./••v
-------
cid rain is a serious environmental problem that affects large
parts of the United States and Canada. Acid rain is particularly
damaging to lakes, streams, and forests and the plants and
animals that live in these ecosystems. Sulfur dioxide (S02) and
nitrogen oxides (NOX), products of fossil fuel (coal, oil, or natural gas)
combustion, are the key pollutants involved in the formation of acid
rain. These pollutants also contribute to the formation of fine particles
(sulfates and nitrates) that are associated with significant human
health effects and regional haze. Sulfates and nitrates are transported
and deposited at levels harmful to sensitive ecosystems in many areas
of the country.
Under the Clean Air Act, EPA implements the Acid Rain Program,
which requires fossil fuel-fired electric generating units to reduce
annual S02 and NOX emissions in order to improve impacted
ecosystems. In 2007, U.S. electric power generation accounted for 69
percent of total U.S S02 emissions and 20 percent of total U.S. N0x
emissions. Over 50 percent of U.S. electricity is generated by burning
coal. Since beginning in 1995, the Acid Rain Program, together with
other initiatives under the Clean Air Act, has led to steep declines
in annual S02 and NOX emissions. Using a variety of long-term
environmental monitoring networks, EPA has documented significant
environmental improvements as a result of the annual emission
reductions under the Acid Rain Program. This report summarizes the
progress achieved to date, compliance with the program by regulated
sources, and some of the key issues influencing the long-term recovery
of ecosystems affected by acid rain.
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CONTENTS
Summary 1
Emission Reductions 4
Origins of the Acid Rain Program 5
S02 Emission Reductions 6
S02 Program Compliance 11
S02 Allowance Market 11
NOX Emission Reductions and Compliance 14
Emission Monitoring and Reporting 18
Environmental Results 20
Status and Trends in Air Quality, Acid Deposition, and Ecological Effects 21
Air Quality 21
Sulfur Dioxide 21
Nitrogen Oxides 27
Acid Deposition 28
Improvements in Surface Water Chemistry 30
Critical Loads Case Study: Adirondack Lakes 34
Trends in Atmospheric Sulfur Concentrations 38
Online Information, Data, and Resources 42
Endnotes 46
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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In 2007, for the first time, S02
emissions were below the Acid Rain
Program's long-term annual emission
cap of 8.95 million tons—three years
before the 2070 statutory deadline.
-------
Sulfur dioxide (S02) and nitrogen oxides (NOX), products
of fossil fuel combustion (coal, oil, and gas), are the key
pollutants involved in the formation of acid rain. These
pollutants also contribute to the formation of fine particles
(sulfates and nitrates) that are associated with significant
human health effects and regional haze. Sulfates and nitrates
are transported and deposited at levels harmful to sensitive
ecosystems in many areas of the country. Additionally, NOX
combines with volatile organic compounds (VOCs) to form
ground-level ozone (smog). In 2007, the U.S. electric power
industry accounted for 69 percent of total U.S. S02 emissions
and 20 percent of total U.S. NOX emissions from man-made
sources.
The Acid Rain Program (ARP) was created under Title IV of the
1990 Clean Air Act (CAA) Amendments to reduce the adverse
effects of acid deposition through reductions in annual
emissions of SO, and NOY. The Act calls for SO, reductions
A A A
from all sources of 10 million tons from 1980 emission
levels, largely achieved through a market-based cap and trade
program which imposes a permanent emission cap on S02
emissions from electric generating units (EGUs) at power
plants. NOX reductions under the ARP are achieved through
a program that applies to a subset of coal-fired EGUs and is
closer to a more traditional, rate-based regulatory system. The
goal of the NOX program is to limit NOX emission levels from
the affected coal-fired boilers so that their emissions are at
least 2 million tons less than the projected level for the year
2000 without implementation of Title IV.
KEY FINDINGS
In 2007, for the first time, S02 emissions were below the ARP s long term annual emission cap of 8.95 million tons—three
years before the 2010 statutory deadline. Total S02 emissions in 2007 were 8.9 million tons from 3,536 affected electric
generating units.
NOX emissions from a subset of 978 coal-fired electric generating units also continued a steady decline in 2007, decreasing
by about 121,000 tons (3.5 percent) from 2006 levels to about 3.0 million tons. Total NOX emissions from all 3,536 ARP
electric generating units were 3.3 million tons in 2007.
Add deposition has declined significantly from levels measured before the implementation of the ARP in 1995. Surface
water quality improvements in lakes and streams and related indicators from long-term monitoring show signs of ecosystem
recovery. However, as evidenced by long-term monitoring and assessment data analyses, the relationship of emission
reductions to ecological and air quality improvements is complex and not entirely commensurate with the level of ARP
emission reductions, suggesting extenuating circumstances attributable to other source sectors or factors such as soil type
and atmospheric chemistry.
Estimated public health benefits from ARP emission reductions exceed program costs by a margin of more than 40:1.
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
-------
The U.S. Environmental Protection Agency (EPA) publishes
this annual report to update the public on the ARP and
related programs, including emission reductions, compliance,
and environmental results. After 13 years of implementation,
monitoring, and assessment, the ARP has proven to be an
effective and efficient means of meeting emission reduction
goals under the CAA. A 2005 study estimated the program's
benefits at $122 billion annually in 2010, while cost estimates
are around $3 billion annually (in 2000 dollars).2 In addition,
data from 2007 show that the ARP has:
• Reduced annual S02 emissions by about 6.8 million tons
since 1990 (43 percent). Sources emitted just below 8.95
million tons of S02 in 2007, well below the current annual
emission cap of 9.5 million tons, and already below the
statutory annual cap set for compliance in 2010.
• Cut annual NOX emissions by 3.4 million tons from 1990
levels. Emissions in 2007 from ARP-affected units were
less than half the level anticipated without the program.
Other efforts, such as the NOX Budget Trading Program
(NBP) in the eastern United States, also contributed to
this reduction.
• Led to significant decreases in acid deposition. For
example, comparisons between the 1989-1991 and
2005-2007 observation periods show wet sulfate
deposition decreased 35 percent in the Northeast and
33 percent in the Midwest. Wet nitrogen deposition also
decreased between these periods with a decrease in the
Northeast by 21 percent and in the Midwest by 7 percent.
These reductions in sulfur and nitrogen deposition have
resulted in positive changes in environmental indicators,
including improved water quality in lakes and streams.
• Achieved full compliance in 2007 with the S02 allowance
holding requirements and NOX emission limits.
• Reduced implementation costs by allowing sources to
choose cost-effective compliance strategies.
• Created an S02 allowance market that has functioned
with adequate liquidity and allowed all participants
opportunities to profit from the cap and trade program
and hedge risk while significantly reducing emissions.
• Required the most complete and accurate emission data
reported and made those data available for agencies,
researchers, affected sources, and the public.
• Delivered pioneering e-government results through
comprehensive electronic data reporting and Web-based
tools, by automating administrative processes, reducing
paper use, and streamlining and simplifying online
systems for doing business with EPA.
Despite the program's historic and projected benefits, EPA
analyses of human health studies, data from long-term
monitoring networks, and ecological assessments have revealed
the need for additional emission reductions to protect human
health and continue ecological recovery and protection. EPA
has identified the need for further S02 and NOX controls on the
power industry to address pollutant transport problems many
states face in efforts to attain National Ambient Air Quality
Standards (NAAQS) for ozone and fine particles. In response,
EPA promulgated two new rules in 2005, the Clean Air
Interstate Rule (CA1R)* and the Clean Air Visibility Rule (CAVR).
CA1R was designed to address transport of fine particles and
ozone in the eastern United States, and CAVR was designed to
improve visibility in national parks and wilderness areas.
For more information on the ARP, CA1R, and related programs,
including additional information on S02 and NOX emissions,
acid deposition monitoring, environmental effects of acid
deposition, and detailed unit-level emission data, please visit
EPA's Clean Air Markets Web site at
.
A 2005 study estimated the program's
benefits at $122 billion annually in 2010,
while cost estimates are around $3 billion
annually (in 2000 dollars).
* On July 11, 2008, the U.S. Court of Appeals for the D.C. Circuit issued a ruling vacating CAIR in its entirety and remanding to EPA for further rulemaking consistent with the
opinion. On December 23, 2008, the court granted EPA's petition for rehearing to the extent that it remanded the case without vacatur of CAIR. Under this ruling, CAIR
remains in place as originally promulgated pending EPA's future rulemaking response.
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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EMISSION REDUCTIONS UNDER CAIR AND CAVR
Starting in 2009 and 2010, CAIR* establishes regional caps on S02 and NOX emissions. Annual S02 emissions for affected
eastern states are capped at 3.7 million tons in 2010 and 2.6 million tons in 2015. Annual NOX emissions for affected eastern
states are capped at 1.5 million tons in 2009 and 1.3 million tons in 2015. CAIR will operate concurrently with the ARP, and
EPA has identified strong signals that early CAIR compliance planning already has influenced ARP performance. In 2007,
annual S02 emissions from ARP units dropped about 450,000 tons from 2006 levels despite a 3.6 percent increase in energy
demand (as measured by heat input) from affected sources. Actions taken in anticipation of CAIR appear to have been the
primary factor in this decline. All of the decrease is attributable to reduced S02 emissions from coal-fired units with add-on
pollution control technology (scrubbers), despite an increase in use of coal-fired units.
CAVR addresses S02 and NOX emissions from 26 sectors, including EGUs in non-CAIR states located in the West and parts
of New England. Affected sources under CAVR must reduce S02 and NOX emissions that impair visibility in national parks
and wilderness areas. Notably, EPA allows states to establish additional regional cap and trade programs to accomplish these
reductions from power plants and other stationary sources.
* On July 11, 2008, the U.S. Court of Appeals for the D.C Circuit issued a ruling vacating CAIR in its entirety and remanding to EPA for further rulemaking consistent with the
opinion. On December 23, 2008, the court granted EPA's petition for rehearing to the extent that it remanded the case without vacatur of CAIR. Under this ruling, CAIR
remains in place as originally promulgated pending EPA's future rulemaking response.
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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Since 7990, ARP sources have
reduced annual SO, and NOV
Z A.
emissions by more than 40 percent,
while increasing electricity generation
by 39 percent
cifm
^K,
-------
A
cid deposition, more commonly known as acid
rain, occurs when emissions of S02 and NOX from
.fossil fuel combustion react with water, oxygen, and
oxidants in the atmosphere to form various acidic compounds.
Prevailing winds transport these compounds hundreds of
miles, often across state borders, where they diminish air
quality, damage public health, acidify lakes and streams, harm
sensitive forests and coastal ecosystems, degrade visibility, and
accelerate the decay of building materials.
The ARP, established under Title IV of the 1990 CM
Amendments, requires major reductions of S02 and NOX
emissions from the electric power industry. The S02 program
sets a permanent cap on the total amount of S02 that may be
emitted by EGUs in the contiguous United States. The program
is phased in, with the final 2010 S02 cap set at 8.95 million
tons, a level of about one-half of the emissions from the power
sector in 1980.
As seen in Figure 1, emissions of both S02 and NOX have
decreased markedly under the ARP, while combustion of fossil
fuels, measured as "heat input," for electricity generation has
increased significantly.
Figure 1: Trends in Electricity Generation, Fossil Energy Use, Prices,
and Emissions from the Electric Power Industry
60
40
• Heat Input
• Electricity Generation*
•Average Retail Price
of Electricity**
NOX Emissions
S02 Emissions
-60
1990
1992
1994
1996
I
I
I
1998 2000
Year
I
2002
2004
2006
2008
* Generation from fossil fuel-fired plants.
** Constant year 2000 dollars adjusted for inflation.
Source: Energy Information Administration (electricity generation, retail price); EPA (heat input and emissions, representing all affected ARP units), 2008
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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Using a market-based cap and trade mechanism to reduce S02
emissions allows flexibility for individual combustion units
to select their own methods of compliance. Currently, one
allowance provides a regulated unit limited authorization to
emit 1 ton of S02. The CM Amendments allocate allowances
to regulated units based on historic fuel consumption and
specific emission rates prior to the start of the program. A small
proportion of allowances is available at auction.3 The total
allowances allocated for each year equal the S02 emission cap.
The program encourages early reductions by allowing sources
to bank unused allowances from one year and use them in later
years. Allowance banking provided a strong incentive in early
years to achieve early reductions.
The ARP adopts 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 ARP. An owner
can meet these NOY limits on an individual unit basis or
A
through averaging plans involving groups of its units. Note
that the ARP was originally implemented in two phases for
S02 and NOX. Phase 1 applied primarily to the largest coal-
fired electric generation sources from 1995-1999 for S02 and
from 1996-1999 for NOX, while Phase 11 for both pollutants
began in 2000, expanding coverage of the program, and
tightening the S02 cap on affected sources.
S02 Emission Reductions
Electric power generation is by far the largest single source of
S02 emissions in the United States, accounting for 69 percent
of total S02 emissions nationwide.4
As shown in Figure 2, ARP sources have reduced annual
S02 emissions by 49 percent compared with 1980 levels
and 43 percent compared with 1990 levels. Reductions in
S02 emissions from other sources not affected by the ARP
(including industrial and commercial boilers and the metals
and refining industries) and use of cleaner fuels in residential
and commercial burners contributed to a similar overall
decline (50 percent) in annual S02 emissions from all sources
since 1980. National S02 emissions from all sources have
fallen from nearly 26 million tons in 1980 to less than 13
million tons in 2007.5
For 2007, EPA allocated over 9.5 million S02 allowances under
the ARP. Together with over 6.2 million unused allowances
carried over (or banked) from prior years, there were 15.8
million allowances available for use in 2007. Sources emitted
approximately 8.9 million tons of S02 in 2007, less than the
allowances allocated for the year, and far less than the total
allowances available (see Figure 3).6
Figure 2: SO Emissions from Acid Rain Program Sources
to
C
2
c
o
t/1
i/i
E
UJ
fN
O
20
18
16
14
12
10
8
6
4
2
0
17.3
Phase I (1995-1999) Sources
Phase 11 (2000 on) Sources
All Affected Sources
Allowances Allocated
11.2
10.6
10.01
9.5
9.5=9.5
9.5
9.4 9.3
8.7
15.3 5.4 5.5 5.3 49
III
1980
1985 1990 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007
Year
Source: EPA, 2008
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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Figure 3: SO Emissions and the Allowance Bank, 1995-2007
25
£ 20
n
= 15
I
.a
5
PM
O
Allowances Allocated
Unused Allowances from Previous Years
Actual Emissions from Affected Sources
16.6
15.0
13.4
11.7
21.6
8.7
0
III
5.5 «5.3
4.9
J19.9
I I I • ^^ 15'7 15'8
11'2 10.6 10.2 10.6 10.3 10.2
in i
1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007
Year
Source: EPA, 2008
The number of banked allowances grew from about 6.2
million available for 2007 compliance to approximately 6.8
million available for 2008 and future years. In 2010, the total
number of Title IV allowances allocated annually will drop
to 8.95 million and remain statutorily fixed at that annual
level. In the next few years, industry expectations of stringent
emission reduction requirements under CA1R* may encourage
sources to pursue additional reductions, which would
increase the amount of banked allowances. However, CA1R
contains tighter retirement ratios (that in effect lower the S02
emission cap). Because of the retirement ratios in the CA1R
region, EPA projects that emissions will be significantly lower
than the Title IV emission cap and that sources will deplete a
large portion of the bank. Table 1 explains in more detail the
origin of the allowances that were available in 2007, and Table
2 shows how those allowances were used.
* On July 11, 2008, the U.S. Court of Appeals for the D.C Circuit issued a ruling vacating CAIR in its entirety and remanding to EPA for further rulemaking consistent with the
opinion. On December 23, 2008, the court granted EPA's petition for rehearing to the extent that it remanded the case without vacatur of CAIR. Under this ruling, CAIR
remains in place as originally promulgated pending EPA's future rulemaking response.
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT 1
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Table 1: Origin of 2007 Allowable SO Emission Levels
Type of Allowance
Allocation
Initial Allocation
Number of S02
Allowances
9,191,897
Explanation of Allowance Allocation Type
Initial allocation is the number of allowances granted to units*
based on the product of their historical utilization and emission
rates specified in the CM.
Allowance Auction
250,000
The allowance auction provides allowances to the market that
were set aside in a special allowance reserve when the initial
allowance allocation was made.
Opt-in Allowances
Total 2007 Allocation
97,678
9,539,575
Opt-in allowances are provided to units entering the program
voluntarily. There were eight opt-in units in 2007.
Total Banked Allowances"
6,236,555
Banked allowances are those allowances accrued in an ARP
account from previous years, which can be used for compliance in
2007 or any future year.
Total 2007 Allowable Emissions 15,776,130
* In this report, the term "unit" means a fossil fuel-fired combustor that serves a generator that provides electricity for sale. The vast majority of S02 emissions under the program
result from coal-fired generation units, but oil and natural gas units are also included in this program.
"Total banked allowances are adjusted from the 2006 Progress Report to account for additional allowance deductions made after the 2006 reconciliation was completed.
Source: EPA, 2008
Table 2: SO Allowance Reconciliation Summary, 2007
Total Allowances Held (1995-2007 vintages)
Facility Accounts
15,776,130
12,384,707
General Accounts
Allowances Deducted for Emissions*
Penalty Allowance Deductions (2008 Vintage)
Banked Allowances
Facility Accounts
3,391,423
8,933,291**
6,842,839
3,451,416
General Accounts
3,391,423
"Includes 536 allowances deducted from opt-in sources for reduced utilization.
"This total reflects the resolution of petitions regarding the amount of emissions subject to compliance. This number is approximately 12,000 tons less than the total emissions
used elsewhere in the report, which are based on emissions reported as of July 1, 2008.
Source: EPA, 2008
8
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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From 2006 to 2007, reductions in S02 emissions from ARP
units in 30 states and the District of Columbia totaled about
558,000 tons. Increases in 18 states totaled about 108,000
tons, resulting in a net national decrease of 450,000 tons, or
about 5 percent for the year. Five states (Indiana, Kentucky,
North Carolina, South Carolina, and West Virginia) accounted
for most of the reductions in 2007, ranging from 47,000 to
106,000 tons of S02 in each of these states. Among the states
with annual S02 emission increases between 2006 and 2007,
Pennsylvania contributed a majority of the added emissions.
Pennsylvania experienced an increase of approximately
57,000 tons (or 6 percent above the state's 2006 total S02
emissions). Fluctuations of a similar magnitude have occurred
in five of the past six years in the state (most recently, S02
emissions declined 91,315 tons from 2005 to 2006). The
2006 to 2007 fluctuation can most likely be attributed to a
normal fluctuation in electricity demand since there were
corresponding increases ranging from 4 to 7 percent in gross
load (megawatt hours of electricity), heat input, and unit
operating time. In addition, there was a small increase in the
S02 emission rate.
The states with the highest emitting sources in 1990 have
generally seen the greatest S02 reductions under the ARP
(see Figure 4). Most of these states are upwind of the areas
the ARP was designed to protect, and reductions have
resulted in important environmental and health benefits
over a large region.
In 2007, annual S02 emissions in 34 states and the District
of Columbia fell by a total of approximately 7.0 million tons
from 1990. In contrast, annual S02emissions increased by
a total of 172,000 tons in 14 states from 1990 to 2007. The
seven states with the greatest reductions in annual emissions
since 1990 include Ohio, which decreased emissions by
nearly 1.3 million tons, and Illinois, Indiana, Kentucky,
Missouri, Tennessee, and West Virginia, each of which
reduced total emissions during this time period by more
than 500,000 tons.
Figure 4: State-by-State SO Emission Levels for Acid Rain Program Sources, 1990-2007
S02 Emissions in 1990
S02 Emissions in 1995
^H S02 Emissions in 2000
^H S02 Emissions in 2007
Scale: Largest bar equals 2.2 million
tons of S02 emissions in Ohio, 1990
Source: EPA, 2008
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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WHY SO EMISSIONS DECREASED IN 2007
In 2007, S02 emissions from sources regulated under the ARP fell below 8.95 million tons, thereby reaching
the 2010 emission cap three years earlier than required by statute. Overall, S02 emissions decreased by about
450,000 tons from 2006 levels (see Table 3). Heat input (measured in million British thermal units [mmBtu])
increased for coal, oil, and gas-fired units, indicating that emissions decreased even as electricity demand grew.
A major factor in the S02 emission decrease was the use of flue gas desulfurization (FGD) systems (also called
scrubbers) at 247 ARP coal-fired units in 2007 versus only 226 in 2006. The increase in coal-fired units with
scrubbers reduced the number of uncontrolled units and thereby reduced the overall S02 emission rate for the
coal-fired units. In addition, the average annual emission rate for the units using scrubbers declined from 2006
to 2007 (0.352 versus 0.318 Ib/mmBtu), further reducing the overall coal-fired average annual S02 emission rate.
It is of historical interest that the ARP allowance allocations for Phase 11 in 2000 were based on 1.2 Ib/mmBtu.
With the exception of reductions that might have occurred as a result of enforcement actions (such as reductions
in South Carolina that were required under a consent decree), most of the S02 reductions in 2007 are likely to
have resulted from early compliance planning for CA1R.* While some states have regulations that will require
S02 reductions in future years (such as North Carolina's Clean Smokestacks Act in 2009), a reason for installing
and operating the controls in 2007 was the significant incentive to bank pre-CAIR vintage S02 allowances.Those
allowances could be used on a 1:1 basis under the CA1R annual S02 program. In contrast, ARP allowances with
later vintage years would be subject to increased retirement ratios under CA1R (2:1 in 2010 through 2014, and
2.86:1 in 2015 and thereafter). Going forward, the court decision might affect sources' compliance planning and
the observed trends in S02 emission reductions.
Table 3: SO NO and Heat Input Trends in Acid Rain Program Units, by Fuel Type
F,,P| 2004 2005 2006 2007
Type S02 1 NOX 1 HI S02 1 NOX 1 HI S02 1 NOX 1 HI S02 1 NOX 1 HI
Coal
Oil
Gas
Other
Total
9,840
378
36
3
10,256
3,484
139
133
6
3,762
20.49
1.00
4.83
0.03
26.35
9,836
350
34
3
10,223
3,356
130
141
6
3,633
20.77
1.00
5.34
0.03
27.14
9,247
135
7
7
9,396
3,209
64
130
7
3,410
20.45
0.58
5.71
0.05
26.80
8,780
149
10
7
8,946
3,075
69
140
5
3,289
20.77
0.62
6.32
0.05
27.76
Notes:
• All emission data are in thousand tons, and all heat input data are in quadrillion Btu (Quads).
• Totals might not reflect individual rows due to rounding.
• Fuel type represents primary fuel type, and many units might combust more than one fuel.
• Data are current as of July 1, 2008, and may differ from past reports as a result of report resubmissions by sources and ongoing data quality assurance activities.
Source: EPA, 2008
" On July 11, 2008, the U.S. Court of Appeals for the D.C. Circuit issued a ruling vacating CAIR in its entirety and remanding to EPA for further rulemaking consistent with
the opinion. On December 23, 2008, the court granted EPA's petition for rehearing to the extent that it remanded the case without vacatur of CAIR. Under this ruling, CAIR
remains in place as originally promulgated pending EPA's future rulemaking response.
10
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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SO2 Program Compliance
Approximately 9 million allowances were deducted from
sources' accounts in 2007 to cover emissions. Table 2
displays these allowance deductions, as well as the remaining
banked allowances from 1995 through 2007. In 2007,
all ARP facilities complied with the requirement to hold
enough allowances to cover S02 emissions. The ARP's cap
and trade approach offers sources the flexibility to comply
with regulations using their choice of the most cost-effective
strategies available. Since the program's inception, the
compliance rate has consistently been extraordinarily high
(over 99 percent). Notably, in those few cases where there
is noncompliance, sources must surrender future year
allowances in an amount equivalent to the excess emissions,
and pay a monetary penalty. Title IV set a penalty of $2,000
per ton in 1990, which is adjusted annually for inflation. The
2007 penalty level was set at $3,273 per excess ton.
SO2 Allowance Market
Figure 5 shows the cumulative volume of S02 allowances
transferred under the ARP. The figure differentiates between
allowances transferred in private transactions and those
annually allocated and transferred to source accounts by EPA.
2007 SO, ALLOWANCE MARKET IN BRIEF
Total Value of the S02
Allowance Market
$5.1 billion*
Average Nominal Price
Total Allowance Volume
(Allowable Emissions)
2007 Private Transactions
$325 per ton
15,776,130
4,700 transactions moving
16.9 million allowances
54 percent of allowances
transferred between
economically unrelated
parties
* Total value of allowance market is a snapshot based on the average nominal price as
of July 1, 2007 ($325) and 2007 total allowance volume.
Private transactions are indicative of both market interest and use
of allowances as a compliance strategy. Of the nearly 356 million
allowances transferred since 1994, about 68 percent were traded
in private transactions. In December 2001, parties began to use
a system developed by EPA to allow online allowance transfers.
In 2007, account holders registered over 99 percent of all private
allowance transfers through EPA's online transfer system.7
Figure 5: Cumulative SO Allowances Transferred through 2007
400
350
EPA Transfers to Account Holders
Private Transactions
1995 1996 1997 1998 1999
2000 2001
Year
Source: EPA, 2008
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
2002 2003 2004 2005 2006 2007 2008
11
-------
In 2007, nearly 4,700 private allowance transfers moving
roughly 16.9 million allowances of past, current, and
future vintages were recorded in the EPA Allowance
Tracking System. About 9.1 million (54 percent) were
transferred in economically significant transactions (i.e.,
between economically unrelated parties). Transfers between
economically unrelated parties are "arm's length" transactions
and are considered a better indicator of an active, functioning
market than are transactions among the various facility and
general accounts associated with a given company.
In the majority of all private transfers, allowances were
acquired by power companies. Figure 6 shows the annual
volume of S02 allowances transferred under the ARP
(excluding allocations, retirements, and other transfers by
EPA) since official recording of transfers began in 1994.
Figure 6: SO Allowances Transferred under the Acid Rain Program
30.0
25.0
^
C
o
= 20.0
1
uo
15.0
re
O 10.0 9.2
5.0
Trades between Related Entities
Trades between Distinct Entities (Significant Transfers)
25.0
16.7
18.7
15.2
8.2
I
4.4
21.4
22.4
19.9
16.5
16.9
7.9
9.5
6.2 12.7 12.6 11.6
8.1
7.5
10.0
9.1
Source: EPA, 2008
0.9 1-9
1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007
Year
S02 ALLOWANCE AUCTION
In addition to the annual allowance allocation, Title IV requires an auction for a limited number of allowances. EPA has been
auctioning allowances for 15 years. The auctions help ensure that new electric generating plants have a source of allowances
beyond those allocated initially to existing units. Proceeds from the auctions are returned to sources in proportion to the
allowances withheld. In addition to allowances offered by EPA, private parties may offer allowances for sale in the auction. All
data regarding allowance auction transactions are available online.
The auction includes two "vintages" of allowances. Vintage describes the earliest year an allowance may be applied against S02
emissions. For instance, this year, in addition to 125,000 year 2008 allowances, the CAA mandates that EPA auction additional
allowances seven years in advance to help provide stability in planning for capital investment. These advance allowances will be
first usable in 2015. The auction of allowances has become an increasingly popular idea over time, with some states using this
approach in recent years and others setting up programs for future years that incorporate auctions.
In 2008, the allowance auction sale prices are very much in line with expectations for this trading market. EPA has seen prices
between $300 and $630 over the last year, an increase from where they were four to five years ago. The prices for the last couple
of years have been relatively stable and declining somewhat, while remaining in rough alignment with market fundamentals.
Complete results of the annual S02 Allowance Auction are available at .
12
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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CAIR AND THE SO TRADING MARKET
In 2007, trading continued similar to the final quarter of 2006. Prices began the year at approximately $500/ton and
held between $500 and $600 per ton throughout the year. The market price index (MP1) was $551 in December 2007,
identical to EPA's projected allowance price for pre-2010 vintages (in 2007 dollars).8
However, prices began to fall in early 2008. In October 2008, spot market prices for the earlier vintages were trading
for $142 to $157 per ton after reaching a low of $93 per ton in late July. In October, 2010 vintages were trading for $93
per ton.9 These prices are considerably lower than the $551 (pre-2010) and $276 (2010-2014) prices projected by EPA.
Most market observers characterized this price depression as a result of the uncertainty related to the CAIR* litigation.
Assessing the ratio of the spot trading price in 2008 to the future 2010 trading price seems to support the litigation
uncertainty hypothesis. Prior to the CAIR oral arguments in March 2008, spot market allowances were trading at
roughly twice the price of 2010 allowances, as would be expected under CAlR's 2:1 allowance surrender requirements.
However, this ratio dropped following the oral arguments, aligning more closely with a scenario in which one allowance
would be surrendered at a 1:1 ratio. With the December 23, 2008 court decision, EPA anticipates that the price
differential between spot market and 2010 vintage prices may be closer to the 2:1 ratio observed prior to the March
2008 oral arguments.
Figure 7: S02 Allowance Trading Volume and
Prices, March 1994-0ctober2008
$1,800
$1,600
$1,400
$1,200
$1,000
$800
$600
$400
$200
$0
2.00
1.80
1.60
1.40
1.20
1.00
0.80
0.60
0.40
0.20
0.00
s s ssssssss s s s s
Date
Note: Transfer volume data provided only through December
Source: EPA (transfer volume); CantorC02e (price), 2008
2007.
Figure 8: Actual and Forecasted S02
Allowance Prices
EPA Projected Allowance
Price, 2007 Dollars
$551
$276
Up to 2010
Vintage
2010-2014
Vintage
October 2008 MPI Range
$157
$142
$93
2008
Vintage
2010
Vintage
Source: EPA (projected price); CantorC02e (MPI), 2008
' On July 11, 2008, the U.S. Court of Appeals for the D.C Circuit issued a ruling vacating CAIR in its entirety and remanding to EPA for further rulemaking consistent with
the opinion. On December 23, 2008, the court granted EPA's petition for rehearing to the extent that it remanded the case without vacatur of CAIR. Under this ruling, CAIR
remains in place as originally promulgated pending EPA's future rulemaking response.
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
13
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NOV Emission Reductions
A
and Compliance
Title IV requires NOX emission reductions for certain coal-fired
EGUs by limiting the NOX emission rate (expressed in
Ib/mmBtu). Congress applied these rate-based emission limits
based on a unit's boiler type (see Table 4).
Although the ARP NOX program does not involve a cap
on emissions, Congress set a program goal of 6.1 million
tons from all ARP sources by 2000. The goal represents a 2
million ton reduction in annual NOX emissions from the NOX
emission levels that were projected to occur in 2000 absent
the ARP (8.1 million tons). This goal was first achieved in
2000 and has been met every year thereafter, including 2007.
Figure 9 shows that NOX emissions from all ARP sources were
3.3 million tons in 2007. This level is 4.8 million tons less
than the projected level in 2000 without the ARP, or more
than double the Title IV NOX emission reduction objective.
These reductions have been achieved even though the amount
of fossil fuel burned to produce electricity (as measured by
heat input) at EGUs in 2007 has increased 42 percent since
1990. While the ARP was responsible for a large portion of
these annual NOX reductions, other programs—such as the
Ozone Transport Commission (OTC), the NBP under EPA's
NOX State Implementation Plan (SIP) Call, and other regional
and state NOX emission control programs—also contributed
significantly to the NOX reductions achieved by sources in
2007.
From 1995 to 2007, annual NOY emissions from ARP units
A
dropped by about 2.8 million tons, a net decrease of about 46
percent Forty-one states and the District of Columbia reduced
NOX emissions during this period versus seven states that
accounted for only about 31,000 tons of increased N0x emissions
during the same period (see Figure 10). From 2006 to 2007,
annual N0x emissions from ARP sources were relatively flat, with
a modest decrease of 121,000 tons or 3.5 percent. North Carolina
had the largest one-year decrease, reducing emissions by about
44,000 tons, which in large part appears to be a result of the 2007
N0x requirement in the state's Clean Smokestacks Act. A number
of states outside the NBP region, including Florida, Iowa, Kansas,
Texas, and Wisconsin, reduced NOX emissions by more than
7,000 tons each from 2006 levels.
Table 4: NO -Affected Title IV Units by Boiler Type and NO Emission Limit
_ Title IV Standard NOY Emission
Coal-Fired Boiler Type „, * , Number of Units
Limits (Ib/mmBtu)
Phase 1 Group 1 Tangentially fired
Phase 1 Group 1 Dry Bottom, Wall-fired
Phase 11 Group 1 Tangentially fired
Phase 11 Group 1 Dry Bottom, Wall-fired
Cell Burners
Cyclones > 1 55 MW
Wet Bottom > 65 MW
Vertically fired
Total All Units
0.45
0.50
0.40
0.46
0.68
0.86
0.84
0.80
N/A
132
113
300
294
37
54
22
26
978
Source: EPA, 2008
14
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
-------
Figure 9: NOX Emission Trends for All Acid Rain Program Units, 1990-2007
x
O
6.1 5.9 6.0 6.0
NOX Program Affected Sources Title IV Sources Not Affected for NO,,
s.s
5.1
4.7
4.5
4.2
3.8 3.6
3.4
3.3
1990 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007
Year
Source: EPA, 2008
Figure 10: State-by-State NO Emission Levels for Acid Rain Program Sources, 1990-2007
| NOX Emissions in 1990
NOX Emissions in 1995
^H NOX Emissions in 2000
^B N°x Emissions in 2007
Scale: Largest bar equals 500
thousand tons of NOX emissions
in Ohio, 1990
Notes:
• Emissions are for all ARP sources, not only the coal-fired units subject to the ARP NOX Program.
• NBP states shaded in gray.
Source: EPA, 2008
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
15
-------
As with S02, the states with the highest N0x-emitting sources
in 1990 have tended to see the greatest power plant NOX
emission reductions (see Figure 10). About half of the 13 states
with NOX emission decreases of more than 100,000 tons since
1990 were in the Ohio River Basin. Indiana, Kentucky, Ohio,
Pennsylvania, and West Virginia account for well over 1 million
tons of NOY emission reductions from 1990 to 2007.
A
The ARP NOX Program does not impose a cap on NOX
emissions and does not rely on allowance trading. The ARP
NOX Program, however, provides compliance flexibility
achieved through an approach that is designed to maximize
NOX emission reductions and ensure that those reductions
are sustained. Under the ARP, EPA allows affected sources
to comply by either meeting a unit-specific emission rate or
including two or more units in an emission rate averaging plan.
These options provide affected sources with the flexibility to
meet the NOX emission reduction requirements in the most
cost-effective manner. In 2007, all 978 units that were subject
to the ARP NOX Program achieved compliance.
About one-third of these units chose to comply with a unit-
specific emission rate. There are three types of unit-specific
emission rates: a standard emission limit; an early election
limit; or an alternative emission limit (AEL) (see accompanying
text box). Not only did all units that chose to meet a unit-
specific emission limit achieve compliance in 2007, most units
that complied based on early election or AEL-based limits even
met the standard limits (See Table 4).
Sources can also meet the NOX limits through averaging
plans for a group of units. All the units in a plan must share
a common owner and designated representative. Through
this approach, utilities may allow certain units to exceed the
applicable NOX emission rate limit, provided this exceedance
is offset entirely by unit(s) that have a NOX emission rate
that falls below the applicable standard. About two-thirds of
the 978 NOX affected units achieved compliance through an
averaging plan.
For those units under an averaging plan, 86 percent (561
units) reported NOX emission rates below the standard that
would have applied on a unit-specific basis. In fact, there were
31 averaging plans for which no units exceeded the applicable
standard. As such, all of the units covered under these plans
could have complied with the NOX emission rate requirements
without the use of an averaging plan. Most of these plans had
less than 10 units in the averaging plan. However, about seven
of these plans included more than 10 units, with one of those
covering a total of 58 units.
For each of the averaging plans, the actual average NOX
emission rate reported was below the plan's allowable NOX
emission rate. On average, the reported NOX emission rate for
each averaging plan was lower than the allowable rate by 0.19
Ib/mmBtu. The number of units in each averaging plan ranged
from two units to nearly 70 units. Most averaging plans
included a smaller number of units, with 49 plans covering
less than 15 units each, and 25 plans covering less than five
units each. Only five averaging plans cover more than 25
units. However, even using a weighted average to account
for the varying size of each averaging plan, the reported NOX
emission rate was lower than the allowable rate by an average
of 0.20 Ib/mmBtu, similar to the unweighted average. These
data indicate that allowing compliance through an averaging
plan has been successful in helping to achieve additional NOX
emission reductions, while allowing sources some flexibility
in determining and implementing a cost-effective compliance
option.
16
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
-------
SOURCES ACHIEVED 100 PERCENT NOX COMPLIANCE IN 2007, USING A VARIETY OF NO^
COMPLIANCE PLAN OPTIONS
Standard Limitation. A unit with a standard limit meets the applicable individual NOX limit prescribed for its boiler
type under 40 CFR 76.5, 76.6, or 76.7 (126 units used this option in 2007).
Early Election. In return for accepting a NOX limit three years earlier than would normally be required, an early
election unit does not become subject to the more stringent Phase 11 NOX limit until 2008 (197 units used the early
election provisions for compliance in 2007).
Alternative Emission Limit (AEL). A utility can petition for a less stringent AEL if it properly installs and operates
the NOX emission 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 data and information about the NOX control
equipment (nine units used this option in 2007).
Emissions Averaging. Many companies meet their NOX emission reduction requirements by choosing to become
subject to a group NOX limit, rather than by meeting individual NOX limits for each unit. The group limit is established
at the end of each calendar year. The group rate 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 (646 units used this option in 2007). Note that 68 units
that used an emissions averaging plan also had an early election emission limit, but used the averaging plan as their
compliance approach.
Note: Unit counts do not include those with a retired unit exemption.
ROLE OF SEASONAL NO,, CONTROL PROGRAMS IN REDUCING ANNUAL EMISSIONS
States subject to EPA's 1998 NOX SIP Call have achieved significant reductions in ozone season NOX emissions since the baseline
years 1990 and 2000. All of these states have achieved reductions since 1990 as a result of programs implemented under the
1990 CAA Amendments, with many of them reducing their emissions by more than half since 1990. A significant portion of
these decreases in NOX emissions has been achieved since 2000, largely as a result of reductions under the OTC program and
the NBP. Further reductions in annual NOX emissions were achieved in 2007. Possible reasons for this decline could include:
• Eight new selective catalytic reduction systems (SCR) and four new selective noncatalytic reduction systems (SNCR) were
installed in 2007.
• Sources might have taken advantage of incentives for generation of early action (compliance supplement pool [CSPD
allowances intended for use under the CA1R* annual NOX program that would have begun in 2009.
For NBP compliance reports, see .
