9
7
Plan Limit Plan Rate
0.55 0.34
-------
3946
Willow Island Power Station
Company
Detroit Edison Co.
ORISCode Plant Name
6034 Belle River
1731 Harbor Beach
1732 Marysville
1733
1745
Monroe
1740 River Rouge
1743 St. Clair
Trenton Channel
Units
1
2
1
10
11
12
9
1
2
3
4
2
o
3
i
2
o
J
4
6
7
16
17
18
19
9A
Plan Limit Plan Rate
0.53 0.32
Company
Wisconsin Electric Power Company
ORISCode Plant Name
6170 Pleasant Prairie
4040 Port Washington Generating Station
1769
Presque Isle
Units
1
2
1
2
o
6
2
3
4
5
6
7
Plan Limit Plan Rate
0.47 0.26
-------
4041
South Oak Creek
4042
Valley (WEPCO)
Company
Dynegy Power Corporation
ORIS Code Plant Name
889 Baldwin Energy Complex
891 Havana
892 Hennepin Power Station
897 Vermilion Power Station
898 Wood River Power Station
Units
1
2
3
9
1
2
1
2
4
5
Plan Limit Plan Rate
0.62 0.22
Company
Dynegy Power Corporation
ORIS Code Plant Name
2850 J M Stuart
6031
2848
Killen Station
O H Hutchings
Units
1
2
3
4
2
H-l
H-2
H-3
H-4
H-5
H-6
Plan Limit Plan Rate
0.62 0.41
Company
Public Service Company of Colorado
ORIS Code Plant Name
465 Arapahoe
Units
o
J
4
Plan Limit Plan Rate
0.80 0.36
Company
ORIS Code Plant Name
Units
Plan Limit Plan Rate
-------
Public Service Company of Colorado
990 Harding Street Station (EW Stout)
991 IPL Eagle Valley Generating Station
994 Petersburg
50
60
70
3
4
5
6
1
2
3
4
0.45
0.28
Company
Public Service Company of Colorado
ORISCode Plant Name
2324 Reid Gardner
Units
1
2
3
4
Plan Limit Plan Rate
0.46 0.34
Company
Public Service Company of Colorado
ORISCode Plant Name
6016 Duck Creek
856 E D Edwards
Units
1
1
9
Plan Limit Plan Rate
0.46 0.31
Company
Public Service Company of New Mexico
ORISCode Plant Name
2451 San Juan
Units
1
2
o
J
4
Plan Limit Plan Rate
0.46 0.42
Company
Public Service Company of New Mexico
ORISCode Plant Name
6094 Bruce Mansfield
2857
2864
Edgewater
R E Burger
Units
1
2
o
J
13
5
6
7
Plan Limit Plan Rate
0.51 0.34
-------
W H Sammis
Company
Public Service Company of New Mexico
ORIS Code Plant Name
2835 Ashtabula
2878 Bay Shore
2837
Eastlake
2838
Lake Shore
Units
7
1
2
3
4
1
2
o
J
4
5
18
Plan Limit Plan Rate
0.57 0.28
Company
Public Service Company of New Mexico
ORIS Code Plant Name
1001 Cayuga
6018 East Bend
1004 Edwardsport
6113
283
1008
Gibson
Miami Fort
R Gallagher
Units
1
2
2
7-1
7-2
8-1
1
2
o
J
4
5
5-1
5-2
6
7
8
1
2
3
4
Plan Limit Plan Rate
0.49 0.39
-------
1010
Wabash River
2830
Walter C Beckjord
Company
Reliant Energy
ORISCode Plant Name
3113 Portland
3131 Shawville
Units
1
2
1
2
3
4
Plan Limit Plan Rate
0.46 0.38
Company
Dynegy Danskammer
ORIS Code Plant Name
2480 Dynegy Danskammer
Units
o
J
4
Plan Limit Plan Rate
0.40 0.24
Company
Dynegy Danskammer
