&EPA
United States Office of Air and Radiation EPA-430-R-00-007
Environmental Protection Clean Air Markets Division July 2000
Agency (6204J)
1999 Compliance Report
ACID l-g RAIN
PROGRAM
Visit us at www.epa.gov/acidrain
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BACKGROUND
The Acid Rain Program was established under Title IV of the 1990 Clean Air Act Amendments. The Program
calls for major reductions of sulfur dioxide (SO2) and nitrogen oxides (NOX), the pollutants that cause acid rain,
while establishing a new approach to environmental protection through the use of market incentives. The
Program sets a permanent cap on the total amount of SO2 that may be emitted by electric utilities nationwide at
about one half of the amount emitted in 1980, and allows flexibility for individual utility units to select their own
methods of compliance. The Program also sets NOX emission limitations (in Ib/mmBtu) for electric utilities
representing about a 27 percent reduction from 1990 levels. The Acid Rain Program is implemented in two
phases: Phase I began in 1995 for SO2 and 1996 for NOX, and ended December 31, 1999; Phase II for both
pollutants began Januaryl, 2000 and involves over 2,300 units. In 1999, there were 398 units affected by the
SO2 provisions of the Acid Rain Program, 236 of which were also affected for NOX, and an additional 303
utility units affected only by the NOX provisions.
Acid rain causes acidification of lakes and streams and contributes to the damage of trees at high elevations. In
addition, acid rain accelerates the decay of building materials, paints, and cultural artifacts, including
irreplaceable buildings, statues, and sculptures. While airborne, SO2 and NOX gases and their particulate matter
derivatives, sulfates and nitrates, contribute to visibility degradation and impact public health.
The SO 2 component of the Acid Rain Program represents a dramatic departure from traditional command and
control regulatory methods that establish source-specific emissions limitations. Instead, the Program introduces
a trading system for SO2 that facilitates lowest-cost emissions reductions and an overall emissions cap that
ensures the maintenance of the environmental goal. The Program features tradable SO2 emissions allowances,
where one allowance is a limited authorization to emit one ton of SO2. Allowances may be bought, sold, or
banked by utilities, brokers, or anyone else interested in holding them. Existing utility units were allocated
allowances for each future compliance year and all participants of the Program are obliged to surrender to EPA
the number of allowances that correspond to their annual emissions starting either in Phase I or Phase II of the
Program.
The NOX component of the Acid Rain Program is more traditional, and establishes an emission rate limit for all
NOx-affected units. Flexibility is also introduced to this command and control measure, however, through
compliance options such as emissions averaging, whereby a utility can meet the standard emission limitations by
averaging the emissions rates of two or more boilers. This allows utilities to over-control at units where it is
technically easier to control emissions, thereby achieving emissions reductions at a lower cost. Additionally,
beginning in 1997, certain Phase II units could voluntarily elect to become subject to Acid Rain NOX limits
before January 1, 2000, the date by which they would normally be subject. By complying with Phase I limits,
these early election units can delay meeting the more stringent Phase II limits until 2008.
At the end of each year, utilities must demonstrate compliance with the provisions of the Acid Rain Program.
For the NOX portion of the Program, utilities must achieve an annual emission limitation at or below mandated
levels. For SO2, utilities are granted a 60-day grace period during which additional SO2 allowances may be
purchased, if necessary, to cover each unit's emissions for the previous year. At the end of the grace period
(the Allowance Transfer Deadline), the allowances a unit holds in its Allowance Tracking System (ATS)
account must equal or exceed the unit's annual SO2 emissions. In addition, in 1995-1999 (Phase I of the
Program), units must have sufficient allowances to cover certain other deductions as well. Any remaining SO2
allowances may be sold or banked for use in future years.
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Table of Contents
Letter from the Director 1
Summary 2
Affected Population in Phase I 4
SO2 Results
Program 4
Compliance Results 5.
Allowance Market £
NOX Results
Program 11
Phase I Units 12
Phase I Compliance Results 11
Phase n Early Election Units 15.
Phase n Early Election Compliance Results 16,
Monitoring Update J/7
Conclusion 19.
Appendix A: Phase I Affected And Early Election Units in 1999
Appendix B-l: Table 1 Units Designating Substitution and Compensating Units -1999
Appendix B-2: List of Phase I Extension Units and 1999 Deductions for Exceeding 1999 Projected
Emissions Limitations
Appendix B-3: Emissions and Utilization of Phase I Units, 1998 and 1999
Appendix B-4: Emissions and Allowance Holdings of Phase I Units
Appendix C-l: List of Averaging Plans and Results in 1999
Appendix C-2: Compliance Results for the 265 Phase INOX Affected Units in 1999
Appendix C-3: Compliance Results for the 274 Early Election Units in 1999
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1999 Compliance Report Page 1
TO THE READER:
It's hard to believe that over 5 years have passed since January 1, 1995 and the official beginning of Phase I
of the Acid Rain Program. Yet the publishing of this 1999 Compliance Report for the Acid Rain Program
brings to a close Phase I (which officially ended December 31, 1999) and marks the beginning of Phase U,
which of course officially began on January 1, 2000.
From a regulatory standpoint, the end of Phase I and the beginning of Phase JJ means a simpler, more
streamlined Program. Relatively complicated Phase I SO2 compliance options such as substitution and
compensating unit plans, Phase I extension plans, and reduced utilization plans disappear beginning in Phase
JJ. Beginning in 2000, affected units are simply required to hold allowances to account for their SO2
emissions.
Similarly, the end of Phase I also marks the end of EPA's responsibility as the permitting authority for Phase I
affected sources. In Phase U, the State or Local title V permitting authority is the sole permitting authority for
all affected sources, including Phase I affected sources formerly permitted by EPA.
But while becoming simpler administratively, the end of Phase I and the beginning of Phase U also brings
significant new challenges. The number of affected units that must undergo annual reconciliation under the
Acid Rain Program expands notably in Phase U. For SO2 purposes, the number of affected units that must
hold allowances to account for SO2 emissions will grow more than fivefold, from 398 units in 1999 to over
2100 units for compliance year 2000. Also, units subject to an Acid Rain NOX emissions limitation will
almost double in Phase U, from 539 units in 1999 (including early election units) to about 1050 units
beginning in 2000.
New units that will be subject to the Acid Rain Program are being built as well. Currently, the Acid Rain
Program expects that about 500 new affected units will come online over the next 2 years. Affected
companies, EPA, and States will need to ensure that these units comply with all requirements of the Program,
including the requirements to monitor properly under 40 CFR part 75 (the Acid Rain Program monitoring
rule) and to hold sufficient allowances to account for SO2 emissions for each compliance year.
As we move to Phase U, I am looking forward to working with all parties involved in the implementation of
the Acid Rain Program, and in furthering the promise shown by the successful implementation of Phase I.
Brian J. McLean, Director
Clean Air Markets Division
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1999 Compliance Report Page 2
SUMMARY
100 Percent Compliance with both SOj and NOx Requirements in 1999
All 701 boilers and combustion turbines (referred to as "units") affected by the SO2 and NOX regulations of
the Acid Rain Program in 1999 successfully met their emissions compliance obligations.