* On July 11, 2008, the U.S. Court of Appeals for the D.C. Circuit issued a ruling vacating CAIR in its entirety and remanding to EPA for further rulemaking consistent with
the opinion. On December 23, 2008, the court granted EPA's petition for rehearing to the extent that it remanded the case without vacatur of CAIR. Under this ruling, CAIR
remains in place as originally promulgated pending EPA's future rulemaking response.
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
17
-------
Emission Monitoring and Reporting
The ARP requires regulated sources to measure, record, and
report emissions using continuous emission monitoring
systems (CEMS) or an approved alternative measurement
method. The vast majority of emissions are monitored with
CEMS while the alternatives provide an efficient means of
monitoring emissions from the large universe of units with
lower overall mass emissions. Figures 11 and 12 show the
number of units with and without S02 CEMS for various fuel
types, as well as the amount of S02 emissions monitored
using CEMS. Even though only 32 percent of units use CEMS,
this covers nearly 99 percent of all S02 emissions from ARP
sources.
CEMS and approved alternatives are a cornerstone of the
ARP's accountability and transparency. Since the program's
inception in 1995, affected sources have met stringent
monitoring quality assurance and control requirements, and
reported hourly emission data in quarterly electronic reports
to EPA. Using automated software audits, EPA rigorously
checks the completeness, quality, and integrity of these data.
All emission data are available to the public on the Data
and Maps Web site maintained by EPA's Clean Air Markets
Division (CAMD) at . The site also provides access to other data associated
with emission trading programs, including reports, queries,
maps, charts, and file downloads covering source information,
emissions, allowances, program compliance, and air quality.
The emission monitoring requirements for the ARP are found
in 40 CFR Part 75. These provisions are also required for
participation in the NBP. The Part 75 requirements will be
used in the future to implement CA1R.*
EMISSIONS COLLECTION AND MONITORING PLAN SYSTEM (ECMPS)
CAMD recently reengineered the process the regulated community uses to maintain, evaluate, and submit monitoring plans,
quality assurance certifications, and quarterly emission data. An important tool in this effort is the Emissions Collection and
Monitoring Plan System (ECMPS). ECMPS will replace the current processes and multiple software tools used previously for
evaluating, submitting, and receiving compliance-related information. Data submitted via ECMPS must meet a basic level of
quality. If an evaluation generates a "critical" error, sources will be able to submit data to meet the regulatory deadline, but then
must resolve errors and resubmit their data. ECMPS also has an expanded set of data validation checks that would assist EPA in
implementing improved auditing as sources begin to comply with CA1R. The first group of sources began using ECMPS on an
optional basis beginning on April 1, 2008. Beginning in 2009, affected sources are required to report using the ECMPS software.
ECMPS incorporates the following components:
• A single desktop tool, made available by EPA, for authorized users to import and evaluate their data and to submit it to CAMD.
• A new data reporting format based on the flexible Extensible Markup Language (XML) standard.
• A centralized database at CAMD for receiving and maintaining submitted data, which can be accessed directly through the
desktop tool.
• Tools and procedures for the quality assurance of data prior to submission, including the consolidation of evaluation results
(feedback) into one set.
• The ability to maintain select data outside of the electronic data report.
• New security requirements.
' On July 11, 2008, the U.S. Court of Appeals for the D.C Circuit issued a ruling vacating CAIR in its entirety and remanding to EPA for further rulemaking consistent with
the opinion. On December 23, 2008, the court granted EPA's petition for rehearing to the extent that it remanded the case without vacatur of CAIR. Under this ruling, CAIR
remains in place as originally promulgated pending EPA's future rulemaking response.
18
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
-------
Figure 11: SO Monitoring Methodology for the Acid Rain Program, Number of Units
Gas Units w/ CEMS
Other Fuel Units w/o CEMS
2,189
Gas Units w/o CEMS
163
Oil Units w/o CEMS
46
Oil Units w/CEMS
Other Fuel Units w/CEMS
Note: "Other fuel units" include units that in 2007 combusted primarily wood, waste, or other nonfossil fuel. The total number of units in Figure 11 excludes 57 affected units that
did not operate in 2007.
Source: EPA, 2008
Figure 12: Percentage of S02 Emissions Covered by Monitoring Methodology
for the Acid Rain Program
All Other Units w/ CEMS
.50%
All Other Units w/o CEMS
1.35%
Source: EPA, 2008
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
19
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The percentage of Northeastern lakes
monitored on a long-term basis that are
categorized as of "acute concern" for
their ability to neutralize acid deposition
has fallen from 30 to 18 percent. This
^^^^^^k
improvement is in large part due to ARP
SO, emission reductions.
-------
TATUS AND TRENDS IN AlR QUALITY, ACID
TION, AND ECOLOGICAL EFFECTS
""he emission reductions achieved under the ARP have
led to important environmental and public health
1 benefits. These include improvements in air quality
with significant benefits to human health; reductions in acid
deposition; the beginnings of recovery from acidification in
fresh water lakes and streams; improvements in visibility; and
reduced risk to forests, materials, and structures. Table 5 on
page 22 shows the regional changes in key air quality and
atmospheric deposition measurements linked to the ARP's
SO, and NOY emission reductions.
2 A
Air Quality
Sulfur Dioxide
Data collected from monitoring networks show that the
decline in S02 emissions from the power industry has
improved air quality. Based on EPA's latest air emission trends
data located at , the
national composite average of S02 annual mean ambient
concentrations decreased 54 percent between 1990 and
2007, as shown in Figure 13 (based on state, local, and EPA
monitoring sites located primarily in urban areas). The largest
single-year reduction (20 percent) occurred in the first year of
the ARP, between 1994 and 1995. These trends are consistent
with the regional ambient air quality trends observed in the
Clean Air Status and Trends (CASTNET) network.
Figure 13: National SO, Air Quality, 1990-2007
E
o.
a.
0.04
0.03 —
National Ambient Air Quality Standard
90% of sites have concentrations below this line
CM
O
on
Average concentration
10% of sites have concentrations below this line
u I I I I I III I II
1990 1992 1994 1996 1998 2000 2002 2004 2006 2008
Year
Note: Data represent 281 monitoring sites, generally located in urban areas or near S02 emission sources, used to evaluate national ambient trends.
Source: EPA, 2008
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT 21
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Table 5: Regional Changes in Air Quality and Deposition of Sulfur and Nitrogen
Compounds, 1989-1991 versus 2005-2007, from Rural Monitoring Networks
Average 1989- Average 2005-
Measurement Region Percent Change Number of Sites
Ambient S02
Concentration (|ig/m3)
Ambient Sulfate
Concentration (|ig/m3)
Wet Sulfate
Deposition (kg-S/ha)
Dry Sulfur Deposition
(kg-S/ha)
Total Sulfur Deposition
(kg-S/ha)
Total Ambient Nitrate
Concentration (Nitrate
+ Nitric Acid) (|ig/m3)
Wet Inorganic
Nitrogen Deposition
(kg-N/ha)
Dry Inorganic
Nitrogen Deposition
(kg-N/ha)
Total Inorganic
Nitrogen Deposition
(kg-N/ha)
Mid-Atlantic
Midwest
Northeast
Southeast
Mid-Atlantic
Midwest
Northeast
Southeast
Mid-Atlantic
Midwest
Northeast
Southeast
Mid-Atlantic
Midwest
Northeast
Southeast
Mid-Atlantic
Midwest
Northeast
Southeast
Mid-Atlantic
Midwest
Northeast
Southeast
Mid-Atlantic
Midwest
Northeast
Southeast
Mid-Atlantic
Midwest
Northeast
Southeast
Mid-Atlantic
Midwest
Northeast
Southeast
13
11
5.6
5.3
6.3
6
3.5
5.4
9.3
7
7.7
6
6.5
6.5
4.1
1.2
16
15
11
8
3.3
4.6
1.8
2.2
6.2
5.6
5.6
4.4
2.6
2.5
1.8
0.88
8.8
9
6.5
5.9
7
6
2.4
3.3
4.3
3.9
2.1
4.2
6.7
4.7
5
4.3
3.7
3.5
1.8
0.9
10
9
6
5.8
2.3
3.5
1.1
1.8
5
5.2
4.4
3.8
1.9
2
1.1
1.08
6.7
7.4
5.3
5.2
-46
-45
-57
-38
-32
-35
-40
-22
-29
-33
-35
-28
-43
-46
-56
-25
-38
-40
-45
-28
-30
-24
-39
-18
-19
7
-21
-14
-27
-20
-39
23
-24
-18
-18
-12
12
11
3
9
12
11
3
9
11
28
17
23
10
10
2
2
10
10
2
2
12
11
3
9
11
28
17
23
10
10
2
2
10
10
2
2
Notes:
•Averages are the arithmetic mean of all sites in a region that were present in both averaging periods.
• Total deposition is estimated from raw measurement data, not rounded, and may not equal the sum of dry and wet deposition.
• Percent change in bold indicates that differences were statistically significant at the 95 percent confidence level. Changes that are not statistically significant may be unduly
influenced by measurements at only a few locations or large variability in measurements.
Source: CASTNET and NADP/NTN, 2008
22
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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ABOUT LONG-TERM MONITORING NETWORKS
To evaluate the impact of emission reductions on the environment, scientists and policymakers use data collected from
long-term national monitoring networks such as CASTNET and the National Atmospheric Deposition Program/National
Trends Network (NADP/NTN). These complementary, long-term monitoring networks provide information on a variety
of indicators necessary for tracking temporal and spatial trends in regional air quality and acid deposition (see Table 6).
Table 6: Air Quality and Acid Deposition Measures
Measured in:
i hpmir^ t hpmir^
Name Symbol Ambient Wet Why are these measured by the networks?
Air Deposition
Sulfur
Dioxide
Sulfate Ion
Nitrate Ion
Nitric Acid
Ammonium
Ion
Ionic
Hydrogen
Calcium
SO
2
S042
y
X
N03 X
HNO
NH4+
u+
Ca2+
x
X
X
Magnesium Mg2+ X
Potassium K+ X
Sodium
Na+
X
X
X
X
y
X
X
X
X
Primary precursor of wet and dry acid deposition; primary precursor to
fine particles in many regions.
Major contributor to wet acid deposition; major component of fine
particles in the Midwest and East; can be transported over large
distances; formed from reaction of S02 in the atmosphere.
Contributor to acid and nitrogen wet depositon; major component
of fine particles in urban areas; formed from reaction of NOX in the
atmosphere.
Strong acid and major component of dry nitrogen deposition; formed as
a secondary product from NOX in the atmosphere.
Contributor to wet and dry nitrogen deposition; major component of
fine particles; provides neutralizing role for acidic compounds; formed
from ammonia gas in the atmosphere.
Indicator of acidity in precipitation; formed from the reaction of sulfate
and nitrate in water.
These base cations neutralize acidic compounds in precipitation and
the environment; also play a major role in plant nutrition and soil
productivity.
CASTNET provides atmospheric data on the dry deposition component of total acid deposition, ground-level ozone,
and other forms of atmospheric 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 CASTNET sites have a continuous
20-year data record, reflecting EPA's commitment to long-term environmental monitoring. Information and data from
CASTNET are available at .
NADP/NTN is a nationwide, long-term network tracking the chemistry of precipitation. NADP/NTN provides
concentration and wet deposition data on hydrogen ion (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 (USGS), 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
stations at the end of 1978 to more than 250 sites spanning the continental United States, Alaska, Puerto Rico, and the
Virgin Islands. Information and data from NADP/NTN are available at .
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
23
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AMBIENT ENVIRONMENTAL MONITORING FOR MERCURY
In 2003, an EPA-sponsored workshop convened by the Society for Environmental Toxicology and Chemistry gathered
scientists from across the United States and several other countries to devise a national ambient mercury monitoring
program. A roadmap for a comprehensive national mercury monitoring program emerged from this workshop.10
A May 2008 National Mercury Monitoring Workshop was an important step in building further broad community
support for a comprehensive, integrated monitoring network. The workshop included participants from federal
agencies (EPA, USGS, NOAA, U.S. Fish and Wildlife Service, NPS), state and tribal agencies, the NADP, industry, and
academic and private research institutions. Workshop participants agreed on the overall goal of a network: "To establish
an integrated, national network to systematically monitor, assess, and report on policy-relevant indicators of atmospheric
mercury concentrations and deposition, and mercury levels in land, water, and biota in terrestrial, freshwater, and coastal
ecosystems in response to changing mercury emissions overtime."
Workshop scientists considered the conceptual framework for a mercury monitoring network, called MercNet, to
include national distribution of sites to understand the sources, consequences, and changes in U.S. mercury pollution.
Collaboration and partnerships among existing mercury science and monitoring programs are integral to MercNet. A
broad cross section of agencies and institutions are working to coordinate mercury monitoring activities. To monitor
mercury in the atmosphere, the NADP membership of federal agencies, states, tribes, academic institutions, industry,
and other organizations are collaborating to establish a new network for monitoring atmospheric mercury species. The
network leverages existing atmospheric mercury sites, where possible. At present, 12 atmospheric mercury monitoring
stations (including Alert, Nunavut, Canada, not shown) are participating in NADP to provide high-resolution, high-
quality data (see Figure 14). For more information, visit the NADP mercury initiative Web page .
Figure 14: Atmospheric Mercury Monitoring
Source: NADP, 2008
24
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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During the late 1990s, following implementation of
Phase 1 of the ARP, dramatic regional improvements in
S02 and ambient sulfate concentrations were observed at
CASTNET sites throughout the eastern United States, and
these improvements continue today. Analyses of regional
monitoring data from CASTNET show the geographic pattern
of S02 and airborne sulfate in the eastern United States.
Three-year mean annual concentrations of S02 and sulfate
from CASTNET long-term monitoring sites are compared from
1989 to 1991 and 2005 to 2007 in both tabular form and
graphically in maps (see Table 5 on page 22 and Figures 15,
16, and 17 on pages 25 through 27).
The map in Figure 15a shows that from 1989 to 1991, prior
to implementation of Phase 1 of the ARP, the highest annual
ambient concentrations of S02 in the East were observed in
western Pennsylvania and along the Ohio River Valley. Figure
15b indicates a significant decline in those concentrations in
nearly all affected areas after implementation of the ARP and
other programs.
Figure 15a: Annual Mean Ambient S02
Concentration, 1989-1991
Figure 15b: Annual Mean Ambient S02
Concentration, 2005-2007
Notes:
• For maps depicting these trends for the entire continental United States, visit .
• Dots on all maps represent monitoring sites. Lack of shading for southern Florida indicates lack of monitoring coverage in the 1989-1991 period.
Source: CASTNET, 2008
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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Before the ARP, in 1989-1991, the highest annual ambient
sulfate concentrations, greater than 11 micrograms per cubic
meter (|ig/m3), were also 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 S02 concentrations,
ambient sulfate concentrations have decreased since the
program was implemented, with average concentrations
decreasing from 22 to 40 percent in regions of the East (see
Table 5 on page 22). Both the magnitude and spatial extent
of the highest concentrations have dramatically declined, with
the largest decreases observed along the Ohio River Valley
(see Figures 16a and 16b).
Figure 16a: Annual Mean Ambient Sulfate Figure 16b: Annual Mean Ambient Sulfate
Concentration, 1989-1991 Concentration, 2005-2007
Notes:
• For maps depicting these trends for the entire continental United States, visit .
• Dots on all maps represent monitoring sites. Lack of shading for southern Florida indicates lack of monitoring coverage in the 1989-1991 period.
Source: CASTNET, 2008
26
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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Nitrogen Oxides
Although the ARP has met its NOX emission reduction targets,
emissions from other sources (such as motor vehicles and
agriculture) contribute to ambient nitrate concentrations in
some areas. NOX levels can also be affected by emissions
transported via air currents over wide regions.
From 2005 to 2007, reductions in NOX emissions during the
ozone season from power plants under the NOX SIP Call have
continued to result in significant region-specific improvements
in ambient total nitrate (N03- plus HN03) concentrations. For
instance, annual mean ambient total nitrate concentrations
for 2005 to 2007 in the Mid-Atlantic region were 30 percent
less than the annual mean concentration in 1989 to 1991
(see Table 5 on page 22 and Figures 17a and 17b). While
these improvements might be partly attributed to added NOX
controls installed for compliance with the NOX SIP Call, the
findings at this time are not conclusive.
Figure 17a: Annual Mean Ambient Total Figure 17b: Annual Mean Ambient Total
Nitrate Concentration, 1989-1991 Nitrate Concentration, 2005-2007
Notes:
• For maps depicting these trends for the entire continental United States, visit .
• Dots on all maps represent monitoring sites. Lack of shading for southern Florida indicates lack of monitoring coverage in the 1989-1991 period.
Source: CASTNET, 2008
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
27
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Acid Deposition
NADP/NTN monitoring data show significant improvements
in the primary acid deposition indicators. For example, wet
sulfate deposition (sulfate that falls to the earth through rain,
snow, and fog) has decreased since the implementation of
the ARP in much of the Ohio River Valley and northeastern
United States. Some of the greatest reductions have occurred
in the mid-Appalachian region, including Maryland, New York,
West Virginia, Virginia, and most of Pennsylvania. Other less
dramatic reductions have been observed across much of New
England, portions of the southern Appalachian Mountains,
and some areas of the Midwest. Between the 1989 to 1991
and 2005 to 2007 observation periods, average decreases in
wet deposition of sulfate averaged around 30 percent for the
eastern United States (see Table 5 on page 22 and Figures
18a and 18b). Along with wet sulfate deposition, wet sulfate
concentrations have also decreased by similar percentages. A
strong correlation between large-scale S02 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. The reduction in dry and total
sulfur deposition (wet plus dry) has been even more dramatic
than that of wet deposition in the Mid-Atlantic and Midwest,
with reductions of about 40 percent (see Table 5 on page 22).
Because continuous data records are available from only a
few sites in the Northeast and Southeast, it is unclear if the
observed reductions in total deposition are representative for
those regions.
A principal reason for reduced sulfate deposition in the
Northeast is a reduction in the long-range transport of sulfate
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 S02 emission reductions in eastern Canada. NADP
data indicate that similar reductions in precipitation acidity,
expressed as hydrogen ion (FT) concentrations, occurred
concurrently with sulfate reductions, with reductions of 30 to 40
percent over much of the East.11
Reductions in nitrogen deposition recorded since the early
1990s have been less pronounced than those for sulfur. As
noted earlier, emission trends from source categories other
than ARP sources significantly affect air concentrations and
deposition of nitrogen. Inorganic nitrogen in wet deposition
decreased commensurately in the Mid-Atlantic and Northeast
(see Figures 19a and 19b). Decreases in dry and total
inorganic nitrogen deposition at CASTNET sites have generally
been more striking than that of wet deposition, with about a
20 percent decrease in total nitrogen deposition for the Mid-
Atlantic and Midwest (see Table 5 on page 22). Other source
sectors and pollutants, particularly agriculture and ammonium
respectively, affect nitrogen transport and deposition.
28
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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Figure 18a: Annual Mean Wet Sulfate
Deposition, 1989-1991
Figure 18b: Annual Mean Wet Sulfate
Deposition, 2005-2007
Source: NADR 2008
Figure 19a: Annual Mean Wet Inorganic Figure 19b: Annual Mean Wet Inorganic
Nitrogen Deposition, 1989-1991 Nitrogen Deposition, 2005-2007
Source: NADP, 2008
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
29
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IMPROVEMENTS IN SURFACE WATER CHEMISTRY
Acid rain, resulting from S02 and NOX emissions, is one
of many large-scale anthropogenic effects that negatively
affect the health of lakes and streams in the United
States. Surface water chemistry provides direct indicators of
the potential effects of acidic deposition and the overall health
of aquatic ecosystems. Long-term surface water monitoring
networks provide information on the chemistry of lakes and
streams and on how water bodies are responding to changes in
emissions. Since the implementation of the ARP, scientists have
measured changes in some lakes and streams in the eastern
United States and found signs of recovery in many, but not all, of
those areas (see Figures 20a, 20b, and 20c).
Two EPA-administered monitoring programs provide
information on the effects of acid rain on aquatic systems:
the Temporally Integrated Monitoring of Ecosystems (TIME)
program and the Long-Term Monitoring (LTM) program.
These programs were designed to track the effect of the 1990
CAA Amendments in reducing the acidity of surface waters
in four regions: New England, the Adirondack Mountains,
the Northern Appalachian Plateau, and the Ridge and Blue
Ridge provinces. The surface water chemistry trend data in the
four regions monitored by the TIME and LTM programs are
essential for tracking the ecological response to ARP emissions
reductions.
The data presented here show regional trends in acidification
from 1990 to 2006 in lakes and streams sampled through the
LTM program (see Figures 20a through 20c). Only sites that
have a complete data record for the time period are represented.
Three indicators of acidity in surface waters are presented—
measured ions of sulfate and nitrate and acid neutralizing
capacity (ANC). These indicators provide information regarding
both sensitivity to surface water acidification and the level of
acidification that has occurred today and in the past. Trends in
these sensitive chemical receptors allow for the determination of
whether the conditions of the water bodies are improving and
heading towards recovery or if the conditions are degrading.
Measurements of sulfate ion concentrations in surface waters
provide important information on the extent of cation
leaching in soils and how sulfate concentrations relate to
deposition and to the levels of ambient atmospheric sulfur.
Figure 20a: Trends in Lake and Stream Water Chemistry at LTM Sites, 1990-2006,
Sulfate Ion Concentration (neq/L/yr)
• Increasing trend
O Increasing non-significant trend
O Decreasing non-significant trend
• Decreasing trend
Source: EPA, 2008
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ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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Figure 20b: Trends in Lake and Stream Water Chemistry at LTM Sites, 1990-2006,
Nitrate Ion Concentration (jieq/L/yr)
0 Increasing trend
O Increasing non-significant trend
O Decreasing non-significant trend
A Decreasing trend
Source: EPA, 2008
Figure 20c: Trends in Lake and Stream Water Chemistry at LTM Sites, 1990-2006,
ANC Concentration (p,eq/L/yr)
7
• Increasing trend
O Increasing non-significant trend
O Decreasing non-significant trend
• Decreasing trend
Source: EPA, 2008
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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IMPROVEMENTS IN SURFACE WATER CHEMISTRY (continued)
Assessments of acidic deposition effects dating from the
1980s to the present have shown sulfate to be the primary
negatively charged ion in most acid-sensitive waters.12 Nitrate
has the same potential as sulfate to acidify drainage waters
and leach acidic aluminum cations from watershed soils. In
most watersheds, however, nitrogen is a limiting factor for
plant growth, and therefore most nitrogen inputs through
deposition are quickly incorporated into biomass as organic
nitrogen with little leaching of nitrate into surface waters.
ANC is an important measure of the sensitivity and the degree
of surface water acidification or recovery that occurs over time.
Acidification results in the diminishing ability of water in the
lake or stream to neutralize strong acids that enter aquatic
ecosystems. Water bodies with ANC values defined as less
than or equal to 0 microequivalents per liter (u,eq/L) are acidic.
Lakes and streams having springtime ANC values less than
50 u,eq/L are generally considered "sensitive" to acidification.
Lakes and streams with ANC higher than 50 u,eq/L are generally
considered less sensitive or insensitive to acidification. When
ANC is low, and especially when it is negative, stream water pH
is also low (less than about 5 to 6), and there may be adverse
impacts on fish and other animals essential for a healthy aquatic
ecosystem. Movement toward recovery of an aquatic ecosystem
is indicated by positive trends in ANC and negative trends in
sulfate and nitrate.
Table 7 presents the aggregate sulfate, nitrate, and ANC trends
(u,eq/L/yr) represented by the LTM sites shown in Figure 20
for four acid sensitive regions of the eastern U.S. The maps
and summary results indicate that:
• Sulfate concentrations are declining at almost all sites in
the Northeast (New England, Adirondacks/Catskills and
Pennsylvania [Northern Appalachians]). However, in the
Blue Ridge (Southern Appalachians), sulfate concentrations
in streams are increasing. This region has soils and other
geologic attributes that can store large amounts of sulfate
deposited and contribute little buffering capacity to
neutralize acidity. When sulfate has exceeded the soil's
ability to store and neutralize sulfate, the excess is exported
to surface waters, mainly streams.
• Nitrate concentrations are decreasing overall in all of the
regions, but several lakes and streams indicate flat or slightly
Table 7: Trend Slopes for LTM Sites
in Four Eastern U.S. Regions, 1990-2006
D™;™ Sulfate Nitrate AMrcmoc
Region SLQpE SLQpE ANC SLOPE
New England
Adirondack?
Appalachian
Plateau
Ridge/Blue
Ridge
-2.3
-2.23
-2.36
0.10
-0.02
-0.31
-0.18
-0.125
0.185
0.82
0.80
0.03
Notes:
• Blue values indicate significance at 95% confidence interval (p < 0.05). Confidence
levels are used to express the reliability and significance of the estimate.
• The slope or trend in a simple linear regression (SLR) model corresponds to the
change in the chemical variable over time. A negative or positive slope indicates
whether the chemical variable in the regional distribution of water bodies is
decreasing or increasing.
• The table of values represents the trend of all the sites in that particular Region.
The individual site trends were calculated for each site and color coded according
to whether the slope is positive or negative and whether the trends are significant
or not significant.
Source: EPA, 2008
increasing nitrate trends. This trend does not appear to
reflect changes in emissions or deposition in these areas and
is likely a result of ecosystem factors.
• ANC, as measured in surface waters, is increasing in
three of the four regions, which in part can be attributed
to declining sulfate deposition. The site trends also
indicate variation within each region. No sites indicate a
significant downward trend in ANC.
The ANC of lakes monitored under the TIME and LTM programs
was also evaluated for 1992 to 1994 and 2004 to 2006 to assess
the impacts of ARP implementation. The analysis compares
average ANC levels for the northeastern lakes that had data in each
time period. Thirty percent of lakes in 1992 to 1994 had three-
year mean ANC levels below 0 |ieq/L These lakes are categorized
as "acute concern," in which a complete loss offish populations
is expected, and planktonic communities have low diversity and
are dominated by acidophilic forms. The percentage of lakes in
this category dropped to 18 percent in 2004 to 2006 (see Figure
21). As a result the three other categories (elevated, moderate, or
low concern) experienced slight increases. These results point to
a decrease in acidity, particularly for the subset of lakes with low
ANC. The lakes from the T1ME/LTM networks are representative of
a broad range of ANC levels.
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ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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Figure 21: Northeastern Lakes by ANC Status Category, 1992-1994 versus 2004-2006
100|ieq/L)
Table 8: Aquatic Ecosystem Status Categories for the Adirondacks
Category Label
Acute Concern
ANC Levels"
< 0 micro
equivalent
per Liter (|ieq/L)
Expected Ecological Effects
Complete loss offish populations is expected. Planktonic communities have extremely low
diversity and are dominated by acidophilic forms. The numbers of individuals in plankton species
that are present are greatly reduced.
Elevated
Concern
0-50
Fish species richness is greatly reduced (more than half of expected species are missing). On
average, brook trout populations experience sub-lethal effects, including loss of health and
reproduction (fitness). During episodes of high acid deposition, brook trout populations may
experience lethal effects. Diversity and distribution of zooplankton communities declines.
Moderate Concern
50-100|ieq/L
Fish species richness begins to decline (sensitive species are lost from lakes). Brook trout
populations are sensitive and variable, with possible sub-lethal effects. Diversity and distribution
of zooplankton communities begin to decline as species that are sensitive to acid deposition are
affected.
Low Concern
>100|ieq/L
Fish species richness may be unaffected. Reproducing brook trout populations are expected
where habitat is suitable. Zooplankton communities are unaffected and exhibit expected diversity
and distribution.
* It is important to note that the wide range of ANC values within these categories makes it likely that substantial improvements in ANC may occur without changing the
categorization of a given lake.
Source: EPA, 2007
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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CRITICAL LOADS CASE STUDY: ADIRONDACK LAKES
ne Adirondack Mountain region of New York long has
been a focal point for environmental concern over acid
I deposition. Soils and lakes usually buffer the acidity
from natural rain, but poor buffering capability of the soils in
the Adirondack region makes the streams, lakes, and ponds
particularly susceptible to acidification. Consequently, acid
deposition has affected hundreds of lakes and thousands of
miles of headwater streams in the region, greatly reducing the
diversity of aquatic life.
Since the mid-1990s, lakes in the Adirondack
region have shown signs of recovery from acid
rain. Because of the S02 and NOX emission
reductions from theARP and other programs,
sulfur and nitrogen deposition to the region
have decreased by approximately 26 percent
and 13 percent, respectively. This has led to
improvement in ANC, a measure of the ability
of water bodies to neutralize or buffer acid
deposition and a sign of ecosystem recovery.
In this case study, critical loads were calculated for 177 lakes
in the Adirondack region (Figure 22). The critical load for
a lake or stream provides a means to gauge the extent to
which a water body has recovered from past acid deposition,
or is potentially at risk due to current deposition levels. The
critical load approach provides a quantitative estimate of the
exposure to one or more pollutants below which significant
harmful effects on specific sensitive elements of the
environment do not occur according to present knowledge.
There are numerous methods and models that can be
used to calculate critical loads for acidity. Drawing on the
peer-reviewed scientific literature (e.g., Dupont, et al.) this
case study uses the Steady-State Water Chemistry (SSWC)
model to calculate the critical load.13 The analysis uses water
chemistry data from the TIME and LTM programs that are part
of the Environmental Monitoring and Assessment Program
(see discussion of surface water trends on pages 30-33).
The focus is on the combined load of sulfur and nitrogen
deposition below which the ANC level would still support
healthy aquatic ecosystems. Research studies have shown that
surface water with ANC values greater than 50 |ieq/L tends to
protect most fish (e.g., brook trout, others) and other aquatic
organisms. So, in this case, the critical load represents the
combined deposition load of sulfur and nitrogen to which
34
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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a lake or stream could be subjected and
still have an ANC of 50 |ieq/L. Critical loads
of combined total sulfur and nitrogen are
expressed in terms of ionic charge balance
as milliequivalent per square meter per year
(meq/mVyr).
When the critical load is "exceeded," it means
that the amount of combined sulfur and
nitrogen atmospheric deposition is greater than
the critical load for a particular lake, preventing
the lake from reaching or maintaining an
ANC concentration of 50 |ieq/L (Figure 22).
On average, the critical load for lakes in the
Adirondack region is 164 meq/nf/yr, while it
is 48 meq/nf/yr for the lakes most susceptible
to acidification (i.e., those lakes with ANC less
than100|ieq/L).
Environmental monitoring data reported
below (and in earlier sections of this report)
demonstrate decreasing trends in pollution
loading and accompanying changes in
environmental response indicators. ARP
emission reductions have resulted in substantial decreases in
atmospheric deposition of sulfur and nitrogen. As Figure 23
shows, decreases in sulfur and nitrogen deposition are evident
in the Adirondack Mountain region as well.
Figure 24 shows trends in sulfate, nitrate, and ANC for
Adirondack Mountain lakes monitored through the
Adirondack LTM program. As a result of decreases in pollution
regional deposition (Figure 23), sulfate concentrations in these
lakes have dropped, which is an important sign of ecological
recovery. While inter-annual variability in ANC and nitrate
concentrations is evident in the Adirondack Mountain LTM
lakes, the overall trend in these lakes of a slight increase
in ANC and modestly decreasing nitrate concentrations
are consistent with the overall ANC and nitrate trends for
Adirondack Mountain lakes shown in Table 7 on page 32.
Figure 22: Critical Loads of Sulfur and Nitrogen
Deposition for 177 Lakes in the Adirondack Region
; • SeiUillvclSUtolCHJI
Highly SonslmliylcSO)
E -1U
Note: Data available at
Source: EPA, 2008
However, it is difficult to determine whether Adirondack
Mountain region aquatic ecosystems are sufficiently protected
without some context for understanding trends evident in the
environmental monitoring data. The critical load provides a
context-setting benchmark. In Figures 25a and 25b, a critical
load exceedance indicates combined sulfur and nitrogen
deposition were greater than a lake or stream could sustain
and still maintain the ANC level of 50 |ieq/L or above.
Exceedances were calculated from deposition for the period
before implementation of the ARP (1989-1991) and fora
recent period after ARP implementation (2005-2007).
For the period from 2005 to 2007, 36 percent of the lakes
within the TIME and LTM programs continued to receive levels
of combined sulfur and nitrogen deposition that exceeded the
critical load. For the period before ARP implementation, 52
percent of lakes received greater acid deposition than could be
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
35
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CRITICAL LOADS CASE STUDY: ADIRONDACK LAKES (continued)
Figure 23: Annual Average Wet Sulfate and Nitrate
Deposition in the Adirondack Region,1990-2006
35
S04
N03
ul I I I I I I I I I I I I I I I I I
1990 1992 1994 1996 1998 2000 2002 2004 2006
Year
Source: NADP, 2008
Figure 24: Annual Average Surface Water Sulfate
and Nitrate Concentration in the Adirondack
Region,! 990-2006, Compared with ANC
120
-*-S04
-i-N03
-A-ANC
o
I I I I I I I I I I I I I I I I I I
1990 1992 1994 1996 1998 2000 2002 2004 2006
neutralized. By the 2005-2007 period, 16 percent
fewer Adirondack Mountain region lakes within the
TIME and LTM programs were receiving sulfur and
nitrogen deposition loads that threaten the health of
these ecosystems.
Figures 25a and 25b also show lakes where
deposition was within 10 percent of the critical load.
These lakes illustrate areas where ecosystem health
has improved over time, even though the deposition
still is greater than the critical load.
Thus, this critical load analysis shows that emission
reductions achieved by the ARP have resulted in
improved environmental conditions and increased
ecosystem protection in the Adirondack Mountain
region. However, the analysis also shows that
despite the ecological recovery that has occurred
over the past decades in the Adirondack region,
deeper reductions in acid deposition are necessary
for greater recovery of these sensitive aquatic
systems, leading to full ecosystem protection.
Year
Source: LTM, 2008
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ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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Figures 25a and 25b: Comparison of Critical Load Exceedances in Adirondack Lakes
before and after Implementation of the Acid Rain Program
Source: EPA, 2008
Exceeds Critical Loa
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
37
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TRENDS IN ATMOSPHERIC SULFUR CONCENTRATIONS
C02 and NOX emissions can react in the atmosphere to
form fine particles, which are harmful to humans and
^J sensitive ecosystems. Sulfate particles are formed after
gaseous S02 is emitted and oxidized. Sulfate particles can then
be deposited on the surface (dry deposition), or the particles
can react in clouds or fog to form sulfuric acid (H2S04),
commonly known as acid rain. CASTNET data, combined
with S02 emission data from CEMS at ARP-affected sources,
provide a more complete picture of how emission reductions
under the ARP are translating into improvements in air quality
and reductions in acid deposition as S02 emissions decrease
over time.
Since S02 is a precursor to the formation of sulfate, reductions
in S02 emissions under the ARP were expected to translate
into similar reductions in atmospheric sulfate concentrations.
Although there is an observed downward trend in ambient
sulfate concentration since the implementation of the ARP,
these reductions have not been as dramatic as those observed
for S02 emissions and ambient S02 concentrations (see
Figures 26 through 28, reproduced from last year's report).
Regional decreases in annual particulate sulfate concentrations
compared with the larger regional decreases in S02 emissions
and the proportional decreases in ambient S02 concentrations
may be understood by examining seasonal changes in the
potential for sulfate formation. In fact, due to complex
atmospheric chemistry interactions, decreases of other
pollutants, namely ozone, have contributed to seasonal
variations in sulfate, although the overall trend in sulfate is
downward.
S02 emissions can undergo further oxidation via several
pathways to form sulfates. Generally, this process takes several
days. Chemical reactions involved in the oxidation of sulfur in
the atmosphere are sensitive to environmental factors, such
as temperature, amount/intensity of sunlight (solar radiation),
water vapor, and quantity of reactive oxidants (such as ozone).
Since these factors vary seasonally, the chemical reactions
involving sulfur are also seasonally dependent.
38
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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Figure 26: Trends in Regional Annual SO Emissions (Coal-fired Acid Rain Program Units)
1
5? Regional S02 Emissions (tons)
from CEMS Measurements
6,400 tons
: 1985
Pre-ARP:1990
I Phase 1: 1996-1 999
Phase II: 2003-2006
Figure 27: Trends in Regional Ambient SO Concentrations (CASTNET Sites)
ID Regional SO2
Concentrations (jig/m3)
from CASTNET Measurements
Source: CASTNET, 2007
Pre-CAA Amendments: 1987-1990
Pre-ARP: 1993-1994
Phase 1:1996-1999
Phase II: 2003-2006
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
39
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TRENDS IN ATMOSPHERIC SULFUR CONCENTRATIONS (continued)
Figure 29 shows the smoothed average concentration trend
in weekly concentrations of S02 and sulfate measured at
CASTNET sites from 2005 through 2007. The concentrations
of sulfate and S02 exhibit opposite seasonal patterns.
The different seasonal patterns are due to changes in the
oxidative potential of the atmosphere. During the summer
months of May through September, concentrations of ground-
level ozone increase and create conditions that allow more S02
to be oxidized and form sulfate. During the winter months of
October through April, the potential for sulfate formation is
significantly lowered because less solar radiation and cooler
temperatures lead to reduced ground level ozone levels. As a
result, sulfur tends to remain in the gaseous form (S02).14
The trends over time in the median* sulfate and S02
concentrations during the summer and winter seasons are
shown in Figures 30 and 31. In the summer, the dramatic
decline seen in gaseous S02 is reflected in the equally
dramatic decline in sulfate concentrations. These patterns
generally mirror the decline in S02 emissions. In winter
months there is a similar downward trend in S02 emissions
and S02 concentrations. However, the particulate sulfate
concentrations do not appear to decrease at the same rate.
In the winter months, regional ozone concentrations and
other oxidants in photochemical smog are typically low, which
leads to reduced conversion of S02 to sulfates. As shown in
Figure 31, the trend in sulfates during the winter months is
relatively flat compared to the S02 trend. These winter results
dampen the signal for particulate sulfate reductions when
aggregated annually as compared to S02, and help explain
the difference between the dramatic decrease in ambient S02
concentrations since the pre-ARP period (Figure 27) and the
comparatively small decrease in annual particulate sulfates
concentration (Figure 28).
* Median, not mean, values are used because the median is a better representation of the geographic diversity of the monitored sites.