ORISCode Plant Name
3644 Carbon
4158 D ave Johnston
6165 Hunter (Emery)
8069 Huntington
8066 Jim Bridger
4162
6101
Naughton
Wyodak
Units
1
2
BW43
BW44
3
2
BW71
BW72
BW73
1
2
o
3
BW91
Plan Limit Plan Rate
0.45 0.42
-------
Company
South Carolina Electric & Gas Company
Company
South Carolina Electric & Gas Company
Company
South Carolina Electric & Gas Company
ORIS Code Plant Name
3280 Canadys Steam
7210
3287
3295
3297
Cope Station
McMeekin
Urquhart
Wateree
3298
Williams
ORIS Code Plant Name
1893 Boswell Energy Center
1891 Laskin Energy Center
10075 Taconite Harbor Energy Center
ORIS Code Plant Name
3 Barry
703 Bowen
641 Crist Electric Generating Plant
6073 Daniel Electric Generating Plant
26 EC Gaston
Units
CAN1
CAN2
CAN3
COP1
MCM1
MCM2
URQ3
WAT1
WAT2
WIL1
Units
1
2
3
4
1
2
1
2
3
Units
1
2
3
4
5
1BLR
2BLR
3BLR
4BLR
4
5
6
7
1
2
1
2
3
Plan Limit Plan Rate
0.42 0.33
Plan Limit Plan Rate
0.41 0.38
Plan Limit Plan Rate
0.46 0.29
-------
4
5
7 Gadsden 1
2
8 Gorgas 10
6
7
8
9
10 Greene County 1
2
708 Hammond 1
2
3
4
709 Harllee Branch 1
2
3
4
710 Jack McDonough MB1
MB2
6002 James H Miller Jr 1
2
3
4
733 Kraft 1
2
3
643 Lansing Smith Generating Plant 1
2
6124 Mclntosh 1
727 Mitchell 3
6257 Scherer 1
2
3
4
642 Scholz Electric Generating Plant 1
2
6052 Wansley 1
2
2049 Watson Electric Generating Plant 4
5
728 Yates Y1BR
Y2BR
Y3BR
Y4BR
Y5BR
-------
Y6BR
Y7BR
Company
Northern Indiana Public Service Company
ORIS Code Plant Name
995 Bailly Generating Station
997 Michigan City Generating Station
6085 R M Schahfer Generating Station
Units
7
8
12
14
15
Plan Limit Plan Rate
0.75 0.46
Company
Lansing Board of Water and Light
ORIS Code Plant Name
1831 Eckert Station
Units
1
2
3
4
5
Plan Limit Plan Rate
0.45 0.23
1832 Erickson
Company
Lansing Board of Water and Light
ORIS Code Plant Name
6068 Jeffrey Energy Center
1250 Lawrence Energy Center
1252 Tecumseh Energy Center
Units
1
2
3
3
4
5
10
9
Plan Limit Plan Rate
0.40 0.31
Company
Lansing Board of Water and Light
ORIS Code Plant Name
2167 New Madrid Power Plant
2168 Thomas Hill Energy Center
Units
1
2
MB1
MB2
MBS
Plan Limit Plan Rate
0.75 0.57
Company
ORIS Code Plant Name
Units
Plan Limit Plan Rate
-------
Public Service Company of Colorado
469
Cherokee
0.80
0.48
Company
Public Service Company of Colorado
ORISCode Plant Name
492 Martin Drake
Units
5
6
7
Plan Limit Plan Rate
0.46 0.39
Company
Public Service Company of Colorado
ORIS Code Plant Name
165 Grand River D am Authority
Units
1
2
Plan Limit Plan Rate
0.46 0.36
Company
Public Service Company of Colorado
ORISCode Plant Name
6061 RD Morrow
Units
1
2
Plan Limit Plan Rate
0.50 0.47
Company
Public Service Company of Colorado