• All 398 units subject to SO2 requirements in 1999 held sufficient allowances to cover their emissions. Of
the 4,948,090 allowances deducted from compliance accounts almost all (4,944,665 or 99.93 percent)
were for emissions, but other deductions were also made as required by the Acid Rain Program
regulations.
• All 539 units subject to the NOX requirements in 1999 demonstrated compliance with applicable annual
emission limitations. Of these 539 units, 236 were also subject to SO2 requirements, while 303 units
were affected only for NOX (33 Phase I units and 270 Phase n "early election" units).
1999 SO2 Emissions of Phase I Units were 29 Percent Below Allowable Level; Emission Rates 45
Percent Lower Than in 1990.
SO2 emissions in 1999 were 2.0 million tons (or 29 percent) below the 6.9 million ton allowable level as
determined by 1999 allowance allocations. Since an additional 9.6 million allowances were carried over, or
banked, from 1998, the overall number of allowances available in 1999 was 16.5 million, of which affected
units consumed only about 30 percent. Actual emissions for the 398 units participating in 1999 were 4.9
million tons, down 350,000 tons from emissions of the 408 units affected in 1998. In 1999, SO2 emission
rates of Phase I units averaged 1.86 Ibs/mmBtu, down from 3.37 Ibs/mmBtu in 1990 for those same units.
1999 Phase I Unit NOX Emission Rates 43 Percent Below 1990; NOX Tons 32 Percent Lower Thar
in 1990
Emission rates for the 265 Phase I utility units dropped by 43 percent below 1990 levels, from an average of
0.70 pounds of NOX per million Btu of heat input (Ib/mmBtu) to an average of 0.40 Ibs/mmBtu; this rate is 18
percent below the compliance rate of 0.49 Ibs/mmBtu for these units. NOX emission levels for these units
were 423,857 tons (or 32 percent) below 1990 levels.
1999 NOX Emission Rates of Early Election Units Even Lower Than Rates for Phase I Units
For the 274 Phase n units which elected to meet Phase INOX rates early, emission rates dropped from an
average of 0.46 Ibs/mmBtu in 1990 to 0.37 Ibs/mmBtu in 1999, a 20 percent decrease and 21 percent below
the compliance rate of 0.47 Ibs/mmBtu for these units. While utilization of these units increased by 28 percent
between 1990 and 1999, NOX tons increased by only 3 percent.
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1999 Compliance Report Page 3
Monitoring Performance Excellent Once Again
For the fifth year of the Acid Rain Program, the continuous emission monitors used by participants continue
to provide some of the most accurate and complete data ever collected by the EPA. Statistics reflect
excellent monitor operation of all units affected by both Phase I and Phase n of the program.
Accuracy: SO2 monitors achieved a median relative accuracy (i.e., deviation from the reference
test method) of 3.0 percent; flow monitors, 3.2 percent; and NOX monitors, 3.6
percent. Any statistically significant systematic underestimation (low bias) is
corrected to eliminate any systematic errors.
Availability: SO2 and flow monitors achieved a median availability of 99.5 and 99.7 percent, respectively,
while NOX monitors achieved a median availability of 99.2 percent.
SO2 Market Active; Volume of Allowances Transferred Continues to Increase in 1999
Activity in the allowance market continued to increase in 1999. The total volume of allowances transferred
increased from 13.5 million in 1998 to 18.7 million in 1999, however transfers of allowances between
unrelated parties decreased from 9.5 million in 1998 to 6.2 million in 1999.
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1999 Compliance Report
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AFFECTED POPULATION IN PHASE I
Exhibit 1 provides a summary of the affected population of units under the Acid Rain Program from 1995
through 1999. The table illustrates that although the units listed in Table 1 of the CAAA are consistently
affected for both SO2 and NOX beginning in 1996, the total universe of affected units varies year to year
because of the flexibility offered by the program.
Exhibit 1
Affected Units During Phase I of the Acid Rain Program
S02
NOX
Table 1
Substitution and
Compensating
Opt-in
TOTAL
Table 1
Substitution
Early-Election
TOTAL
1995
263
182
0
445
NA
NA
NA
NA
1996
263
161
7
431
144
95
NA
239
1997
263
153
7
423
170
95
272
537
1998
263
135
10
408
111
94
275
540
1999
263
125
10
398
111
94
274
539
SO2 PROGRAM
398 Units Underwent Annual Reconciliation for SO2 in 1999
There were 388 affected utility units and 10 opt-in units that underwent annual reconciliation in 1999 to
determine whether sufficient allowances were held to cover emissions. These 398 units are listed in Appendix
A and include 263 utility units specifically required to participate during Phase I, 125 utility units not initially
required to participate until Phase n, but electing to participate early as part of multi-unit compliance plans,1
During Phase I of the of the Acid Rain Program, a unit not originally affected until Phase II may elect to
enter the program early as a substitution unit or a compensating unit to help fulfill the compliance obligations for one
of the Table 1 units targeted by Phase I. A unit brought into Phase I as a substitution unit can assist a Table 1 unit
in meeting its emissions reductions obligations. Utilities may make cost-effective emissions reductions at the
substitution unit instead of at the Table 1 unit, achieving the same overall emissions reductions that would have
occurred without the participation of the substitution unit. A Table 1 unit may designate a Phase II unit as a
substitution unit only if both units are under the control of the same owner or operator. Additionally, Table 1 units
that reduce their utilization below their baseline may designate a compensating unit to provide compensating
generation to account for the reduced utilization of the Table 1 unit. (A unit's baseline is defined as its heat input
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1999 Compliance Report Page 5
and 10 other units that elected to join as part of the Opt-in Program.2 There were 10 fewer units undergoing
annual reconciliation in 1999 than in 1998.
1999 SO2 Emissions Target was 6.99 Million Tons
The number of allowances allocated in a particular year, the amount representing that year's allowable SO2
emissions level, is the sum of allowance allocations granted to sources under several provisions of the Act. In
1999, the emissions target established by the program for the 398 participating units was 6.99 million tons.
However, the total allowable SO2 emission level in 1999 was actually 16.62 million tons, consisting of the
6.99 million 1999 allowances granted through the program and an additional 9.63 million allowances carried
over, or banked, from 1998.
The initial allocation and the allowances for substitution and compensating units represent the basic
allowances granted to units that authorize them to emit SO2 under the Acid Rain Program. Additional
allowances for the year 1999 were also made available through the allowance auctions, held annually since
1993. Other allowances issued in 1999 were from special provisions in the Act, which are briefly explained
in Exhibit 2 on the following page. In addition, any allowances carried over from previous years (banked
allowances) are available for compliance and included in the allowable total.
Beginning in the year 2000 at the onset of Phase n, the volume of allowances allocated annually to the Phase
I units will be reduced and the requirement to hold allowances will be extended to smaller, cleaner plants.
Nationwide, the cap for all utilities with an output capacity of greater than 25 megawatts will be 9.48 million
allowances from 2000-2009. In 2010, the cap will be reduced further to 8.95 million allowances, a level
approximating one half of industry-wide emissions in 1980.