Figure 28: Trends in Regional Ambient Sulfate Concentrations (CASTNET Sites)
~^rji Average Regional SO4
Concentrations (jig/m3)
from CASTNET Measurements
Source: CASTNET, 2007
Pre-CAA Amendments: 1987-1990
Pre-ARP: 1993-1994
Phase 1:1996-1999
Phase II: 2003-2006
40
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
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In addition, EPA program-driven reductions in ozone
concentrations, background NOX levels, and meteorological
variables have changed the oxidative condition of the
atmosphere over large regions in the United States. Since the
rate of conversion of S02 to particulate sulfate is controlled
by the level of oxidant in the atmosphere, fluctuations in
ozone concentrations will lead to changes in particulate
sulfate concentrations. Thus, it will continue to be important
to sample for all species of oxidized sulfur in the atmosphere
(gaseous S02, particulate sulfates, and sulfur in precipitation
measured as aqueous sulfate) in evaluating the ongoing
effectiveness of sulfur control programs.
Figure 29: Sulfur Seasonal Variability,
2005-2007
IB
re
o
u
0
I
2005
I I I
2006
Year
Source: CASTNET Dataset DryChem, EPA, 2008
I
2007
I
2008
Figure 30: Trends in Sulfate and S02
Concentrations for May-September,
1989-2007
Median Sulfate
Median S02
Figure 31: Trends in Sulfate and S02
Concentrations for October-April,
1989-2007
Median Sulfate
Median S02
I I
1989 1991
I I I I I I I I
1993 1995 1997 1999 2001 2003 2005 2007
Year
Source: CASTNET Dataset DryChem, EPA, 2008
I I I I I I I I I I
1989 1991 1993 1995 1997 1999 2001 2003 2005 2007
Year
Source: CASTNET Dataset DryChem, EPA, 2008
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
41
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ONLINE INFORMATION, DATA, AND RESOURCES
The availability and transparency of data, from emission
measurement to allowance trading to deposition
monitoring, is a cornerstone of effective cap and trade
programs. CAMD, in the Office of Air and Radiation's Office
of Atmospheric Programs, develops and manages programs
for collecting these data and assessing the effectiveness of cap
and trade programs, including the ARP.
The CAMD Web site provides a public resource for general
information on how market-based programs work and what
they have accomplished, along with the processes, information,
and tools necessary to participate in any of these market-based
programs.
For information about EPA's air emission
trading programs, see
.
For information about the ARP, see
.
EPA has created supplementary maps that allow the user to
display geospatial data on an interactive 3D platform. The
maps come in the form of a KMZ file (a compressed KML
file) that is downloaded directly to your computer. You only
need to download these files once, and then you can look
Adirondack Water Quality
Google
Detailed water quality monitoring information for the Adirondack region in New York. Clicking on individual monitoring sites displays monitoring
site details and trend information.
42
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
-------
at them as often as you wish. Data can be explored in new
and meaningful ways by turning different layers on and
off, overlaying data points and satellite imagery and using
navigation tools to change the view of the Earth's surface.
KMZ/KML files are supported by programs such as Google
Earth, ESR1 Arc Explorer, and NASA WorldWind View. These
interactive mapping applications provide a unique way to
identify environmental trends and track the progress of
various EPA programs, such as the ARP.
For more information or to utilize the program, visit
the Web site at .
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
43
-------
ONLINE INFORMATION, DATA, AND RESOURCES (continued)
U.S. SO Emissions from Acid Rain Program Sources, 2007
This example depicts 2007 S02 emissions from Acid Rain Program sources in the continental United States. Mote that the legend displays both the
SO and NO maximum value circles, even if only one pollutant (SO in this example) is selected for display on the map.
44
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
-------
National Air Quality Monitoring Network Locations
Map showing the locations ofCASTNETand NADP air quality monitoring sites. Clicking on Individual locations shows detail Information for
each site.
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
45
-------
•
it&,
1. See .
2. Chestnut, L. G., and Mills, D. M. 2005. A fresh look at the benefits and costs of the U.S. Acid Rain Program. Journal of
Environmental Management, 77(3): 252-256.
3. For the statutory provisions on allowance allocations, see Section 403 of the CAA, as amended in 1990.
See .
4. See .
5. See .
6. Detailed emissions and allowance data for ARP sources are available on the Data and Maps portion of EPA's Clean Air
Markets Web site at .
7. Allowance transfers are posted and updated daily on .
8. The market price index (MP1) presented in this report is based on trade, bid, and offer price as tracked by CantorC02e.
9. Note that very few trades occurred in October.
10. See details of this roadmap in:
Mason, R.P., Abbott, M.L., Bodaly R.A., Bullock, O.R., Driscoll, C.T., Evers, D., Lindberg, S.E., Murray, M., and Swain, E.B.
2005. Monitoring the response to changing mercury deposition. Environmental Science & Technology, 39(1):14A-22A.
Harris, R., Krabbenhoft, D.P., Mason, R., Murry M.W, Reash, R., and Saltman, T. 2007. Ecosystem Responses to Mercury
Contamination, Indicators of Change. CRC Press. 240 pages.
11. See data available at .
12. Driscoll, C.T., Lawrence, G., Bulger, A., Butler, T, Cronan, C., Eagar, C., Lambert, K.F., Likens, G.E., Stoddard, J., and Weathers,
K. 2001. Acid deposition in the Northeastern U.S.: Sources and Inputs, Ecosystem Effects, and Management Strategies.
Bioscience, 51:180-198.
Webb, J. R., Cosby, B.J., Deviney FA. Jr., Galloway, J.N., Maben, S.W, and Bulger, A.J. 2004. Are Brook Trout Streams in
Western Virginia and Shenandoah National Park Recovering from Acidification? Environmental Science and Technology,
38(15):4091-4096.
13. Dupont, J., Clair, T.A., Gagnon, C, Jeffries, D.S, Kahl, J.S., Nelson, S.J., and Peckenham, J.M. 2005. Estimation of Critical
Loads of Acidity for Lakes in Northeastern United States and Eastern Canada, Environmental Monitoring and Assessment,
109:275-291.
14. These seasonal patterns in S02 and sulfates have been documented previously by:
Sickles, J. E., 11, and Shadwick, D. S. 2007. Seasonal and regional air quality and atmospheric deposition in the eastern United
States. Journal of Geophysical Research, 112, D17302, doi:10.1029/2006JD008356.
Hicks, B.B., Meyers, T. P., Hosker, R. P. Jr., and Artz, R. S. 2001. Climatological features of regional surface air quality from
the Atmospheric Integrated Research Monitoring Network (AlRMoN) in the USA, Atmospheric Environment, 36(6):
1053-1068.
Day, D. E., Malmet, W C., and Kreidenweis, S. M. 1997. Seasonal Variations in Aerosol Composition and Acidity at
Shenandoah and Great Smoky Mountains National Parks. Journal of the Air & Waste Management Association, 47:411-418.
46
ACID RAIN AND RELATED PROGRAMS: 2007 PROGRESS REPORT
-------
-------
United States
Environmental Protection Agency
1200 Pennsylvania Avenue, NW.
(6204N)
Washington, DC 20460
Official Business
Penalty for Private Use $300
EPA-430-K-08-010
January 2009
www.epa.gov
Recycled/Recyclable—Printed with vegetable oil based inks on 100% postconsumer, process chlorine free recycled paper.
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
AL AMEA Sylacauga Plant 560181,2 010 01
AL Barry 3 1 , 2, 3, 4, 5, 6A, 6B, 7A, 51872 52343 51275 51275 1068
AL Calhoun Power Company I, LLC
AL Charles R Lowman
AL Colbert
AL Decatur Energy Center
AL E B Harris Generating Plant
AL E C Gaston
AL Gadsden
AL Gorgas
AL Greene County
AL Hog Bayou Energy Center
AL James H Miller Jr
AL Mclntosh (7063)
AL McWilliams
AL Morgan Energy Center
AL Plant H. Allen Franklin
AL SABIC Innovative Plastics - Burkville
AL Tenaska Central Alabama Gen Station
AL Tenaska Lindsay Hill
AL Theodore Cogeneration
AL Washington County Cogen (Olin)
AL Widows Creek
AR Carl Bailey
AR Cecil Lynch
AR City Water & Light - City of Jonesboro
AR Dell Power Plant
AR Flint Creek Power Plant
AR Fulton
AR Hamilton Moses
AR Harry D. Mattison Power Plant
AR Harvey Couch
AR Hot Spring Power Co., LLC
AR Independence
7B
55409 CT1, CT2, CT3, CT4 0
561,2,3 14774
471,2,3,4,5 41776
55292 CTG-1, CTG-2, CTG-3 0
78971 A, 1B, 2A, 2B 0
261,2,3,4,5 57815
71,2 3981
86,7,8,9,10 39880
101,2, CT2, CT3, CT4, 16411
CT5, CT6, CT7, CT8,
CT9, CT10
55241 COG01 0
6002 1, 2, 3, 4 57457
7063 "1, "2, "3 938
533 "4, **V1, **V2 844
55293 CT-1, CT-2, CT-3 0
77101A, 1B, 2A, 2B 0
7698 CC1 0
55440 CTGDB1, CTGDB2, 0
CTGDB3
55271 CT1, CT2, CT3 0
7721 CC1 0
7697 CC1 0
50 1, 2, 3, 4, 5, 6, 7, 8 35471
20201 10
1672,3 3
56505 SN04, SN06, SN07 0
553401,2 0
61381 15192
7825 CT1 0
1681,2 0
56328 3, 4 0
1691,2 119
55714SN-01.SN-02 0
6641 1,2 36556
6
18818
86320
7
27
144541
9756
74324
31469
4
16279
33301
6
8
141307
9478
72601
30650
1
60375
855
24
9
23
6
18
6
6
6
56118
259
24
2
25
40531
10
4
7
837
6
70927
0
59527
0
2
8
8
2
2
3
3
3
32724
5
0
0
0
8723
0
0
0
0
4
29539
4
16279
33301
6
8
141307
9478
72601
30650
2
2539
53019
1
19
3234
278
1723
819
0
59527
0
2
8
8
2
2
3
3
3
32724
5
0
0
0
8723
0
0
0
0
4
29539
1
848
855
22
1
15
4
16
3
3
3
23394
254
24
2
25
31808
10
4
7
837
2
41388
Pagel
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
AR KGen Hot Spring LLC 55418 CT-1, CT-2 042 22
AR Lake Catherine 1701,2,3,4 164 1145 0 0 1145
AR McClellan 20301 15 803 433 433 370
AR Oswald Generating Station 55221 G1 , G2, G3, G4, G5, G6, 0 70 0 0 70
AR Pine Bluff Energy Center
AR Robert E Ritchie
AR Thomas Fitzhugh
AR Union Power Station
AR White Bluff
AZ Agua Fria Generating Station
AZ Apache Station
AZ APS Saguaro Power Plant
AZ APS West Phoenix Power Plant
AZ Arlington Valley Energy Facility
AZ Cholla
AZ Coronado Generating Station
AZ De Moss Petrie Generating Station
AZ Desert Basin Generating Station
AZ Gila River Power Station
AZ Griffith Energy LLC
AZ Irvington Generating Station
AZ Kyrene Generating Station
AZ Mesquite Generating Station
AZ Navajo Generating Station
AZ New Harquahala Generating Company, LLC
AZ Ocotillo Power Plant
AZ Redhawk Generating Facility
AZ Santan
AZ South Point Energy Center, LLC
AZ Springerville Generating Station
G7
55075 CT-1
1731,2
201 2
55380 CTG-1, CTG-2, CTG-3,
CTG-4, CTG-5, CTG-6,
CTG-7, CTG-8
6009 1,2
141 1,2,3
1601,2,3,4
1181,2, CT3
117CC4, CC5A, CC5B
55282 CTG1.CTG2
1131,2,3,4
6177U1B, U2B
124GT1
55129DBG1, DBG2
55306 1CTGA, 1CTGB, 2CTGA,
2CTGB, 3CTGA, 3CTGB,
4CTGA, 4CTGB
55124P1, P2
1261,2,3,4
147K-1, K-2, K-7
55481 1, 2, 5, 6
4941 1, 2, 3
55372 CTG1.CTG2, CTG3
1161,2
55455 CC1 A, CC1B, CC2A,
CC2B
8068 5A, 5B, 6A
55177 A, B
8223 1, 2, TS3
0
2201
1
0
44840
196
4951
229
33
0
21147
11636
0
0
0
4
1249
40
39
65750
1
6219
510
20
11
26030
16881
8
4
39
3
0
13
8
33516
0
2662
0
5
4
23523
16881
0
4
16
0
2898
25
0
75524
0
188
0
0
0
14260
6
2992
2
40
4437
13
42
29
9
7
6280
4
2908
2
16
4437
6
0
8
9
5
5993
3
0
13
8
33516
0
2662
0
5
4
23523
16881
0
4
16
1
1249
27
31
32234
1
3557
510
15
7
2507
0
8
0
23
4
2908
2
16
4437
6
0
8
9
5
5993
2
84
0
24
0
7
42
21
0
2
287
Page 2
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
AZ Sundance Power Plant 55522 CT01 , CT02, CT03, 0
CT04, CT05, CT06,
CT07, CT08, CT09, CT10
AZYumaAxis 1201 42
CAAESAIamitos 3151,2,3,4,5,6 9700
CA AES Huntington Beach 335 1 , 2, 3A, 4A 2796
CA AES Redondo Beach 356 5, 6, 7, 8, 1 7 1 372
CA Agua Mansa Power 55951 AMP- 1 0
CA Almond Power Plant 73151 0
CA Anaheim Combustion Turbine 76931 0
CA Blythe Energy 55295 1,2 0
CA Broadway 420 B3 365
CA Cabrillo Power I Encina Power Station 302 1 , 2, 3, 4, 5 6800
CA CalPeak Power - Border LLC 55510 GT-1, GT-2 0
CA CalPeak Power - El Cajon LLC 5551 2 GT-1 , GT-2 0
CA Cal Peak Power - Enterprise LLC 5551 3 GT-1 , GT-2 0
CA CalPeak Power - Panoche LLC 55508 GT-1 , GT-2 0
CA CalPeak Power - Vaca Dixon LLC 55499 GT-1 , GT-2 0
CA Calpine Gilroy Cogen, LP 10034 S-100 0
CA Calpine Sutler Energy Center 551 1 2 CT01 , CT02 0
CA Carson Cogeneration 7527 1,2 0
CA Carson Cogeneration Company 10169 D1 0
CA Chula Vista Power Plant 55540 1 A, 1 B 0
CA Coalinga Cogeneration Company 501311 0
CA Contra Costa Power Plant 228 9, 10 4850
CA Coolwater Generating Station 329 1 , 2, 31 , 32, 41 , 42 16
CA Cosumnes Power Plant 55970 2, 3 0
CA Creed Energy Center 55625 UNIT1 0
CA Delta Energy Center, LLC 55333 1,2,3 0
CA Donald Von Raesfeld 56026 PCT1 , PCT2 0
CA Dynegy South Bay, LLC 31 0 1 , 2, 3, 4 7047
CA El Centra 3893,4,2-2 1485
CAEISegundo 3303,4 1082
CA Elk Hills Power 55400 CTG-1 , CTG-2 0
CA Escondido Power Plant 55538 CT1 A, CT1 B 0
CA Etiwanda Generating Station 3313,4 1779
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
20 0 0 20
312 1 1 311
576 5 5 571
342 7 7 335
177 2 2 175
00 00
60 06
00 00
63 33
152 0 0 152
13 13 13 0
00 00
00 00
00 00
00 00
00 00
21 11
86 62
72 25
29 1 1 28
20 02
21 11
243 0 0 243
64 42
44 8 8 36
10 01
14 11 11 3
229 2 2 227
14 4 4 10
5993 1 1 5992
82 2 2 80
18 8 8 10
20 02
52 23
PageS
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
CA
CA
2007 He
Plant Allowances Acco
Plant Name Code Units Allocated of3/
Feather River Energy Center 55847 UNIT1 0
Fresno Cogeneration Partners, LP 10156 GEN1 0
CA Gilroy Energy Center, LLC 55810 S-3, S-4, S-5 0
CA
Gilroy Energy Center, LLC for King City 10294 2 0
CA Glenarm 422 GTS, GT4 0
CA Goose Haven Energy Center 55627 UNIT1 0
CA Grayson Power Plant 377 4, 5, 9 138
CA
CA
Hanford Energy Park Peaker 55698 HEP1 , HEP2 0
Harbor Generating Station 399 10, 11, 12, 13, 14, **10A, 2348
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
10 01
00 00
30 03
10 01
584 0 0 584
10 01
1094 1 1 1093
40 04
365 0 0 365
CA Haynes Generating Station
CA Henrietta Peaker Plant
CA High Desert Power Project
CA Humboldt Bay
CA Indigo Generation Facility
CA Kings River Conservation District Malaga
CA La Paloma Generating Plant
CA Lake
CA Lambie Energy Center
CA Larkspur Energy Faciity
CA Los Esteros Critical Energy Fac
CA Los Medanos Energy Center, LLC
CA Magnolia
CA Malburg Generating Station
CA Mandalay Generating Station
CA Metcalf Energy Center
CA Miramar Energy Facility
CA Morro Bay Power Plant, LLC
CA Moss Landing
CA Mountainview Power Company, LLC
CA NCPA Combustion Turbine Project #2
CA Olive
CA Ormond Beach Generating Station
CA Palomar Energy
CA Pastoria Energy Facility
**10B
4001,2,5,6,9,10 6193
55807 HPP1.HPP2 0
55518 CTG1, CTG2, CTG3 0
246 1, 2 382
55541 1, 2, 3 0
56239 GT-1, GT-2 0
55151 CTG-1, CTG-2, CTG-3, 0
CTG-4
7987 01 0
55626 UNIT1 0
555421,2 0
55748 CTG1, CTG2, CTG3, 0
CTG4
55217X724, X725 0
560461 0
56041 M1, M2 0
345 1, 2 2670
553931,2 0
56232 1 0
259 1, 2, 3, 4 8575
260 1 A, 2A, 3A, 4A, 6-1, 7-1 10567
3583-1,3-2,4-1,4-2 135
7449 NA1 0
601301,02 158
3501,2 9106
55985 CTG1, CTG2 0
55656 CT001, CT002, CT004 0
18066
4
11
579
0
0
30
16
1
5
4
10
9
41
4
9
2
9
38
43
23
92
5
10
14
10
0
9
44
0
0
15
0
0
2
0
8
2
2
2
7
0
2
19
14
0
0
3
8
11
10
0
9
44
0
0
15
0
0
2
0
8
2
2
2
7
0
2
19
14
0
0
3
8
11
18056
4
2
535
0
0
15
16
1
3
4
2
7
39
2
2
2
7
19
29
23
92
2
2
3
Page 4
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
CA Pittsburg Power Plant (CA) 271 5,6,7 1 0937
CA Potrero Power Plant 273 3-1 321
CA Redding Power Plant 7307 5 0
CA Ripon Generation Station 561 35 1 , 2 0
CA Riverside Energy Resource Center 561 43 1 , 2 0
CA Riverview Energy Center 55963 1 0
CA Roseville Energy Park 56298 CT001 , CT002 0
CA Sacramento Power Authority Cogen 7552 1 0
CA Salinas River Cogeneration Company 50865 1 0
CA Sargent Canyon Cogen Company 50864 1 0
CASCACogenll 75511A, 1B, 1C 0
CA Scattergood Generating Station 404 1,2,3 1 672
CA Sunrise Power Company 551 82 CTG1 , CTG2 0
CA Tracy Peaker 55933 TPP1 , TPP2 0
CA Valley Gen Station 408 5,6,7 1 003
CA Walnut Energy Center 56078 1,2 0
CA Wellhead Power Gates, LLC 55875 GT1 0
CA Wolfskill Energy Center 55855 UNIT1 0
CA Woodland Generation Station 7266 1,2 0
CA Yuba City Energy Center 1 0349 2 0
CO Arapahoe 465 3, 4 2576
CO Arapahoe Combustion Turbine 55200 CT5, CT6 0
CO Blue Spruce Energy Center 55645 CT-01 , CT-02 0
CO Brush 3 10682GT2 0
CO Brush 4 55209 GT4, GTS 0
CO Cameo 468 2 904
CO Cherokee 469 1 , 2, 3, 4 16272
CO Comanche (470) 470 1 , 2 1 461 2
CO Craig 6021C1.C2, C3 18665
CO Fort St. Vrain 61 12 2, 3, 4 0
CO Fountain Valley Combustion Turbine 55453 1 , 2, 3, 4, 5, 6 0
CO Frank Knutson Station 55505 BR1, BR2 0
CO Front Range Power Plant 55283 1,2 0
COHayden 525H1.H2 15293
CO Limon Generating Station 55504 L1.L2 0
CO Manchief Station 551 27 CT1 , CT2 0
CO Martin Drake 492 5, 6, 7 6398
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
500 0 0 500
82 26
66 1 1 65
20 0 0 20
00 00
10 01
21 0 0 21
10 3 37
21 11
21 11
21 2 2 19
5052 14 14 5038
10 8 82
80 08
14955 7 7 14948
10 4 46
00 00
10 01
195 1 1 194
10 01
3236 2963 2963 273
12 0 0 12
65 51
70 07
70 07
1797 1639 1639 158
25100 7082 7082 18018
16058 12605 12605 3453
3989 3799 3799 190
21 9 9 12
36 0 0 36
12 2 2 10
96 63
2855 2718 2718 137
11 1 1 10
62 24
10129 9129 9129 1000
PageS
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
CO Nucla 5271 1122
CO Pawnee 62481 14443
CO Rawhide Energy Station 6761 A, B, C, D, 101 1800
CO Ray D Nixon 8219 1 , 2, 3 4477
CO Rocky Mountain Energy Center 55835 1,2 0
CO Spindle Hill Energy Center 56445 CT-01 , CT-02 0
COValmont 4775 3165
CO Valmont Combustion Turbine Facility 55207 CT7, CT8 0
CO Zuni 478 1 , 2, 3 345
CT Alfred L Pierce Generating Station 6635 0
CT Bridgeport Energy 55042 BE1.BE2 0
CT Bridgeport Harbor Station 568 BHB1, BHB2, BHB3 18287
CT Capitol District Energy Center 50498 GT 0
CT Devon 5447,8,11,12,13,14 8340
CT Lake Road Generating Company 55149 LRG1, LRG2, LRG3 0
CT Middletown 5622,3,4 7518
CT Milford Power Company LLC 551 26 CT01 , CT02 0
CT Montville 546 5, 6 6883
CT New Haven Harbor 6156NHB1 13070
CT Norwalk Harbor Station 548 1 , 2 1 0599
CT Wallingford Energy 55517 CT01 , CT02, CT03, 0
CT04, CT05
DC Benning Generation Station 603 15, 16 1373
DE Delaware City Refinery 52193DCPP4 0
DE Edge Moor 593 3, 4, 5 1 631 6
DE Hay Road 71 53 5, 6, 7, "3 1 58
DE Indian River 594 1 , 2, 3, 4 25035
DE McKee Run 599 3 2585
DE NRG Energy Center Dover 10030 2, 3 0
DEVanSant 731 8 "11 138
DE Warren F. Sam Beasley Pwr Station 7962 1 0
FL Anclote 8048 1 , 2 27785
FL Arvah B Hopkins 688 1 , 2, HC3, HC4 5605
FL Auburndale Cogeneration Facility 54658 1,6 0
FL Bayside Power Station 7873 CT1 A, CT1 B, CT1 C, 0
CT2A, CT2B, CT2C,
CT2D
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
1266 1230 1230 36
17652 14126 14126 3526
5780 928 928 4852
4517 4043 4043 474
98 81
10 6 64
5550 788 788 4762
15 0 0 15
354 2 2 352
70 07
19 6 6 13
6050 2744 2744 3306
20 02
4171 0 0 4171
14 8 86
23489 513 513 22976
66 60
23879 127 127 23752
4764 815 815 3949
10103 560 560 9543
40 0 0 40
178 141 141 37
65 28 28 37
9180 9112 9112 68
26 7 7 19
24696 23471 23471 1225
370 98 98 272
10 0 0 10
277 0 0 277
51 14
36822 27039 27039 9783
1028 498 498 530
32 21
20 18 18 2
Page 6
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
FL Big Bend 645 BB01 , BB02, BB03, 44567
BB04
FL Brandy Branch 7846 1 , 2, 3 0
FL C D Mclntosh Jr Power Plant 6761,2,3,5 11867
FL Cane Island 7238 2, 3, "1 0
FL Cape Canaveral 609PCC1.PCC2 9188
FL Charles Larsen Memorial Power Plant 675 **8 972
FL Crist Electric Generating Plant 641 4, 5, 6, 7 25866
FL Crystal River 628 1 , 2, 4, 5 75640
FL Curtis H. Stanton Energy Center 564 1 , 2 11 294
FL Cutler 610 PCU5, PCU6 0
FLDebary 6046 "7, "8, "9, "10 2820
FL Deerhaven 663 B1 , B2, CT3 8369
FL Desoto County Generating Co, LLC 55422 CT1 , CT2 0
FL Fort Myers 612 PFM3A, PFM3B, 12649
FMCT2A, FMCT2B,
FMCT2C, FMCT2D,
FMCT2E, FMCT2F
FL Hardee Power Station 50949 CT2B 0
FL Henry D King 658 7, 8 89
FL Mines Energy Complex 7302 1 A, 1 B, 2A, 2B, 3A, 3B 0
FL Indian River (55318) 55318 1 , 2, 3 6408
FL Indian River (683) 683 **C, **D 639
FL Intercession City 8049 "7, "8, "9, "1 0, "1 1 , 2820
"12, "13, "14
FL J D Kennedy 666 7 2725
FL J R Kelly 664 CC1 58
FL Lansing Smith Generating Plant 643 1 , 2, 4, 5 14081
FL Lauderdale 613 4GT1 , 4GT2, 5GT1 , 5364
5GT2
FL Manatee 6042 PMT1, PMT2, MTCT3A, 26478
MTCT3B, MTCT3C,
MTCT3D
FL Martin 6043 PMR1 , PMR2, PMR8A, 17901
PMR8B, PMR8C,
PMR8D, HRSG3A,
HRSG3B, HRSG4A,
HRSG4B
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
12205 9903 9903 2302
175 4 4 171
33036 7473 7473 25563
36 4 4 32
16326 4296 4296 12030
3429 0 0 3429
89114 41182 41182 47932
120458 92321 92321 28137
24383 6468 6468 17915
50 05
8371 51 51 8320
10456 7949 7949 2507
71 16
26905 21 21 26884
39 0 0 39
59 0 0 59
448 16 16 432
950 914 914 36
4450 0 0 4450
4184 23 23 4161
60 0 0 60
173 1 1 172
37090 15203 15203 21887
7900 12 12 7888
46759 11815 11815 34944
28105 10573 10573 17532
Page 7
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
FL Midulla Generating Station 7380 1 , 2, 4A, 4B, 5A, 5B, 6A, 0
6B, 7A, 7B, 8A, 8B
FL Mulberry Cogeneration Facility 54426 1 0
FL Northside 667 3, 1A, 2A 23618
FL Oleander Power Project 55286 O-1 , O-2, O-3, 0-4 0
FL Orange Cogeneration Facility 54365 1,2 0
FL Orlando CoGen 54466 1 0
FL Osprey Energy Center 5541 2 CT1 , CT2 0
FLPLBartow 6341,2,3 11198
FL Polk 7242 "1 , "2, "3, "4, "5 0
FL Port Everglades 617 PPE1 , PPE2, PPE3, 16600
PPE4
FL Putnam 6246 HRSG11, HRSG12, 6424
HRSG21, HRSG22
FL Reedy Creek 7254 32432 60
FL Reliant Energy Osceola 551 92 OSC1 , OSC2, OSC3 0
FL Riviera 619 PRV3, PRV4 7214
FL S O Purdom 689 7, 8 443
FLSanford 620 PSN3, SNCT4A, 12922
SNCT4B, SNCT4C,
SNCT4D, SNCT5A,
SNCT5B, SNCT5C,
SNCT5D
FL Santa Rosa Energy Center 55242 CT-1 0
FL Scholz Electric Generating Plant 642 1,2 4010
FL Seminole (136) 136 1 , 2 36776
FL Shady Hills 55414 GT1 01, GT201, GT301 0
FL St. Johns River Power 207 1 , 2 22960
FL Stanton A 55821 25, 26 0
FL Stock Island 6584 CT4 2572
FL Suwannee River 638 1 , 2, 3 1 156
FL Tiger Bay 7699 1 0
FL Tom G Smith 673 S-3 89
FL Turkey Point 621 PTP1 , PTP2, TPCT5A, 1 1 783
TPCT5B, TPCT5C,
TPCT5D
FL University of Florida 7345 1 0
FL Vandolah Power Project 55415 GT1 01, GT201, GT301, 0
GT401
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
159 2 2 157
11 10
5849 4216 4216 1633
14 2 2 12
32 21
32 21
65 51
14931 12430 12430 2501
1075 1071 1071 4
28179 10252 10252 17927
13320 4 4 13316
477 0 0 477
31 12
11352 5685 5685 5667
24 4 4 20
36253 326 326 35927
10 01
36850 4983 4983 31867
55560 20335 20335 35225
17 12 12 5
16677 13657 13657 3020
19 4 4 15
216 2 2 214
2256 884 884 1372
98 2 2 96
570 0 0 570
20956 7904 7904 13052
16 1 1 15
103 17 17 86
PageS
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
FL Vero Beach Municipal 693 3, 4, **5 739
GA Baconton 55304 CT1 , CT4, CT5, CT6 0
GA Bowen 703 1 BLR, 2BLR, 3BLR, 1 09781
4BLR
GA Chattahoochee Energy Facility 79178A, 8B 0
GA Dahlberg (Jackson County) 7765 1,2,3, 4, 5, 6, 7, 8, 9, 1 0 0
GA Doyle Generating Facility 55244 CTG-1, CTG-2, CTG-3, 0
CTG-4, CTG-5
GA Effingham County Power, LLC 554061,2 0
GA Hammond 708 1 , 2, 3, 4 27835
GA Harllee Branch 709 1 , 2, 3, 4 53485
GA Hartwell Energy Facility 70454 MAG1 , MAG2 0
GA Heard County Power, LLC 55141 CT1 , CT2, CT3 0
GA Jack McDonough 71 0 MB1 , MB2 1 7469
GA KGen Sandersville LLC 55672 CT1 , CT2, CT3, CT4, 0
CT5, CT6, CT7, CT8
GA Kraft 733 1,2,3,4 6440
GA Mclntosh (61 24) 61 24 1 , CT1 , CT2, CT3, CT4, 5556
CT5, CT6, CT7, CT8
GA Mclntosh Combined Cycle Facility 56150 10A, 10B, 11A, 11B 0
GAMcManus 7151,2 2123
GA Mid-Georgia Cogeneration 55040 1,2 0
GA Mitchell (GA) 727 3 5463
GA MPC Generating, LLC 7764 1,2 0
GA Murray Energy Facility 55382 CCCT1 , CCCT2, CCCT3, 0
CCCT4
GA Robins 7348 CT1 , CT2 0
GA Scherer 6257 1,2,3,4 84823
GA Sewell Creek Energy 78131,2,3,4 0
GA Smarr Energy Facility 7829 1,2 0
GA Sowega Power Project 7768 CT2, CT3 0
GA Talbot Energy Facility 791 6 1 , 2, 3, 4, 5, 6 0
GA Tenaska Georgia Generating Station 55061 CT1 , CT2, CT3, CT4, 0
CT5, CT6
GA Walton County Power, LLC 551 28 T1 , T2, T3 0
GA Wansley (6052) 6052 1 , 2, 6A, 6B, 7A, 7B 58728
GA Wansley (7946) 7946 CT9A, CT9B 0
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
1818 0 0 1818
20 0 0 20
211841 196841 196841 15000
63 33
13 1 1 12
50 0 0 50
53 32
105919 47808 47808 58111
99218 98363 98363 855
40 04
00 00
29176 28538 28538 638
20 02
9357 7705 7705 1652
6423 3414 3414 3009
20 12 12 8
9520 338 338 9182
11 0 0 11
6536 4919 4919 1617
00 00
54 41
20 02
118921 76456 76456 42465
80 08
40 04
10 0 0 10
40 1 1 39
40 04
30 03
97755 93850 93850 3905
22 20
Page 9
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
GA Washington County Power, LLC 55332 T1 , T2, T3, T4 0
GA West Georgia Generating Company 55267 1 , 2, 3, 4 0
GA Yates 728 Y1 BR, Y2BR, Y3BR, 38220
Y4BR, Y5BR, Y6BR,
Y7BR
lAAmes 11227,8 2237
IA Burlington (IA) 1 104 1 4499
IA Dayton Avenue Substation 6463 GT2 0
lADubuque 10461,5,6 1425
IA Earl F Wisdom 12171,2 379
IA Emery Station 803111,12 0
IA Exira Station 56013 U-1 , U-2, U-3 0
IA Fair Station 12182 5575
IA George Neal North 1 091 1,2,3 23688
IA George Neal South 7343 4 15144
IA Greater Des Moines Energy Center 7985 1,2 0
IA Lansing 10471,2,3,4 5107
IA Lime Creek 71 55 "1, "2 510
IA Louisa 6664101 15593
IA Milton L Kapp 10482 5795
IA Muscatine 11678,9 3389
lAOttumwa 62541 19095
lAPella 11756,7,8 1803
IA Pleasant Hill Energy Center 71453 0
IA Prairie Creek 1 073 3, 4 41 59
IA Riverside (1081) 10819 1745
IA Sixth Street 1 058 2, 3,4,5 1 530
IA Streeter Station 11317 554
IA Sutherland 1 077 1 , 2, 3 2766
IA Walter Scott Jr. Energy Center 1 082 1 , 2, 3, 4 1 871 7
ID Bennett Mountain Power Project 55733 CT01 0
ID Evander Andrews Power Complex 7953 CT2, CT3 0
ID Rathdrum Combustion Turbine Project 7456 1,2 0
ID Rathdrum Power, LLC 55179 CTGEN1 0
IL Baldwin Energy Complex 889 1 , 2, 3 55620
IL Calumet Energy Team 55296 "1, "2 0
ILCoffeen 86101,02 20466
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
40 04
50 05
77478 77219 77219 259
5271 1082 1082 4189
4870 4831 4831 39
26 0 0 26
1440 1396 1396 44
2213 973 973 1240
17 4 4 13
110 0 0 110
7038 2519 2519 4519
30476 23500 23500 6976
19271 17269 17269 2002
30 2 2 28
6623 6604 6604 19
160 117 117 43
16369 11726 11726 4643
4055 4029 4029 26
10116 3447 3447 6669
19118 13862 13862 5256
7639 348 348 7291
21 0 0 21
3897 3863 3863 34
3490 2993 2993 497
1149 1126 1126 23
1993 1048 1048 945
9831 9767 9767 64
22277 19797 19797 2480
100 1 1 99
400 0 0 400
00 00
53 32
39917 26329 26329 13588
10 0 0 10
26835 24250 24250 2585
Page 10
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
IL Cordova Energy Company 55188 1 , 2 0
I L Crawford 8677,8 17086
IL Crete Energy Park 55253 GT1 , GT2, GTS, GT4 0
IL Dallman 963 31, 32, 33 8152
I L Duck Creek 60161 11201
IL E D Edwards 856 1 , 2, 3 18940
IL Elgin Energy Center 55438 CT01 , CT02, CT03, CT04 0
IL Elwood Energy Facility 551 99 1 , 2, 3, 4, 5, 6, 7, 8, 9 0
ILFisk 88619 10032
IL Freedom Power Project 7842 CT1 0
IL Geneva Energy, LLC 55174 1 0
IL Gibson City Power Plant 55201 GCTG1 , GCTG2 0
IL Goose Creek Power Plant 55496 CT-01 , CT-02, CT-03, CT- 0
04, CT-05, CT-06
IL Grand Tower 862 CT01 , CT02 3030
IL Havana 891 1 , 2, 3, 4, 5, 6, 7, 8, 9 9095
IL Hennepin Power Station 892 1 , 2 9958
IL Holland Energy Facility 55334 CTG1 , CTG2 0
IL Hutsonville 863 05, 06 4525
IL Interstate 7425 1 0
IL Joliet 29 384 71 , 72, 81 , 82 2861 1
IL Joliet 9 874 5 8676
IL Joppa Steam 887 1 , 2, 3, 4, 5, 6 28992
IL Kendall Energy Facility 55131 GTG-1, GTG-2, GTG-3, 0
GTG-4
IL Kincaid Station 876 1 , 2 28578
IL Kinmundy Power Plant 55204 KCTG1 , KCTG2 0
IL Lakeside 964 7, 8 4303
IL Lee Energy Facility 55236 CT1 , CT2, CT3, CT4, 0
CT5, CT6, CT7, CT8
IL Lincoln Generating Facility 55222 CTG-1 , CTG-2, CTG-3, 0
CTG-4, CTG-5, CTG-6,
CTG-7, CTG-8
I L Marion 9764,5,6,123 13361
IL MEPI Gt Facility 7858 1 , 2, 3, 4, 5 0
IL Meredosia 864 01 , 02, 03, 04, 05, 06 7192
I L Newton 60171,2 29557
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
14 2 2 12
10215 8882 8882 1333
00 00
8152 3464 3464 4688
13132 548 548 12584
26775 14536 14536 12239
20 0 0 20
225 0 0 225
5698 4954 4954 744
00 00
42 22
25 0 0 25
12 0 0 12
3182 2 2 3180
12839 7319 7319 5520
11586 4888 4888 6698
22 20
7550 2953 2953 4597
50 05
17467 15189 15189 2278
5839 5077 5077 762
31395 26282 26282 5113
15 4 4 11
17183 17164 17164 19
10 0 0 10
11266 10436 10436 830
30 03
16 0 0 16
15386 4898 4898 10488
25 0 0 25
18385 11389 11389 6996
26094 23497 23497 2597
Page 11
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
IL NRG Rockford Energy Center 552380001,0002 0 53 0 0 53
IL NRG Rockford II Energy Center 55936 U1 010 01
IL Pinckneyville Power Plant 55202 CT01 , CT02, CT03, 0 40 0 0 40
IL Powerton
IL PPL University Park Power Project
IL Raccoon Creek Power Plant
IL Reliant Energy - Aurora
CT04, CT05, CT06,
CT07, CT08
879 51, 52, 61, 62 42393
55640 CT01, CT02, CT03, 0
CT04, CT05, CT06,
CT07, CT08, CT09,
CT10, CT11.CT12
55417 CT-01, CT-02, CT-03, CT- 0
04
55279 AGS01, AGS02, AGS03, 0
AGS04, AGS05, AGS06,
AGS07, AGS08, AGS09,
AGS10
23624
24
8
10
20542
0
20542
0
3082
24
8
10
IL Reliant Energy Shelby County
IL Rocky Road Power, LLC
IL Southeast Chicago Energy Project
IL Tilton Power Station
IL University Park Energy
IL Venice
IL Vermilion Power Station
IL Waukegan
IL Will County
IL Wood River Power Station
IL Zion Energy Center
IN A B Brown Generating Station
IN Alcoa Allowance Management Inc
IN Anderson
IN Bailly Generating Station
IN C. C. Perry K Steam Plant
55237 SCE1.SCE2, SCE3,
SCE4, SCE5, SCE6,
SCE7, SCE8
55109T1.T2, T3, T4
55281 CTG5, CTG6, CTG7,
CTG8, CTG9, CTG10,
CTG11.CTG12
7760 1, 2, 3, 4
55250 UP1, UP2, UPS, UP4,
UPS, UP6, UP7, UPS,
UP9, UP10, UP11, UP12
913CT03, CT04, CT05,
CT2A, CT2B
897 1,2
8837,8, 17
884 1, 2, 3, 4
898 1, 2, 3, 4, 5
55392 CT-1, CT-2, CT-3
61371,2,3,4
6705 1, 2, 3, 4
7336 ACT1, ACT2, ACTS
995 7, 8
99211
0
0
0
0
0
100
12
0
0
0
0
0
62
6666
19158
30971
11749
0
10527
99281
0
11683
1796
144
9744
16091
19909
13312
1
11074
79614
13
5193
600
0
2022
13993
17311
6462
0
8745
78825
0
4314
22
533
0
2022
13993
17311
6462
0
8745
78828
0
4314
555
0
100
12
0
144
7722
2098
2598
6850
1
2329
786
13
879
45
Page 12
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
IN Cayuga
IN Clifty Creek
IN Dean H Mitchell Generating Station
IN Edwardsport
IN F B Culley Generating Station
IN Frank E Ratts
IN Georgetown Substation
IN Gibson
IN Harding Street Station (EW Stout)
IN Henry County Generating Station
IN Hoosier Energy Lawrence Co Station
IN IPL Eagle Valley Generating Station
IN Lawrenceburg Energy Facility
IN Merom
IN Michigan City Generating Station
IN Montpelier Electric Gen Station
IN Noblesville
IN Petersburg
IN R Gallagher
IN R M Schahfer Generating Station
IN Richmond (IN)
IN Rockport
IN State Line Generating Station (IN)
IN Sugar Creek Power Company, LLC
IN Tanners Creek
IN Vermillion Energy Facility
IN Wabash River Gen Station
IN Wheatland Generating Facility LLC
IN Whitewater Valley
IN Whiting Clean Energy, Inc.