ORIS Code Plant Name
2442 Four Comers Steam Elec Station
Units
1
2
o
J
4
5
Plan Limit Plan Rate
0.61 0.54
Company
Tampa Electric Company
ORIS Code Plant Name
645 Big Bend
Units
BB01
BB02
BB03
BB04
Plan Limit Plan Rate
0.72 0.00
Company
Reliant Energy
ORIS Code Plant Name
2836 Avon Lake Power Plant
8226
3098
Cheswick
Elrama
Units
10
12
1
1
9
Plan Limit Plan Rate
0.56 0.38
-------
3138
New Castle
Company
Dominion Resources Services, Inc
ORISCode Plant Name
981 State Line Generating Station
Units
3
4
Plan Limit Plan Rate
0.70 0.49
Company
Dominion Resources Services, Inc
ORISCode Plant Name
1043 Frank ERatts
6213 Merom
Units
1SG1
2SG1
1SG1
2SG1
Plan Limit Plan Rate
0.47 0.33
Company
Dominion Resources Services, Inc
ORISCode Plant Name
3796 Bremo Power Station
3803 Chesapeake Energy Center
3797 Chesterfield Power Station
7213 Clover Power Station
3804 Possum Point Power Station
Units
o
J
4
3
5
6
1
2
4
Plan Limit Plan Rate
0.41 0.28
Company
Constellation Power Source Generation, Inc.
ORISCode Plant Name
602 Brandon Shores
1552 CP Crane
1554 Herbert A Wagner
Units
1
2
1
2
2
3
Plan Limit Plan Rate
0.56 0.38
Company
Western Kentucky Energy Corporation
ORIS Code Plant Name
1381 Coleman
Units
Cl
C2
Plan Limit Plan Rate
0.49 0.33
-------
6823 D B Wilson
1382 HMP&L Station 2
6639 R D Green
1383 Robert Reid
C3
Wl
HI
H2
Gl
G2
Rl
Company
Western Kentucky Energy Corporation
ORISCode Plant Name
2706 Asheville
2708 Cape Fear
3251 HB Robinson
2713 LVSutton
2709
6250
2712
Lee
Mayo
Roxboro
2716 W H Weatherspoon
Units
1
2
5
6
1
1
2
3
1
2
3
1A
IB
1
2
3A
3B
4A
4B
1
2
3
Plan Limit Plan Rate
0.45 0.34
Company
Western Kentucky Energy Corporation
ORIS Code Plant Name
3393 Allen
3396
47
Bull Run
Colbert
3399 Cumberland
Units
1
2
o
6
i
i
2
o
J
4
5
1
Plan Limit Plan Rate
0.58 0.39
-------
2
3403 Gallatin 1
2
3
4
3406 Johnsonville 1
10
2
3
4
5
6
7
8
9
3407 Kingston 1
2
3
4
5
6
7
8
9
1378 Paradise 1
2
o
J
1379 Shawnee 1
2
3
4
5
6
7
8
9
50 Widows Creek 1
2
o
J
4
5
6
7
Company ORIS Code Plant Name Units Plan Limit Plan Rate
-------
Western Kentucky Energy Corporation
2642
Rochester 7 - Russell Station
0.40
0.34
Company
PSEG Power, LLC
ORISCode Plant Name
2403 Hudson Generating Station
2408 Mercer Generating Station
Units
2
1
2
Plan Limit Plan Rate
0.62 0.46
Company
PSEG Power, LLC
ORISCode Plant Name
1104 Burlington
1046 Dubuque
1047
1048
1073
1058
1077
Lansing
Milton L Kapp
Prairie Creek
Sixth Street
Sutherland
Units
1
1
5
1
2
3
2
o
J
4
2
o
J
4
5
1
2
Plan Limit Plan Rate
0.46 0.31
Company
PSEG Power, LLC
ORIS Code Plant Name
2161 James River
6195
Southwest
Units
3
4
5
1
Plan Limit Plan Rate
0.50 0.36
Company
PSEG Power, LLC
ORIS Code Plant Name