SO2 COMPLIANCE RESULTS
Phase I Units Better 1999 SO2 Allowable Emissions Level by 29 Percent
The Phase I units affected in 1999 emitted at a level approximately 29 percent below 1999 allocations, as
shown in Exhibit 3. This percentage is greater than that of 1998, since SO2 emissions decreased while
allocations remained relatively constant. Appendix B-3 reports the 1999 emission and utilization levels for all
Phase I affected units, as well as a comparison to these levels in 1998.
averaged over the years 1985-1987). A Table 1 unit may designate a Phase II unit as a compensating unit if the
Phase II compensating unit is in the Table 1 unit's dispatch system or has a contractual agreement with the Table 1
unit, and the emissions rate of the compensating unit has not declined substantially since 1985. See Appendix B-l
for the relationship of these units to their Table 1 counterparts.
The Opt-in Program gives sources not required to participate in the Acid Rain Program the opportunity to
enter the program on a voluntary basis, install continuous emission monitoring systems (CEMS), reduce their SO2
emissions, and receive their own allowances.
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1999 Compliance Report
Page 6
Relative to 1998, the 263 Table 1 units decreased their emissions by about 310,000 tons, or more than seven
percent in 1999, while decreasing their utilization by just under one percent. The 4.35 million tons emitted by
these Table 1 units were still substantially below their 1999 allocation of 5.55 million allowable tons.
Exhibit 2
Origin of 1999 Allowable Emissions Level
Type of Allowance
Allocation
Initial Allocation
Phase I Extension
Allowances for Substitution Units
Allowance Auctions
Allowances for Compensating
Units
Opt-in Allowances
Small Diesel Allowances
TOTAL 1999 ALLOCATION
BANKED 1998 ALLOWANCES
TOTAL 1999 ALLOWABLE
Number of
Allowances
5,550,820
171,710
909,455
150,000
85,138
97,392
25,617
6,990,132
9,627,980
16,618,112
Explanation of Allowance Allocation Type
Initial Allocation is the number of allowances granted to units
based on their historic utilization, emissions rates specified in the
Clean Air Act and other provisions of the Act.
Phase I Extension allowances are given to Phase I units that
reduce their emissions by 90 percent or reassign their emissions
reduction obligations to units that reduce their emissions by 90
percent.
Allowances for Substitution Units are the initial allocation
granted to Phase II units which entered Phase I as substitution
units.
Allowance Auctions provide allowances to the market that were
set aside in a Special Allowance Reserve when the initial
allowance allocation was made.
Allowances for Compensating Units are the initial allocation
granted to Phase II units which entered Phase I as compensating
units.
Opt-in Allowances are provided to units entering the program
voluntarily.
Small Diesel Allowances are allocated annually to small diesel
refineries that produce and desulfurize diesel fuel during the
previous year. These allowances can be earned through 1 999.
Banked Allowances are those held over from 1995 through 1998
which can be used for compliance in 1 999 or any future year.
Substitution and compensating units in 1999 expended a lower percentage of their annual allocation then in
1998. In 1999, these 125 units were responsible for emitting approximately 510,000 tons of SO2, about 52
percent of their 990,000 allowance allocation. In 1998, 135 substitution and compensating units emitted
approximately 550,000 tons of SO2, or 58 percent of their 950,000 allowable level.
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1999 Compliance Report
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Exhibit 3
Summary of SO2 Emissions versus Allocations
(Millions of Tons)
•
Table 1
S&C
Other
TOTALS
95 Alloc.
5.55
1.33
1.86
8.74
95 Emiss.
4.45
0.85
0.00
5.30
96 Alloc.
5.55
1.18
1.57
8.30
96 Emiss.
4.77
0.63
0.04
5.44
97 Alloc.
5.55
1.04
0.56
7.15
97 Emiss.
4.77
0.62
0.08
5.47
98 Alloc.
5.55
0.95
0.45
6.95
98 Emiss.
4.66
0.55
0.08
5.29
99 Alloc.
5.55
0.99
0.45
6.99
99 Emiss.
4.35
0.51
0.08
4.94
No new opt-in units joined the program in 1999, so the total allocation to opt-ins of 97,000 allowances
remained almost the same as in 1998, but emissions levels rose from 80,000 tons in 1998 to 84,000 tons in
1999. The percentage of emissions to allowances allocated to opt-in units in 1999 therefore rose to 87
percent, as compared to 82 percent in 1998.
Deducting Allowances for Compliance
The total number of allowances deducted in 1999 was 4,948,090 which represents approximately 71 percent
of all 1999 allowances issued. Almost all (99.93 percent) of the deducted allowances were for emissions.
Exhibit 4 displays these allowance deductions, as well as the remaining bank of 1995 through 1999
allowances.
At an individual unit, the number of allowances surrendered was equal to the number of tons emitted at the
unit, except where the unit shared a common stack with other units. For the purposes of surrendering
allowances for emissions at a common stack, the utility was allowed to choose the proportion of allowances
deducted from each unit sharing the stack, as long as enough allowances were surrendered to cover the total
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1999 Compliance Report Page
number of tons emitted. If no apportionment was made, EPA deducted allowances equally among the units
sharing the stack to cover total emissions reported by the stack. Appendix B-4 reflects the deductions for
emissions at each unit after the common stack apportionment was made. Units sharing a common stack are
listed directly under the entry for their common stack.
Under the Acid Rain Program, certain units applied for and received approval of Phase I Extension plans
during the Phase I permitting process. These units fell into two categories: "control units" which were
required to cut their emissions by 90 percent using qualifying technology3 by 1997, and "transfer units" which
reassigned their emissions reduction obligations to a control unit. Both kinds of units received extra SO2
emissions allowances to cover the SO2 they emitted beyond their basic Phase I allocations during 1995 and
1996. In addition, the control units were given Phase I extension allowances for 1997, 1998, and 1999. A
total of 3.5 million allowances was distributed to all Phase I extension control and transfer units.4
For 1999, all 19 control units demonstrated meeting the 90 percent reduction requirement and, therefore, did
not surrender any 1999 extension allowances. The 1999 tonnage emissions limitation, though, was exceeded
by three control units and three transfer units and resulted in a surrender of a total of 22,477 vintage 2000
allowances. The deduction amounts for each Phase I extension unit are included in Appendix B-2.
SO2 ALLOWANCE MARKET
The flexibility provided by the Acid Rain Program enabled the 398 units subject to an SO2 emissions
limitation in 1999 to pursue a variety of compliance options to meet their SO2 reduction obligations, including
scrubber installation, fuel switching, energy efficiency, and allowance trading. The presence of the allowance
market has given some sources the incentive to overcontrol their SO2 emissions in order to bank their
allowances for use in future years. Other sources have been able to postpone and possibly avoid
expenditures for control by acquiring allowances from sources that overcontrolled. The flexibility in
compliance options is possible because of the accountability provided through strict monitoring requirements
for all affected units that ensure one allowance is equivalent to one ton of SO2. The program's flexibility
enabled all 398 sources to be in compliance in 1999 and significantly reduced the cost of achieving these
emissions reductions as compared to the cost of a technological mandate.
Qualifying technology is defined at 40 CFR 72.2.