IN Worthington Generation
KS Chanute 2
KS Cimarron River
1001 1,2,4 30203
983 1, 2, 3, 4, 5, 6 50488
9964,5,6,11 11762
10046-1,7-1,7-2,8-1 1076
10122,3 9904
10431SG1.2SG1 7253
7759 GT1, GT2, GTS, GT4 0
61131,2,3,4,5 88393
990 9, 10, 50, 60, 70, GT4, 13915
GTS, GT6
7763 1, 2, 3 0
7948 1, 2, 3, 4, 5, 6 0
991 1, 2, 3, 4, 5, 6 3858
55502 1, 2, 3, 4 0
62131SG1.2SG1 29748
9974,5,6,12 12990
55229 G1CT1, G1CT2, G2CT1, 0
G2CT2, G3CT1, G3CT2,
G4CT1, G4CT2
1007CT3, CT4, CT5 160
994 1, 2, 3, 4 54094
10081,2,3,4 11795
608514,15,17,18 31463
7335 RCT1, RCT2 0
6166MB1.MB2 66006
9813,4 11650
55364CT11.CT12 0
988U1, U2, U3, U4 20359
55111 1,2,3,4,5,6,7,8 0
10101,2,3,4,5,6 13140
55224 EU-01, EU-02, EU-03, 0
EU-04
10401,2 8932
55259 CT1, CT2 0
551481,2,3,4 0
126814 0
12301 12
95323
71884
0
6497
3715
23375
13
76593
36339
6
0
16502
38
22419
13502
0
46
23000
62992
39813
9
63086
18200
2
34846
4
63901
8
9661
89
4
0
18
90783
66884
0
6188
3676
21286
0
72947
36201
0
0
16101
4
11294
13492
0
0
22500
59992
39803
0
48833
9333
0
33829
0
60858
0
8614
4
0
0
1
90783
66884
0
6188
3676
21286
0
72947
36201
0
0
16101
4
11294
13492
0
0
22500
59992
39803
0
48833
9333
0
33829
0
60858
0
8614
4
0
0
1
4540
5000
0
309
39
2089
13
3646
138
6
0
401
34
11125
10
0
46
500
3000
10
9
14253
8867
2
1017
4
3043
8
1047
85
4
0
17
Page 13
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
KS Coffeyville 12714 11
KS East 12th Street 70134 10
KS Fort Dodge aka Judson Large 1233 4 39
KS Garden City 1336S-2 0
KS Gordon Evans Energy Center 1240 1 , 2, E1 CT, E2CT, E3CT 89
KS Great Bend Station aka Arthur Mullergren 12353 1
KS Holcomb 108SGU1 4011
KS Hutchinson Energy Center 1248 1 , 2, 3, 4 18
KS Jeffrey Energy Center 6068 1 , 2, 3 55835
KS Kaw 12941,2,3 1922
KS La Cygne 1241 1,2 33007
KS Lawrence Energy Center 12503,4,5 9346
KS McPherson 3 75151 0
KS Murray Gill Energy Center 1 242 1 , 2, 3, 4 118
KS Nearman Creek 6064 N1 , CT4 6930
KS Neosho Energy Center 1243 7 13
KS Osawatomie Generating Station 7928 1 0
KS Quindaro 12951,2 4111
KSRiverton 123912,39,40 2803
KS Tecumseh Energy Center 12529,10 6172
KS West Gardner Generating Station 7929 1 , 2, 3, 4 0
KY Big Sandy 1353 BSU1, BSU2 26148
KY Bluegrass Generation Company, LLC 55164 GTG1, GTG2, GTG3 0
KY Cane Run 1363 4, 5, 6 14402
KYColeman 1381C1.C2, C3 15714
KY D B Wilson 6823 W1 12465
KY E W Brown 1 355 1 , 2, 3, 5, 6, 7, 8, 9, 1 0, 201 27
11
KY East Bend 60182 18322
KY Elmer Smith 1374 1 , 2 9018
KY Ghent 1356 1 , 2, 3, 4 52666
KY Green River 1357 4, 5 7923
KY H L Spurlock 6041 1 , 2, 3 26415
KY Henderson I 13726 810
KY HMP&L Station 2 1382H1.H2 11694
KY John S. Cooper 1 384 1 , 2 981 8
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
63 0 0 63
76 0 0 76
48 2 2 46
60 0 0 60
31 12
81 17
6836 1076 1076 5760
10 01
76956 65774 65774 11182
40 04
23188 23055 23055 133
3062 2538 2538 524
114 0 0 114
40 04
14482 7328 7328 7154
10 01
30 03
12634 4607 4607 8027
8057 6987 6987 1070
5303 4402 4402 901
12 0 0 12
48155 46751 46751 1404
00 00
16064 14879 14879 1185
4583 2992 2992 1591
10941 9499 9499 1442
50451 49824 49824 627
2575 2452 2452 123
3571 3123 3123 448
47424 45228 45228 2196
32641 22060 22060 10581
41344 36943 36943 4401
10020 185 185 9835
11694 5035 5035 6659
22641 19821 19821 2820
Page 14
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
KY Marshall 55232 CT1, CT2, CT3, CT4, 0
CT5, CT6, CT7, CT8
KY Mill Creek 1 364 1 , 2, 3, 4 40828
KY Paddy's Run 136613 0
KY Paradise 1 378 1 , 2, 3 48638
KY R D Green 6639 G1 , G2 1 1 672
KY Riverside Generating Company 55198 GTG1 01, GTG201, 0
GTG301 , GTG401 ,
GTG501
KY Robert Reid 1383R1 942
KY Shawnee 1 379 1 , 2, 3, 4, 5, 6, 7, 8, 9, 1 0 37929
KY Smith Generating Facility 54 SCT1 , SCT2, SCT3, 0
SCT4, SCT5, SCT6,
SCT7
KY Trimble County 6071 1,5,6, 7, 8, 9, 1 0 9634
KY Tyrone 1361 1,2,3,4,5 1713
KY William C. Dale 1 385 1 , 2, 3, 4 3831
LA A B Paterson 1 407 3, 4 15
LA Acadia Power Station 551 73 CT1 , CT2, CT3, CT4 0
LA Arsenal Hill Power Plant 1416 5A 30
LA Bayou Cove Peaking Power Plant 55433 CTG-1, CTG-2, CTG-3, 0
CTG-4
LA Big Cajun 1 1 464 1 B1 , 1 B2, CTG1 , CTG2 54
LA Big Cajun 2 6055 2B1 , 2B2, 2B3 44165
LA Calcasieu Plant 551 65 GTG1 , GTG2 0
LA Carville Energy Center 55404 COG01 , COG02 0
LA D G Hunter 6558 3, 4 32
LADocBonin 14431,2,3 81
LA Dolet Hills Power Station 51 1 20501
LA Evangeline Power Station (Coughlin) 1 396 6-1 , 7-1 , 7-2 1 74
LA Hargis-Hebert Electric Generating Static 56283 U-1 , U-2 0
LAHouma 143915,16 24
LA Lieberman Power Plant 14173,4 1 58
LA Little Gypsy 1 402 1 , 2, 3 1 1 66
LA Louisiana 1 1 391 1 A, 2A, 3A, 4A, 5A 120
LA Louisiana 2 139210,11,12 0
LAMichoud 14091,2,3 668
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
52 0 0 52
129702 27896 27896 101806
50 05
62075 34651 34651 27424
4212 2705 2705 1507
00 00
8257 6736 6736 1521
41403 36305 36305 5098
1357 2 2 1355
28578 1048 1048 27530
4288 3483 3483 805
9081 8215 8215 866
90 0 0 90
43 31
215 0 0 215
40 04
56 0 0 56
39186 37228 37228 1958
00 00
65 51
230 0 0 230
639 0 0 639
21646 11509 11509 10137
1330 5 5 1325
00 00
192 0 0 192
984 7 7 977
8957 24 24 8933
388 80 80 308
60 06
4006 223 223 3783
Page 15
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
LA Monroe 144811,12 58
LA Morgan City Electrical Gen Facility 14494 5
LA Natchitoches 145010 0
LA Ninemile Point 14031,2,3,4,5 1891
LA Perryville Power Station 55620 1-1,1 -2, 2-1 0
LA Plaquemine Cogen Facility 55419 500, 600, 700, 800 0
LA Quachita Power, LLC 55467 CTGEN1 , CTGEN2, 0
CTGEN3
LA R S Cogen 551 1 7 RS-5, RS-6 0
LA R S Nelson 1 393 3, 4, 6 1 9794
LA Rodemacher Power Station (61 90) 61 90 1 , 2 221 58
LARuston 14582,3 9
LA Sterlington 1404 10, 7C, 7AB 246
LA T J Labbe Electric Generating Station 561 08 U-1 , U-2 0
LA Taft Cogeneration Facility 55089 CT1 , CT2, CT3 0
LA Teche Power Station 1400 2, 3 473
LA Waterford 1 & 2 8056 1 , 2 8089
LA Willow Glen 1394 1 , 2, 3, 4, 5 967
MA ANP Bellingham Energy Project 5521 11,2 0
MA ANP Blackstone Energy Company 5521 21,2 0
MA Bellingham 103071,2 0
MA Berkshire Power 55041 1 0
MA Brayton Point 1 61 9 1 , 2, 3, 4 481 56
MA Canal Station 1 599 1 , 2 31 234
MA Cleary Flood 16828,9 2822
MA Dartmouth Power 52026 1 0
MA Dighton 55026 1 0
MA Fore River Station 5531 711,12 0
MA Indeck-Pepperell 10522CC1 0
MA Kendall Square 1595 1 , 2, 3, 4 828
MA Lowell Cogeneration Company 10802 001 0
MA Masspower 1 0726 1,2 0
MA Millennium Power Partners 55079 1 0
MA Montgomery L'Energia Power Partners LP 54586 1 0
MA Mount Tom 16061 5611
MA Mystic 1 588 4, 5, 6, 7, 81 , 82, 93, 94 2601 9
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
464 0 0 464
40 0 0 40
10 01
14545 20 20 14525
34 6 6 28
20 8 8 12
53 32
14 8 86
39400 14553 14553 24847
50740 12904 12904 37836
37 0 0 37
1926 0 0 1926
00 00
289 3 3 286
1396 3 3 1393
32850 1404 1404 31446
4110 56 56 4054
66 60
66 60
21 11
22 20
32427 30781 30781 1646
6955 6675 6675 280
822 47 47 775
11 10
23 1 1 22
19 8 8 11
14 0 0 14
39 9 9 30
40 04
42 22
94 45
60 06
7739 4858 4858 2881
15483 1941 1941 13542
Page 16
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
MA New Boston 15891 12482
MA Salem Harbor 1 626 1 , 2, 3, 4 24779
MA Somerset 16138 6750
MA West Springfield 1 642 3, CTG1 , CTG2 3746
MD Brandon Shores 602 1 , 2 26305
MDCP Crane 15521,2 8392
MD Herbert A Wagner 1 554 1 , 2, 3, 4 1 2491
MD Mirant Chalk Point 1 571 1 , 2, 3, 4, "GTS, **GT4, 37726
"GTS, "GT6
MD Mirant Dickerson 1 572 1 , 2, 3, GT2, GTS 1 9358
MD Mirant Morgantown 15731,2 33121
MD Panda Brandywine 548321,2 0
MDPerryman 1556 "51 1131
MD R. Paul Smith Power Station 1 570 9, 1 1 2948
MD Riverside 15594 1463
MD Rock Springs Generating Facility 7835 1 , 2, 3, 4 0
MD Vienna 15648 3645
ME Androscoggin Energy 55031 CT01 , CT02, CT03 0
ME Bucksport Clean Energy 50243 GEN4 0
ME Maine Independence Station 55068 1,2 0
ME Mason Steam 14963,4,5 4
ME Rumford Power 55100 1 0
ME Westbrook Energy Center 55294 1,2 0
ME William F Wyman 15071,2,3,4 11540
Ml 48th Street Peaking Station 7258 9, "7, "8 596
MIBCCobb 16951,2,3,4,5 12862
Ml Belle River 6034 1 , 2, CTG1 21 , CTG1 22, 37274
CTG131
Ml Conners Creek 1726 15, 16, 17, 18 15951
Ml Dan E Karn 1 702 1 , 2, 3, 4 1 8346
Ml Dearborn Industrial Generation 55088 GTP1, GT2100, GT3100 0
Ml Del ray 1728 CTG111, CTG121 40
Ml DTE East China 55718 1 , 2, 3, 4 0
Ml Eckert Station 1 831 1 , 2, 3, 4, 5, 6 1 1 21 1
Ml Endicott Generating 42591 1810
Ml Erickson 18321 6646
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
50 0 0 50
7375 6444 6444 931
4699 2710 2710 1989
1968 366 366 1602
42417 42041 42041 376
30937 30631 30631 306
21192 20983 20983 209
47329 46374 46374 955
34517 33843 33843 674
94943 93069 93069 1874
65 51
43 31
5946 5536 5536 410
00 00
20 0 0 20
415 395 395 20
43 31
58 4 4 54
34 4 4 30
23 0 0 23
17 1 1 16
65 51
3117 1654 1654 1463
1635 0 0 1635
11132 10914 10914 218
67077 23193 23193 43884
20727 0 0 20727
17867 17517 17517 350
30 03
256 0 0 256
00 00
7466 5944 5944 1522
2880 1037 1037 1843
3963 3431 3431 532
Page 17
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
Greenwood
Ml Harbor Beach
Ml J BSims
MIJ C Weadock
MIJ H Campbell
MIJ R Whiting
Ml Jackson Ml Facility
Ml James De Young
Ml Kalamazoo River Generating Station
Ml Kalkaska Ct Project #1
Ml Livingston Generating Station
Ml Marysville
Ml Michigan Power Limited Partnership
Ml Mistersky
Ml Monroe
Ml New Covert Generating Project
Ml Presque Isle
Ml Renaissance Power
Ml River Rouge
Ml Shiras
Ml St. Clair
Ml Sumpter Plant
Ml Trenton Channel
Ml Wyandotte
Ml Zeeland Generating Station
MN Allen S King
MN Black Dog
MN Blue Lake Generating Plant
MN Boswell Energy Center
MN Cambridge Station
MN Cascade Creek
MN Cottage Grove Cogeneration
MN Faribault Energy Park
MN Fibrominn Biomass Power Plant
MN Fox Lake
60351,CTG111,CTG112, 539 697 637
CTG121
1731 1 3520 781 556
18253 1484 1238 740
17207,8 9436 9123 8944
17101,2,3 45264 57175 29809
17231,2,3 11374 10366 10163
55270 7EA, LM1, LM2, LM3, 0 5 1
LM4, LM5, LM6
18305 1048 2040 785
55101 1 010
7984 1 A, 1B 0 00
551021,2,3,4 0 1 0
17329,10,11,12 5274 3503 0
549151 0 12 2
18225,6,7 1179 9411 0
17331,2,3,4 97171 126393 126393
55297001,002,003 0 53
17693,4,5,6,7,8,9 16850 18541 14235
55402 CT1, CT2, CT3, CT4 0 40
17401,2,3 15505 18170 14597
18433 500 2229 94
17431,2,3,4,6,7 34931 38579 38576
79721,2,3,4 0 20 0
1745 16, 17, 18, 19,9A 22827 28579 28579
18665,7,8 1913 4351 1861
55087 CC1, CC2, CCS, CC4 0 82
19151 15628 19761 2549
19043,4,5 11928 58923 3460
80277,8 0 20 0
18931,2,3,4 23817 27640 21579
20382 0 00
6058CT2, CT3 0 104 0
5501001 0 52
56164EU006 0 32
55867 BLR-1 0 154 154
18883 2069 359 323
637
556
740
8944
29809
10163
1
785
0
0
0
0
2
0
126393
3
14235
0
14597
94
38576
0
28579
1861
2
2549
3460
0
21579
0
0
2
2
154
323
60
225
498
179
27366
203
4
1255
1
0
1
3503
10
9411
0
2
4306
4
3573
2135
3
20
0
2490
6
17212
55463
20
6061
0
104
3
1
0
36
Page 18
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
MN Hibbard Energy Center 1897 3, 4 2081
MN High Bridge 19123,4,5,6 7622
MN Hoot Lake 19432,3 3220
MN Hutchinson - Plant 2 6358 1 0
MN Lakefield Junction Generating 7925 CT01 , CT02, CT03, 0
CT04, CT05, CT06
MN Laskin Energy Center 1891 1,2 3341
MN Mankato Energy Center 56104CT-2 0
MN Minnesota River Station 7844 U001 0
MN Minnesota Valley 19184 938
MN Northeast Station 1961 NEPP 1052
MN Pleasant Valley Station 784311,12,13 0
MN Riverside (1 927) 1 927 6, 7, 8 9483
MN Sherburne County 6090 1 , 2, 3 39231
MN Silver Lake 20084 3133
MN Solway Plant 7947 1 0
MN Taconite Harbor Energy Center 1 0075 1,2,3 0
MO Asbury 2076 1 6975
MO Audrain Power Plant 55234 CT1 , CT2, CT3, CT4, 0
CT5, CT6, CT7, CT8
MO Blue Valley 21323 4670
MO Chamois Power Plant 21692 5457
MO Columbia 21236,7,8 4659
MO Columbia Energy Center (MO) 55447 CT01 , CT02, CT03, CT04 0
MO Dogwood Energy Facility 55178 CT-1, CT-2 0
MO Empire District Elec Co Energy Ctr 6223 3A, 3B, 4A, 4B 557
MO Essex Power Plant 7749 1 0
MO Hawthorn 2079 6, 7, 8, 9, 5A 12773
MO Holden Power Plant 7848 1 , 2, 3 0
MO latan 6065 1 16208
MO James River 2161 3, 4, 5, **GT2 12039
MO Labadie 21 03 1 , 2, 3, 4 66987
MO Lake Road 20986 1239
MO McCartney Generating Station 7903 MGS1A, MGS1B, 0
MGS2A, MGS2B
MO Meramec 21 04 1 , 2, 3, 4 1 8756
MO Montrose 2080 1,2,3 1 1 073
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
6663 354 354 6309
43482 2096 2096 41386
5743 3574 3574 2169
80 08
59 0 0 59
3341 1339 1339 2002
11 10 10 1
00 00
3277 0 0 3277
4203 1158 1158 3045
21 4 4 17
14269 12972 12972 1297
81668 25494 25494 56174
4986 1837 1837 3149
90 09
5596 5062 5062 534
32330 9871 9871 22459
80 08
4966 3080 3080 1886
1115 1110 1110 5
4659 1116 1116 3543
20 0 0 20
10 2 28
36 0 0 36
10 0 0 10
1988 1923 1923 65
98 0 0 98
15084 14290 14290 794
11987 3604 3604 8383
60345 58325 58325 2020
4333 3003 3003 1330
40 0 0 40
24307 22767 22767 1540
14207 14136 14136 71
Page 19
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
MO New Madrid Power Plant 21671,2 26187 14302 14292 14292 10
MO Nodaway Power Plant 7754 1,2 0 20 0 0 20
MO Peno Creek Energy Center 7964 CT1A, CT1B, CT2A, 0 40 0 0 40
MO Rush Island
MO Sibley
MO Sikeston
MO Sioux
MO South Harper Peaking Facility
MO Southwest
MO St. Francis Power Plant
MO State Line (MO)
MO Thomas Hill Energy Center
MS Attala Generating Plant
MS Batesville Generation Facility
MS Baxter Wilson
MS BTEC New Albany LLC
MS BTEC Southaven LLC
MS Caledonia
MS Chevron Cogenerating Station
MS Choctaw Gas Generation, LLC
MS Crossroads Energy Center (CPU)
MS Daniel Electric Generating Plant
MS Delta
MS Gerald Andrus
MS Kemper County
MS KGen Hinds LLC
MS Magnolia Facility
MS Moselle Generating Plant
MS Natchez
MS R D Morrow Senior Generating Plant
CT2B, CT3A, CT3B,
CT4A, CT4B
61551,2
2094 1, 2, 3
67681
21071,2
56151 1,2,3
61951
7604 1, 2
7296 1,2-1, 2-2
2168MB1, MB2, MBS
55220 A01, A02
55063 1, 2, 3
2050 1, 2
13213 AA-001, AA-002, AA-003,
AA-004, AA-005, AA-006
55219 S01, S02, SOS, S04, SOS,
S06, S07, SOS
55197 AA-001, AA-002, AA-003
20475
55694 AA-001, AA-002
55395 CT01, CT02, CT03, CT04
6073 1, 2, 3A, 3B, 4A, 4B
2051 1, 2
80541
7960 KCT1, KCT2, KCT3,
KCT4
55218H01.H02
55451 CTG-1, CTG-2, CTG-3
2070 1, 2, 3, 5, "4
20521
6061 1, 2
30612
8791
6791
20315
0
4184
0
0
30110
0
0
3924
0
0
0
0
0
0
25505
76
3282
0
0
0
1035
2
10054
23913
20884
8230
49145
3
4236
46
230
15214
20
13
7480
8
8
50
20
6
8
33764
183
4529
190
4
18
1146
16
13127
22462
11796
7002
46988
0
4229
2
5
15199
4
5
478
0
0
5
9
2
0
32135
0
1736
0
2
6
1
0
10429
22462
11796
7002
46988
0
4229
2
5
15199
4
5
478
0
0
5
9
2
0
32135
0
1736
0
2
6
1
0
10429
1451
9088
1228
2157
3
7
44
225
15
16
8
7002
8
8
45
11
4
8
1629
183
2793
190
2
12
1145
16
2698
Page 20
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
MS Red Hills Generation Facility 55076 AA001 , AA002 0
MS Reliant Energy Choctaw County Gen 55706 CTG1 , CTG2, CTG3 0
MS Rex Brown 2053 3, 4, 1 A, 1 B 21 2
MS Silver Creek Generating Plant 7988 1 , 2, 3 0
MS Southaven Power, LLC 55269 AA-001 , AA-002, AA-003 0
MS Sweatt Electric Generating Plant 2048 1,2 164
MS Sylvarena Generating Plant 7989 1 , 2, 3 0
MS Warren Peaking Power Facility 55303 AA-001 , AA-002, AA-003, 0
AA-004
MS Watson Electric Generating Plant 2049 1 , 2, 3, 4, 5 23565
MT Colstrip 6076 1 , 2, 3, 4 23051
MT Glendive Generating Station 2176GT-2 0
MT Hardin 55749 U1 0
MTJECorette 21872 5062
MT Lewis & Clark 6089 B1 1 444
NC Asheville 2706 1,2,3,4 1 1 883
NC Belews Creek 8042 1 , 2 63471
NC Buck 2720 5, 6, 7, 8, 9 7871
NC Cape Fear 2708 5, 6 8493
NC Cliffside 2721 1 , 2, 3, 4, 5 1 8406
NC Craven County Wood Energy 10525 ES5A 0
NC Dan River 2723 1,2,3 7480
NC Elizabethtown Power 10380 UNIT1 , UNIT2 0
NC G G Allen 2718 1, 2, 3, 4, 5 23076
NC H F Lee Steam Electric Plant 2709 1,2,3,10,11,12,13 9085
NCLVSutton 27131,2,3 12619
NC Lincoln 7277 1,2,3, 4, 5, 6, 7, 8, 9,10, 0
11, 12, 13, 14,15,16
NC Lumberton Power 10382 UNIT1, UNIT2 0
NC Marshall 2727 1 , 2, 3, 4 49030
NCMayo 6250 1 A, 1B 25570
NC NCEMC Anson Plant 56249 ES1-A, ES1-B, ES2-A, 0
ES2-B, ES3-A, ES3-B,
ES4-A, ES4-B, ES5-A,
ES5-B, ES6-A, ES6-B
NC Plant Rowan County 7826 1 , 2, 3, 4, 5 0
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
2999 1649 1649 1350
15 0 0 15
846 1 1 845
30 0 0 30
75 52
189 0 0 189
30 0 0 30
00 00
42818 23329 23329 19489
17157 16992 16992 165
00 00
504 385 385 119
8028 3476 3476 4552
4210 1175 1175 3035
11960 528 528 11432
93131 86388 86388 6743
10774 10261 10261 513
14500 13182 13182 1318
29728 27565 27565 2163
130 125 125 5
8081 7672 7672 409
148 141 141 7
54495 50551 50551 3944
17054 15503 15503 1551
22432 20392 20392 2040
211 0 0 211
169 164 164 5
36022 24755 24755 11267
42155 22811 22811 19344
30 0 0 30
17 3 3 14
Page 21
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
NC Richmond County Plant 78051,2,3,4,6,7,8 0 93 8 8 85
NCRiverbend 27327,8,9,10 9158 16702 15906 15906 796
NC Rockingham County Combustion Turbine 55116 CT1, CT2, CT3, CT4, 0 52 4 4 48
NC Rosemary Power Station
NC Roxboro
NC W H Weatherspoon
ND Antelope Valley
ND Coal Creek
ND Coyote
ND Leland Olds
ND Milton R Young
ND R M Heskett
ND Stanton
NE Beatrice
NECWBurdick
NE Canaday
NE Cass County Station
NE Gerald Gentleman Station
NE Gerald Whelan Energy Center
NE Lon D Wright Power Plant
NE Nebraska City Station
NE North Omaha Station
NE Platte
NE Rokeby
NE Salt Valley Generating Station
NE Sarpy County Station
NE Sheldon
NH Granite Ridge Energy
NH Merrimack
NH Newington
NH Newington Power Facility
NH Schiller
NJ AES Red Oak
NJ B L England
7805 1 , 2, 3, 4, 6, 7, 8
27327,8,9, 10
55116CT1.CT2, CT3, CT4,
CT5
50555 1 , 2
27121,2, 3A,3B,4A,4B
27161,2,3
6469 B1 , B2
6030 1 , 2
8222 B1
28171,2
2823 B1 , B2
2790 B2
28241,10
8000 1 , 2
2241 B-3, GT-2, GT-3
22261
55972 CT1 , CT2
6077 1 , 2
601
2240 8, SOT
60961
2291 1 , 2, 3, 4, 5
591
6373 2, 3
7887 SVGS2, SVGS3, SVGS4
2292 CT3, CT4A, CT4B,
CT5A, CT5B
2277 1 , 2
551700001,0002
2364 1 , 2
80021
55661 1 , 2
2367 4, 5, 6
55239 1 , 2, 3
2378 1 , 2, 3
0
9158
0
0
69736
3873
23078
44497
16182
35506
28836
3202
8781
0
0
627
0
28377
2335
2044
13194
17379
2927
0
0
0
4448
0
13530
11663
0
4614
0
11162
93
16702
52
12
125889
10566
28876
28406
26954
58586
30612
9033
2688
20
27
1802
0
38634
3103
3752
14254
28052
6737
10
15
7
8115
26
37164
2336
74
3861
10
12754
8
15906
4
2
65247
9605
13672
28306
12505
48012
28203
2977
2588
2
0
82
0
28816
2207
1708
14173
14749
2641
0
0
1
4627
6
36484
2269
14
3747
6
12733
2
65247
9605
13672
28306
12505
48012
28203
2977
2588
2
0
82
0
28816
2207
1708
14173
14749
2641
0
0
10
60642
961
15204
100
14449
10574
2409
6056
100
18
27
1720
0
9818
896
2044
81
13303
4096
10
15
1
4627
6
36484
2269
14
3747
6
12733
3488
20
680
67
60
114
4
21
Page 22
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
NJ Bayonne Plant Holding, LLC 50497 001 001 , 002001 , 004001 0
N J Bergen 2398 1 1 01 , 1 201 , 1 301 , 1 401 , 4022
2101,2201
NJ Burlington Generating Station 2399 1 21 , 1 22, 1 23, 1 24 561
NJ Calpine Newark Cogeneration 50797001001 0
NJ Camden Plant Holding, LLC 10751002001 0
NJ Deepwater 2384 1 , 8 5856
NJ EPS Parlin Holdings, LLC 50799 001 001 , 003001 0
NJ Gilbert Generating Station 2393 9, 04, 05, 06, 07 3191
NJ Hudson Generating Station 2403 1,2 17169
NJ Kearny Generating Station 2404 1 21 , 1 22, 1 23, 1 24 298
NJ Linden Cogeneration Facility 50006 004001 0
NJ Linden Generating Station 2406 5, 6, 7, 8, 1 1 01 , 1 201 , 3577
2101,2201
NJ Mercer Generating Station 2408 1,2 15122
NJ Newark Bay Cogen 50385 1001 , 2001 0
NJ North Jersey Energy Associates 10308 1001, 1002 0
NJ Ocean Peaking Power, LP 55938 OPP3, OPP4 0
NJ Pedricktown Cogeneration Plant 10099001001 0
NJ Sewaren Generating Station 24111,2,3,4 1285
NJ Sherman Avenue 7288 1 0
NJ Sunoco Power Generation, LLC 50561 0001 , 0002 0
NM Afton Generating Station 552100001 0
NM Bluffview Power Plant 55977 CTG-1 0
NM Cunningham 2454 121B, 122B, 123T, 124T 311
NM Four Corners Steam Elec Station 2442 1 , 2, 3, 4, 5 37442
NM Lordsburg Generating Station 7967 1,2 0
NM Luna Energy Facility 55343 CTG1 , CTG2 0
NM Maddox 2446 051 B 255
NM Milagro Cogeneration and Gas Plant 54814 1,2 0
NM Person Generating Project 55039 GT-1 0
NM Prewitt Escalante Generating Station 871 1874
NM Pyramid Generating Station 7975 1 , 2, 3, 4 0
NM Reeves Generating Station 2450 1,2,3 115
NM Rio Grande 2444 6, 7, 8 84
NM San Juan 2451 1 , 2, 3, 4 40788
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
60 06
27 16 16 11
371 14 14 357
00 00
41 13
2573 2554 2554 19
00 00
51 14
17174 4441 4441 12733
306 0 0 306
84 44
3586 11 11 3575
15133 14333 14333 800
80 08
32 21
10 0 0 10
20 02
295 65 65 230
92 27
21 11
00 00
11 10
1672 5 5 1667
28704 10240 10240 18464
00 00
66 60
919 2 2 917
22 20
48 0 0 48
1180 1124 1124 56
11 1 1 10
111 0 0 111
652 2 2 650
47752 15285 15285 32467
Page 23
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
NV Apex Generating Station 55514 CTG01, CTG02 064 42
NV Chuck Lenzie Generating Station 55322 CTG-1 , CTG-2, CTG-3, 0 22 16 16 6
NV El Dorado Energy
NV Fort Churchill
NV Harry Allen
NV Las Vegas Cogeneration II, LLC
NV Mohave
NV North Valmy
NV REI Bighorn
NV Reid Gardner
NV Silverhawk
NV Sunrise
NV Tracy
NV Tri-Center Naniwa Energy
NY 23rd and 3rd
NY 74th Street
NY AES Cayuga, LLC
NY AES Greenidge
NY AES Hickling
NY AES Jennison
NY AES Somerset (Kintigh )
NY AES Westover (Goudey)
NY AG - Energy
NY Allegany Station No. 133
NY Arthur Kill
NY Astoria Energy
NY Astoria Generating Station
NY Athens Generating Company
NY Batavia Energy
NY Bayswater Peaking Facility
NY Bethlehem Energy Center (Albany)
NY Bethpage Energy Center
NY Binghamton Cogen Plant
NY Bowline Generating Station
NY Brentwood
55514CTG01.CTG02
55322 CTG-1 , CTG-2, CTG-3,
CTG-4
55077 EDE1, EDE2
2330 1 , 2
7082 "3, "4
10761 1,2,3,4,5
2341 1 , 2
8224 1 , 2
55687 BHG1 , BHG2
2324 1,2,3,4
55841 A01 , A03
23261
2336 1,2,3, 4, 5, 6
55494 CT1 , CT2, CT3, CT4,
CT5, CT6
79102301,2302
2504120,121, 122
2535 1 , 2
2527 4, 5, 6
2529 1,2,3,4
2531 1,2,3,4
60821
2526 11, 12, 13
108031,2
1061900001
2490 20, 30
55375 CT1 , CT2
8906 20, 30, 40, 50
55405 1,2,3
54593 1
55699 1 , 2
253910001, 10002,10003
50292 GT1 , GT2, GTS, GT4
55600 1
2625 1 , 2
7912 BW01
0
0
0
948
1184
0
53216
11222
0
9314
0
50
375
0
0
1343
10143
5147
3278
2774
13889
4860
0
0
3845
0
10870
0
0
0
6637
0
0
8481
0
6
22
19
5634
23
26
0
21385
8
21064
18
375
2110
31
0
1343
3673
4489
0
0
4264
8022
1
3
501
10
4249
15
0
9
27
2
0
849
0
4
16
6
6
0
1
0
7342
4
1154
6
0
9
0
0
606
3660
3083
0
0
4261
7931
0
0
5
10
940
11
0
5
3
1
0
534
0
6
6
0
1
0
7342
4
1154
6
0
9
0
0
606
3660
3083
0
0
4261
7931
0
0
5
10
940
11
0
5
3
1
0
534
0
13
5628
23
25
0
14043
4
19910
12
375
2101
31
0
737
13
1406
0
0
3
91
1
3
496
0
3309
4
0
4
24
1
0
315
0
Page 24
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
NY Brooklyn Navy Yard Cogeneration 54914 1,2 0
NY Carr Street Generating Station 50978 A, B 0
NY Carthage Energy 106201 0
NY Charles Poletti 2491 001 6438
NY Dunkirk 2554 1,2,3,4 1 7270
NY Dynegy Danskammer 2480 1,2,3,4 1 1 027
NY Dynegy Roseton 8006 1 , 2 30496
NY EF Barrett 251110,20 4709
NY East River 2493 1 , 2, 60, 70 3859
NY EPCOR Power (Castleton) LLC 10190 1 0
NY Equus Freeport Power Generating Station 56032 0001 0
NY Far Rockaway 251340 469
NY Freeport Power Plant No. 2 2679 5 0
NY Fulton Cogeneration Associates 5413801GTDB 0
NY Glenwood 2514 40, 50 1842
NY Glenwood Landing Energy Center 7869 UGT012, UGT013 0
NY Harlem River Yard 7914 HR01, HR02 0
NY Hawkeye Energy Greenport, LLC 55969 U-01 0
NY Hell Gate 7913 HG01 , HG02 0
NY Huntley Power 2549 65, 66, 67, 68 21 899
NY Indeck-Corinth Energy Center 50458 1 0
NY Indeck-Olean Energy Center 54076 1 0
NY Indeck-Oswego Energy Center 50450 1 0
NY Indeck-Silver Springs Energy Center 50449 1 0
NY Indeck-Yerkes Energy Center 50451 1 0
NY Independence 54547 1 , 2, 3, 4 0
NY Lovett Generating Station 2629 3, 4, 5 9782
NY Massena Energy Facility 54592 001 0
NY Niagara Generation, LLC 50202 1 0
NY North 1st 7915NO1 0
NY Northport 251 6 1 , 2, 3, 4 35369
NY Onondaga Cogeneration 50855 1,2 0
NY Oswego Harbor Power 2594 3, 5, 6 22538
NY Pinelawn Power 5618800001 0
NY Poletti 500 MW CC 56196 CTG7A, CTG7B 0
NY Port Jefferson Energy Center 251 7 3, 4, UGT002, UGT003 1 0551
NY Pouch Terminal 8053 PT01 0
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
41 22 22 19
41 13
30 03
763 612 612 151
24212 9930 9930 14282
13027 12172 12172 855
24046 4654 4654 19392
960 258 258 702
2463 230 230 2233
43 31
21 11
509 1 1 508
00 00
10 01
197 0 0 197
40 04
00 00
19 16 16 3
00 00
31182 10613 10613 20569
41 13
51 1 1 50
67 0 0 67
13 0 0 13
27 0 0 27
76 61
7244 6984 6984 260
00 00
595 544 544 51
00 00
13229 9923 9923 3306
60 06
1513 1474 1474 39
32 21
11 9 92
2540 1928 1928 612
21 11
Page 25
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
NY PPL Edgewood Energy 55786 CT01 , CT02 0
NY PPL Shoreham Energy 55787 CT01 , CT02 0
NY Project Orange Facility 54425 001 , 002 0
NY Ravenswood Generating Station 2500 10, 20, 30, UCC001 10835
NY Rensselaer Cogen 54034 1GTDBS 0
NY Richard M Flynn (Holtsville) 7314001 0
NY Rochester 7 - Russell Station 2642 1,2,3,4 651 8
NY S A Carlson 26829,10,11,12,20 3037
NY Sterling Power Plant 50744 00001 0
NY Vernon Boulevard 7909 VB01 , VB02 0
NY WPS Syracuse Generation, LLC 106211 0
OH AMP-Ohio Gas Turbines Bowling Green 55262 CT1 0
OH AMP-Ohio Gas Turbines Gallon 55263 CT1 0
OH AMP-Ohio Gas Turbines Napoleon 55264 CT1 0
OHAshtabula 28357 15232
OH Avon Lake Power Plant 2836 10,12 25045
OH Bay Shore 2878 1 , 2, 3, 4 20529
OH Cardinal 2828 1 , 2, 3 49319
OH Conesville 2840 3, 4, 5, 6 45744
OH Darby Electric Generating Station 55247 CT1 , CT2, CT3, CT4, 0
CT5, CT6
OH Eastlake 2837 1 , 2, 3, 4, 5 34273
OH Frank M Tait Station 2847 1 , 2, 3 0
OH Gen J M Gavin 8102 1 , 2 68837
OH Greenville Electric Gen Station 55228 G1 CT1 , G1 CT2, G2CT1 , 0
G2CT2, G3CT1 , G3CT2,
G4CT1 , G4CT2
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
10 01
99 90
11 10
2353 1495 1495 858
40 04
58 54 54 4
22804 21719 21719 1085
3812 3498 3498 314
00 00
00 00
30 03
20 02
20 02