130 Cross
3317 Dolphus M Grainger
3319
Jefferies
Units
1
1
2
3
Plan Limit Plan Rate
0.46 0.26
-------
6249
Winy ah
Company
PSEG Power, LLC
Company
Dairyland Power Cooperative
Company
Dairyland Power Cooperative
Company
Louisville Gas and Electric Company
ORIS Code Plant Name
4050 Edgewater
ORIS Code Plant Name
4140 Alma
4143 Genoa
4271 JPMadgett
ORIS Code Plant Name
2103 Labadie
2104 Meramec
6155 Rush Island
2107 Sioux
ORIS Code Plant Name
1355 EW Brown
1356 Ghent
1357 Green River
Units
4
5
Units
B4
B5
1
Bl
Units
1
2
o
J
4
1
2
o
J
4
1
2
1
2
Units
1
2
3
1
2
3
4
1
2
3
4
Plan Limit Plan Rate
0.63 0.28
Plan Limit Plan Rate
0.48 0.41
Plan Limit Plan Rate
0.53 0.18
Plan Limit Plan Rate
0.45 0.27
-------
1361
Tyrone
Company
Louisville Gas and Electric Company
ORISCode Plant Name
1241 La Cygne
Units
1
2
Plan Limit Plan Rate
0.68 0.65
Company
Louisville Gas and Electric Company
ORIS Code Plant Name
1012 F B Culley Generating Station
Units
1
2
3
Plan Limit Plan Rate
0.50 0.21
Company
Wisconsin Public Service Corp
ORISCode Plant Name
4072 Pulliam
4078
Weston
Units
o
J
4
5
6
7
8
1
9
Plan Limit Plan Rate
0.47 0.41
Company
Wisconsin Public Service Corp
ORISCode Plant Name
4146 Stoneman
Units
Bl
B2
Plan Limit Plan Rate
0.46 0.36
Company
Wisconsin Public Service Corp
ORIS Code Plant Name
863 Hutsonville
864 Meredosia
6017
Newton
Units
05
06
01
02
03
04
05
1
9
Plan Limit Plan Rate
0.45 0.18
-------
Company
Wisconsin Public Service Corp
ORIS Code Plant Name
861 Coffeen
Units
01
02
Plan Limit Plan Rate
0.86 0.36
Company
NSP (d/b/a Xcel Energy)
ORIS Code Plant Name
1915 AllenS King
1904 Black Dog
1912 High Bridge
1918 Minnesota Valley
1927 Riverside
6090
Sherburne County
Units
1
3
4
3
4
5
6
4
6
7
8
1
9
Plan Limit Plan Rate
0.53 0.44
Company
Consumers Energy Company
ORIS Code Plant Name
1695 B C Cobb
1702
1720
1710
1723
Dan E Kam
J C Weadock
JH Campbell
J R Whiting
Units
1
2
o
J
4
5
1
2
7
8
1
2
o
3
1
2
Plan Limit Plan Rate
0.46 0.28
Company
ORIS Code Plant Name
Units
Plan Limit Plan Rate
-------
American Electric Power Service
1353 Big Sandy
2828 Cardinal
3775 Clinch River
2840 Conesville
8102 Gen JM Gavin
3776 Glen Lyn
3935 John E Amos
3947 Kammer
3936 Kanawha River
3948 Mitchell
6264 Mountaineer
2872 Muskingum River
3938 Phil Sporn
2843 Picway
6166 Rockport
988
Tanners Creek
BSU1
BSU2
1
2
3
1
2
3
3
4
5
6
1
2
51
52
6
1
2
o
6
i
2
o
J
1
2
1
2
1
1
2
o
J
4
5
11
21
31
41
51
9
MB1
MB2
Ul
U2
U3
U4
0.59
0.40
-------
Company
American Electric Power Service
ORIS Code Plant Name
2535 AES Cayuga (Milliken)
2527 AES Greemdge
6082 AES Somerset (Kintigh )
2526 AES Westover (Goudey)
Units
1
2
4
5
6
1
11
12
13
Plan Limit Plan Rate
0.45 0.21
------- |