Beginning in 1997, each of the 19 units designated as control units was required to show it had reduced
its annual emissions by at least 90 percent using qualifying control technology. If a unit could not make this
demonstration, all or a portion of the extension allowances it received for the year under the Phase I Extension
provisions were required to be surrendered. In addition, also beginning in 1997, each of the same 19 control units
and each of the 61 other units designated as transfer units was required to meet a tonnage emission limitation
approved in its permit. A unit that exceeded its limitation was required to surrender allowances for the following
year.
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1999 Compliance Report
Page 9
Exhibit 4
SO2 Allowance Reconciliation Summary
Total Allowances Held in Accounts as of 3/1/00 (1995 through 1999 Vintages)*
16,556,056
Table 1 Unit Accounts
Substitution & Compensating Unit Accounts
Opt-in Accounts
Other Accounts**
Allowances Deducted for Emissions in 1999
8,577,556
1,137,851
87,482
6,753,167
4,944,676
Table 1 Unit Accounts
Substitution & Compensating Unit Accounts
Opt-in Unit Accounts
Allowances Deducted Under Special Phase I Provisions in 1999***
4,350,181
510,495
84,000
3,425
Table 1 Unit Accounts
Substitution & Compensating Unit Accounts
Opt-in Unit Accounts
Banked Allowances
980
2,311
134
11,607,955
Table 1 Unit Accounts
Substitution & Compensating Unit Accounts
Opt-in Unit Accounts
Other Accounts**
4,226,395
625,045
3,348
6,753,167
* The number of allowances held in the Allowance Tracking System (ATS) accounts equals the number of 1999 allowances
allocated (see Exhibit 2) plus the number of 1998 banked allowances. March 1, 2000 represents the Allowance Transfer
Deadline, the point in time at which the 1999 Phase I affected unit accounts are frozen and after which no transfers of 1995
through 1999 allowances will be recorded. The freeze on these accounts is removed when annual reconciliation is complete.
** Other accounts refers to general accounts within the ATS that can be held by any utility, individual or other
organization, and unit accounts for units not affected in Phase I.
***Allowances were deducted for both underutilization and state cap provisions in 1999 (see Appendix B-4 for a thorough
explanation).
The marginal cost of reducing a ton of SO2 from the utility sector should be reflected in the price of an
allowance. The cost of reductions continues to be lower than anticipated when the Clean Air Act
Amendments were enacted, and the price of allowances reflects this. The cost of compliance was initially
estimated at $400-1000/ton, but declined from over $200 in early 1999 to less than $150 by the end of 1999.
The price was $13 I/ton at the 2000 allowance auction, and prices have remained in the $130 to $140 range
since January of 2000. Some market observers believe lower than expected allowance prices during the first
several years of the program were due primarily to lower than expected compliance costs and larger than
expected emission reductions, which have increased the supply of allowances and put downward pressure on
prices. Exhibit 5 displays the price trend since mid-1994, based on monthly price reports from Cantor
Fitzgerald Environmental Brokerage Services, and a market survey conducted by Fieldston Publications.
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1999 Compliance Report
Page 10
Exhi
bit5
SO2 Allowance Price Indices
Fieldston Publications Price Index Cantor Fitzgerald Market Price Index
$250
$0
Jan-94
Jan-95 Jan-96
Jan-97 Jan-98 Jan-99 Jan-00
Activity in the allowance market created under the Acid Rain Program remained strong in 1999, with 2,832
transactions moving about 18.7 million allowances in the Allowance Tracking System (ATS), the accounting
system developed to track holdings of allowances. In terms of economically significant transfers, or those
between unrelated parties, the volume of allowances declined from 9.5 million in 1998 to 6.2 million in 1999.
Thirty three percent of annual activity consisted of allowances transferred between economically distinct
organizations, with a little less than half of that amount represented by allowances directly acquired by utilities.
The most active market segment in 1999 in terms of allowance volume was composed of exchanges in the
reallocation category, which covered 11.4 million allowances. The next most active segment were trades
between brokers/traders and utilities, which accounted for 3.4 million allowances.
All transactions, along with data on account balances and ownership, are posted on the Acid Rain Division's
Internet site (www.epa.gov/acidrain) on a daily basis in order to better inform trading participants. Also
available are cumulative market statistics and analysis.
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1999 Compliance Report
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Exhibit 6
20
SO2 Allowances Transferred Under the Acid Rain Program
0)
u
c
10
0
1994 1995 1996 1997 1998
DTransactions Between Economically Related Entities
D Transactions Between Economically Unrelated Entities
1999
ACID RAIN NOX PROGRAM
Instead of using allowance trading to facilitate emissions reductions, the Title IV NOX program establishes
standard emission limitations for affected units. Title IV of the 1990 Clean Air Act Amendments required
EPA to establish NOX annual average emission limits (in pounds of NOX per million British thermal units of fuel
consumed (Ib/mmBtu)) for coal-fired electric utility units in two phases.
In April 1995, EPA promulgated 40 CFR part 76, which established NOX emission limits beginning on
January 1, 1996 for Group 1 boilers that were also part of the Phase I SO2 program. (Group 1 boilers are
dry bottom, wall-fired boilers or tangentially-fired boilers). Phase I dry bottom wall-fired boilers are subject
to a NOX emission limit of 0.50 Ib/mmBtu; Phase I tangentially-fired boilers are subject to a NOX emission
limit of 0.45 Ib/mmBtu.
In addition, the April 1995 regulations allowed Phase U Group 1 units to use an "early election" compliance
option. Under this regulatory provision, Phase U, Group 1 NOxaffected units can demonstrate compliance
with the higher Phase I limits for their boiler type from 1997 through 2007 and not meet the more stringent
Phase U limits until 2008. If the utility fails to meet this annual limit for the boiler during any year, the unit is
subject to the more stringent Phase U limit for Group 1 boilers beginning in 2000, or the year following the
exceedance, whichever is later.
In December 1996, EPA revised the NOX emission limits for Phase U, Group 1 boilers (0.46 Ib/mmBtu for
dry bottom wall-fired boilers and 0.40 Ib/mmBtu for tangentially-fired boilers) and established emission limits
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1999 Compliance Report
Page 12
for cell burner, cyclone, wet bottom and vertically-fired boilers (referred to as "Group 2 boilers") effective on
January 1, 2000. As a result of the April 1995 and December 1996 rulemakings, NOX reductions were
projected to be approximately 400,000 tons per year in 1996 through 1999 (Phase I), and 2,060,000 tons
per year in 2000 and subsequent years (Phase II).
PHASE I NOX UNITS
265 Phase I Units Were Subject to Emission Limitations in 1999
In 1999, 265 coal-fired utility units were subject to the Title IV Phase I emission limitations for NOX. The 265
Phase INOX affected units include 171 Table 1 units and 94 substitution units whose owners chose to
participate in Phase I as part of an SO2 compliance strategy. This group of units is subject to the Phase I
emission limitations throughout Phase I and Phase U. Exhibit 7 below shows the number of Phase INOX
affected units by boiler type.
Exhibit 7
Phase I NOX Units by Boiler Type
Boiler Type
Tangentially -fired Boilers
Dry Bottom Wall-fired Boilers
Standard
Emission Limit
0.45
0.50
Table 1
Units
94
77
Substitution
Units
41
53
All Units
135
130
Phase I NOX Compliance Options
For each Phase INOX affected unit, a utility can comply with the applicable standard emission limitation, or
may qualify for one of two additional compliance options which add flexibility to the rate-based compliance
requirements:
! Emissions Averaging. A utility can meet the standard emission limitation by averaging the heat-input
weighted annual emission rates of two or more units.