20 02
6705 6655 6655 50
38873 38773 38773 100
13257 13207 13207 50
85688 81288 81288 4400
140926 114053 114053 26873
51 0 0 51
61504 61454 61454 50
12 0 0 12
30623 29164 29164 1459
80 08
OH Hamilton Municipal Power Plant
OH Hanging Rock Energy Facility
OH J M Stuart
OH Killen Station
OH Kyger Creek
OH Lake Shore
OH Madison Generating Station
OH Miami Fort Generating Station
OH Muskingum River
29179 1665 2927 1565
55736 CTG1, CTG2, CTG3, 0 74
CTG4
28501,2,3,4 76200 108394 107319
6031 2 16928 14688 8601
28761,2,3,4,5 39155 62435 57435
283818 6336 5182 5132
551101,2,3,4,5,6,7,8 0 14 0
28326,7,8,5-1,5-2 40036 48689 46939
28721,2,3,4,5 41070 136438 132459
1565
4
107319
8601
57435
5132
0
46939
132459
1362
3
1075
6087
5000
50
14
1750
3979
Page 26
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
OH Niles 28611,2 6919 15192 15112 15112 80
OH O H Hutchings 2848 H-1 , H-2, H-3, H-4, H-5, 9923 4775 4721 4721 54
OH Omega JV2 Bowling Green
OH Omega JV2 Hamilton
OH Picway
OH R E Burger
OH Richard Gorsuch
OH Richland Peaking Station
OH Robert P Mone
OH Rolling Hills Generating LLC
OH Tait Electric Generating Station
OH Troy Energy, LLC
OHWHSammis
OH W H Zimmer Generating Station
OH Walter C Beckjord Generating Station
OH Washington Energy Facility
OH Waterford Plant
OH West Lorain
OH Woodsdale
OK Anadarko
OK Chouteau Power Plant
OK Comanche (8059)
OK Grand River Dam Authority
OK Green Country Energy, LLC
OK Horseshoe Lake
OK Hugo
OK McClain Energy Facility
OK Mooreland
OK Muskogee
OK Mustang
OK Northeastern
OK Oneta Energy Center
H-6
7783 P001
7782 P001
28439
2864 5, 6, 7, 8
7253 1, 2, 3, 4
2880 CTG4, CTG5, CTG6
7872 1, 2, 3
55401 CT-1, CT-2, CT-3, CT-4,
CT-5
55248 CT4, CT5, CT6, CT7
55348 1, 2, 3, 4
2866 1, 2, 3, 4, 5, 6, 7
60191
2830 1, 2, 3, 4, 5, 6
55397 CT1, CT2
55503 1, 2, 3
2869 2, 3, 4, 5, 6
7158**GT1,**GT2,
**GT4, "GTS,
3006 3, 7, 8
7757 1, 2
8059 7251, 7252
1651,2
55146CTGEN1.CTGEN2,
CTGEN3
2951 6,7,8,9, 10
67721
55457 CT1, CT2
3008 1, 2, 3
2952 3, 4, 5, 6
2953 1, 2, 3, 4
29633302,3313,3314,
3301 A, 3301B
55225 CTG-1, CTG-2, CTG-3,
CTG-4
*GT3,
*GT6
0
0
2128
17621
19500
0
0
0
0
0
72492
16154
23268
0
0
0
2056
0
0
335
23038
0
717
11877
0
51
32154
222
36394
1
1
7641
22557
30283
15
4
0
0
2
101840
17280
61352
5
7
25
12
13
34
915
38487
12
5648
20129
72
388
52496
1894
46425
0
0
7418
22509
27358
0
0
0
0
2
101790
16776
54909
2
2
2
0
0
4
3
17629
6
47
10151
8
1
23173
3
30362
0
0
7418
22509
27358
0
0
0
0
2
101790
16776
54909
2
2
2
0
0
4
3
17629
6
47
10151
8
1
23173
3
30362
1
1
223
48
2925
15
4
0
0
0
50
504
6443
3
5
23
12
13
30
912
20858
6
5601
9978
64
387
29323
1891
16063
Page 27
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
OKPonca 7622,3,4 0 00 00
OK Redbud Power Plant 55463 CT-01 , CT-02, CT-03, CT- 0 14 8 86
OK Riverside (4940)
OK Seminole (2956)
OK Sooner
OK Southwestern
OK Spring Creek Power Plant
OK Tenaska Kiamichi Generating Station
OKTulsa
OR Boardman
OR Boardman Power Holdings LLC
OR Coyote Springs
OR Hermiston
OR Hermiston Power Plant
OR Klamath Cogeneration Project
OR Klamath Energy LLC
OR Port Westward
PA AES Ironwood
PA Allegheny Energy Hunlock Unit 4
PA Allegheny Energy Unit 1 and Unit 2
PA Allegheny Energy Unit 8 and Unit 9
PA Allegheny Energy Units 3, 4 & 5
PA Armstrong Energy Ltd Part
PA Armstrong Power Station
PA Bethlehem Power Plant
PA Bruce Mansfield
PA Brunner Island
PA Brunot Island Power Station
PA Chambersburg Units 12 and 13
PA Cheswick
PA Conemaugh
PA Cromby
PA Eddystone Generating Station
PA Elrama
04
49401501, 1502
2956 1, 2, 3
6095 1,2
2964 8002, 8003, 801N, 801S
55651 CT-01, CT-02, CT-03, CT-
04
55501 CTGDB1, CTGDB2,
CTGDB3, CTGDB4
29651402, 1403,1404
61061SG
55683 1
7350CTG1.CTG2
54761 1,2
55328 CTG-1, CTG-2
55103CT1.CT2
55544 GT1, GT2, GTS, GT4
56227 PWEU1
55337 0001, 0002
56397 4
551961,2
55377 8, 9
557103,4
55347 1, 2, 3, 4
31781,2
55690 1, 2, 3, 5, 6, 7
6094 1, 2, 3
31401, 2, 3
3096 3, 2A, 2B
5565412, 13
82261
31181,2
31591,2
3161 1,2,3,4
3098 1, 2, 3, 4
804
1359
20450
182
0
0
160
13377
0
0
0
0
0
0
0
0
0
0
0
0
0
12869
0
41259
48595
0
0
16891
54690
4313
9756
7414
4727
10686
34723
608
1
39
208
14063
0
6
12
8
7
8
4
8
20
20
20
22
11
32052
23
20597
106449
31
20
34189
7779
4053
8130
4427
12
862
17822
2
0
12
2
14037
0
6
8
6
5
0
4
6
0
0
0
2
7
31484
17
20547
106148
0
0
34089
6784
3446
6864
4267
12
862
17822
2
0
12
2
14037
0
6
8
6
5
0
4
6
0
0
0
2
7
31484
17
20547
106148
0
0
34089
6784
3446
6864
4267
4715
9824
16901
606
1
27
206
26
0
0
4
2
2
8
0
2
20
20
20
20
4
568
6
50
301
31
20
100
995
607
1266
160
Page 28
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
PA Fairless Energy, LLC 55298 1A, 1B, 2A, 2B 0 29 8 8 21
PA Fayette Energy Facility 55516 CTG1, CTG2 052 23
PA FPL Energy Marcus Hook, LP 558010001,0002,0003 0 10 6 64
PA Grays Ferry Cogen Partnership 54785 2 021 11
PA Handsome Lake Energy 55233 EU-1A, EU-1B, EU-2A, 000 00
PA Hatfields Ferry Power Station
PA Hazleton Generation
PA Homer City
PA Hunlock Power Station
PA Hunterstown Combined Cycle
PA Keystone
PA Liberty Electric Power Plant
PA Lower Mount Bethel Energy
PA Martins Creek
PA Mitchell Power Station
PA Montour
PA Mt. Carmel Cogeneration
PA New Castle
PA North East Cogeneration Plant
PA Ontelaunee Energy Center
PA PEI Power Power Corporation
PA Portland
PA Schuylkill
PA Seward
PA Shawville
PA Sunbury
PA Titus
PA WPS Westwood Generation, LLC
Rl Manchester Street
Rl Pawtucket Power Associates, LP
Rl Rhode Island State Energy Partners
Rl Tiverton Power
SC Broad River Energy Center
EU-2B, EU-3A, EU-3B,
EU-4A, EU-4B, EU-5A,
EU-5B
31791,2,3
10870 TURB2, TURB3, TURB4
31221,2,3
31766
55976 CT101, CT201, CT301
31361,2
55231 0001, 0002
55667 CT01, CT02
31481,2,3,4
3181 1,2,3,33
31491,2
10343SG-101
31383,4,5
54571 001, 002
55193CT1.CT2
50279 2
31131,2,5
31691
31301,2
3131 1,2,3,4
31523,4, 1A, 1B, 2A, 2B
31151,2,3
50611 031
32369,10,11
54056 1
55107RISEP1, RISEP2
55048 1
55166 CT-1, CT-2, CT-3, CT-4,
CT-5
49772
0
61702
2257
0
58264
0
0
36295
3530
48871
0
12905
0
0
0
6973
572
7194
21067
16550
6617
0
1663
0
0
0
0
146160
12
138883
3676
10
174242
14
3
14974
884
128361
508
18632
0
13
0
32818
541
8195
49225
34946
14609
250
1799
1
7
10
5
144937
0
120768
3674
3
171081
4
2
14973
634
127780
501
18512
0
2
0
32730
221
8096
49065
29808
14489
231
4
0
6
3
2
144937
0
120768
3674
3
171081
4
2
14973
634
127780
501
18512
0
2
0
32730
221
8096
49065
29808
14489
231
4
0
6
3
2
1223
12
18115
2
7
3161
10
1
1
250
581
7
120
0
11
0
88
320
99
160
5138
120
19
1795
1
1
7
3
Page 29
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
SC
sc
SC
sc
sc
sc
sc
sc
sc
sc
sc
sc
2007 He
Plant Allowances Acco
Plant Name Code Units Allocated of3/
Canadys Steam 3280 CAN1 , CAN2, CANS 1 0450
Cherokee County Cogen 55043 CCCP1 0
Columbia Energy Center (SC) 55386 CT-1 , CT-2 0
Cope Station 7210 COP1 2616
Cross 1301,2,3 14544
Darlington County 325012,13 0
Dolphus M Grainger 3317 1 , 2 3391
HB Robinson 3251 1 3815
Hagood 3285 HAG4 2189
Jasper County Generating Facility 55927 CT01 , CT02, CT03 0
Jefferies 33191,2,3,4 7630
John S. Rainey Generating Station 7834 CT3, CT4, CT5, CT1A, 0
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
25373 17881 17881 7492
70 07
32 21
4068 2334 2334 1734
9592 9192 9192 400
39 3 3 36
10740 10340 10340 400
13873 12611 12611 1262
1400 1 1 1399
236 6 6 230
23048 22647 22647 401
16 2 2 14
SC McMeekin
SC Mill Creek Combustion Turbine Sta
SC Urquhart
SC W S Lee
SC Wateree
SC Williams
SC Winyah
SD Angus Anson
SD Big Stone
SD Groton Generating Station
SD Huron
SD Lange
TN Allen
TN Brownsville Power I, LLC
TN Bull Run
TN Cumberland
TN Gallatin
TN Gleason Generating Facility
TN John Sevier
TN Johnsonville
CT1B, CT2A, CT2B
3287 MCM1, MCM2 8118
7981 1, 2, 3, 4, 5, 6, 7, 8 0
3295 URQ3, URQ4, URQ5, 7036
URQ6
3264 1, 2, 3, 7C, 8C 7854
3297 WAT1, WAT2 18987
3298 WIL1 15821
6249 1, 2, 3, 4 20845
72372,3,4 1871
60981 13715
56238 CT001 0
3344 **2A, **2B 183
55478 CT1 0
3393 1,2,3 20595
55081 AA-001, AA-002, AA-003, 0
AA-004
3396 1 25047
3399 1, 2 78282
3403 1,2,3, 4, GCT5, GCT6, 32872
GCT7, GCT8
55251 CTG-1, CTG-2, CTG-3 0
3405 1,2,3,4 25907
3406 1,2,3, 4, 5, 6, 7, 8, 9, 10, 34783
JCT17, JCT18, JCT19,
JCT20
11750
114
10642
11533
33725
25974
16090
14949
21217
100
2
16
25404
12
44072
57282
54370
50
29000
71329
10467
6
7171
10942
30939
22494
15688
5
9043
0
0
0
13211
0
40008
17096
23111
0
27714
64993
10467
6
7171
10942
30939
22494
15688
5
9043
0
0
0
13211
0
40008
17096
23111
0
27714
64993
1283
108
3471
591
2786
3480
402
14944
12174
100
2
16
12193
12
4064
40186
31259
50
1286
6336
Page 30
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
TN Kingston 3407 1 , 2, 3, 4, 5, 6, 7, 8, 9 48855 54629 51093 51093 3536
TN Lagoon Creek 7845 LCT1 , LCT2, LCT3, 0 1012 1 1 1011
TXAES Deepwater, Inc.
TX AES Western Power, LLC
TX Alex Ty Cooke Generating Station
TX Altura Channelview Cogen Facility
TX Barney M. Davis
TX Bastrop Clean Energy Center
TX Baytown Energy Center
TX Big Brown
TX Blackhawk Station
TX Bosque County Power Plant
TX Brazos Valley Energy, LP
TX Bryan
TX C E Newman
TX C. R. Wing Cogeneration Plant
TX Calpine Hidalgo Energy Center
TX Cedar Bayou
TX Channel Energy Center
TX Coleto Creek
TX Collin
TX Colorado Bend Energy Center
TX Corpus Christ! Energy Center
TX Cottonwood Energy Project
TX Dansby
TX Decker Creek
TX Decordova
TX Deer Park Energy Center
TX Eagle Mountain
TX Eastman Cogeneration Facility
TX Ennis-Tractebel Power Company
LCT4, LCT5, LCT6,
LCT7, LCT8, LCT9,
LCT10, LCT11.LCT12
1067001001
3461 DWP9
3602 1, 2
50815 ENG101, ENG201,
ENG301.ENG401,
ENG501.ENG601
4939 1,2
55168CTG-1A, CTG-1B
55327 CTG-1, CTG-2, CTG-3
3497 1, 2
55064 001, 002
55172GT-1.GT-2, GT-3
55357 CTG1.CTG2
3561 6
3574 BW5
521761,2
7762 HRSG1, HRSG2
3460 CBY1, CBY2, CBY3
55299 CTG1, CTG2
61781
35001
56350 CT1 A, CT1B, CT2A,
CT2B
55206 CU1.CU2
55358 CT1, CT2, CT3, CT4
6243 1,2
3548 1,2
80631
55464 CTG1.CTG2, CTG3,
CTG4
3489 1, 2, 3
551761,2
55223 GT-1
0
28
130
0
894
0
0
40863
0
0
0
19
3
0
0
2460
0
14721
92
0
0
0
94
323
1018
0
292
0
0
14110
0
382
22
4
15
13
85041
13
4
9
139
22
14
7
15536
24
17893
0
2
13
22
732
323
5
24
0
93
6
2361
0
0
11
1
6
11
76797
6
2
6
0
0
2
4
6
20
14274
0
0
7
8
1
5
1
20
0
7
4
2361
0
0
11
1
6
11
76797
6
2
6
0
0
2
4
6
20
14274
0
0
7
8
1
5
1
20
0
7
4
11749
0
382
11
3
9
2
8244
7
2
3
139
22
12
3
15530
4
3619
0
2
6
14
731
318
4
4
0
86
2
Page 31
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
TX Exelon Laporte Generating Station 55365 GT-1 , GT-2, GT-3, GT-4 0
TX Exxonmobil Beaumont Refinery 50625 61 STK1 , 61 STK2, 0
61STK3
TX Fort Phantom Power Station 4938 31 3
TX FPLE Forney, LP 55480 U1 , U2, U3, U4, U5, U6 0
TX Freestone Power Generation 55226 GT1 , GT2, GTS, GT4 0
TX Frontera Generation Facility 55098 1,2 0
TX Gibbons Creek Steam Electric Station 61 36 1 1 441 4
TX Graham 3490 1,2 731
TX Greens Bayou 3464 GBY5 389
TX Gregory Power Facility 55086 1 01 , 1 02 0
TX Guadalupe Generating Station 55153 CTG-1, CTG-2, CTG-3, 0
CTG-4
TX H W Pirkey Power Plant 7902 1 20532
TX Handley Generating Station 3491 2, 3, 4, 5, 1A, 1 B 705
TX Harrington Station 61 93 061 B, 062B, 063B 26224
TX Harrison County Power Project 55664 GT-1 , GT-2 0
TX Hays Energy Project 551 44 STK1 , STK2, STK3, 0
STK4
TX Holly Street 35493,4 191
TX J K Spruce 7097 "1 6692
TXJL Bates 34381,2 172
TX J Robert Massengale Generating Station 3604 GT1 0
TXJTDeely 6181 1,2 26841
TX Jack County Generation Facility 55230 CT-1 , CT-2 0
TX Johnson County Generation Facility 54817 EAST 0
TX Jones Station 3482 1 51 B, 1 52B 218
TX Knox Lee Power Plant 3476 2, 3, 4, 5 285
TX Lake Creek 3502 1,2 230
TX Lake Hubbard 3452 1,2 774
TX Lamar Power (Paris) 55097 1,2,3,4 0
TX Laredo 34391,2,3 114
TX Leon Creek 3609 3, 4, CGT1 , CGT2, 12
CGT3, CGT4
TX Lewis Creek 3457 1,2 588
TX Limestone 298 LIM1, LIM2 37945
TX Lone Star Power Plant 3477 1 0
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
33 0 0 33
18 9 99
00 00
21 18 18 3
13 9 94
21 5 5 16
24046 11386 11386 12660
19 10 10 9
3006 2 2 3004
18 10 10 8
16 10 10 6
50019 1953 1953 48066
60 2 2 58
36111 19191 19191 16920
10 3 37
12 8 84
191 2 2 189
13955 3394 3394 10561
00 00
11 1 1 10
38879 23535 23535 15344
10 8 82
10 3 37
1636 6 6 1630
1776 1 1 1775
50 05
20 8 8 12
12 10 10 2
84 44
300 0 0 300
3504 6 6 3498
45915 14677 14677 31238
50 05
Page 32
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
TX Lost Pines 1 551541,2 0 58 7 7 51
TX Magic Valley Generating Station 551 23 CTG-1 , CTG-2 096 63
TX Martin Lake 61461,2,3 98933 86451 79038 79038 7413
TX Midlothian Energy 55091 STK1 , STK2, STK3, 0 22 15 15 7
TX Monticello
TX Moore County Station
TX Morgan Creek
TX Mountain Creek Generating Station
TX Mustang Station
TX Mustang Station Units 4 and 5
TX New Gulf Power Facility
TX Newman
TX Nichols Station
TX North Lake
TX North Texas
TX Nueces Bay
TX O W Sommers
TX Odessa-Ector Generating Station
TX Oklaunion Power Station
TX P H Robinson
TX Paint Creek Power Station
TX Paris Energy Center
TX Pasadena Power Plant
TX Permian Basin
TX Plant X
TX Power Lane Steam Plant
TX Quail Run Energy Center
TXRW Miller
TX Ray Olinger
TX Reliant Energy Channelview Cogen
TX Rio Nogales Power Project, LP
TX Rio Pecos Power Station
STK4, STK5, STK6
61471,2,3
34833
3492 5, 6
3453 2, 6, 7, 8, 3A, 3B
55065 1,2
56326 GEN1.GEN2
501371
3456 1, 2, 3, "4, "5, GT-6A,
GT-6B
3484141B, 142B, 143B
3454 1, 2, 3
36273
3441 5, 6, 7
3611 1, 2
55215GT1.GT2, GTS, GT4
1271
3466 PHR1, PHR2, PHR3,
PHR4
3524 1, 2, 3, 4
50109HRSG1, HRSG2
55047 CG-1, CG-2, CG-3
3494 5, 6
3485 111B, 112B, 113B, 114B
41952,3
56349 CT1 A, CT1B, CT2A,
CT2B
3628 1, 2, 3, "4, "5
3576 BW2, BW3, CE1, GE4
55187CHV1.CHV2, CHV3,
CHV4
55137 CTG-1, CTG-2, CTG-3
3526
81811
0
1070
669
0
0
0
230
213
575
13
637
666
0
7859
2620
155
0
0
907
91
496
0
2073
181
0
0
243
81985
1
1
100
28
7
4
1650
1676
5
19
0
3845
14
8482
2901
0
10
11
5
692
2965
0
2087
1416
20
11
0
74351
0
0
2
6
0
0
7
6
0
0
0
5
10
4385
0
0
2
8
1
5
0
0
1
3
16
6
0
74351
0
0
2
6
0
0
7
6
0
0
0
5
10
4385
0
0
2
8
1
5
0
0
1
3
16
6
0
7634
1
1
98
22
7
4
1643
1670
5
19
0
3840
4
4097
2901
0
8
3
4
687
2965
0
2086
1413
4
5
0
Page 33
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
TXSabine 34591,2,3,4,5 1719 10282 15 15 10267
TX Sabine Cogeneration Facility 551 04 SAB-1 , SAB-2 042 22
TX Sam Bertron 3468 SRB1, SRB2, SRB3, 274 2052 0 0 2052
TX Sam Rayburn Plant
TX Sam Seymour
TX San Angelo Power Station
TX San Jacinto Steam Electric Station
TX San Miguel
TX Sand Hill Energy Center
TX Sandow
TX Silas Ray
TX Sim Gideon
TX South Houston Green Power Site
TX Spencer
TX SRW Cogen Limited Partnership
TX Stryker Creek
TX Sweeny Cogeneration Facility
TX Sweetwater Generating Plant
TX T C Ferguson
TX Tenaska Frontier Generation Station
TX Tenaska Gateway Generating Station
TX Tolk Station
TX Tradinghouse
TX Trinidad
TX Twin Oaks Power, LP
TX V H Braunig
TX Valley (TXU)
TX Victoria Power Station
TXW A Parish
TX W B Tuttle
TX Welsh Power Plant
TX West Texas Energy Facility
SRB4
3631 CT7, CT8, CT9
61791,2,3
3527
7325SJS1.SJS2
6183SM-1
7900SH1.SH2, SH3, SH4,
SH5
66484
35599,10
3601 1, 2, 3
55470 EPN801, EPN802,
EPN803
4266 4, 5
55120CTG-1.CTG-2
3504 1, 2
550151,2,3,4
50615GT01.GT02, GT03
49371
55062 1, 2, 3
55132OGTDB1.OGTDB2,
OGTDB3
6194171 B, 172B
3506 1,2
35079
7030 U1, U2
36121,2, 3, CT01.CT02
3508 1, 2, 3
34436
3470 WAP1, WAP2, WAP3,
WAP4, WAP5, WAP6,
WAP7, WAP8
36131,2,3,4
61391,2,3
55240 STK1, STK2
0
43800
161
0
17216
0
25698
0
380
0
42
0
695
0
0
253
0
0
29225
1588
142
5623
615
719
362
66984
80
41395
0
5
41994
0
46
17340
15
30682
548
1909
134
317
12
10
168
5
987
38
35
60442
20
10
7771
4894
5
60
120372
640
52012
0
3
33186
0
4
8369
4
23365
0
4
88
2
9
3
12
0
3
10
9
18873
5
2
4564
6
1
0
57804
0
26413
0
3
33186
0
4
8369
4
23365
0
4
88
2
9
3
12
0
3
10
9
18873
5
2
4564
6
1
0
57804
0
26413
0
2
8808
0
42
8971
11
7317
548
1905
46
315
3
7
156
5
984
28
26
41569
15
8
3207
4888
4
60
62568
640
25599
0
Page 34
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
TX Wilkes Power Plant 3478 1 , 2, 3 277
TX Wise County Power Company 55320 GT-1 , GT-2 0
TX Wolf Hollow I, LP 55139CTG1.CTG2 0
UT Bonanza 77901-1 13750
UT Carbon 36441,2 4412
UT Currant Creek Power Project 56102 CTG1A, CTG1 B 0
UT Desert Power Plant 55858 UNT1 , UNT2 0
UT Gadsby 3648 1 , 2, 3, 4, 5, 6 3979
UT Hunter 61651,2,3 26668
UT Huntington 8069 1 , 2 17678
UT Intermountain 6481 1 SGA, 2SGA 5770
UT Lake Side Power Plant 56237 CT01 , CT02 0
UT Millcreek Power 56253 MC-1 0
UT Nebo Power Station 56177 U1 0
UT West Valley Generation Project 55622 U1 , U2, U3, U4, U5 0
VA AltaVista Power Station 1 0773 1,2 0
VA Bellemeade Power Station 50966 1,2 0
VA Bremo Power Station 37963,4 7189
VA Buchanan - Units 1 and 2 55738 1,2 0
VA Chesapeake Energy Center 3803 1,2,3,4 1 4759
VA Chesterfield Power Station 3797 3, 4, 5, 6, **8A 35332
VA Clinch River 3775 1,2,3 17112
VA Clover Power Station 7213 1 , 2 5876
VA Commonwealth Chesapeake 55381 CT-001 , CT-002, CT-003, 0
CT-004, CT-005, CT-006,
CT-007
VA Doswell Limited Partnership 52019 CT1 0
VA Elizabeth River Combustion Turbine Sta 52087 CT-1 , CT-2, CT-3 0
VA Glen Lyn 3776 6, 51 , 52 7800
VA Gordonsville Power Station 54844 1,2 0
VA Hopewell Power Station 107711,2 0
VA Ladysmith Combustion Turbine Sta 7838 1,2 0
VA Louisa Generation Facility 7837 EU1 , EU2, EU3, EU4, 0
EU5
VA Marsh Run Generation Facility 7836 EU1 , EU2, EU3 0
VA Mecklenburg Power Station 52007 1,2 0
VA Mirant Potomac River 3788 1 , 2, 3, 4, 5 1 3349
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
2117 4 4 2113
86 62
20 7 7 13
2558 1251 1251 1307
6712 6512 6512 200
28 8 8 20
40 04
61 1 1 60
6952 6672 6672 280
4551 4351 4351 200
19756 4764 4764 14992
22 2 2 20
00 00
42 22
52 2 2 50
93 80 80 13
15 8 87
10940 10452 10452 488
20 0 0 20
20773 20318 20318 455
71210 71096 71096 114
27477 26674 26674 803
2015 1630 1630 385
14 11 11 3
53 32
38 21 21 17
11837 11491 11491 346
12 5 57
318 283 283 35
12 5 57
20 8 8 12
14 6 68
586 513 513 73
3840 3748 3748 92
Page 35
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
VA Possum Point Power Station 3804 3, 4, 5, 6A, 6B 13708 2201 1949 1949 252
VA Remington Combustion Turbine Station 78391,2,3,4 0 12 7 75
VA Southampton Power Station 107741,2 0 243 146 146 97
VA Tenaska Virginia Generating Station 55439 CTGDB1 , CTGDB2, 0 22 4 4 18
VA Wolf Hills Energy
VA Yorktown Power Station
VT J C McNeil
WA Centralia
WA Chehalis Generation Facility
WA Encogen Generating Station
WA Finley Combustion Turbine
WA Frederickson Power LP
WA Fredonia Generating Station
WA Goldendale Generating Station
WA River Road
Wl Alma
Wl Bay Front
Wl Blount Street
Wl Columbia
Wl Combined Locks Energy Center, LLC
Wl Concord
Wl Depere Energy Center
Wl E J Stoneman Generation Station
Wl Edgewater (4050)
Wl Elk Mound Generating Station
Wl Fox Energy Company LLC
Wl Genoa
Wl Germantown Power Plant
Wl Island Street Peaking Plant
WIJ P Madgett
Wl Manitowoc
Wl Neenah Energy Facility
Wl Nelson Dewey
CTGDB3
55285 WH01, WH02, WH03, 0
WH04, WH05, WH06,
WH07, WH08, WH09,
WH10
38091,2,3 15650
5891 104
3845 30, 40, 50, 60, BW21, 39413
BW22
55662 CT1, CT2 0
7870 CT1, CT2, CT3 0
7945 1 0
55818F1CT 0
607 CT3, CT4 0
55482 CT-1 0
7605 1 0
4140B4, B5 3099
39821,2,5 1889
39923,5,6,7,8,9,11 3810
8023 1, 2 24242
55558 B06 0
7159 "1, "2, "3, "4 504
55029 B01 0
4146B1.B2 400
4050 3, 4, 5 23092
7863 1,2 0
56031 CTG-1, CTG-2 0
41431 8019
6253 "5 0
55836 1 A, 1B 0
4271 B1 7436
41256,7,8,9 1724
55135CT01.CT02 0
4054 1,2 5332
24837
51
2239
20
151
0
6
21
8
15
7600
8992
11931
31580
19
20
17
692
80000
20
2
13792
8
53
22710
3475
6
15502
24228
6
2131
16
3
0
2
0
2
5
6905
1149
2766
25425
0
1
1
682
16668
0
2
12480
1
0
8039
2104
1
15063
24228
6
2131
16
3
0
2
0
2
5
6905
1149
2766
25425
0
1
1
682
16668
0
2
12480
1
0
8039
2104
1
15063
609
45
108
4
148
0
4
21
6
10
695
7843
9165
6155
19
19
16
10
63332
20
0
1312
7
53
14671
1371
5
439
Page 36
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
2007 He
Plant Allowances Acco
State Plant Name Code Units Allocated of3/
Wl Paris 7270 "1 , "2, "3, "4 496
Wl Pleasant Prairie 6170 1 , 2 28482
Wl Port Washington Generating Station 4040 21 , 22 4283
Wl Pulliam 4072 3, 4, 5, 6, 7, 8, 32 6935
Wl Riverside Energy Center, LLC 55641 CT-01 , CT-02 0
Wl Rock River 4057 1 , 2 3042
Wl Rockgen Energy Center 55391 CT-1 , CT-2, CT-3 0
Wl Sheboygan Falls Energy Facility 56166 1 , 2 0
Wl South Fond Du Lac 7203 **CT1 , **CT2, **CT3, 71 7
**CT4
Wl South Oak Creek 4041 5, 6, 7, 8 21642
Wl Valley (WEPCO) 4042 1 , 2, 3, 4 7483
Wl West Campus Cogeneration Facility 7991 U1 , U2 0
Wl West Marinette 4076 "33, "34 765
Wl Weston 4078 1 , 2, 3 12276
Wl Whitewater Cogeneration Facility 5501101 0
WV Albright Power Station 3942 1 , 2, 3 8626
WV Big Sandy Peaker Plant 55284 GS01 , GS02, GS03, 0
GS04, GS05, GS06,
GS07, GS08, GS09,
GS10, GS11.GS12
WV Ceredo Generating Station 55276 01 , 02, 03, 04, 05, 06 0
WV Fort Martin Power Station 3943 1 , 2 35702
WV Harrison Power Station 3944 1 , 2, 3 58766
WV John E Amos 3935 1 , 2, 3 90000
WV Kammer 3947 1 , 2, 3 23971
WV Kanawha River 3936 1 , 2 8753
WV Mitchell (WV) 3948 1 , 2 38585
WV Mount Storm Power Station 3954 1 , 2, 3 54839
WV Mountaineer (1301) 62641 35223
WV North Branch Power Station 7537 1 A, 1 B 0
WV Phil Sporn 3938 1 1 , 21 , 31 , 41 , 51 23078
WV Pleasants Energy, LLC 55349 1,2 0
WV Pleasants Power Station 6004 1 , 2 37797
WV Rivesville Power Station 3945 7, 8 3766
WV Willow Island Power Station 3946 1,2 61 80
WY Dave Johnston 41 58 BW41 , BW42, BW43, 2491 2
BW44
d in Allowances
jnts as 2007 2007 Allowances Carried Over
1/2008 Emissions Underutilization Deducted to 2008
19 1 1 18
34915 2230 2230 32685
4162 4 4 4158
11479 10448 10448 1031
54 41
9498 2 2 9496
10 01
00 00
3182 0 0 3182
32959 13693 13693 19266
8310 6848 6848 1462
12 2 2 10
1963 0 0 1963
10274 9108 9108 1166
53 32
20903 20793 20793 110
00 00
17 0 0 17
88193 88031 88031 162
4828 4738 4738 90
126696 103546 103546 23150
44422 43127 43127 1295
13788 13384 13384 404
9410 6084 6084 3326
3006 2774 2774 232
8353 2302 2302 6051
1375 1034 1034 341
55237 40530 40530 14707
55 50
39082 38437 38437 645
2944 2884 2884 60
4378 4327 4327 51
21756 21356 21356 400
Page 37
-------
Appendix A: Acid Rain Program - Year 2007 SO2 Allowance Holdings And Deductions
State
Plant Name
Plant
Code
Units
2007
Allowances
Allocated
Held in
Accounts as
of 3/1/2008
2007
Emissions
2007
Underutilization
Allowances
Deducted
Allowances
Carried Over
to 2008
WY Jim Bridger
WY Laramie River
WY Naughton
WY Neil Simpson II
WY Neil Simpson II
WY Wygen I
WY Wyodak
(CT2)
8066 BW71, BW72, BW73,
BW74
6204 1, 2, 3
41621,2,3
7504 001, CT1
55477 CT2
55479 001
6101 BW91
65038
13239
17162
0
0
0
18317
19454
17973
21888
1693
24
1022
7935
19054
10387
21589
617
0
833
7835
19054
10387
21589
617
0
833
7835
400
7586
299
1076
24
189
100
Page 38
-------
2007 Acid Rain Program NOx Compliance Summary
State
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
Facility Name
Barry
Barry
Barry
Barry
Barry
Charles R Lowman
Charles R Lowman
Charles R Lowman
Colbert
Colbert
Colbert
Colbert
Colbert
E C Gaston
E C Gaston
Facility ID
(ORISPL)
3
3
3
3
3
56
56
56
47
47
47
47
47
26
26
Unit ID
1
2
3
4
5
1
2
3
1
2
3
4
5
1
2
Unit Operator(s)
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
Alabama Power Company
PowerSouth Energy
Cooperative, Inc.
PowerSouth Energy
Cooperative, Inc.
PowerSouth Energy
Cooperative, Inc.
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Alabama Power Company
Alabama Power Company
Compliance
Approach
Averaging
Averaging
Averaging
Averaging
Averaging
Plan
Plan
Plan
Plan
Plan
Standard Limit
Early Election
Early Election
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Standard
Emissions
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
Actual Early Election AEL (if Averaging Plan Limit (if
Emission Rate Limit (if applicable) applicable)
applicable)
0,
0,
o.
o.
0,
o.
0,
0,
0,
0,
o.
o.
o.
o.
0,
.31
.31
.31
.27
.31
.43
.46 0.50
.48 0.50
.43
.43
.43
.43
.11
.39
.39
0.46
0.46
0.46
0.46
0.46
0.56
0.56
0.56
0.56
0.56
0.46
0.46
Actual Averaging
Plan Rate (if
applicable)
0.26
0.26
0.26
0.26
0.26
0.38
0.38
0.38
0.38
0.38
0.26
0.26
Page: 1
-------
2007 Acid Rain Program NOx Compliance Summary
State
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
Facility Name
E C Gaston
E C Gaston
E C Gaston
Gadsden
Gadsden
Gorgas
Gorgas
Gorgas
Gorgas
Gorgas
Greene County
Greene County
James H Miller Jr
James H Miller Jr
James H Miller Jr
Facility ID
(ORISPL)
26
26
26
7
7
8
8
8
8
8
10
10
6002
6002
6002
Unit ID
3
4
5
1
2
10
6
7
8
9
1
2
1
2
3
Unit Operator(s)
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.41
0.41
0.25
0.55
0.54
0.33
0.45
0.45
0.42
0.43
0.27
0.32
0.18
0.19
0.20
AEL (if Averaging Plan Limit (if
applicable) applicable)
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
Actual Averaging
Plan Rate (if
applicable)
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
Page: 2
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2007 Acid Rain Program NOx Compliance Summary
State
AL
AL
AL
AL
AL
AL
AL
AL
AL
AR
AR
AR
AR
AR
AZ
AZ
Facility Name
James H Miller Jr
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Flint Creek Power Plant
Independence
Independence
White Bluff
White Bluff
Apache Station
Apache Station
Facility ID
(ORISPL)
6002
50
50
50
50
50
50
50
50
6138
6641
6641
6009
6009
160
160
Unit ID
4
1
2
3
4
5
6
7
8
1
1
2
1
2
2
3
Unit Operator(s)
Alabama 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
Southwestern Electric
Power Company
Entergy Corporation
Entergy Corporation
Entergy Corporation
Entergy Corporation
Arizona Electric Power
Cooperative
Arizona Electric Power
Cooperative
Compliance
Approach
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Standard
Emissions
Limit
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.40
0.40
0.46
0.40
0.40
0.40
0.40
0.46
0.46
Actual Early Election AEL (if Averaging Plan Limit (if Actual Averaging
Emission Rate Limit (if applicable) applicable) Plan Rate (if
applicable) applicable)
0,
0,
o.
o.
0,
o.
0,
0,
0,
0,
o.
o.
o.
o.