! Alternative Emission Limitation (AEL). A utility can petition for a less stringent alternative
emission limitation if it uses properly installed and operated low NOX burner technology (LNBT)
designed to meet the standard limit, but is unable to achieve that limit. EPA determines whether an
AEL is warranted based on analyses of emissions data and information about the NOX control
equipment.
Exhibit 8 summarizes the compliance options chosen by Phase I affected NOX units for 1999. As in 1996,
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1999 Compliance Report
Page 13
1997, and 1998, averaging was the most widely chosen compliance option. For 1999, there were 22
averaging plans involving 204 Phase INOX units. See Appendix C-l: List of Averaging Plans and Results in
1999.
Exhibit 8
Compliance Options Chosen in 1999
Compliance Option
Compliance with Standard Emission Limitation
Emissions Averaging
Alternative Emission Limitation
TOTAL
Number of Units
51
204
10
265
PHASE I NOX COMPLIANCE RESULTS
For 1999, EPA has determined that all 265 Phase INOX units met the required emission limit through
compliance with either the standard emission limitation, emissions averaging, or an alternative emission
limitation. See Appendix C-2: Compliance Results for the 265 NOX Affected Units. For a more detailed
description of EPA's methodology for determining compliance with Phase INOX limits, see Appendix C-4 in
the Acid Rain Program 1996 Compliance Report.
NOX Emission Rate Reduction
From 19905 to 1999, the average NOX emission rate of the 265 Phase I units declined by 43 percent (from
0.70 Ib/mmBtu to 0.40 Ib/mmBtu). As shown in Exhibit 9, on average, both Table 1 and substitution units
were below the average Phase I emission limit of 0.49 Ib/mmBtu (the heat input weighted average of the
applicable limits).
For a more detailed description of the 1990 baseline refer to the Acid Rain Program 1996 Compliance
Report.
-------
1999 Compliance Report
Page 14
Exhibit 9
Average NOX Emission Rates for 265 Phase I Units
NCkRate
(Ib/mmBtu)
1.00
0.80
0.60
0.40
0.20
0.00
0.77
Weighted Average
Emissions Limitation
/ (0-49)
0.52
0.45
0.36
0.44
0.36
i
0.43
0.37
i
0.42
0.34
1990 1996 1997 1998 1999
D Table 1 Units (171) D Substitution Units (94)
NOX Mass Emissions Reduction
Exhibit 10 illustrates the change in NOX mass emissions since 1990 for Table 1 and substitution units. For the
265 units, total NOX mass emissions in 1999 were 32 percent lower than in 1990, and 3 percent lower than in
1998. However, in 1999, total heat input was only 0.1 percent lower than in 1998. Therefore, the 2 percent
decrease in the NOX emission rate from 0.41 Ib/mmBtu 1998 to 0.40 Ib/mmBtu in 1999 had a greater impact
on the reduction in NOX mass emissions in 1999 than the reduction in total heat input.
-------
1999 Compliance Report
Page 15
Exhibit 10
NOX Mass Emissions for 265 Phase I Units
1,600,000
NOX
Tons
1,200,000 -
800,000 -
400,000 -
1990
1996
1997
1998
287,583
1,046,339
669,017
676,797
257,176
686,492
672,265
1999
D Table 1 Units (171) D Substitution Units (94)
PHASE II EARLY ELECTION UNITS
274 Units Were Subject to Early Election Requirements in 1999
Nineteen ninety-nine was the third year in which early election utilities were required to meet the Phase INOX
limit6 Exhibit 11 shows the number of early election units by boiler type and their corresponding emission
limit.
Exhibit 11
Distribution of 1999 Early Election Units by Boiler Type
Boiler Type
T angenti ally -fired
Dry Bottom Wall-fired
Total
Standard
Emission Limit
0.45
0.50
Operating Phase H,
Group 1 Units
300
314
614
Early Election
Units
171
103
274
Percent of
Units Electing
57%
33%
45%
Compared with 1998, the universe of early election units was the same, except that the early election plan
for D.B. Wilson Unit Wl was terminated effective January 1, 1999.
-------
1999 Compliance Report
Page 16
PHASE II EARLY ELECTION COMPLIANCE RESULTS
For 1999, EPA determined that all 274 units complied with the Phase I, Group 1 emission limitations and have
continued eligibility for early election in 2000 through 2007. See Appendix C-3: Compliance Results for the
274 Early Election Units in 1999.
Average NOX emission rates for early election units have declined by 20 percent, from 0.46 Ib/mmBtu in 1990
to 0.37 Ib/mmBtu in 1999. This decline is less dramatic than the decline at Phase INOX units because 51
percent of the early election units are newer units already subject to the 1979 New Source Performance
Standards (NSPS) NOX emission limits. The overall NOX emission rate for the early election units is
comparable to the average rate of 0.40 Ib/mmBtu for all Phase INOX units. Exhibit 12 summarizes the NOX
emission rate reductions from 1990 to 1999 by boiler type for the 264 early election units that were operating
in 1990.
Exhibit 12
Average NOX Emission Rate for 264 Early Election Units
0.80
0.60
NOxRate
(Ib/mmBtu)
0.40 -'
0.20 -'
0.00
Tangentially-Fired Boilers
Emissions Limit (0.45)
0.45
0.37
0.37
0.36
Dry-Bottom Wall-Fired Boilers
Emissions Limit (0.50)
0.47
0.38
0.38
0.38
1990 1997 1998 1999 1990 1997 1998 1999
NOX Mass Emissions Reduction
The total NOX mass emissions from the operating early election units increased by 25,708 tons (or 2 percent)
from 1990 to 1999, reflecting an increase in utilization (see Exhibit 13). However, for the 264 early election
units operating in 1990, heat input increased during the nine year period by approximately 28 percent. The
NOX mass emissions decreased by 4 percent from 1998 to 1999, due to a 1 percent decrease in heat input
and a 3 percent decrease in the overall NOX emission rate.
-------
1999 Compliance Report
Page 17
Exhibit 13
NOX Mass Emissions for 264 Early Election Units
1,600,000
1,200,000 -
NOX
Tons 800'000
400,000 -
565,084
716,480
576,567
750,872
594,394
772,054
578,383
736,161
1990
1997
1998
1999
D T-Fired Units (163) D DB Units (101)
SO2 AND NOX MONITORING IN 1999
In order to verify the reductions of SO2 and NOX emissions mandated under the Clean Air Act and to support
the SO2 allowance trading program, a fundamental objective of the Acid Rain Program is to ensure accurate
and complete accounting of pollutant emissions from affected boilers and turbines. To implement this
objective, concentrations of emitted SO2 and NOX from each affected unit (boiler or turbine) are measured
and recorded using Continuous Emissions Monitoring Systems (CEMS) (or an approved alternate
measurement method) certified by EPA to meet the high accuracy standards of the Acid Rain Program.
CEMS are used to determine SO2 mass emissions and NOX emission rates. SO2 mass emissions are
determined using CEMS to measure SO2 concentration and stack flow rate. NOX emission rates, on the other
hand, are determined with NOX and diluent gas (CO2 or O2) concentration monitors. These
monitors are required to meet strict initial and on-going performance standards to demonstrate the accuracy,
precision, and timeliness of their measurement capability.
One measure of the accuracy of a CEMS is the relative accuracy test audit (RATA), which is required for
initial certification of a CEMS and for on-going quality assurance. The relative accuracy test audit ensures that
the installed monitor measures the "true" value of the pollutant by comparing the monitor to a reference method
which simultaneously measures the stack gas pollutant. Thus, the lower the relative accuracy resulting from the
test audit, the more accurate the monitor. All monitoring systems must meet a certain relative accuracy
-------
1999 Compliance Report
Page 18
standard in order to be qualified to report emissions to the Acid Rain Program; 10 percent for SO2 and NOX
and 15 percent for flow (beginning January 1, 2000, the flow standard is 10 percent). As a further incentive
for high quality maintenance, CEMS that achieve a superior accuracy result, less than or equal to 7.5 percent
for SO2 and NOX and less than or equal to 10 percent for flow (beginning January 1, 2000, the flow standard
for superior accuracy is 7.5 percent), are granted a reduced frequency annual RATA requirement in place of
the semiannual requirement. Because the RATA determines relative accuracy as an absolute value, it does not
detect whether the difference between the reference method values and the readings from the CEMS being
tested is due to random error or to systematic bias. Therefore, an additional test is required to ensure that
emissions are not underestimated: the bias test. This test determines if the CEMS is systematically biased low
compared to the reference method and if so, a bias adjustment factor is calculated and applied to all reported
data from that monitoring system to ensure there is no systematic underreporting. Exhibit 14 highlights the
relative accuracy results achieved by Acid Rain CEMS in 1999.
Exhibit 14
1999 Relative Accuracy Test Audit (RATA) Results
Mean Relative Accuracy
Median Relative Accuracy
Percent Meeting Relative Accuracy
Standard
SO2 Concentration
4.2%
3.0%
96.2%
Volumetric Flow Rate
3.9%
3.2%
99.4%
NOX Rate
4.5%
3.4%
95.7%
Another metric used to determine the effectiveness of a CEMS is the percentage of hours that a monitoring
system is operating properly and meeting all performance standards and therefore, able to record and report
an emissions value. This metric is defined as the percent monitor availability (PMA). Exhibit 15 shows the
monitor availabilities reported in 1999 and indicates that the CEMS used to determine SO2 mass emissions
and NOX emission rates are well maintained and fulfilling the high performance standards required by the Acid
Rain Program.
Exhibit 15
1999 CEMS Availability
Parameter
SO2
Flow
NOX
Median % Availability at End of 1999
Coal-Fired Units
99.5
99.7
99.2
Oil and Gas Units
98.9
99.0
98.4
-------
1999 Compliance Report Page 19
CONCLUSION
1999 proved to be another successful year for both the Acid Rain Program's rate-based approach to NOX
reduction and cap-and-trade approach to SO2 reduction. In 1999, all Phase I affected utility units not only
met their compliance goals, but exceeded them, achieving an overall reduction of 423,857 tons of NOX from
1990 levels, and maintaining the extraordinary reductions of more than 5 million tons of SO2 from 1980 levels,
first achieved in 1995. Additionally, the 274 Phase n NOX early election units had increased emissions of two
percent since 1990, while their utilization increased by 28 percent during the same period.
Exceedance of compliance goals translates into additional environmental and health benefits. For example, the
greater and earlier reductions of SO2 have resulted in a 10 - 25 percent drop in rainfall acidity in the Northeast
in 1995 through 1997 since the beginning of Phase I.7
One factor mitigating the benefit of the overcompliance in the SO2 program, of course, is the ability to use
banked allowances in the future. The 40 percent of 1995 allowances, 35 percent of 1996 allowances, 23
percent of 1997 allowances, 24 percent of 1998 allowances, and 29 percent of 1999 allowances that were
not retired for compliance purposes can be used to cover emissions in a later year. However, receiving health
and environmental benefits earlier may be of greater value than receiving those benefits several years from
now.
The NOX program, based on the more traditional rate-based approach, offers less flexibility and displays a
lesser degree of overcompliance. It requires each unit to achieve reductions or, at a minimum, for a group of
units to achieve an average emission rate equal to or lower than their individual limits. This approach does not
allow emission reductions in one year to be used in another year, and as a result, the incentive to overcomply is
diminished.
The pattern and certainty of emissions reductions over time will also differ between the two programs.
Beginning in the year 2000 when both programs are in full implementation, SO2 emissions are expected to
decline steadily toward the emissions cap level of 8.95 million tons, whereas NOX emissions, in the absence of
an emissions cap, are expected to rise as existing sources are utilized more and new sources, which are not
required to offset their emissions, are built and operated.
Despite these differences, both the SO2 and NOX components of the Acid Rain Program were successful in
Phase I. Through the continued efforts of Phase I participants and with additional reductions from Phase n
units beginning in 2000, the long term goals of the Acid Rain Program — a 10 million ton reduction of SO2
emissions and two million ton reduction of NOX emissions — will be achieved.
Lynch, James A., Van C. Bowersox, and Jeffrey W. Grimm. 2000. "Changes in Sulfate Deposition in
Eastern USA Following Implementation of Phase I of Title IV of the Clean Air Act Amendments of 1990."
Atmospheric Environment 34: 1665-1680.
-------
APPENDIX A: PHASE I AFFECTED (• ) AND EARLY ELECTION (E) UNITS IN 1999
ST
AL
AL
AL
AL
AR
AR
AR
AZ
AZ
AZ
AZ
AZ
COO
CO
Plant Name
Charles R Lowman
Colbert
E C Gaston
Gadsden
Flint Creek
Independence
White Bluff
Apache
Cholla
Coronado
Navajo
Springerville
Craig
Comanche
Unit ID
2
3
1
2
3
4
5
1
2
3
4
5
1
2
1
1
2
1
2
2
3
1
2
3
4
U1B
U2B
1
2
3
1
2
Cl
C2
C3
1
2
SO2 NOx
E
E
. .
. .
.
•
• •
. .
. .
•
• •
•
•
•
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
ST
CO
CO
CO
CO
CO
CT
FL
FL
FL
FL
FL
FL
FL
FL
GA
GA
Plant Name
Cherokee
Pawnee
Rawhide
Ray D Nixon
Valmont
Bridgeport Harbor
Big Bend
C D Mclntosh
Cnst
Crystal River
Deerhaven
St Johns River
Scholz
Seminole
Arkwright
Bowen
Unit ID
3
4
1
101
1
5
BHB3
BB01
BB02
BB03
BB04
3
4
5
6
7
2
4
5
B2
1
2
1
2
1
2
1
2
3
4
1BLR
2BLR
3BLR
4BLR
SO2 N<
E
E
E
E
E
E
E
•
•
•
•
E
•
•
•
•
E
E
E
E
E
E
. .