.20
.45
.45
.45
.45
.45
.45
.24
.23
.28
.26 0.45
.25 0.45
.24 0.45
.27 0.45
0.46 0
0.56 0
0.56 0
0.56 0
0.56 0
0.56 0
0.56 0
0.56 0
0.56 0
0.56 0
.26
.38
.38
.38
.38
.38
.38
.38
.38
.34
0.47 0.50
0.42 0.50
Page: 3
-------
2007 Acid Rain Program NOx Compliance Summary
State
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
CO
CO
CO
CO
Facility Name
Cholla
Cholla
Cholla
Cholla
Coronado Generating Station
Coronado Generating Station
Irvington Generating Station
Navajo Generating Station
Navajo Generating Station
Navajo Generating Station
Springerville Generating
Station
Springerville Generating
Station
Arapahoe
Arapahoe
Cameo
Cherokee
Facility ID
(ORISPL)
113
113
113
113
6177
6177
126
4941
4941
4941
8223
8223
465
465
468
469
Unit ID
1
2
3
4
U1B
U2B
4
1
2
3
1
2
3
4
2
1
Unit Operator(s)
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
Compliance
Approach
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Standard Limit
Early Election
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Standard Limit
Averaging Plan
Standard
Emissions
Limit
0.40
0.40
0.40
0.40
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.40
0.80
0.80
0.46
0.80
Actual
Emission Rate
0.38
0.36
0.34
0.33
0.41
0.45
0.42
0.38
0.35
0.33
0.19
0.19
0.76
0.27
0.35
0.33
Early Election AEL (if Averaging Plan Limit (if
Limit (if applicable) applicable)
applicable)
0.45
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.80
0.80
0.80
Actual Averaging
Plan Rate (if
applicable)
0.43
0.43
0.51
Page: 4
-------
2007 Acid Rain Program NOx Compliance Summary
State
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
Facility Name
Cherokee
Cherokee
Cherokee
Comanche (470)
Comanche (470)
Craig
Craig
Craig
Hayden
Hayden
Martin Drake
Martin Drake
Martin Drake
Pawnee
Rawhide Energy Station
Ray D Nixon
Facility ID
(ORISPL)
469
469
469
470
470
6021
6021
6021
525
525
492
492
492
6248
6761
8219
Unit ID
2
3
4
1
2
C1
C2
C3
H1
H2
5
6
7
1
101
1
Unit Operator(s)
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
Compliance
Approach
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Standard Limit
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Standard
Emissions
Limit
0.80
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.46
0.40
0.46
0.46
0.46
0.46
0.40
0.46
Actual
Emission Rate
0.68
0.31
0.34
0.33
0.27
0.29
0.27
0.38
0.42
0.32
0.39
0.42
0.41
0.22
0.16
0.26
Early Election AEL (if Averaging Plan Limit (if
Limit (if applicable) applicable)
applicable)
0.80
0.50
0.45
0.45
0.50
0.50
0.50
0.50
0.46
0.46
0.46
0.50
0.45
0.50
Actual Averaging
Plan Rate (if
applicable)
0.51
0.41
0.41
0.41
Page: 5
-------
2007 Acid Rain Program NOx Compliance Summary
State
CO
CT
DE
DE
DE
DE
DE
DE
FL
FL
FL
FL
FL
FL
FL
FL
Facility Name
Valmont
Bridgeport Harbor Station
Edge Moor
Edge Moor
Indian River
Indian River
Indian River
Indian River
Big Bend
Big Bend
Big Bend
Big Bend
C D Mclntosh Jr Power Plant
Crist Electric Generating Plant
Crist Electric Generating Plant
Crist Electric Generating Plant
Facility ID
(ORISPL)
477
568
593
593
594
594
594
594
645
645
645
645
676
641
641
641
Unit ID
5
BHB3
3
4
1
2
3
4
BB01
BB02
BB03
BB04
3
4
5
6
Unit Operator(s)
Public Service Company of
Colorado
PSEG Power Connecticut
LLC
Conectiv Delmarva
Generation, LLC
Conectiv Delmarva
Generation, LLC
Indian River Operations, Inc.
Indian River Operations, Inc.
Indian River Operations, Inc.
Indian River Operations, Inc.
Tampa Electric Company
Tampa Electric Company
Tampa Electric Company
Tampa Electric Company
Lakeland Electric
Gulf Power Company
Gulf Power Company
Gulf Power Company
Compliance
Approach
Early Election
Early Election
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
0.40
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.84
0.84
0.84
0.45
0.46
0.45
0.45
0.50
Actual Early Election AEL (if Averaging Plan Limit (if Actual Averaging
Emission Rate Limit (if applicable) applicable) Plan Rate (if
applicable) applicable)
0,
0,
o.
o.
0,
o.
0,
0,
0,
0,
0,
0,
0,
0,
.33 0.45
.14 0.45
.24
.25
.38
.37
.31
.33
.65
.65
.40
.11
.38 0.50
.34
0.31
0.26
0.76 0.49
0.76 0.49
0.76 0.49
0.76 0.49
0.46 0.26
0.46 0.26
0.46 0.26
Page: 6
-------
2007 Acid Rain Program NOx Compliance Summary
State
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
GA
Facility Name
Crist Electric Generating Plant
Crystal River
Crystal River
Crystal River
Crystal River
Curtis H. Stanton Energy
Center
Deerhaven
Lansing Smith Generating
Plant
Lansing Smith Generating
Plant
Scholz Electric Generating
Plant
Scholz Electric Generating
Plant
Seminole (136)
Seminole (136)
St. Johns River Power
St. Johns River Power
Bowen
Facility ID
(ORISPL)
641
628
628
628
628
564
663
643
643
642
642
136
136
207
207
703
Unit ID
7
1
2
4
5
1
B2
1
2
1
2
1
2
1
2
1BLR
Unit Operator(s)
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limit
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.08
0.37
0.38
0.49
0.47
0.37
0.46 0.50
0.49
0.38
0.58
0.58
0.35 0.50
0.40 0.50
0.42 0.50
0.45 0.50
0.14
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.46
0.44
0.44
0.44
0.44
0.46
0.46
0.46
0.46
0.46
Actual Averaging
Plan Rate (if
applicable)
0.26
0.27
0.27
0.27
0.27
0.26
0.26
0.26
0.26
0.26
Page: 7
-------
2007 Acid Rain Program NOx Compliance Summary
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
Facility Name
Bowen
Bowen
Bowen
Hammond
Hammond
Hammond
Hammond
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Jack McDonough
Jack McDonough
Kraft
Kraft
Kraft
Mclntosh (6124)
Mitchell (GA)
Scherer
Scherer
Scherer
Scherer
Wansley (6052)
Wansley (6052)
Yates
Yates
Facility ID
(ORISPL)
703
703
703
708
708
708
708
709
709
709
709
710
710
733
733
733
6124
727
6257
6257
6257
6257
6052
6052
728
728
Unit ID
2BLR
3BLR
4BLR
1
2
3
4
1
2
3
4
MB1
MB2
1
2
3
1
3
1
2
3
4
1
2
Y1BR
Y2BR
Unit Operator(s)
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Georgia
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Power Company
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
0.45
0.45
0.45
0.50
0.50
0.50
0.50
0.68
0.50
0.68
0.68
0.45
0.45
0.45
0.45
0.45
0.50
0.45
0.40
0.40
0.45
0.40
0.45
0.45
0.45
0.45
Actual Early Election
Emission Rate Limit (if
applicable)
0.21
0.16
0.16
0.38
0.38
0.38
0.25
0.48
0.48
0.40
0.40
0.24
0.24
0.55
0.55
0.55
0.54
0.59
0.16
0.14
0.13
0.14 0.45
0.21
0.24
0.41 0.00
0.47
AEL (if Averaging Plan Limit (if
applicable) applicable)
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
Actual Averaging
Plan Rate (if
applicable)
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
Page: 8
-------
2007 Acid Rain Program NOx Compliance Summary
State
GA
GA
GA
GA
GA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
Facility Name
Yates
Yates
Yates
Yates
Yates
Ames
Ames
Burlington (IA)
Dubuque
Dubuque
Earl F Wisdom
Fair Station
George Neal North
George Neal North
George Neal South
Lansing
Lansing
Lansing
Facility ID
(ORISPL)
728
728
728
728
728
1122
1122
1104
1046
1046
1217
1218
1091
1091
7343
1047
1047
1047
Unit ID
Y3BR
Y4BR
Y5BR
Y6BR
Y7BR
7
8
1
1
5
1
2
2
3
4
1
2
3
Unit Operator(s)
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
Georgia Power Company
City of Ames
City of Ames
IES Utilities, Inc
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Standard Limit
Averaging Plan
Averaging Plan
Alternative
Emissions Limit
Standard Limit
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
0.45
0.45
0.45
0.45
0.45
0.40
0.46
0.45
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
Actual Early Election
Emission Rate Limit (if
applicable)
0.47
0.38
0.38
0.27
0.27
0.33 0.45
0.39 0.50
0.15
0.62
0.75
0.57
0.41
0.31 0.50
0.24 0.50
0.21 0.50
0.00
0.55
0.66
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.59
0.46
0.46
0.46
Actual Averaging
Plan Rate (if
applicable)
0,
0,
0,
0,
0,
0,
0,
0,
0,
0,
.26
.26
.26
.26
.26
.32
.32
.32
.32
.32
Page: 9
-------
2007 Acid Rain Program NOx Compliance Summary
State
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IL
Facility Name
Lansing
Louisa
Milton L Kapp
Muscatine
Ottumwa
Prairie Creek
Prairie Creek
Riverside (1081)
Sixth Street
Sixth Street
Sixth Street
Sixth Street
Sutherland
Sutherland
Walter Scott Jr. Energy Center
Walter Scott Jr. Energy Center
Walter Scott Jr. Energy Center
Baldwin Energy Complex
Facility ID
(ORISPL)
1047
6664
1048
1167
6254
1073
1073
1081
1058
1058
1058
1058
1077
1077
1082
1082
1082
889
Unit ID
4
101
2
9
1
3
4
9
2
3
4
5
1
2
1
2
3
1
Unit Operator(s)
Interstate Power & Light
Company
MidAmerican Energy
Company
Interstate Power & Light
Company
Muscatine Power and Water
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
MidAmerican Energy
Company
MidAmerican Energy
Company
MidAmerican Energy
Company
Dynegy Midwest
Generation, Inc.
Compliance
Approach
Early Election
Early Election
Averaging Plan
Standard Limit
Early Election
Averaging Plan
Standard Limit
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Standard Limit
Standard
Emissions
Limit
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
0.46
0.40
0.46
0.86
Actual Early Election AEL (if Averaging Plan Limit (if
Emission Rate Limit (if applicable) applicable)
applicable)
0.46 0.50
0.18 0.50
0.12 0.46
0.21
0.18 0.45
0.50 0.46
0.36
0.24
0.35 0.46
0.24 0.46
0.27 0.46
0.18 0.46
0.31 0.46
0.27 0.46
0.34 0.50
0.42 0.45
0.18 0.50
0.07
Actual Averaging
Plan Rate (if
applicable)
0.32
0.32
0.32
0.32
0.32
0.32
0.32
0.32
Page: 10
-------
2007 Acid Rain Program NOx Compliance Summary
State
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
Facility Name
Baldwin Energy Complex
Baldwin Energy Complex
Coffeen
Coffeen
Crawford
Crawford
Dallman
Duck Creek
E D Edwards
E D Edwards
E D Edwards
Fisk
Havana
Facility ID
(ORISPL)
889
889
861
861
867
867
963
6016
856
856
856
886
891
Unit ID
2
3
01
02
7
8
33
1
1
2
3
19
9
Unit Operator(s)
Dynegy Midwest
Generation, Inc.
Dynegy Midwest
Generation, Inc.
Ameren Energy Generating
Company
Ameren Energy Generating
Company
Midwest Generation EME,
LLC
Midwest Generation EME,
LLC
City of Springfield, IL
AmerenEnergy Resources
Generating Company
AmerenEnergy Resources
Generating Company
AmerenEnergy Resources
Generating Company
AmerenEnergy Resources
Generating Company
Midwest Generation EME,
LLC
Dynegy Midwest
Generation, Inc.
Compliance
Approach
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Standard Limit
Standard
Emissions
Limit
0.86
0.45
0.86
0.86
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.40
0.46
Actual Early Election
Emission Rate Limit (if
applicable)
0.07
0.09
0.35
0.35
0.14 0.45
0.16 0.45
0.23 0.45
0.28
0.25
0.25
0.15
0.13 0.45
0.05
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.44
0.72
0.72
0.46
0.46
0.46
0.46
Actual Averaging
Plan Rate (if
applicable)
0.13
0.33
0.33
0.21
0.21
0.21
0.21
Page: 11
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2007 Acid Rain Program NOx Compliance Summary
State
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
Facility Name
Hennepin Power Station
Hennepin Power Station
Hutsonville
Hutsonville
Joliet 29
Joliet 29
Joliet 29
Joliet 29
Joliet 9
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Kincaid Station
Kincaid Station
Facility ID
(ORISPL)
892
892
863
863
384
384
384
384
874
887
887
887
887
887
887
876
876
Unit ID
1
2
05
06
71
72
81
82
5
1
2
3
4
5
6
1
2
Unit Operator(s)
Dynegy Midwest
Generation, Inc.
Dynegy Midwest
Generation, Inc.
Ameren Energy Generating
Company
Ameren Energy Generating
Company
Midwest Generation EME,
LLC
Midwest Generation EME,
LLC
Midwest Generation EME,
LLC
Midwest Generation EME,
LLC
Midwest Generation EME,
LLC
Electric Energy, Inc.
Electric Energy, Inc.
Electric Energy, Inc.
Electric Energy, Inc.
Electric Energy, Inc.
Electric Energy, Inc.
Dominion Energy Services
Company
Dominion Energy Services
Company
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard
Emissions
Limit
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
Actual Early Election AEL (if Averaging Plan Limit (if
Emission Rate Limit (if applicable) applicable)
applicable)
0.11 0.44
0.11 0.44
0.23 0.72
0.23 0.72
0.11
0.11
0.11
0.11
0.38
0.13
0.13
0.13
0.13
0.11
0.11
0.38
0.38
Actual Averaging
Plan Rate (if
applicable)
0.13
0.13
0.33
0.33
Page: 12
-------
2007 Acid Rain Program NOx Compliance Summary
State Facility Name
Facility ID
(ORISPL)
Unit ID Unit Operator(s)
Compliance
Approach
Standard Actual Early Election AEL (if Averaging Plan Limit (if Actual Averaging
Emissions Emission Rate Limit (if applicable) applicable) Plan Rate (if
Limit applicable) applicable)
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
976 4 Southern Illinois Power Standard Limit
Cooperative
864 01 Ameren Energy Generating Averaging Plan
Company
864 02 Ameren Energy Generating Averaging Plan
Company
864 03 Ameren Energy Generating Averaging Plan
Company
864 04 Ameren Energy Generating Averaging Plan
Company
864 05 Ameren Energy Generating Averaging Plan
Company
6017 1 Ameren Energy Generating Standard Limit
Company
6017 2 Ameren Energy Generating Standard Limit
Company
879 51 Midwest Generation EME, Standard Limit
LLC
879 52 Midwest Generation EME, Standard Limit
LLC
879 61 Midwest Generation EME, Standard Limit
LLC
879 62 Midwest Generation EME, Standard Limit
LLC
897 1 Dynegy Midwest Averaging Plan
Generation, Inc.
897 2 Dynegy Midwest Averaging Plan
Generation, Inc.
883 7 Midwest Generation EME, Early Election
LLC
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
0.58
0.47
0.47
0.47
0.47
0.25
0.09
0.10
0.59
0.59
0.59
0.59
0.27
0.27
0.13
0.72
0.72
0.72
0.72
0.72
0.44
0.44
0.33
0.33
0.33
0.33
0.33
0.13
0.13
0.45
Page: 13
-------
2007 Acid Rain Program NOx Compliance Summary
State
IL
IL
IL
IL
IL
IL
IL
IN
IN
IN
IN
IN
IN
Facility Name
Waukegan
Will County
Will County
Will County
Will County
Wood River Power Station
Wood River Power Station
A B Brown Generating Station
A B Brown Generating Station
Alcoa Allowance Management
Inc
Bailly Generating Station
Bailly Generating Station
Cayuga
Facility ID
(ORISPL)
883
884
884
884
884
898
898
6137
6137
6705
995
995
1001
Unit ID
8
1
2
3
4
4
5
1
2
4
7
8
1
Unit Operator(s)
Midwest Generation EME,
LLC
Midwest Generation EME,
LLC
Midwest Generation EME,
LLC
Midwest Generation EME,
LLC
Midwest Generation EME,
LLC
Dynegy Midwest
Generation, Inc.
Dynegy Midwest
Generation, Inc.
Southern Indiana Gas and
Electric Company
Southern Indiana Gas and
Electric Company
Alcoa Allowance
Management, Inc.
Northern Indiana Public
Service Company
Northern Indiana Public
Service Company
Duke Energy Corporation,
Duke Energy Corporation
Compliance
Approach
Early Election
Standard Limit
Standard Limit
Early Election
Early Election
Standard Limit
Averaging Plan
Early Election
Early Election
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
0.40
0.86
0.86
0.40
0.40
0.40
0.40
0.46
0.46
0.68
0.86
0.86
0.45
Actual Early Election AEL (if Averaging Plan Limit (if
Emission Rate Limit (if applicable) applicable)
applicable)
0.12 0.45
0.42
0.44
0.14 0.45
0.13 0.45
0.14
0.16 0.44
0.29 0.50
0.28 0.50
0.28
0.75 0.74
0.75 0.74
0.31 0.48
Actual Averaging
Plan Rate (if
applicable)
0.13
0.45
0.45
0.22
IN Cayuga
1001
Duke Energy Corporation, Averaging Plan
Duke Energy Corporation
0.45
0.31
0.48
0.22
Page: 14
-------
2007 Acid Rain Program NOx Compliance Summary
State
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
Facility Name
Cliffy Creek
Cliffy Creek
Cliffy Creek
Cliffy Creek
Cliffy Creek
Cliffy Creek
Dean H Mitchell Generating
Station
Dean H Mitchell Generating
Station
Dean H Mitchell Generating
Station
Dean H Mitchell Generating
Station
Edwardsport
Edwardsport
Edwardsport
Facility ID
(ORISPL)
983
983
983
983
983
983
996
996
996
996
1004
1004
1004
Unit ID
1
2
3
4
5
6
11
4
5
6
7-1
7-2
8-1
Unit Operator(s)
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
Duke Energy Corporation,
Duke Energy Corporation
Duke Energy Corporation,
Duke Energy Corporation
Duke Energy Corporation,
Compliance
Approach
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
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.46
0.46
0.46
0.54
0.54
0.54
0.00 0.50
0.00 0.45
0.00 0.45
0.00 0.45
0.63
0.54
0.58
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.84
0.84
0.84
0.84
0.84
0.84
0.48
0.48
0.48
Actual Averaging
Plan Rate (if
applicable)
0.46
0.46
0.46
0.46
0.46
0.46
0.22
0.22
0.22
Duke Energy Corporation
Page: 15
-------
2007 Acid Rain Program NOx Compliance Summary
State
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
Facility Name
F B Culley Generating Station
F B Culley Generating Station
Frank E Ratts
Frank E Ratts
Gibson
Gibson
Gibson
Gibson
Gibson
Harding Street Station (EW
Stout)
Harding Street Station (EW
Stout)
Harding Street Station (EW
Stout)
IPL Eagle Valley Generating
Station
Facility ID
(ORISPL)
1012
1012
1043
1043
6113
6113
6113
6113
6113
990
990
990
991
Unit ID
2
3
1SG1
2SG1
1
2
3
4
5
50
60
70
3
Unit Operator(s)
Southern Indiana Gas and
Electric Company
Southern Indiana Gas and
Electric Company
Hoosier Energy REC, Inc.
Hoosier Energy REC, Inc.
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
Indianapolis Power & Light
Company
Indianapolis Power & Light
Company
Indianapolis Power & Light
Company
Indianapolis Power & Light
Company
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.15
0.15
0.60
0.46
0.27
0.32
0.29
0.28
0.29
0.32
0.27
0.19
0.48
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.50
0.50
0.47
0.47
0.48
0.48
0.48
0.48
0.48
0.45
0.45
0.45
0.45
Actual Averaging
Plan Rate (if
applicable)
0.15
0.15
0.27
0.27
0.22
0.22
0.22
0.22
0.22
0.26
0.26
0.26
0.26
Page: 16
-------
2007 Acid Rain Program NOx Compliance Summary
State
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
Facility Name
IPL Eagle Valley Generating
Station
IPL Eagle Valley Generating
Station
IPL Eagle Valley Generating
Station
Merom
Merom
Michigan City Generating
Station
Petersburg
Petersburg
Petersburg
Petersburg
R Gallagher
R Gallagher
R Gallagher
R Gallagher
Facility ID
(ORISPL)
991
991
991
6213
6213
997
994
994
994
994
1008
1008
1008
1008
Unit ID
4
5
6
1SG1
2SG1
12
1
2
3
4
1
2
3
4
Unit Operator(s)
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
Duke Energy Corporation,
Duke Energy Corporation
Duke Energy Corporation,
Duke Energy Corporation
Duke Energy Corporation,
Duke Energy Corporation
Duke Energy Corporation,
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
0.45
0.45
0.45
0.46
0.46
0.86
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.50
Actual Early Election
Emission Rate Limit (if
applicable)
0.48
0.30
0.30
0.20 0.50
0.21 0.50
0.38
0.27
0.25
0.26
0.25
0.34
0.34
0.34
0.34
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.45
0.45
0.45
0.47
0.47
0.74
0.45
0.45
0.45
0.45
0.48
0.48
0.48
0.48
Actual Averaging
Plan Rate (if
applicable)
0.26
0.26
0.26
0.27
0.27
0.45
0.26
0.26
0.26
0.26
0.22
0.22
0.22
0.22
Duke Energy Corporation
Page: 17
-------
2007 Acid Rain Program NOx Compliance Summary
State
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
Facility Name
R M Schahfer Generating
Station
R M Schahfer Generating
Station
R M Schahfer Generating
Station
R M Schahfer Generating
Station
Rockport
Rockport
State Line Generating Station
(IN)
State Line Generating Station
(IN)
Tanners Creek
Tanners Creek
Tanners Creek
Tanners Creek
Wabash River Gen Station
Wabash River Gen Station
Facility ID
(ORISPL)
6085
6085
6085
6085
6166
6166
981
981
988
988
988
988
1010
1010
Unit ID
14
15
17
18
MB1
MB2
3
4
U1
U2
U3
U4
1
2
Unit Operator(s)
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
Duke Energy Corporation
Duke Energy Corporation,
Duke Energy Corporation
Compliance
Approach
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
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.46
0.27 0.50
0.17 0.45
0.18 0.45
0.25
0.25
0.22 0.45
0.65
0.33
0.33
0.33
0.26
0.08
0.36
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.74
0.74
0.56
0.56
0.69
0.69
0.56
0.56
0.56
0.56
0.48
0.48
Actual Averaging
Plan Rate (if
applicable)
0.45
0.45
0.34
0.34
0.49
0.49
0.34
0.34
0.34
0.34
0.22
0.22
Page: 18
-------
2007 Acid Rain Program NOx Compliance Summary
State
IN
IN
IN
IN
IN
IN
KS
KS
KS
KS
KS
KS
KS
KS
KS
KS
Facility Name
Wabash River Gen Station
Wabash River Gen Station
Wabash River Gen Station
Wabash River Gen Station
Whitewater Valley
Whitewater Valley
Holcomb
Jeffrey Energy Center
Jeffrey Energy Center
Jeffrey Energy Center
La Cygne
La Cygne
Lawrence Energy Center
Lawrence Energy Center
Lawrence Energy Center
Nearman Creek
Facility ID
(ORISPL)
1010
1010
1010
1010
1040
1040
108
6068
6068
6068
1241
1241
1250
1250
1250
6064
Unit ID
3
4
5
6
1
2
SGU1
1
2
3
1
2
3
4
5
N1
Unit Operator(s)
Duke Energy Corporation,
Duke Energy Corporation
Duke Energy Corporation,
Duke Energy Corporation
Duke Energy Corporation,
Duke Energy Corporation
Duke Energy Corporation,
Duke Energy Corporation
City of Richmond
City of Richmond
Sunflower Electric Power
Corporation
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 Board of Public
Utilities
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Standard
Emissions
Limit
0.50
0.46
0.50
0.45
0.46
0.40
0.46
0.40
0.40
0.40
0.86
0.50
0.40
0.40
0.40
0.46
Actual Early Election
Emission Rate Limit (if
applicable)
0.36
0.36
0.36
0.36
0.34 0.50
0.34 0.45
0.31
0.41
0.36
0.16
0.35
0.31
0.23
0.34
0.18
0.43 0.50
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.48
0.48
0.48
0.48
0.40
0.40
0.40
0.68
0.68
0.40
0.40
0.40
Actual Averaging
Plan Rate (if
applicable)
0.22
0.22
0.22
0.22
0.30
0.30
0.30
0.33
0.33
0.30
0.30
0.30
Page: 19
-------
2007 Acid Rain Program NOx Compliance Summary
State
KS
KS
KS
KS
KS
KS
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
Facility Name
Quindaro
Quindaro
Riverton
Riverton
Tecumseh Energy Center
Tecumseh Energy Center
Big Sandy
Big Sandy
Cane Run
Cane Run
Cane Run
Coleman
Coleman
Coleman
D B Wilson
E W Brown
Facility ID
(ORISPL)
1295
1295
1239
1239
1252
1252
1353
1353
1363
1363
1363
1381
1381
1381
6823
1355
Unit ID
1
2
39
40
10
9
BSU1
BSU2
4
5
6
C1
C2
C3
W1
1
Unit Operator(s)
Kansas City Board of Public
Utilities
Kansas City Board 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
Western Kentucky Energy
Corporation
Western Kentucky Energy
Corporation
Louisville Gas and Electric
Company
Compliance
Approach
Standard Limit
Standard Limit
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
0.86
0.50
0.46
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.40
0.50
0.50
0.50
0.46
0.50
Actual Early Election
Emission Rate Limit (if
applicable)
0.78
0.27
0.43 0.50
0.38 0.45
0.35
0.37
0.42
0.42
0.35 0.50
0.39 0.50
0.31 0.45
0.31
0.31
0.31
0.34
0.47
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.40
0.40
0.56
0.56
0.49
0.49
0.49
0.49
0.45
Actual Averaging
Plan Rate (if
applicable)
0.30
0.30
0.34
0.34
0.32
0.32
0.32
0.32
0.28
Page: 20
-------
2007 Acid Rain Program NOx Compliance Summary
State
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
Facility Name
E W Brown
E W Brown
East Bend
Elmer Smith
Ghent
Ghent
Ghent
Ghent
Green River
Green River
H L Spurlock
H L Spurlock
HMP&L Station 2
HMP&L Station 2
John S. Cooper
Facility ID
(ORISPL)
1355
1355
6018
1374
1356
1356
1356
1356
1357
1357
6041
6041
1382
1382
1384
Unit ID
2
3
2
2
1
2
3
4
4
5
1
2
H1
H2
1
Unit Operator(s)
Louisville Gas and Electric
Company
Louisville Gas and Electric
Company
Duke Energy Corporation,
Duke Energy Corporation
Owensboro Municipal
Utilities
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
Compliance
Approach
Averaging
Averaging
Averaging
Plan
Plan
Plan
Standard Limit
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Plan
Plan
Plan
Plan
Plan
Plan
Standard Limit
Early Election
Averaging
Averaging
Plan
Plan
Standard Limit
Standard
Emissions
Limit
0.45
0.45
0.50
0.45
0.45
0.40
0.46
0.46
0.46
0.50
0.50
0.40
0.50
0.50
0.50
Actual Early Election AEL (if Averaging Plan Limit (if
Emission Rate Limit (if applicable) applicable)
applicable)
0.33
0.33
0.29
0.24
0.23
0.28
0.25
0.22
0.39
0.38
0.26
0.17 0.45
0.32
0.30
0.48
0.45
0.45
0.48
0.45
0.45
0.45
0.45
0.45
0.45
0.49
0.49
Actual Averaging
Plan Rate (if
applicable)
0,
0,
o.
o.
0,
0,
0,
0,
o.
o.
o.
.28
.28
.22
.28
.28
.28
.28
.28
.28
.32
.32
Page: 21
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2007 Acid Rain Program NOx Compliance Summary
State
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
Facility Name
John S. Cooper
Mill Creek
Mill Creek
Mill Creek
Mill Creek
Paradise
Paradise
Paradise
R D Green
R D Green
Robert Reid
Shawnee
Shawnee
Shawnee
Shawnee
Facility ID
(ORISPL)
1384
1364
1364
1364
1364
1378
1378
1378
6639
6639
1383
1379
1379
1379
1379
Unit ID
2
1
2
3
4
1
2
3
G1
G2
R1
1
2
3
4
Unit Operator(s)
Compliance
Approach
East Kentucky Power
Cooperative
Louisville Gas and
Company
Louisville Gas and
Company
Louisville Gas and
Company
Louisville Gas and
Company
Tennessee Valley
Electric
Electric
Electric
Electric
Authority
Tennessee Valley Authority
Tennessee Valley Authority
Western Kentucky
Corporation
Western Kentucky
Corporation
WKE Station Two,
Tennessee Valley
Tennessee Valley
Tennessee Valley
Tennessee Valley
Energy
Energy
Inc.
Authority
Authority
Authority
Authority
Standard Limit
Early Election
Early Election
Early Election
Early Election
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Standard
Emissions
Limit
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
Actual Early Election AEL (if Averaging Plan Limit (if Actual Averaging
Emission Rate Limit (if applicable) applicable) Plan Rate (if
applicable) applicable)
0,
0,
o.
o.
0,
o.
0,
0,
0,
0,
o.
o.
o.
o.
o.
.48
.32 0.45
.32 0.45
.22 0.50
.22 0.50
.47
.66
.71
.29
.28
.47
.37
.37
.37
.37
0.56 0.38
0.56 0.38
0.56 0.38
0.49 0.32
0.49 0.32
0.49 0.32
0.56 0.38
0.56 0.38
0.56 0.38
0.56 0.38
Page: 22
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2007 Acid Rain Program NOx Compliance Summary
State
KY
KY
KY
KY
KY
KY
KY
KY
KY
LA
LA
LA
LA
LA
LA
Facility Name
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Trimble County
Tyrone
William C. Dale
William C. Dale
Big Cajun 2
Big Cajun 2
Big Cajun 2
Dolet Hills Power Station
R S Nelson
Rodemacher Power Station
Facility ID
(ORISPL)
1379
1379
1379
1379
1379
6071
1361
1385
1385
6055
6055
6055
51
1393
6190
Unit ID
5
6
7
8
9
1
5
3
4
2B1
2B2
2B3
1
6
2
Unit Operator(s)
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
Louisiana Generating, LLC
CLECO Power, LLC
Entergy Corporation
CLECO Power, LLC
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Standard
Emissions
Limit
0.46
0.46
0.46
0.46
0.46
0.40
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.40
0.46
Actual Early Election AEL (if Averaging Plan Limit (if Actual Averaging
Emission Rate Limit (if applicable) applicable) Plan Rate (if
applicable) applicable)
0,
0,
o.
o.
0,
o.
0,
0,
0,
0,
o.
o.
o.
o.
o.
.37
.37
.37
.37
.37
.21 0.45
.42
.40 0.50
.40 0.50
.20 0.50
.20 0.50
.15 0.50
.25 0.50
.22 0.45
.38 0.50
0.56 0.38
0.56 0.38
0.56 0.38
0.56 0.38
0.56 0.38
0.45 0.28
(6190)
MA Brayton Point
1619
Dominion Energy Brayton
Point, LLC
Standard Limit
0.40
0.10
Page: 23
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2007 Acid Rain Program NOx Compliance Summary
State
MA
MA
MA
MA
MA
MA
MA
MA
MD
MD
MD
MD
MD
MD
MD
Facility Name
Brayton Point
Brayton Point
Mount Tom
Salem Harbor
Salem Harbor
Salem Harbor
Somerset
Somerset
Brandon Shores
Brandon Shores
Brandon Shores
Brandon Shores
Brandon Shores
Brandon Shores
C P Crane
Facility ID
(ORISPL)
1619
1619
1606
1626
1626
1626
1613
1613
602
602
602
602
602
602
1552
Unit ID
2
3
1
1
2
3
7
8
1
1
1
2
2
2
1
Unit Operator(s)
Dominion Energy Brayton
Point, LLC
Dominion Energy Brayton
Point, LLC
FirstLight Power Resources
Services, LLC
Dominion Energy Salem
Harbor, LLC
Dominion Energy Salem
Harbor, LLC
Dominion Energy Salem
Harbor, LLC
Somerset Power, LLC
Somerset Power, LLC
Constellation Power Source
Generation Inc.
Constellation Power Source
Generation Inc.
Constellation Power Source
Generation Inc.
Constellation Power Source
Generation Inc.
Constellation Power Source
Generation Inc.
Constellation Power Source
Generation Inc.
Constellation Power Source
Generation Inc.
Compliance
Approach
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
0.40
0.46
0.46
0.46
0.46
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.46
0.46
0.86
Actual Early Election
Emission Rate Limit (if
applicable)
0.23
0.11
0.11
0.14
0.13
0.16
0.00
0.12
0.26
0.26
0.26
0.38
0.38
0.38
0.57
AEL (if Averaging Plan Limit (if Actual Averaging
applicable) applicable) Plan Rate (if
applicable)
0.56 0.35
0.56 0.35
0.56 0.35
0.56 0.35
0.56 0.35
0.56 0.35
0.56 0.35
Page: 24
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2007 Acid Rain Program NOx Compliance Summary
State
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
Ml
Ml
Ml
Ml
Ml
Facility Name
C P Crane
Herbert A Wagner
Herbert A Wagner
Mirant Chalk Point
Mirant Chalk Point
Mirant Dickerson
Mirant Dickerson
Mirant Dickerson
Mirant Morgantown
Mirant Morgantown
R. Paul Smith Power Station
R. Paul Smith Power Station
B C Cobb
B C Cobb
B C Cobb
B C Cobb
B C Cobb
Facility ID
(ORISPL)
1552
1554
1554
1571
1571
1572
1572
1572
1573
1573
1570
1570
1695
1695
1695
1695
1695
Unit ID
2
2
3
1
2
1
2
3
1
2
11
9
1
2
3
4
5
Unit Operator(s)
Constellation Power Source
Generation Inc.
Constellation Power Source
Generation Inc.
Constellation Power Source
Generation Inc.
Mirant Chalk Point, LLC
Mirant Chalk Point, LLC
Mirant Mid-Atlantic, LLC
Mirant Mid-Atlantic, LLC
Mirant Mid-Atlantic, LLC
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Alternative
Emissions Limit
Alternative
Emissions Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
0.86
0.46
0.68
0.50
0.50
0.40
0.40
0.40
0.45
0.45
0.45
0.50
0.40
0.40
0.40
0.40
0.40
Actual Early Election
Emission Rate Limit (if
applicable)
0.51
0.45
0.21
0.45
0.45
0.34
0.34
0.34
0.19
0.36
0.36
0.43
0.05
0.04
0.06
0.38
0.17
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.56
0.56
0.56
0.70
0.70
0.56
0.56
0.47
0.47
0.47
0.47
0.47
Actual Averaging
Plan Rate (if
applicable)
0.35
0.35
0.35
0.34
0.34
0.23
0.23
0.23
0.23
0.23
Page: 25
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2007 Acid Rain Program NOx Compliance Summary
State
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Facility Name
Belle River
Belle River
Dan E Karn
Dan E Karn
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Eckert Station
Endicott Generating
Erickson
Harbor Beach
J B Sims
J C Weadock
J C Weadock
Facility ID
(ORISPL)
6034
6034
1702
1702
1831
1831
1831
1831
1831
1831
4259
1832
1731
1825
1720
1720
Unit ID
1
2
1
2
1
2
3
4
5
6
1
1
1
3
7
8
Unit Operator(s)
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
Consumers Energy
Company
Consumers Energy
Company
Compliance
Approach
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Standard Limit
Averaging
Averaging
Plan
Plan
Early Election
Averaging
Averaging
Plan
Plan
Standard
Emissions
Limit
0.46
0.46
0.40
0.46
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.40
0.40
Actual Early Election AEL (if Averaging Plan Limit (if
Emission Rate Limit (if applicable) applicable)
applicable)
0.22
0.17
0.26
0.17
0.21
0.25
0.16
0.20
0.20
0.22
0.18
0.20
0.61
0.25 0.50
0.34
0.32
0.55
0.55
0.47
0.47
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.55
0.47
0.47
Actual Averaging
Plan Rate (if
applicable)
0,
0,
0,
0,
o.
o.
0,
o.
0,
0,
0,
o.
o.
o.
.30
.30
.23
.23
.20
.20
.20
.20
.20
.20
.20
.30
.23
.23
Page: 26
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2007 Acid Rain Program NOx Compliance Summary
State
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Facility Name
J H Campbell
J H Campbell
J H Campbell
J R Whiting
J R Whiting
J R Whiting
James De Young
Marysville
Marysville
Marysville
Marysville
Monroe
Monroe
Monroe
Monroe
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Facility ID
(ORISPL)
1710
1710
1710
1723
1723
1723
1830
1732
1732
1732
1732
1733
1733
1733
1733
1769
1769
1769
1769
Unit ID
1
2
3
1
2
3
5
10
11
12
9
1
2
3
4
3
4
5
6
Unit Operator(s)
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limit
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
Emissions
Limit
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
0.46
0.46
Actual Early Election
Emission Rate Limit (if
applicable)
0.17
0.32
0.17
0.24
0.24
0.23
0.46
0.00
0.00
0.00
0.00
0.41
0.41
0.30
0.30
0.31
0.31
0.38
0.37
AEL (if Averaging Plan Limit (if
applicable) applicable)
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
0.46
0.46
0.46
0.46
Actual Averaging
Plan Rate (if
applicable)
0.23
0.23
0.23
0.23
0.23
0.23
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.17
0.17
0.17
0.17
Page: 27
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2007 Acid Rain Program NOx Compliance Summary
State
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
MN
MN
Facility Name
Presque Isle
Presque Isle
Presque Isle
River Rouge
River Rouge
Shiras
St. Clair
St. Clair
St. Clair
St. Clair
St. Clair
St. Clair
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Wyandotte
Allen S King
Black Dog
Facility ID
(ORISPL)
1769
1769
1769
1740
1740
1843
1743
1743
1743
1743
1743
1743
1745
1745
1745
1745
1745
1866
1915
1904
Unit ID
7
8
9
2
3
3
1
2
3
4
6
7
16
17
18
19
9A
7
1
3
Unit Operator(s)
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
Wyandotte Municipal
Services
Northern States Power (Xcel
Energy)
Northern States Power (Xcel
Energy)
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limit
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0,
0,
o.
o.
0,
o.
o.
o.
o.
o.
o.
o.
o.
o.
o.
o.
o.
o.
.40
.41
.41
.23
.34
.14
.40
.37
.40
.35
.15
.18
.42
.42
.42
.42
.18
.38
0.80
0.67
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.46
0.46
0.46
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.50
0.50
Actual Averaging
Plan Rate (if
applicable)
0.17
0.17
0.17
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.41
0.41
Page: 28
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2007 Acid Rain Program NOx Compliance Summary
State
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
MN
Facility Name
Black Dog
Boswell Energy Center
Boswell Energy Center
Boswell Energy Center
Boswell Energy Center
High Bridge
High Bridge
High Bridge
High Bridge
Hoot Lake
Hoot Lake
Laskin Energy Center
Laskin Energy Center
Minnesota Valley
Northeast Station
Riverside (1927)
Riverside (1927)
Riverside (1 927)
Facility ID
(ORISPL)
1904
1893
1893
1893
1893
1912
1912
1912
1912
1943
1943
1891
1891
1918
1961
1927
1927
1927
Unit ID
4
1
2
3
4
3
4
5
6
2
3
1
2
4
NEPP
6
7
8
Unit Operator(s) Compliance
Approach
Northern States Power (Xcel Averaging Plan
Energy)
Minnesota Power, Inc. Averaging Plan
Minnesota Power, Inc. Averaging Plan
Minnesota Power, Inc. Averaging Plan
Minnesota Power, Inc. Averaging Plan
Northern States Power (Xcel Averaging Plan
Energy)
Northern States Power (Xcel Averaging Plan
Energy)
Northern States Power (Xcel Averaging Plan
Energy)
Northern States Power (Xcel Averaging Plan
Energy)
Otter Tail Power Company Early Election
Otter Tail Power Company Standard Limit
Minnesota Power, Inc. Averaging Plan
Minnesota Power, Inc. Averaging Plan
Northern States Power (Xcel Averaging Plan
Energy)
City of Austin Standard Limit
Northern States Power (Xcel Averaging Plan
Energy)
Northern States Power (Xcel Averaging Plan
Energy)
Northern States Power (Xcel Averaging Plan
Energy)
Standard
Emissions
Limit
0.46
0.46
0.46
0.40
0.40
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.67
0.43
0.43
0.38 0.45
0.33
0.57
0.57
0.57
0.57
0.44 0.45
0.19
0.22
0.22
0.00
0.39
0.83
0.83
0.95
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.50
0.41
0.41
0.41
0.41
0.50
0.50
0.50
0.50
0.41
0.41
0.50
0.50
0.50
0.50
Actual Averaging
Plan Rate (if
applicable)
0.41
0.35
0.35
0.35
0.35
0.41
0.41
0.41
0.41
0.35
0.35
0.41
0.41
0.41
0.41
Page: 29
-------
2007 Acid Rain Program NOx Compliance Summary
State
MN
MN
MN
MN
MN
MN
MN
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
Facility Name
Sherburne County
Sherburne County
Sherburne County
Silver Lake
Taconite Harbor Energy Center
Taconite Harbor Energy Center
Taconite Harbor Energy Center
Asbury
Blue Valley
latan
James River
James River
James River
Labadie
Labadie
Labadie
Labadie
Facility ID
(ORISPL)
6090
6090
6090
2008
10075
10075
10075
2076
2132
6065
2161
2161
2161
2103
2103
2103
2103
Unit ID
1
2
3
4
1
2
3
1
3
1
3
4
5
1
2
3
4
Unit Operator(s)
Northern States Power (Xcel
Energy)
Northern States Power (Xcel
Energy)
Northern States Power (Xcel
Energy)
Rochester Public Utilities
Minnesota Power, Inc.
Minnesota Power, Inc.
Minnesota Power, Inc.
Empire District Electric
Company
Independence Power and
Light
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limit
Standard Limit
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0,
0,
o.
o.
0,
o.
o.
0,
0,
0,
0,
o.
o.
o.
o.
o.
o.
.20
.20
.38
.38
.42
.26
.37
.70
.30
.30
.27
.27
.32
.11
.11
.11
.11
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.50
0.50
0.50
0.41
0.41
0.41
0.50
0.50
0.50
0.52
0.52
0.52
0.52
Actual Averaging
Plan Rate (if
applicable)
0.41
0.41
0.41
0.35
0.35
0.35
0.33
0.33
0.33
0.14
0.14
0.14
0.14
Page: 30
-------
2007 Acid Rain Program NOx Compliance Summary
State
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
Facility Name
Meramec
Meramec
Meramec
Meramec
Montrose
Montrose
Montrose
New Madrid Power Plant
New Madrid Power Plant
Rush Island
Rush Island
Sibley
Sikeston
Sioux
Sioux
Southwest
Thomas Hill Energy Center
Thomas Hill Energy Center
Facility ID
(ORISPL)
2104
2104
2104
2104
2080
2080
2080
2167
2167
6155
6155
2094
6768
2107
2107
6195
2168
2168
Unit ID
1
2
3
4
1
2
3
1
2
1
2
3
1
1
2
1
MB1
MB2
Unit Operator(s)
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
KCP&L Greater Missouri
Operations Company
Sikeston Bd. of Municipal
Utilities
Union Electric Company
Union Electric Company
City Utilities of Springfield,
MO
Associated Electric
Cooperative, Inc.
Associated Electric
Cooperative, Inc.
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limit
Standard Limit
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limit
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
0.86
Actual Early Election
Emission Rate Limit (if
applicable)
0.12
0.11
0.20
0.19
0.33
0.34
0.34
0.60
0.66
0.09
0.19
0.59
0.24 0.50
0.22
0.20
0.37
0.61
0.68
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.52
0.52
0.52
0.52
0.76
0.76
0.52
0.52
0.52
0.52
0.50
0.76
0.76
Actual Averaging
Plan Rate (if
applicable)
0,
0,
0,
0,
o.
o.
0,
o.
0,
0,
0,
0,
0,
.14
.14
.14
.14
.52
.52
.14
.14
.14
.14
.33
.52
.52
Page: 31
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2007 Acid Rain Program NOx Compliance Summary
State
MO
MS
MS
MS
MS
MS
MS
MT
MT
MT
MT
MT
MT
NC
NC
NC
NC
NC
NC
Facility Name
Thomas Hill Energy Center
Daniel Electric Generating
Plant
Daniel Electric Generating
Plant
R D Morrow Senior Generating
Plant
R D Morrow Senior Generating
Plant
Watson Electric Generating
Plant
Watson Electric Generating
Plant
Colstrip
Colstrip
Colstrip
Colstrip
J E Corette
Lewis & Clark
Asheville
Asheville
Belews Creek
Belews Creek
Buck
Buck
Facility ID
(ORISPL)
2168
6073
6073
6061
6061
2049
2049
6076
6076
6076
6076
2187
6089
2706
2706
8042
8042
2720
2720
Unit ID
MBS
1
2
1
2
4
5
1
2
3
4
2
B1
1
2
1
2
5
6
Unit Operator(s)
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Standard Limit
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election AEL (if Averaging Plan Limit (if
Emission Rate Limit (if applicable) applicable)
applicable)
0,
0,
o.
o.
0,
o.
0,
0,
0,
0,
0,
0,
0,
0,
0,
o.
o.
o.
o.
.20
.35
.32
.47
.47
.53
.67
.31 0.45
.30 0.45
.27 0.45
.41 0.45
.24
.38 0.45
.21
.06
.05
.06
.25
.25
0.76
0.46
0.46
0.50
0.50
0.46
0.46
0.44
0.44
0.48
0.48
0.48
0.48
Actual Averaging
Plan Rate (if
applicable)
0,
0,
o.
o.
o.
o.
0,
0,
0,
o.
o.
o.
0.
.52
.26
.26
.47
.47
.26
.26
.27
.27
.22
.22
.22
22
Page: 32
-------
2007 Acid Rain Program NOx Compliance Summary
State
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
Facility Name
Buck
Buck
Buck
Cape Fear
Cape Fear
Cliffside
Cliffside
Cliffside
Cliffside
Cliffside
Dan River
Dan River
Dan River
GG Allen
GG Allen
GG Allen
GG Allen
GG Allen
H F Lee Steam Electric Plant
H F Lee Steam Electric Plant
H F Lee Steam Electric Plant
L V Sutton
Facility ID
(ORISPL)
2720
2720
2720
2708
2708
2721
2721
2721
2721
2721
2723
2723
2723
2718
2718
2718
2718
2718
2709
2709
2709
2713
Unit ID
7
8
9
5
6
1
2
3
4
5
1
2
3
1
2
3
4
5
1
2
3
1
Unit Operator(s)
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.46
0.46
0.40
Actual Early Election
Emission Rate Limit (if
applicable)
0.31
0.15
0.16
0.22
0.23
0.42
0.38
0.38
0.40
0.07
0.34
0.23
0.22
0.18
0.17
0.17
0.19
0.22
0.49
0.33
0.31
0.37
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.48
0.48
0.48
0.44
0.44
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.44
0.44
0.44
0.44
Actual Averaging
Plan Rate (if
applicable)
0.22
0.22
0.22
0.27
0.27
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.27
0.27
0.27
0.27
Page: 33
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2007 Acid Rain Program NOx Compliance Summary
State
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
Facility Name
L V Sutton
L V Sutton
Marshall
Marshall
Marshall
Marshall
Mayo
Mayo
Riverbend
Riverbend
Riverbend
Riverbend
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
Facility ID
(ORISPL)
2713
2713
2727
2727
2727
2727
6250
6250
2732
2732
2732
2732
2712
2712
2712
2712
2712
2712
Unit ID
2
3
1
2
3
4
1A
1B
10
7
8
9
1
2
3A
3B
4A
4B
Unit Operator(s)
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
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
Compliance
Approach
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Plan
Standard
Emissions
Limit
0.46
0.46
0.40
0.40
0.40
0.40
0.46
0.46
0.40
0.40
0.40
0.40
0.46
0.40
0.46
0.46
0.46
0.46
Actual Early Election
Emission Rate Limit (if
applicable)
0.37
0.31
0.18
0.24
0.22
0.20
0.07
0.07
0.18
0.20
0.22
0.17
0.09
0.06
0.12
0.12
0.09
0.09
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.44
0.44
0.48
0.48
0.48
0.48
0.44
0.44
0.48
0.48
0.48
0.48
0.44
0.44
0.44
0.44
0.44
0.44
Actual Averaging
Plan Rate (if
applicable)
0.27
0.27
0.22
0.22
0.22
0.22
0.27
0.27
0.22
0.22
0.22
0.22
0.27
0.27
0.27
0.27
0.27
0.27
Page: 34
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2007 Acid Rain Program NOx Compliance Summary
State
NC
NC
NC
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
NE
NE
Facility Name
W H Weatherspoon
W H Weatherspoon
W H Weatherspoon
Antelope Valley
Antelope Valley
Coal Creek
Coal Creek
Coyote
Leland Olds
Leland Olds
Milton R Young
Milton R Young
Stanton
Stanton
Gerald Gentleman Station
Gerald Gentleman Station
Facility ID
(ORISPL)
2716
2716
2716
6469
6469
6030
6030
8222
2817
2817
2823
2823
2824
2824
6077
6077
Unit ID
1
2
3
B1
B2
1
2
B1
1
2
B1
B2
1
10
1
2
Unit Operator(s)
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Standard Limit
Standard Limit
Standard Limit
Early Election
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Early Election
Early Election
Early Election
Standard
Emissions
Limit
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
Actual Early Election AEL (if Averaging Plan Limit (if
Emission Rate Limit (if applicable) applicable)
applicable)
0.82 0.44
0.82 0.44
0.42 0.44
0.38 0.45
0.32 0.45
0.25
0.20
0.69
0.31 0.50
0.50
0.84
0.86
0.22
0.28 0.45
0.21 0.50
0.30 0.50
Actual Averaging
Plan Rate (if
applicable)
0.27
0.27
0.27
Page: 35
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2007 Acid Rain Program NOx Compliance Summary
State
NE
NE
NE
NE
NE
NE
NE
NE
NE
NH
NH
NH
NH
NJ
NJ
NJ
Facility Name
Gerald Whelan Energy Center
Lon D Wright Power Plant
Nebraska City Station
North Omaha Station
North Omaha Station
North Omaha Station
North Omaha Station
North Omaha Station
Platte
Merrimack
Schiller
Schiller
Schiller
B L England
Deepwater
Hudson Generating Station
Facility ID
(ORISPL)
60
2240
6096
2291
2291
2291
2291
2291
59
2364
2367
2367
2367
2378
2384
2403
Unit ID
1
8
1
1
2
3
4
5
1
2
4
5
6
2
8
2
Unit Operator(s)
Nebraska Municipal Energy
Agency
City of Fremont
Omaha Public Power
District
Omaha Public Power
District
Omaha Public Power
District
Omaha Public Power
District
Omaha Public Power
District
Omaha Public Power
District
Grand Island Utilities Dept.
Public Service of New
Hampshire
Public Service of New
Hampshire
Public Service of New
Hampshire
Public Service of New
Hampshire
North American Energy
Services
Conectiv Atlantic
Generation, LLC
PSEG
Compliance
Approach
Early Election
Standard Limit
Early Election
Standard Limit
Standard Limit
Standard Limit
Early Election
Standard Limit
Early Election
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election AEL (if Averaging Plan Limit (if
Emission Rate Limit (if applicable) applicable)
applicable)
0.30 0.45
0.20
0.43 0.50
0.31
0.31
0.31
0.34 0.45
0.34
0.35 0.45
0.19
0.19
0.07
0.22
0.53
0.41
0.26 0.67
Actual Averaging
Plan Rate (if
applicable)
0.16
Page: 36
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2007 Acid Rain Program NOx Compliance Summary
State
NJ
NJ
NM
NM
NM
NM
NM
NM
NM
NM
NM
NM
NV
NV
NV
NV
Facility Name
Mercer Generating Station
Mercer Generating Station
Escalante
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
San Juan
San Juan
San Juan
San Juan
Mohave
Mohave
North Valmy
North Valmy
Facility ID
(ORISPL)
2408
2408
87
2442
2442
2442
2442
2442
2451
2451
2451
2451
2341
2341
8224
8224
Unit ID
1
2
1
1
2
3
4
5
1
2
3
4
1
2
1
2
Unit Operator(s)
PSEG
PSEG
Tri-State Generation &
Transmission
Arizona Public Service
Company
Arizona Public Service
Company
Arizona Public Service
Company
Arizona Public Service
Company
Arizona Public Service
Company
Public Service Company of
New Mexico
Public Service Company of
New Mexico
Public Service Company of
New Mexico
Public Service Company of
New Mexico
Southern California Edison
Company
Southern California Edison
Company
Sierra Pacific Power
Company
Sierra Pacific Power
Company
Compliance
Approach
Averaging Plan
Averaging Plan
Early Election
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
Standard
Emissions
Limit
0.84
0.84
0.40
0.46
0.46
0.46
0.68
0.68
0.46
0.46
0.46
0.46
0.40
0.40
0.46
0.46
Actual Early Election
Emission Rate Limit (if
applicable)
0.09
0.09
0.35 0.45
0.78
0.65
0.61
0.48
0.49
0.44
0.46
0.42
0.41
0.00 0.45
0.00 0.45
0.34 0.50
0.41 0.50
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.67
0.67
0.60
0.60
0.60
0.60
0.60
0.46
0.46
0.46
0.46
Actual Averaging
Plan Rate (if
applicable)
0.16
0.16
0.55
0.55
0.55
0.55
0.55
0.43
0.43
0.43
0.43
Page: 37
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2007 Acid Rain Program NOx Compliance Summary
State
NV
NV
NV
NV
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
Facility Name
Reid Gardner
Reid Gardner
Reid Gardner
Reid Gardner
AES Cayuga, LLC
AES Cayuga, LLC
AES Greenidge
AES Greenidge
AES Greenidge
AES Somerset (Kintigh )
AES Westover (Goudey)
AES Westover (Goudey)
AES Westover (Goudey)
Dunkirk
Dunkirk
Dunkirk
Dunkirk
Dynegy Danskammer
Dynegy Danskammer
Huntley Power
Huntley Power
Huntley Power
Facility ID
(ORISPL)
2324
2324
2324
2324
2535
2535
2527
2527
2527
6082
2526
2526
2526
2554
2554
2554
2554
2480
2480
2549
2549
2549
Unit ID
1
2
3
4
1
2
4
5
6
1
11
12
13
1
2
3
4
3
4
65
66
67
Unit Operator(s)
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
Huntley Power, LLC
Huntley Power, LLC
Huntley Power, LLC
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Standard Limit
Standard Limit
Averaging Plan
Averaging Plan
Standard Limit
Standard Limit
Early Election
Standard
Emissions
Limit
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
0.40
Actual Early Election
Emission Rate Limit (if
applicable)
0.38
0.40
0.28
0.27
0.22
0.22
0.65
0.65
0.20
0.19
0.30
0.30
0.30
0.15 0.45
0.16 0.45
0.16
0.16
0.23
0.31
0.57
0.57
0.15 0.45
AEL (if Averaging Plan Limit (if
applicable) applicable)
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
0.40
0.40
Actual Averaging
Plan Rate (if
applicable)
0.32
0.32
0.32
0.32
0.21
0.21
0.21
0.21
0.21
0.21
0.21
0.21
0.21
0.28
0.28
Page: 38
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2007 Acid Rain Program NOx Compliance Summary
State
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
OH
OH
OH
OH
OH
Facility Name
Huntley Power
Lovett Generating Station
Lovett Generating 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
Ashtabula
Avon Lake Power Plant
Avon Lake Power Plant
Bay Shore
Bay Shore
Facility ID
(ORISPL)
2549
2629
2629
2642
2642
2642
2642
2682
2682
2682
2682
2835
2836
2836
2878
2878
Unit ID
68
4
5
1
2
3
4
10
11
12
9
7
10
12
1
2
Unit Operator(s)
Huntley Power, LLC
Mirant Lovett, LLC
Mirant Lovett, LLC
Rochester Gas & Electric
Corporation
Rochester Gas & Electric
Corporation
Rochester Gas & Electric
Corporation
Rochester Gas & Electric
Corporation
Jamestown Board of Public
Utilities
Jamestown Board of Public
Utilities
Jamestown Board of Public
Utilities
Jamestown Board of Public
Utilities
FirstEnergy Generation
Corporation
Orion Power Operating
Services- Midwest, Inc.
Orion Power Operating
Services- Midwest, Inc.
FirstEnergy Generation
Corporation
FirstEnergy Generation
Corporation
Compliance
Approach
Early Election
Standard Limit
Standard Limit
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
Standard
Emissions
Limit
0.40
0.46
0.46
0.40
0.40
0.40
0.40
0.46
0.46
0.46
0.46
0.45
0.40
0.68
0.80
0.80
Actual Early Election AEL (if Averaging Plan Limit (if
Emission Rate Limit (if applicable) applicable)
applicable)
0,
0,
0,
0,
0,
o.
o.
0,
o.
0,
0,
0,
0,
o.
o.
.15 0.45
.33
.36
.38
.38
.28
.28
.43 0.50
.00 0.50
.41 0.50
.41 0.50
.20
.38
.38
.12
0.41
0.40
0.40
0.40
0.40
0.52
0.64
0.64
0.52
0.52
Actual Averaging
Plan Rate (if
applicable)
0.32
0.32
0.32
0.32
0.28
0.38
0.38
0.28
0.28
Page: 39
-------
2007 Acid Rain Program NOx Compliance Summary
State
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Facility Name
Bay Shore
Bay Shore
Cardinal
Cardinal
Cardinal
Conesville
Conesville
Conesville
Conesville
Eastlake
Eastlake
Eastlake
Eastlake
Eastlake
Gen J M Gavin
Gen J M Gavin
Facility ID
(ORISPL)
2878
2878
2828
2828
2828
2840
2840
2840
2840
2837
2837
2837
2837
2837
8102
8102
Unit ID
3
4
1
2
3
3
4
5
6
1
2
3
4
5
1
2
Unit Operator(s)
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 Power Company
Ohio Power Company
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
0.68
0.68
Actual Early Election
Emission Rate Limit (if
applicable)
0.41
0.41
0.34
0.32
0.26
0.52
0.38
0.40
0.40
0.22
0.21
0.23
0.21
0.28
0.45
0.26
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.52
0.52
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.52
0.52
0.52
0.52
0.52
0.56
0.56
Actual Averaging
Plan Rate (if
applicable)
0.28
0.28
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.28
0.28
0.28
0.28
0.28
0.34
0.34
Page: 40
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2007 Acid Rain Program NOx Compliance Summary
State
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Facility Name
Hamilton Municipal Power
Plant
J M Stuart
J M Stuart
J M Stuart
J M Stuart
Killen Station
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Lake Shore
Miami Fort Generating Station
Facility ID
(ORISPL)
2917
2850
2850
2850
2850
6031
2876
2876
2876
2876
2876
2838
2832
Unit ID
9
1
2
3
4
2
1
2
3
4
5
18
5-1
Unit Operator(s)
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
Duke Energy Corporation,
Duke Energy Corporation
Compliance
Approach
Standard Limit
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
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.35
0.37
0.34
0.36
0.38
0.39
0.40
0.40
0.40
0.40
0.40
0.30
0.00
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.62
0.62
0.62
0.62
0.62
0.84
0.84
0.84
0.84
0.84
0.52
0.48
Actual Averaging
Plan Rate (if
applicable)
0.37
0.37
0.37
0.37
0.37
0.46
0.46
0.46
0.46
0.46
0.28
0.36
OH Miami Fort Generating Station
2832 5-2 Duke Energy Corporation, Averaging Plan
Duke Energy Corporation
0.80
0.00
0.48
0.36
Page: 41
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2007 Acid Rain Program NOx Compliance Summary
State Facility Name
Facility ID
(ORISPL)
Unit ID Unit Operator(s)
Compliance
Approach
Standard Actual Early Election AEL (if Averaging Plan Limit (if Actual Averaging
Emissions Emission Rate Limit (if applicable) applicable) Plan Rate (if
Limit applicable) applicable)
OH Miami Fort Generating Station
OH Miami Fort Generating Station
OH Miami Fort Generating Station
OH Muskingum River
OH Muskingum River
OH Muskingum River
OH Muskingum River
OH Muskingum River
OH OH Hutchings
OH OH Hutchings
OH OH Hutchings
OH OH Hutchings
OH OH Hutchings
OH OH Hutchings
OH Picway
2832
2832
2832
Duke Energy Corporation, Averaging Plan 0.45
Duke Energy Corporation
Duke Energy Corporation, Averaging Plan 0.68
Duke Energy Corporation
Duke Energy Corporation, Averaging Plan 0.46
Duke Energy Corporation
0.23
0.28
0.27
2872
2872
2872
2872
2872
2848
2848
2848
2848
2848
2848
2843
1
2
3
4
5
H-1
H-2
H-3
H-4
H-5
H-6
9
Ohio Power Company
Ohio Power Company
Ohio Power Company
Ohio Power Company
Ohio Power Company
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
Dayton Power and Light
Company
Columbus Southern Power
Company
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
0.84
0.84
0.86
0.86
0.68
0.40
0.40
0.40
0.40
0.40
0.40
0.50
0.64
0.64
0.64
0.64
0.36
0.64
0.64
0.40
0.40
0.38
0.38
0.44
0.48
0.48
0.48
0.36
0.36
0.36
0.56
0.56
0.56
0.56
0.56
0.62
0.62
0.62
0.62
0.62
0.62
0.56
0.34
0.34
0.34
0.34
0.34
0.37
0.37
0.37
0.37
0.37
0.37
0.34
Page: 42
-------
2007 Acid Rain Program NOx Compliance Summary
State
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Facility Name
R E Burger
R E Burger
R E Burger
R E Burger
Richard Gorsuch
Richard Gorsuch
Richard Gorsuch
Richard Gorsuch
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
Facility ID
(ORISPL)
2864
2864
2864
2864
7253
7253
7253
7253
2866
2866
2866
2866
2866
2866
2866
Unit ID
5
6
7
8
1
2
3
4
1
2
3
4
5
6
7
Unit Operator(s)
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limit
Standard Limit
Standard Limit
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.34
0.34
0.34
0.34
0.39
0.39
0.39
0.39
0.21
0.21
0.21
0.21
0.26
0.28
0.29
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
Actual Averaging
Plan Rate (if
applicable)
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
Page: 43
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2007 Acid Rain Program NOx Compliance Summary
State
OH
OH
OH
OH
OH
OH
OH
OK
OK
OK
OK
Facility Name
W H Zimmer Generating
Station
Walter C Beckjord Generating
Station
Walter C Beckjord Generating
Station
Walter C Beckjord Generating
Station
Walter C Beckjord Generating
Station
Walter C Beckjord Generating
Station
Walter C Beckjord Generating
Station
Grand River Dam Authority
Grand River Dam Authority
Hugo
Muskogee
Facility ID
(ORISPL)
6019
2830
2830
2830
2830
2830
2830
165
165
6772
2952
Unit ID
1
1
2
3
4
5
6
1
2
1
4
Unit Operator(s)
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,
Duke Energy Corporation
Grand River Dam Authority
Grand River Dam Authority
Western Farmers Electric
Cooperative, Inc.
Oklahoma Gas& Electric
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limit
Early Election
Standard
Emissions
Limit
0.46
0.40
0.40
0.46
0.40
0.45
0.45
0.46
0.46
0.46
0.40
Actual Early Election
Emission Rate Limit (if
applicable)
0.38 0.50
0.59
0.62
0.50
0.37
0.39
0.43
0.42
0.30
0.20
0.27 0.45
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.46
0.46
Actual Averaging
Plan Rate (if
applicable)
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
Company
Page: 44
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2007 Acid Rain Program NOx Compliance Summary
State Facility Name
Facility ID
(ORISPL)
Unit ID Unit Operator(s)
Compliance
Approach
Standard Actual Early Election AEL (if Averaging Plan Limit (if Actual Averaging
Emissions Emission Rate Limit (if applicable) applicable) Plan Rate (if
Limit applicable) applicable)
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
PA Cheswick
2952 5 Oklahoma Gas & Electric Early Election 0.40
Company
2952 6 Oklahoma Gas & Electric Early Election 0.40
Company
2963 3313 Public Service Company of Averaging Plan 0.40
Oklahoma
2963 3314 Public Service Company of Averaging Plan 0.40
Oklahoma
6095 1 Oklahoma Gas & Electric Early Election 0.40
Company
6095 2 Oklahoma Gas & Electric Early Election 0.40
Company
6106 1SG Portland General Electric Early Election 0.46
Company
3178 1 Allegheny Energy Supply Averaging Plan 0.50
Company, LLC
3178 2 Allegheny Energy Supply Averaging Plan 0.50
Company, LLC
6094 1 FirstEnergy Generation Averaging Plan 0.50
Corporation
6094 2 FirstEnergy Generation Averaging Plan 0.50
Corporation
6094 3 FirstEnergy Generation Averaging Plan 0.46
Corporation
3140 1 PPL Brunner Island, LLC Standard Limit 0.45
3140 2 PPL Brunner Island, LLC Standard Limit 0.45
3140 3 PPL Brunner Island, LLC Standard Limit 0.45
8226 1 Orion Power Midwest, LP Standard Limit 0.45
0.32
0.34
0.36
0.36
0.34
0.35
0.45
0.35
0.34
0.29
0.29
0.30
0.33
0.33
0.35
0.32
0.45
0.45
0.56
0.56
0.45
0.45
0.50
0.50
0.56
0.56
0.52
0.52
0.52
0.34
0.34
0.34
0.34
0.28
0.28
0.28
Page: 45
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2007 Acid Rain Program NOx Compliance Summary
State
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
Facility Name
Conemaugh
Conemaugh
Cromby
Eddystone Generating Station
Eddystone Generating Station
Elrama
Elrama
Elrama
Elrama
Hatfields Ferry Power Station
Hatfields Ferry Power Station
Hatfields Ferry Power Station
Homer City
Homer City
Homer City
Facility ID
(ORISPL)
3118
3118
3159
3161
3161
3098
3098
3098
3098
3179
3179
3179
3122
3122
3122
Unit ID
1
2
1
1
2
1
2
3
4
1
2
3
1
2
3
Unit Operator(s)
Reliant Energy Northeast
Management Company
Reliant Energy Northeast
Management Company
Exelon Generation
Company LLC
Exelon Generation
Company LLC
Exelon Generation
Company LLC
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Allegheny Energy Supply
Company, LLC
Allegheny Energy Supply
Company, LLC
Allegheny Energy Supply
Company, LLC
EME Homer City
Generation, LP
EME Homer City
Generation, LP
EME Homer City
Generation, LP
Compliance
Approach
Standard Limit
Standard Limit
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.35
0.32
0.38 0.50
0.34 0.45
0.29 0.45
0.51
0.51
0.51
0.51
0.47
0.47
0.47
0.28 0.50
0.17 0.50
0.32 0.50
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.66
0.66
0.66
0.66
0.56
0.56
0.56
Actual Averaging
Plan Rate (if
applicable)
0.51
0.51
0.51
0.51
0.34
0.34
0.34
Page: 46
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2007 Acid Rain Program NOx Compliance Summary
State
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
Facility Name
Keystone
Keystone
Martins Creek
Martins Creek
Mitchell Power Station
Montour
Montour
New Castle
New Castle
New Castle
Portland
Facility ID
(ORISPL)
3136
3136
3148
3148
3181
3149
3149
3138
3138
3138
3113
Unit ID
1
2
1
2
33
1
2
3
4
5
1
Unit Operator(s)
Reliant Energy Northeast
Management Company
Reliant Energy Northeast
Management Company
PPL Martins Creek, LLC
PPL Martins Creek, LLC
Allegheny Energy Supply
Company, LLC
PPL Montour, LLC
PPL Montour, LLC
Orion Power Midwest, LP
Orion Power Midwest, LP
Orion Power Midwest, LP
Reliant Energy Mid-Atlantic
Compliance
Approach
Early Election
Early Election
Standard Limit
Standard Limit
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Standard
Emissions
Limit
0.40
0.40
0.50
0.50
0.45
0.40
0.40
0.46
0.46
0.46
0.45
Actual
Emission Rate
0.23
0.19
0.45
0.45
0.32
0.26
0.33
0.35
0.36
0.41
0.24
Early Election AEL (if Averaging Plan Limit (if
Limit (if applicable) applicable)
applicable)
0.45
0.45
0.56
0.45
0.45
0.50
0.50
0.50
0.45
Actual Averaging
Plan Rate (if
applicable)
0.34
0.37
PA Portland
3113
Power Holdings, LLC
Reliant Energy Mid-Atlantic Averaging Plan
Power Holdings, LLC
0.45
0.37
0.45
0.37
PA Shawville
3131
Reliant Energy Mid-Atlantic Averaging Plan
Power Holdings, LLC
0.50
0.46
0.45
0.37
PA Shawville
3131
Reliant Energy Mid-Atlantic Averaging Plan
Power Holdings, LLC
0.50
0.46
0.45
0.37
Page: 47
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2007 Acid Rain Program NOx Compliance Summary
State
PA
PA
PA
PA
PA
PA
PA
SC
SC
SC
SC
SC
SC
SC
SC
Facility Name
Shawville
Shawville
Sunbury
Sunbury
Titus
Titus
Titus
Canadys Steam
Canadys Steam
Canadys Steam
Cope Station
Cross
Cross
Dolphus M Grainger
Dolphus M Grainger
Facility ID
(ORISPL)
3131
3131
3152
3152
3115
3115
3115
3280
3280
3280
7210
130
130
3317
3317
Unit ID
3
4
3
4
1
2
3
CAN1
CAN2
CANS
COP1
1
2
1
2
Unit Operator(s)
Reliant Energy Mid-Atlantic
Power Holdings, LLC
Reliant Energy Mid-Atlantic
Power Holdings, LLC
Sunbury Generation, LP
Sunbury Generation, LP
Reliant Energy Mid-Atlantic
Power Holdings, LLC
Reliant Energy Mid-Atlantic
Power Holdings, LLC
Reliant Energy Mid-Atlantic
Power Holdings, LLC
South Carolina Electric &
Gas Company
South Carolina Electric &
Gas Company
South Carolina Electric &
Gas Company
South Carolina Electric &
Gas Company
Santee Cooper
Santee Cooper
Santee Cooper
Santee Cooper
Compliance
Approach
Averaging Plan
Averaging Plan
Standard Limit
Standard Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.38
0.38
0.29
0.27
0.35 0.45
0.35 0.45
0.35 0.45
0.41
0.40
0.37
0.26
0.09
0.10 0.45
0.45
0.43
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.45
0.45
0.45
0.45
0.45
0.42
0.42
0.42
0.42
0.46
0.46
0.46
Actual Averaging
Plan Rate (if
applicable)
0.37
0.37
0.37
0.37
0.37
0.31
0.31
0.31
0.31
0.21
0.21
0.21
Page: 48
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2007 Acid Rain Program NOx Compliance Summary
State
SC
sc
SC
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
sc
SD
Facility Name
H B Robinson
Jefferies
Jefferies
McMeekin
McMeekin
Urquhart
WS Lee
WS Lee
WS Lee
Wateree
Wateree
Williams
Winyah
Winyah
Winyah
Winyah
Big Stone
Facility ID
(ORISPL)
3251
3319
3319
3287
3287
3295
3264
3264
3264
3297
3297
3298
6249
6249
6249
6249
6098
Unit ID
1
3
4
MCM1
MCM2
URQ3
1
2
3
WAT1
WAT2
WIL1
1
2
3
4
1
Unit Operator(s)
Carolina Power & Light
Company
Santee Cooper
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Alternative
Emissions Limit
Alternative
Emissions Limit
Alternative
Emissions Limit
Standard Limit
Standard
Emissions
Limit
0.40
0.46
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.49
0.49
0.48
0.35
0.35
0.26
0.25
0.23
0.24
0.30
0.24
0.33
0.09
0.11
0.13
0.12
0.69
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.44
0.46
0.46
0.42
0.42
0.42
0.48
0.48
0.48
0.42
0.42
0.42
0.46
0.61
0.60
0.60
Actual Averaging
Plan Rate (if
applicable)
0.27
0.21
0.21
0.31
0.31
0.31
0.22
0.22
0.22
0.31
0.31
0.31
0.21
Page: 49
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2007 Acid Rain Program NOx Compliance Summary
State
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
Facility Name
Allen
Allen
Allen
Bull Run
Cumberland
Cumberland
Gallatin
Gallatin
Gallatin
Gallatin
John Sevier
John Sevier
John Sevier
John Sevier
Johnsonville
Facility ID
(ORISPL)
3393
3393
3393
3396
3399
3399
3403
3403
3403
3403
3405
3405
3405
3405
3406
Unit ID
1
2
3
1
1
2
1
2
3
4
1
2
3
4
1
Unit Operator(s)
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0,
0,
o.
o.
0,
o.
0,
0,
0,
0,
o.
o.
o.
o.
0,
.42
.46
.53
.36
.32
.41
.16
.16
.16
.16
.33
.33
.39
.39
.40
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
Actual Averaging
Plan Rate (if
applicable)
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
Page: 50
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2007 Acid Rain Program NOx Compliance Summary
State
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
Facility Name
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Facility ID
(ORISPL)
3406
3406
3406
3406
3406
3406
3406
3406
3406
3407
3407
3407
3407
3407
3407
Unit ID
10
2
3
4
5
6
7
8
9
1
2
3
4
5
6
Unit Operator(s)
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Tennessee
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Valley Authority
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0,
0,
o.
o.
0,
o.
0,
0,
0,
0,
o.
o.
o.
.40
.40
.40
.40
.40
.40
.40
.40
.40
.27
.27
.27
.27
0.27
0.24
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
Actual Averaging
Plan Rate (if
applicable)
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
Page: 51
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2007 Acid Rain Program NOx Compliance Summary
State
TN
TN
TN
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
Facility Name
Kingston
Kingston
Kingston
Big Brown
Big Brown
Coleto Creek
Gibbons Creek Steam Electric
Station
H W Pirkey Power Plant
Harrington Station
Harrington Station
Harrington Station
J K Spruce
J T Deely
J T Deely
Limestone
Limestone
Martin Lake
Facility ID
(ORISPL)
3407
3407
3407
3497
3497
6178
6136
7902
6193
6193
6193
7097
6181
6181
298
298
6146
Unit ID
7
8
9
1
2
1
1
1
061 B
062B
063B
**1
1
2
LIM1
LIM2
1
Unit Operator(s)
Tennessee Valley Authority
Tennessee Valley Authority
Tennessee Valley Authority
Luminant Generation
Company LLC
Luminant Generation
Company LLC
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
NRG Texas Power LLC
NRG Texas Power LLC
Luminant Generation
Company LLC
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Standard
Emissions
Limit
0.40
0.40
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
Actual
Emission Rate
0,
0,
o.
o.
0,
o.
o.
0,
0,
0,
0,
o.
o.
o.
o.
o.
o.