• •
E
E
•
• •
•
•
•
•
•
•
A-l
-------
APPENDIX A: PHASE I AFFECTED (• ) AND EARLY ELECTION (E) UNITS IN 1999
ST
GA
GA
GA
GA
GA
GA
GA
GA
GA
IA
IA
IA
IA
IA
Plant Name
Hammond
Harllee Branch
Jack McDonough
Kraft
Mcintosh
Mitchell
Scherer
Wansley
Yates
Ames
Burlington
Council Bluffs
Des Moines
George Neal North
Unit ID SO2 NOx
1
2 • •
3 • •
4
1
2
3 •
4
MB1
MB2
1
2
3
1
3 • •
3
4 E
1
2 • •
Y1BR
Y2BR
Y3BR
Y4BR
Y5BR
Y6BR
Y7BR
7 E
8 E
1
1 E
2 E
3 E
11
1
2 E
3 E
ST
IA
IA
IA
IA
IA
IA
IA
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
Plant Name
George Neal South
Lansing
Louisa
Milton L Kapp
Ottumwa
Prairie Creek
Riverside
Baldwin
Coffeen
Crawford
Dallman
Fisk
Grand Tower
Havana
Hennepin
Hutsonville
Joppa Steam
Kincaid
Unit ID
4
4
101
2
1
4
9
1
2
3
1
2
7
8
33
19
7
8
9
6
1
2
5
6
1
2
3
4
5
6
1
2
SO2 NOx
E
E
E
•
E
.
•
•
•
•
•
•
E
E
E
E
•
•
•
•
•
•
•
•
.
• •
•
•
•
•
•
.
A-2
-------
APPENDIX A: PHASE I AFFECTED (• ) AND EARLY ELECTION (E) UNITS IN 1999
ST
IL
IL
IL
IL
IL
IL
IN
IN
IN
IN
IN
IN
IN
IN
Plant Name
Meredosia
Newton
Vermilion
Waukegan
Will County
Wood River
A B Brown
Bailly
Breed
Cayuga
Cliffy Creek
Dean H Mitchell
Elmer W Stout
F B Culley
Unit ID SO2 NOx
1
2 •
3 •
4
5
1
2 •
1
2 • •
7 E
8 E
3 E
4 E
1
1 E
2 E
7
8
1
1
2 • •
1
2
3
4
5
6
4 E
5 E
6 E
11 E
50
60
70
2 • •
3
ST Plant Name
IN Frank ERatts
IN Gibson
IN H T Pntchard
IN Merom
IN Michigan City
IN Petersburg
IN RMSchahfer
IN R Gallagher
IN Rockport
IN State Line
IN Tanners Creek
IN Wabash River
IN Wamck
Unit ID
1SG1
2SG1
1
2
3
4
3
4
5
6
1SG1
2SG1
12
1
2
3
4
15
17
18
1
2
3
4
MB1
MB2
3
U4
1
2
3
5
6
1
2
3
4
SO2 N<
. .
•
•
•
•
•
.
•
•
•
E
E
•
.
• •
•
•
E
E
E
•
•
•
•
E
E
E
•
•
•
•
•
•
•
•
•
•
A-3
-------
APPENDIX A: PHASE I AFFECTED (• ) AND EARLY ELECTION (E) UNITS IN 1999
ST
IN
KS
KS
KS
KS
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KYI
KY
Plant Name
Whitewater Valley
LaCygne
Nearman Creek
Quindaro
Riverton
Cane Run
Coleman
Cooper
E W Brown
East Bend
Elmer Smith
Ghent
Green River
HLSpurlock
Hmp&L Station 2
Mill Creek
Paradise
Unit ID
1
2
1
2
1
2
39
40
4
5
6
Cl
C2
C3
1
2
1
2
3
2
1
2
1
5
1
2
HI
H2
1
2
3
4
3
SO2 NOx
E
E
.
•
E
•
E
E
E
E
E
•
•
•
•
•
•
•
• •
. .
•
.
• •
. .
•
E
•
•
E
E
E
E
•
ST
KY
KY
KY
KY
LA
LA
LA
LA
MA
MA
MD
MD
MD
MD
MI
MI
MI
MI
MI
Plant Name
RD Green
Shawnee
Trimble County
WC Dale
Big Cajun 2
Dolet Hills
RS Nelson
Rodemacher
Brayton Point
Mount Tom
CP Crane
Chalk Point
Morgantown
RP Smith
B C Cobb
DanEKam
JBSims
J C Weadock
JH Campbell
Unit ID
Gl
G2
10
1
3
4
2B1
2B2
2B3
1
6
2
1
2
1
1
2
1
2
3
1
2
9
11
4
5
2
3
7
8
1
2
SO2 N<
. .
•
.
E
E
E
E
E
E
E
E
E
•
•
•
•
•
. .
•
•
•
• •
. .
•
E
E
•
E
E
E
• •
•
A-4
-------
APPENDIX A: PHASE I AFFECTED (• ) AND EARLY ELECTION (E) UNITS IN 1999
ST
MI
MI
MN
MN
MN
MN
MO
MO
MO
MO
MO
MO
MO
MO
MO
Plant Name
JR Whiting
Presque Isle
Clay Boswell
High Bridge
Hoot Lake
Sherbume County
Asbury
Hawthorn
latan
James River
Labadie
Meramec
Montrose
New Madrid
Rush Island
Unit ID SO2 NOx
1 • E
2 •
3 • E
7 E
8 E
9 E
3 E
3 • •
4
5
6
2 E
1
2 • •
1
5
1
3
4
5
1
2 • •
3
4
1
2 • •
3 • •
4
1
2 • •
3
1
2 •
1
2
ST Plant Name Unit ID
MO Sibley 1
2
3
MO Sioux 1
2
MO Sikeston 1
MO Southwest 1
MO Thomas Hill MB1
MB2
MBS
MS Jack Watson 4
5
MS RD Morrow 1
2
MS Victor J Daniel Jr 1
2
MT Colstnp 1
2
3
4
MT Lewis & Clark Bl
NC Buck 5
6
7
8
9
NC Cliffside 1
2
3
4
5
NC Dan River 1
2
3
SO2 N<
.
•
•
.
•
E
•
•
•
• •
. .