.24
.24
.24
.15
.14
.15
.13
.17
.28
.31
.15
.13
.13
.13
.19
.20
.16
Early Election AEL (if Averaging Plan Limit (if
Limit (if applicable) applicable)
applicable)
0.56
0.56
0.56
0.45
0.45
0.45
0.45
0.56
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
Actual Averaging
Plan Rate (if
applicable)
0.38
0.38
0.38
0.34
Page: 52
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2007 Acid Rain Program NOx Compliance Summary
State
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
Facility Name
Martin Lake
Martin Lake
Monticello
Monticello
Monticello
Oklaunion Power Station
Sam Seymour
Sam Seymour
Sam Seymour
San Miguel
Sandow
Tolk Station
Tolk Station
W A Parish
W A Parish
W A Parish
Facility ID
(ORISPL)
6146
6146
6147
6147
6147
127
6179
6179
6179
6183
6648
6194
6194
3470
3470
3470
Unit ID
2
3
1
2
3
1
1
2
3
SM-1
4
171B
172B
WAP5
WAP6
WAP7
Unit Operator(s)
Luminant Generation
Company LLC
Luminant Generation
Company LLC
Luminant Generation
Company LLC
Luminant Generation
Company LLC
Luminant Generation
Company LLC
West Texas Utilities
Company
Lower Colorado River
Authority
Lower Colorado River
Authority
Lower Colorado River
Authority
San Miguel Electric
Cooperative
Luminant Generation
Company LLC
Southwestern Public
Service Company
Southwestern Public
Service Company
NRG Texas Power LLC
NRG Texas Power LLC
NRG Texas Power LLC
Compliance
Approach
Early Election
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Standard
Emissions
Limit
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
Actual
Emission Rate
0.16
0.15
0.15
0.15
0.21
0.34
0.10
0.11
0.12
0.19
0.20
0.20
0.23
0.05
0.04
0.04
Early Election AEL (if Averaging Plan Limit (if
Limit (if applicable) applicable)
applicable)
0.45
0.45
0.45
0.45
0.50
0.56
0.45
0.45
0.45
0.50
0.45
0.45
0.45
0.50
0.50
0.45
Actual Averaging
Plan Rate (if
applicable)
0.34
Page: 53
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2007 Acid Rain Program NOx Compliance Summary
State
TX
TX
TX
TX
UT
UT
UT
UT
UT
UT
UT
UT
UT
UT
VA
VA
VA
VA
VA
VA
VA
VA
Facility Name
W A Parish
Welsh Power Plant
Welsh Power Plant
Welsh Power Plant
Bonanza
Carbon
Carbon
Hunter
Hunter
Hunter
Huntington
Huntington
Intermountain
Intermountain
Bremo Power Station
Bremo Power Station
Chesapeake Energy Center
Chesapeake Energy Center
Chesapeake Energy Center
Chesapeake Energy Center
Chesterfield Power Station
Chesterfield Power Station
Facility ID
(ORISPL)
3470
6139
6139
6139
7790
3644
3644
6165
6165
6165
8069
8069
6481
6481
3796
3796
3803
3803
3803
3803
3797
3797
Unit ID
WAP8
1
2
3
1-1
1
2
1
2
3
1
2
1SGA
2SGA
3
4
1
2
3
4
3
4
Unit Operator(s)
NRG Texas Power 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
Dominion Generation
Dominion Generation
Dominion Generation
Dominion Generation
Dominion Generation
Dominion Generation
Compliance
Approach
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Averaging Plan
Averaging Plan
Early Election
Early Election
Averaging Plan
Early Election
Averaging Plan
Early Election
Early Election
Averaging Plan
Averaging Plan
Early Election
Early Election
Averaging Plan
Early Election
Early Election
Early Election
Standard
Emissions
Limit
0.40
0.46
0.46
0.46
0.46
0.40
0.40
0.40
0.40
0.46
0.40
0.40
0.46
0.46
0.46
0.46
0.40
0.40
0.46
0.40
0.40
0.40
Actual
Emission Rate
0.04
0.16
0.16
0.19
0.36
0.52
0.50
0.37
0.37
0.34
0.36
0.23
0.39
0.36
0.67
0.36
0.42
0.44
0.20
0.25
0.39
0.25
Early Election
Limit (if
applicable)
0.45
0.50
0.45
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.45
0.45
0.45
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.56
0.56
0.56
0.45
0.45
0.45
0.45
0.41
0.41
0.41
Actual Averaging
Plan Rate (if
applicable)
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.27
0.27
0.27
Page: 54
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2007 Acid Rain Program NOx Compliance Summary
State
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
Facility Name
Chesterfield Power Station
Chesterfield Power Station
Clinch River
Clinch River
Clinch River
Clover Power Station
Clover Power Station
Glen Lyn
Glen Lyn
Glen Lyn
Mirant Potomac River
Mirant Potomac River
Mirant Potomac River
Mirant Potomac River
Mirant Potomac River
Possum Point Power Station
Facility ID
(ORISPL)
3797
3797
3775
3775
3775
7213
7213
3776
3776
3776
3788
3788
3788
3788
3788
3804
Unit ID
5
6
1
2
3
1
2
51
52
6
1
2
3
4
5
3
Unit Operator(s)
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
Mirant Potomac River, LLC
Mirant Potomac River, LLC
Mirant Potomac River, LLC
Mirant Potomac River, LLC
Mirant Potomac River, LLC
Dominion Generation
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Early Election
Early Election
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.23
0.23
0.41
0.41
0.40
0.28
0.27
0.40
0.38
0.43
0.33 0.45
0.29 0.45
0.25 0.45
0.23 0.45
0.25 0.45
0.12 0.45
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.41
0.41
0.56
0.56
0.56
0.41
0.41
0.56
0.56
0.56
Actual Averaging
Plan Rate (if
applicable)
0.27
0.27
0.34
0.34
0.34
0.27
0.27
0.34
0.34
0.34
Page: 55
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2007 Acid Rain Program NOx Compliance Summary
State
VA
VA
VA
WA
WA
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Facility Name
Possum Point Power Station
Yorktown Power Station
Yorktown Power Station
Centralia
Centralia
Alma
Alma
Blount Street
Blount Street
Blount Street
Columbia
Columbia
DTE Stoneman, LLC
DTE Stoneman, LLC
Edgewater (4050)
Edgewater (4050)
Facility ID
(ORISPL)
3804
3809
3809
3845
3845
4140
4140
3992
3992
3992
8023
8023
4146
4146
4050
4050
Unit ID
4
1
2
BW21
BW22
B4
B5
7
8
9
1
2
B1
B2
4
5
Unit Operator(s)
Dominion Generation
Dominion Generation
Dominion Generation
TransAlta Centralia
Generation, LLC
TransAlta Centralia
Generation, LLC
Dairyland Power
Cooperative
Dairyland Power
Cooperative
Madison Gas & Electric
Company
Madison Gas & Electric
Company
Madison Gas & Electric
Company
Wisconsin Power & Light
Company
Wisconsin Power & Light
Company
WPS Power Development,
Inc.
WPS Power Development,
Inc.
Wisconsin Power & Light
Company
Wisconsin Power & Light
Company
Compliance
Approach
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Standard Limit
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
0.40
0.40
0.40
0.40
0.40
0.50
0.50
0.68
0.46
0.46
0.40
0.40
0.46
0.46
0.86
0.46
Actual
Emission Rate
0.09
0.37
0.37
0.27
0.22
0.82
0.82
0.43
0.31
0.34
0.14
0.12
0.37
0.37
0.18
0.16
Early Election AEL (if Averaging Plan Limit (if
Limit (if applicable) applicable)
applicable)
0.41
0.45
0.45
0.45
0.45
0.48
0.48
0.50
0.50
0.45
0.45
0.46
0.46
0.64
0.50 0.64
Actual Averaging
Plan Rate (if
applicable)
0.27
0.39
0.39
0.37
0.37
0.17
0.17
Page: 56
-------
2007 Acid Rain Program NOx Compliance Summary
State
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Facility Name
Genoa
J P Madgett
Pleasant Prairie
Pleasant Prairie
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
Valley (WEPCO)
Facility ID
(ORISPL)
4143
4271
6170
6170
4072
4072
4072
4072
4072
4072
4041
4041
4041
4041
4042
Unit ID
1
B1
1
2
3
4
5
6
7
8
5
6
7
8
1
Unit Operator(s)
Dairyland Power
Cooperative
Dairyland Power
Cooperative
Wisconsin Electric Power
Company
Wisconsin Electric Power
Company
Wisconsin Public Service
Corporation
Wisconsin Public Service
Corporation
Wisconsin Public Service
Corporation
Wisconsin Public Service
Corporation
Wisconsin Public Service
Corporation
Wisconsin Public Service
Corporation
Wisconsin Electric Power
Company
Wisconsin Electric Power
Company
Wisconsin Electric Power
Company
Wisconsin Electric Power
Company
Wisconsin Electric Power
Company
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
0.45
0.50
0.46
0.46
0.46
0.46
0.46
0.46
0.50
0.50
0.50
0.50
0.45
0.45
0.50
Actual Early Election
Emission Rate Limit (if
applicable)
0.33
0.31
0.05
0.07
0.76
0.76
0.88
0.88
0.38
0.29
0.16
0.16
0.13
0.13
0.34
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.48
0.48
0.46
0.46
0.47
0.47
0.47
0.47
0.47
0.47
0.46
0.46
0.46
0.46
0.46
Actual Averaging
Plan Rate (if
applicable)
0.39
0.39
0.17
0.17
0.47
0.47
0.47
0.47
0.47
0.47
0.17
0.17
0.17
0.17
0.17
Page: 57
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2007 Acid Rain Program NOx Compliance Summary
State
Wl
Wl
Wl
Wl
Wl
Wl
wv
wv
wv
wv
wv
wv
wv
wv
wv
Facility Name
Valley (WEPCO)
Valley (WEPCO)
Valley (WEPCO)
Weston
Weston
Weston
Albright Power Station
Albright Power Station
Albright Power Station
Fort Martin Power Station
Fort Martin Power Station
Harrison Power Station
Harrison Power Station
Harrison Power Station
John E Amos
Facility ID
(ORISPL)
4042
4042
4042
4078
4078
4078
3942
3942
3942
3943
3943
3944
3944
3944
3935
Unit ID
2
3
4
1
2
3
1
2
3
1
2
1
2
3
1
Unit Operator(s)
Wisconsin Electric Power
Company
Wisconsin Electric Power
Company
Wisconsin Electric Power
Company
Wisconsin Public Service
Corporation
Wisconsin Public Service
Corporation
Wisconsin Public Service
Corporation
Monongahela Power
Company
Monongahela Power
Company
Monongahela Power
Company
Monongahela Power
Company
Monongahela Power
Company
Allegheny Energy Supply
Company, LLC
Allegheny Energy Supply
Company, LLC
Allegheny Energy Supply
Company, LLC
Appalachian Power
Company
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.34
0.36
0.36
0.80
0.38
0.25
0.54
0.46
0.27
0.29
0.26
0.30
0.33
0.29
0.32
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.46
0.46
0.46
0.47
0.47
0.47
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
Actual Averaging
Plan Rate (if
applicable)
0.17
0.17
0.17
0.47
0.47
0.47
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
Page: 58
-------
2007 Acid Rain Program NOx Compliance Summary
State
WV
wv
WV
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
Facility Name
John E Amos
John E Amos
Kammer
Kammer
Kammer
Kanawha River
Kanawha River
Mitchell (WV)
Mitchell (WV)
Mount Storm Power Station
Mount Storm Power Station
Mount Storm Power Station
Mountaineer (1301)
Phil Sporn
Phil Sporn
Phil Sporn
Phil Sporn
Facility ID
(ORISPL)
3935
3935
3947
3947
3947
3936
3936
3948
3948
3954
3954
3954
6264
3938
3938
3938
3938
Unit ID
2
3
1
2
3
1
2
1
2
1
2
3
1
11
21
31
41
Unit Operator(s)
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Alternative
Emissions Limit
Alternative
Emissions Limit
Alternative
Emissions Limit
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.32
0.46
0.56
0.56
0.56
0.37
0.37
0.31
0.34
0.34
0.33
0.37
0.25
0.41
0.41
0.41
0.41
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.76
0.69
0.74
0.56
0.56
0.56
0.56
0.56
Actual Averaging
Plan Rate (if
applicable)
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
Page: 59
-------
2007 Acid Rain Program NOx Compliance Summary
State
WV
wv
WV
wv
wv
wv
wv
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
WY
Facility Name
Phil Sporn
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
Facility ID
(ORISPL)
3938
6004
6004
3945
3945
3946
3946
4158
4158
4158
4158
8066
8066
8066
8066
6204
6204
6204
4162
Unit ID
51
1
2
7
8
1
2
BW41
BW42
BW43
BW44
BW71
BW72
BW73
BW74
1
2
3
1
Unit Operator(s)
Central Operating Company
Allegheny Energy Supply
Company, LLC
Allegheny Energy Supply
Company, LLC
Monongahela Power
Company
Monongahela Power
Company
Allegheny Energy Supply
Company, LLC
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
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Early Election
Early Election
Early Election
Early Election
Averaging Plan
Standard
Emissions
Limit
0.46
0.50
0.50
0.80
0.80
0.80
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
Actual Early Election
Emission Rate Limit (if
applicable)
0.38
0.23
0.25
0.84
0.58
0.38
0.68
0.45 0.50
0.44 0.50
0.49
0.24
0.40
0.23
0.27
0.38 0.45
0.26 0.50
0.27 0.50
0.27 0.50
0.52
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.45
0.45
0.45
0.45
0.45
0.45
Actual Averaging
Plan Rate (if
applicable)
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
Page: 60
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2007 Acid Rain Program NOx Compliance Summary
State
WY
WY
WY
Facility Name
Naughton
Naughton
Wyodak
Facility ID
(ORISPL)
4162
4162
6101
Unit ID
2
3
BW91
Unit Operator(s)
PacifiCorp
PacifiCorp
PacifiCorp
Compliance
Approach
Averaging Plan
Averaging Plan
Averaging Plan
Standard
Emissions
Limit
0.40
0.40
0.50
Actual
Emission Rate
0.52
0.39
0.27
Early Election
Limit (if
applicable)
AEL (if Averaging Plan Limit (if
applicable) applicable)
0.45
0.45
0.45
Actual Averaging
Plan Rate (if
applicable)
0.34
0.34
0.34
Page: 61
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2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
10
10
10
10
10
10
10
10
10
10
10
11
11
11
11
11
11
11
11
11
11
11
21
21
21
21
21
28
28
28
28
28
33
33
33
34
34
35
35
47
47
51
51
Facility Name
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Harding Street Station (EW Stout)
Harding Street Station (EW Stout)
Harding Street Station (EW Stout)
IPL Eagle Valley Generating Station
IPL Eagle Valley Generating Station
IPL Eagle Valley Generating Station
IPL Eagle Valley Generating Station
Petersburg
Petersburg
Petersburg
Petersburg
Bailly Generating Station
Bailly Generating Station
Michigan City Generating Station
R M Schahfer Generating Station
R M Schahfer Generating Station
New Madrid Power Plant
New Madrid Power Plant
Thomas Hill Energy Center
Thomas Hill Energy Center
Thomas Hill Energy Center
Martin Drake
Martin Drake
Martin Drake
Grand River Dam Authority
Grand River Dam Authority
R D Morrow Senior Generating Plant
R D Morrow Senior Generating Plant
State Line Generating Station (IN)
State Line Generating Station (IN)
Frank E Ratts
Frank E Ratts
Facility ID
(ORISPL)
983
983
983
983
983
983
2876
2876
2876
2876
2876
990
990
990
991
991
991
991
994
994
994
994
995
995
997
6085
6085
2167
2167
2168
2168
2168
492
492
492
165
165
6061
6061
981
981
1043
1043
Unit ID
1
2
3
4
5
6
1
2
3
4
5
50
60
70
3
4
5
6
1
2
3
4
7
8
12
14
15
1
2
MB1
MB2
MBS
5
6
7
1
2
1
2
3
4
1SG1
2SG1
Plan Limit
0.84
0.84
0.84
0.84
0.84
0.84
0.84
0.84
0.84
0.84
0.84
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.74
0.74
0.74
0.74
0.74
0.76
0.76
0.76
0.76
0.76
0.46
0.46
0.46
0.46
0.46
0.50
0.50
0.69
0.69
0.47
0.47
Plan Rate
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.45
0.45
0.45
0.45
0.45
0.52
0.52
0.52
0.52
0.52
0.41
0.41
0.41
0.36
0.36
0.47
0.47
0.49
0.49
0.27
0.27
Page: 1
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
51
51
53
53
53
53
53
53
53
53
57
57
57
57
57
57
57
57
57
61
61
61
61
62
62
62
67
67
68
68
68
68
71
71
100
100
100
100
100
100
100
100
100
Facility Name
Merom
Merom
Bremo Power Station
Bremo Power Station
Chesapeake Energy Center
Chesterfield Power Station
Chesterfield Power Station
Clover Power Station
Clover Power Station
Possum Point Power Station
Coleman
Coleman
Coleman
D B Wilson
HMP&L Station 2
HMP&L Station 2
R D Green
R D Green
Robert Reid
Rochester 7 - Russell Station
Rochester 7 - Russell Station
Rochester 7 - Russell Station
Rochester 7 - Russell Station
Hudson Generating Station
Mercer Generating Station
Mercer Generating Station
Edgewater (4050)
Edgewater (4050)
Alma
Alma
Genoa
J P Madgett
La Cygne
La Cygne
Albright Power Station
Albright Power Station
Albright Power Station
Armstrong Power Station
Armstrong Power Station
Fort Martin Power Station
Fort Martin Power Station
Harrison Power Station
Harrison Power Station
Facility ID
(ORISPL)
6213
6213
3796
3796
3803
3797
3797
7213
7213
3804
1381
1381
1381
6823
1382
1382
6639
6639
1383
2642
2642
2642
2642
2403
2408
2408
4050
4050
4140
4140
4143
4271
1241
1241
3942
3942
3942
3178
3178
3943
3943
3944
3944
Unit ID
1SG1
2SG1
3
4
3
5
6
1
2
4
C1
C2
C3
W1
H1
H2
G1
G2
R1
1
2
3
4
2
1
2
4
5
B4
B5
1
B1
1
2
1
2
3
1
2
1
2
1
2
Plan Limit
0.47
0.47
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.49
0.49
0.49
0.49
0.49
0.49
0.49
0.49
0.49
0.40
0.40
0.40
0.40
0.67
0.67
0.67
0.64
0.64
0.48
0.48
0.48
0.48
0.68
0.68
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
Plan Rate
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
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
0.16
0.16
0.16
0.17
0.17
0.39
0.39
0.39
0.39
0.33
0.33
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
Page: 2
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
100
100
100
100
100
100
100
100
100
100
100
100
100
102
102
102
102
102
102
102
102
102
102
102
102
102
102
102
102
102
102
102
102
102
102
102
102
108
108
108
108
108
108
Facility Name
Harrison Power Station
Hatfields Ferry Power Station
Hatfields Ferry Power Station
Hatfields Ferry Power Station
Mitchell Power Station
Pleasants Power Station
Pleasants Power Station
R. Paul Smith Power Station
R. Paul Smith Power Station
Rivesville Power Station
Rivesville Power Station
Willow Island Power Station
Willow Island Power Station
Belle River
Belle River
Harbor Beach
Marysville
Marysville
Marysville
Marysville
Monroe
Monroe
Monroe
Monroe
River Rouge
River Rouge
St. Clair
St. Clair
St. Clair
St. Clair
St. Clair
St. Clair
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
Trenton Channel
J M Stuart
J M Stuart
J M Stuart
J M Stuart
Killen Station
O H Hutchings
Facility ID
(ORISPL)
3944
3179
3179
3179
3181
6004
6004
1570
1570
3945
3945
3946
3946
6034
6034
1731
1732
1732
1732
1732
1733
1733
1733
1733
1740
1740
1743
1743
1743
1743
1743
1743
1745
1745
1745
1745
1745
2850
2850
2850
2850
6031
2848
Unit ID
3
1
2
3
33
1
2
11
9
7
8
1
2
1
2
1
10
11
12
9
1
2
3
4
2
3
1
2
3
4
6
7
16
17
18
19
9A
1
2
3
4
2
H-1
Plan Limit
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.55
0.62
0.62
0.62
0.62
0.62
0.62
Plan Rate
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.37
0.37
0.37
0.37
0.37
0.37
Page: 3
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
108
108
108
108
108
109
109
111
111
111
111
116
116
116
116
123
123
123
123
123
123
123
123
123
123
123
123
123
125
125
125
125
125
125
125
125
125
125
126
126
126
126
126
Facility Name
O H Mulchings
O H Mulchings
O H Mulchings
O H Mulchings
O H Mulchings
Arapahoe
Arapahoe
Reid Gardner
Reid Gardner
Reid Gardner
Reid Gardner
San Juan
San Juan
San Juan
San Juan
Carbon
Carbon
Dave Johnston
Dave Johnston
Hunter
Huntington
Jim Bridger
Jim Bridger
Jim Bridger
Naughton
Naughton
Naughton
Wyodak
Canadys Steam
Canadys Steam
Canadys Steam
Cope Station
McMeekin
McMeekin
Urquhart
Wateree
Wateree
Williams
Boswell Energy Center
Boswell Energy Center
Boswell Energy Center
Boswell Energy Center
Laskin Energy Center
Facility ID
(ORISPL)
2848
2848
2848
2848
2848
465
465
2324
2324
2324
2324
2451
2451
2451
2451
3644
3644
4158
4158
6165
8069
8066
8066
8066
4162
4162
4162
6101
3280
3280
3280
7210
3287
3287
3295
3297
3297
3298
1893
1893
1893
1893
1891
Unit ID
H-2
H-3
H-4
H-5
H-6
3
4
1
2
3
4
1
2
3
4
1
2
BW43
BW44
3
2
BW71
BW72
BW73
1
2
3
BW91
CAN1
CAN2
CANS
COP1
MCM1
MCM2
URQ3
WAT1
WAT2
WIL1
1
2
3
4
1
Plan Limit
0.62
0.62
0.62
0.62
0.62
0.80
0.80
0.46
0.46
0.46
0.46
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
0.45
0.45
0.45
0.45
0.42
0.42
0.42
0.42
0.42
0.42
0.42
0.42
0.42
0.42
0.41
0.41
0.41
0.41
0.41
Plan Rate
0.37
0.37
0.37
0.37
0.37
0.43
0.43
0.32
0.32
0.32
0.32
0.43
0.43
0.43
0.43
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.31
0.35
0.35
0.35
0.35
0.35
Page: 4
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
126
126
126
126
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
Facility Name
Laskin Energy Center
Taconite Harbor Energy Center
Taconite Harbor Energy Center
Taconite Harbor Energy Center
Barry
Barry
Barry
Barry
Barry
Bo wen
Bo wen
Bo wen
Bo wen
Crist Electric Generating Plant
Crist Electric Generating Plant
Crist Electric Generating Plant
Crist Electric Generating Plant
Daniel Electric Generating Plant
Daniel Electric Generating Plant
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
Gadsden
Gadsden
Gorgas
Gorgas
Gorgas
Gorgas
Gorgas
Greene County
Greene County
Hammond
Hammond
Hammond
Hammond
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Jack McDonough
Jack McDonough
Facility ID
(ORISPL)
1891
10075
10075
10075
3
3
3
3
3
703
703
703
703
641
641
641
641
6073
6073
26
26
26
26
26
7
7
8
8
8
8
8
10
10
708
708
708
708
709
709
709
709
710
710
Unit ID
2
1
2
3
1
2
3
4
5
1BLR
2BLR
3BLR
4BLR
4
5
6
7
1
2
1
2
3
4
5
1
2
10
6
7
8
9
1
2
1
2
3
4
1
2
3
4
MB1
MB2
Plan Limit
0.41
0.41
0.41
0.41
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
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
Plan Rate
0.35
0.35
0.35
0.35
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
Page: 5
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
127
128
128
130
130
130
130
130
130
132
132
132
132
133
133
133
Facility Name
James H Miller Jr
James H Miller Jr
James H Miller Jr
James H Miller Jr
Kraft
Kraft
Kraft
Lansing Smith Generating Plant
Lansing Smith Generating Plant
Mclntosh(6124)
Mitchell (GA)
Scherer
Scherer
Scherer
Scherer
Scholz Electric Generating Plant
Scholz Electric Generating Plant
Wansley (6052)
Wansley (6052)
Watson Electric Generating Plant
Watson Electric Generating Plant
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Cherokee
Cherokee
Baldwin Energy Complex
Hennepin Power Station
Hennepin Power Station
Vermilion Power Station
Vermilion Power Station
Wood River Power Station
James River
James River
James River
Southwest
Eckert Station
Eckert Station
Eckert Station
Facility ID
(ORISPL)
6002
6002
6002
6002
733
733
733
643
643
6124
727
6257
6257
6257
6257
642
642
6052
6052
2049
2049
728
728
728
728
728
728
728
469
469
889
892
892
897
897
898
2161
2161
2161
6195
1831
1831
1831
Unit ID
1
2
3
4
1
2
3
1
2
1
3
1
2
3
4
1
2
1
2
4
5
Y1BR
Y2BR
Y3BR
Y4BR
Y5BR
Y6BR
Y7BR
1
2
3
1
2
1
2
5
3
4
5
1
1
2
3
Plan Limit
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
0.46
0.46
0.80
0.80
0.44
0.44
0.44
0.44
0.44
0.44
0.50
0.50
0.50
0.50
0.45
0.45
0.45
Plan Rate
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.26
0.51
0.51
0.13
0.13
0.13
0.13
0.13
0.13
0.33
0.33
0.33
0.33
0.20
0.20
0.20
Page: 6
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
133
133
133
133
137
137
137
137
137
137
137
137
138
138
138
138
138
138
138
138
138
138
138
138
139
139
139
139
139
139
139
139
139
140
140
141
141
141
141
141
141
142
142
Facility Name
Eckert Station
Eckert Station
Eckert Station
Erickson
Jeffrey Energy Center
Jeffrey Energy Center
Jeffrey Energy Center
Lawrence Energy Center
Lawrence Energy Center
Lawrence Energy Center
Tecumseh Energy Center
Tecumseh Energy Center
Labadie
Labadie
Labadie
Labadie
Meramec
Meramec
Meramec
Meramec
Rush Island
Rush Island
Sioux
Sioux
Coffeen
Coffeen
Hutsonville
Hutsonville
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Brandon Shores
Brandon Shores
Cross
Dolphus M Grainger
Dolphus M Grainger
Jefferies
Jefferies
Winyah
Elrama
Elrama
Facility ID
(ORISPL)
1831
1831
1831
1832
6068
6068
6068
1250
1250
1250
1252
1252
2103
2103
2103
2103
2104
2104
2104
2104
6155
6155
2107
2107
861
861
863
863
864
864
864
864
864
602
602
130
3317
3317
3319
3319
6249
3098
3098
Unit ID
4
5
6
1
1
2
3
3
4
5
10
9
1
2
3
4
1
2
3
4
1
2
1
2
01
02
05
06
01
02
03
04
05
1
2
1
1
2
3
4
1
1
2
Plan Limit
0.45
0.45
0.45
0.45
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.72
0.72
0.72
0.72
0.72
0.72
0.72
0.72
0.72
0.56
0.56
0.46
0.46
0.46
0.46
0.46
0.46
0.66
0.66
Plan Rate
0.20
0.20
0.20
0.20
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.30
0.14
0.14
0.14
0.14
0.14
0.14
0.14
0.14
0.14
0.14
0.14
0.14
0.33
0.33
0.33
0.33
0.33
0.33
0.33
0.33
0.33
0.35
0.35
0.21
0.21
0.21
0.21
0.21
0.21
0.51
0.51
Page: 7
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
142
142
145
145
145
145
145
145
145
145
145
145
145
145
145
145
145
145
145
145
145
145
145
145
145
145
145
145
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
Facility Name
Elrama
Elrama
Asheville
Asheville
Cape Fear
Cape Fear
Crystal River
Crystal River
Crystal River
Crystal River
H B Robinson
H F Lee Steam Electric Plant
H F Lee Steam Electric Plant
H F Lee Steam Electric Plant
L V Sutton
L V Sutton
L V Sutton
Mayo
Mayo
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
Roxboro
W H Weatherspoon
W H Weatherspoon
W H Weatherspoon
Allen
Allen
Allen
Bull Run
Colbert
Colbert
Colbert
Colbert
Colbert
Cumberland
Cumberland
Gallatin
Gallatin
Gallatin
Gallatin
Facility ID
(ORISPL)
3098
3098
2706
2706
2708
2708
628
628
628
628
3251
2709
2709
2709
2713
2713
2713
6250
6250
2712
2712
2712
2712
2712
2712
2716
2716
2716
3393
3393
3393
3396
47
47
47
47
47
3399
3399
3403
3403
3403
3403
Unit ID
3
4
1
2
5
6
1
2
4
5
1
1
2
3
1
2
3
1A
1B
1
2
3A
3B
4A
4B
1
2
3
1
2
3
1
1
2
3
4
5
1
2
1
2
3
4
Plan Limit
0.66
0.66
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
Plan Rate
0.51
0.51
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.27
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
Page: 8
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
148
Facility Name
John Sevier
John Sevier
John Sevier
John Sevier
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Kingston
Paradise
Paradise
Paradise
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Shawnee
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Widows Creek
Facility ID
(ORISPL)
3405
3405
3405
3405
3406
3406
3406
3406
3406
3406
3406
3406
3406
3406
3407
3407
3407
3407
3407
3407
3407
3407
3407
1378
1378
1378
1379
1379
1379
1379
1379
1379
1379
1379
1379
50
50
50
50
50
50
50
50
Unit ID
1
2
3
4
1
10
2
3
4
5
6
7
8
9
1
2
3
4
5
6
7
8
9
1
2
3
1
2
3
4
5
6
7
8
9
1
2
3
4
5
6
7
8
Plan Limit
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
Plan Rate
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
0.38
Page: 9
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
149
149
149
149
149
149
149
149
149
150
150
151
151
151
151
200
200
201
201
201
201
201
299
299
299
299
299
299
299
299
299
299
300
300
300
300
303
303
303
303
303
303
303
Facility Name
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Weston
Weston
Weston
DTE Stoneman, LLC
DTE Stoneman, LLC
Duck Creek
E D Edwards
E D Edwards
E D Edwards
Dynegy Danskammer
Dynegy Danskammer
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
E W Brown
E W Brown
E W Brown
Ghent
Ghent
Ghent
Ghent
Green River
Green River
Tyrone
Big Bend
Big Bend
Big Bend
Big Bend
Ashtabula
Bay Shore
Bay Shore
Bay Shore
Bay Shore
Bruce Mansfield
Bruce Mansfield
Facility ID
(ORISPL)
4072
4072
4072
4072
4072
4072
4078
4078
4078
4146
4146
6016
856
856
856
2480
2480
2442
2442
2442
2442
2442
1355
1355
1355
1356
1356
1356
1356
1357
1357
1361
645
645
645
645
2835
2878
2878
2878
2878
6094
6094
Unit ID
3
4
5
6
7
8
1
2
3
B1
B2
1
1
2
3
3
4
1
2
3
4
5
1
2
3
1
2
3
4
4
5
5
BB01
BB02
BB03
BB04
7
1
2
3
4
1
2
Plan Limit
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.46
0.46
0.46
0.46
0.46
0.46
0.40
0.40
0.60
0.60
0.60
0.60
0.60
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.76
0.76
0.76
0.76
0.52
0.52
0.52
0.52
0.52
0.52
0.52
Plan Rate
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.37
0.37
0.21
0.21
0.21
0.21
0.28
0.28
0.55
0.55
0.55
0.55
0.55
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.49
0.49
0.49
0.49
0.28
0.28
0.28
0.28
0.28
0.28
0.28
Page: 10
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
303
303
303
303
303
303
303
303
303
303
303
303
303
303
303
303
303
303
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
Facility Name
Bruce Mansfield
Eastlake
Eastlake
Eastlake
Eastlake
Eastlake
Lake Shore
R E Burger
R E Burger
R E Burger
R E Burger
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
WH Sammis
Belews Creek
Belews Creek
Buck
Buck
Buck
Buck
Buck
Cayuga
Cayuga
Cliffside
Cliffside
Cliffside
Cliffside
Cliffside
Dan River
Dan River
Dan River
East Bend
Edwardsport
Edwardsport
Edwardsport
G G Allen
G G Allen
G G Allen
G G Allen
Facility ID
(ORISPL)
6094
2837
2837
2837
2837
2837
2838
2864
2864
2864
2864
2866
2866
2866
2866
2866
2866
2866
8042
8042
2720
2720
2720
2720
2720
1001
1001
2721
2721
2721
2721
2721
2723
2723
2723
6018
1004
1004
1004
2718
2718
2718
2718
Unit ID
3
1
2
3
4
5
18
5
6
7
8
1
2
3
4
5
6
7
1
2
5
6
7
8
9
1
2
1
2
3
4
5
1
2
3
2
7-1
7-2
8-1
1
2
3
4
Plan Limit
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.52
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
Plan Rate
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.28
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
Page: 11
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2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
305
307
307
307
307
307
307
307
307
307
307
307
Facility Name
G G Allen
Gibson
Gibson
Gibson
Gibson
Gibson
Marshall
Marshall
Marshall
Marshall
R Gallagher
R Gallagher
R Gallagher
R Gallagher
Riverbend
Riverbend
Riverbend
Riverbend
WSLee
WSLee
WSLee
Wabash River Gen Station
Wabash River Gen Station
Wabash River Gen Station
Wabash River Gen Station
Wabash River Gen Station
Wabash River Gen Station
Miami Fort Generating Station
Miami Fort Generating Station
Miami Fort Generating Station
Miami Fort Generating Station
Miami Fort Generating Station
W H Zimmer Generating Station
Walter C Beckjord Generating Station
Walter C Beckjord Generating Station
Walter C Beckjord Generating Station
Walter C Beckjord Generating Station
Walter C Beckjord Generating Station
Facility ID
(ORISPL)
2718
6113
6113
6113
6113
6113
2727
2727
2727
2727
1008
1008
1008
1008
2732
2732
2732
2732
3264
3264
3264
1010
1010
1010
1010
1010
1010
2832
2832
2832
2832
2832
6019
2830
2830
2830
2830
2830
Unit ID
5
1
2
3
4
5
1
2
3
4
1
2
3
4
10
7
8
9
1
2
3
1
2
3
4
5
6
5-1
5-2
6
7
8
1
1
2
3
4
5
Plan Limit
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
Plan Rate
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
Page: 12
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2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
307
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
308
Facility Name
Walter C Beckjord Generating Station
Big Sandy
Big Sandy
Cardinal
Cardinal
Cardinal
Clinch River
Clinch River
Clinch River
Conesville
Conesville
Conesville
Conesville
Flint Creek Power Plant
Gen J M Gavin
Gen J M Gavin
Glen Lyn
Glen Lyn
Glen Lyn
H W Pirkey Power Plant
John E Amos
John E Amos
John E Amos
Kammer
Kammer
Kammer
Kanawha River
Kanawha River
Mitchell (WV)
Mitchell (WV)
Mountaineer (1301)
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Northeastern
Northeastern
Oklaunion Power Station
Phil Sporn
Phil Sporn
Phil Sporn
Facility ID
(ORISPL)
2830
1353
1353
2828
2828
2828
3775
3775
3775
2840
2840
2840
2840
6138
8102
8102
3776
3776
3776
7902
3935
3935
3935
3947
3947
3947
3936
3936
3948
3948
6264
2872
2872
2872
2872
2872
2963
2963
127
3938
3938
3938
Unit ID
6
BSU1
BSU2
1
2
3
1
2
3
3
4
5
6
1
1
2
51
52
6
1
1
2
3
1
2
3
1
2
1
2
1
1
2
3
4
5
3313
3314
1
11
21
31
Plan Limit
0.48
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
Plan Rate
0.36
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
Page: 13
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
308
308
308
308
308
308
308
308
308
308
308
308
310
310
310
310
310
310
310
310
310
311
311
311
311
311
311
311
311
311
313
313
313
313
313
313
313
313
313
313
313
313
313
Facility Name
Phil Sporn
Phil Sporn
Picway
Rockport
Rockport
Tanners Creek
Tanners Creek
Tanners Creek
Tanners Creek
Welsh Power Plant
Welsh Power Plant
Welsh Power Plant
Portland
Portland
Shawville
Shawville
Shawville
Shawville
Titus
Titus
Titus
AES Cayuga, LLC
AES Cayuga, LLC
AES Greenidge
AES Greenidge
AES Greenidge
AES Somerset (Kintigh )
AES Westover (Goudey)
AES Westover (Goudey)
AES Westover (Goudey)
Allen S King
Black Dog
Black Dog
High Bridge
High Bridge
High Bridge
High Bridge
Minnesota Valley
Riverside (1927)
Riverside (1927)
Riverside (1 927)
Sherburne County
Sherburne County
Facility ID
(ORISPL)
3938
3938
2843
6166
6166
988
988
988
988
6139
6139
6139
3113
3113
3131
3131
3131
3131
3115
3115
3115
2535
2535
2527
2527
2527
6082
2526
2526
2526
1915
1904
1904
1912
1912
1912
1912
1918
1927
1927
1927
6090
6090
Unit ID
41
51
9
MB1
MB2
U1
U2
U3
U4
1
2
3
1
2
1
2
3
4
1
2
3
1
2
4
5
6
1
11
12
13
1
3
4
3
4
5
6
4
6
7
8
1
2
Plan Limit
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.45
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
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
Plan Rate
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.37
0.37
0.37
0.37
0.37
0.37
0.37
0.37
0.37
0.21
0.21
0.21
0.21
0.21
0.21
0.21
0.21
0.21
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
0.41
Page: 14
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
313
314
314
314
314
314
314
314
314
314
314
314
314
314
314
314
316
316
328
328
328
328
328
328
328
328
328
328
328
328
328
336
336
337
337
337
337
337
337
337
337
337
337
Facility Name
Sherburne County
B C Cobb
B C Cobb
B C Cobb
B C Cobb
B C Cobb
Dan E Karn
Dan E Karn
J C Weadock
J C Weadock
J H Campbell
J H Campbell
J H Campbell
J R Whiting
J R Whiting
J R Whiting
Avon Lake Power Plant
Avon Lake Power Plant
Dubuque
Dubuque
Lansing
Lansing
Lansing
Milton L Kapp
Prairie Creek
Sixth Street
Sixth Street
Sixth Street
Sixth Street
Sutherland
Sutherland
F B Culley Generating Station
F B Culley Generating Station
Pleasant Prairie
Pleasant Prairie
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
Presque Isle
South Oak Creek
Facility ID
(ORISPL)
6090
1695
1695
1695
1695
1695
1702
1702
1720
1720
1710
1710
1710
1723
1723
1723
2836
2836
1046
1046
1047
1047
1047
1048
1073
1058
1058
1058
1058
1077
1077
1012
1012
6170
6170
1769
1769
1769
1769
1769
1769
1769
4041
Unit ID
3
1
2
3
4
5
1
2
7
8
1
2
3
1
2
3
10
12
1
5
1
2
3
2
3
2
3
4
5
1
2
2
3
1
2
3
4
5
6
7
8
9
5
Plan Limit
0.50
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.64
0.64
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
0.50
0.50
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
Plan Rate
0.41
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.38
0.38
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
0.15
0.15
0.17
0.17
0.17
0.17
0.17
0.17
0.17
0.17
0.17
0.17
Page: 15
-------
2007 Acid Rain Program NOx Averaging Plan Summary
Averaging
Plan ID
337
337
337
337
337
337
337
368
368
375
375
375
375
375
375
Facility Name
South Oak Creek
South Oak Creek
South Oak Creek
Valley (WEPCO)
Valley (WEPCO)
Valley (WEPCO)
Valley (WEPCO)
Brandon Shores
Brandon Shores
Brandon Shores
Brandon Shores
C P Crane
C P Crane
Herbert A Wagner
Herbert A Wagner
Facility ID
(ORISPL)
4041
4041
4041
4042
4042
4042
4042
602
602
602
602
1552
1552
1554
1554
Unit ID
6
7
8
1
2
3
4
1
2
1
2
1
2
2
3
Plan Limit
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.56
0.56
0.56
0.56
0.56
0.56
0.56
0.56
Plan Rate
0.17
0.17
0.17
0.17
0.17
0.17
0.17
0.35
0.35
0.35
0.35
0.35
0.35
0.35
0.35
Page: 16
------- |