•
•
•
•
•
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
A-5
-------
APPENDIX A: PHASE I AFFECTED (• ) AND EARLY ELECTION (E) UNITS IN 1999
ST
NC
NC
NC
ND
ND
ND
NE
NE
NE
NE
NE
NHE
NJ
NM
NV
NV
NV
Plant Name
GG Allen
Marshall
Riverbend
Antelope Valley
Leland Olds
Stanton
Gerald Gentleman
Gerald Whelan
Nebraska City
North Omaha
Platte
Merrimack
B L England
Escalante
Mohave
North Valmy
Reid Gardner
Unit ID
1
2
o
J
4
5
1
2
o
J
4
7
8
9
10
Bl
B2
1
10
1
2
1
1
4
1
1
2
1
2
1
1
2
1
2
4
SO2 NOx
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
•
•
•
•
E
E
E
E
E
E
ST Plant Name
NY CRHuntley
NY Dunkirk
NY Greenidge
NY Kintigh
NY Miffiken
NY Northport
NY Port Jefferson
NY S A Carlson
OH Acme
OH Ashatabula
OH Avon Lake
OH Bay Shore
Unit ID
67
68
1
2
3
4
6
1
1
2
1
2
3
4
3
4
9
10
11
12
13
14
15
16
91
92
7
8
9
10
11
9
10
11
12
1
2
3
4
SO2 N<
E
E
E
E
• •
• •
• •
E
• •
• •
•
•
•
•
•
•
E
E
E
E
•
•
•
•
•
•
• •
•
•
•
•
•
•
•
•
•
•
•
•
A-6
-------
APPENDIX A: PHASE I AFFECTED (• ) AND EARLY ELECTION (E) UNITS IN 1999
ST
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Plant Name
Cardinal
Conesville
Eastlake
Edgewater
Gen J M Gavin
Gorge
JM Stuart
Kyger Creek
Lake Shore
Miami Fort
Unit ID SO2 NOx
1
2 •
1
2
3
4
5 E
6 E
1
2
3
4
5
11
12
13
1
2
25
26
1
2
3
4
1
2
3
4
5
18
91
92
93
94
5-1
5-2
6
7
ST
OH
OH
OH
OH
OH
OH
OH
OH
OH
OK
OK
OK
OR
PA
Plant Name
Muskingum River
Niles
Picway
Poston
RE Burger
Toronto
WHSamms
WHZimmer
Walter CBeckjord
Muskogee
Northeastern
Sooner
Boardman
Armstrong
Unit ID
1
2
3
4
5
1
2
9
1
2
3
1
2
3
4
5
6
7
9
10
11
5
6
7
1
5
6
4
5
6
3313
3314
1
2
1SG
1
2
SO2 N<
•
•
•
•
•
•
•
• •
•
•
•
•
•
•
•
•
•
• •
•
• •
• •
• •
• •
•
E
• •
• •
E
E
E
E
E
E
E
E
• •
• •
A-7
-------
APPENDIX A: PHASE I AFFECTED (• ) AND EARLY ELECTION (E) UNITS IN 1999
ST
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
Plant Name
Bruce Mansfield
Brunner Island
Cheswick
Conemaugh
Cromby
Eddy stone
Hatfield's Ferry
Homer City
Keystone
Martins Creek Cree
Mitchell
Montour
New Castle
Unit ID
1
2
3
1
2
3
1
1
2
1
1
2
1
2
3
1
2
3
1
2
1
2
3
4
33
1
2
1
2
3
4
5
SO2 NOx ST Plant Name
PA Shawville
•
E
•
• • PA Sunbury
• •
PA Titus
•
•
SC Cross
E
E SC WSLee
E
•
TN Allen
•
E
E TN Cumberland
E
E TN DuPont
E Johnsonville
•
.
TN Gallatin
•
• •
E TN John Sevier
E
•
.
E
E
E
Unit ID
1
2
3
4
3
4
1
2
3
1
2
1
2
3
1
2
3
1
2
JVD1
JVD2
JVD3
JVD4
1
2
3
4
1
2
3
4
SO2 N<
. .
•
•
•
•
• •
E
E
E
E
E
E
E
E
•
•
•
•
•
.
•
•
•
.
•
•
• •
E
E
E
E
PA
Portland
A-8
-------
APPENDIX A: PHASE I AFFECTED (• ) AND EARLY ELECTION (E) UNITS IN 1999
ST
TN
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
Plant Name
Johnsonville
Big Brown
Coleto Creek
Gibbons Creek
Harrington
J K Spruce
J T Deely
Limestone
Martin Lake
Monticello
Oklaunion
Pirkey
Sam Seymour
San Miguel
Sandow
Unit ID
1
2
o
J
4
5
6
7
8
9
10
1
2
1
1
061B
062B
063B
XXI
1
2
LIM1
LIM2
1
2
3
1
2
o
J
1
1
1
2
3
SM-1
4
SO2 NOx
• •
• •
• •
• •
• •
• •
• •
• •
• •
• •
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
ST
TX
TX
TX
UT
UT
UT
UT
UT
VA
VA
VA
VA
VA
VA
WA
Plant Name
Tolk
W A Parish
Welsh
Bonanza
Carbon
Hunter
Huntington
Intermountain
Chesapeake
Chesterfield
Glen Lyn
Possum Point
Potomac River
Yorktown
Centralia
Unit ID
171B
172B
WAP5
WAP6
WAP7
WAP8
1
2
3
1-1
1
2
1
2
1
1SGA
2SGA
1
2
4
3
4
51
52
3
1
2
3
4
5
1
2
BW21
BW22
SO2 N<
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
A-9
-------
APPENDIX A: PHASE I AFFECTED (• ) AND EARLY ELECTION (E) UNITS IN 1999
ST
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
Plant Name
Alma
Blount Street
Columbia
Edgewater
Genoa
JPMadgett
Nelson Dewey
North Oak Creek
Port Washington
Pulliam
Rock River
South Oak Creek
Valley
Unit ID SO2 NOx
Bl
B2
B3
B4
B5
8 E
9 E
1 E
2 E
3
4
5 E
1
Bl
1
2
1
2 •
3
4
1
2 •
3
4
5
5
6
7
8
1
2 •
5
6
7
8
1
2
3
4
ST Plant Name
WI Western
WV Albright
WV Fort Martin
WV Harrison
WV Kammer
WV Mitchell
WV Mountaineer
WV Mt Storm
WV Pleasants
WV Rivesville
WY Dave Johnston
WY JimBridger
WY Laramie River
WY Wyodak
Unit ID
1
2
3
1
2
3
1
2
1
2
3
1
2
3
1
2
1
1
2
3
1
2
7
8
BW41
BW42
BW71
BW72
BW73
BW74
1
2
3
BW91
SO2 N<
• •
• •
•
• •
• •
• •
• •
•
• •
• •
• •
•
•
•
• •
• •
E
• •
• •
• •
•
•
•
•
E
E
•
•
•
E
E
E
E
•
A-10
-------
APPENDIX B-l:
Table 1 Units Designating Substitution and Compensating Units for 1999
Substitution Units
Table 1 Units
State Plant Name Units
I AL EC Gaston
FL Big Bend
FL Crist
GA Bowen
GA Bowen
GA Bowen
GA Bowen
GA Hammond
GA Hammond
GA Hammond
GA Hammond
GA Jack Mcdonough
GA Yates
GA Yates
GA Yates
GA Yates
IL Baldwin
IL Hennepin
BB01,BB02,BB03
1BLR
2BLR
3BLR
4BLR
MB2
Y2BR
Y3BR
Y4BR
YSBR
3
Substitution Units
State Plant Name Units
| IL Hennepin
^
fe*
w
^
w
^
^
^
w
>
^
^
w
^
w
^
w
^
AL
Gadsden
1,2
FL
Big Bend
BB04
FL
FL
Crist
Scholz
4,5
1,2
GA
Harllee Branch
1
GA
Harllee Branch
2
GA
Harllee Branch
3
GA
Harllee Branch
4
GA
Arkwright
1
GA
Arkwright
2
GA
Arkwright
3
GA
Arkwright
4
GA
Mitchell
3
GA
Kraft
1
GA
Kraft
2
GA
Kraft
3
GA
Mclntosh
1
IL
IL
Havana
Wood River
6
1
IL Meredosia
IL Vermilion
2
IL
IL
IL
Hutonsville
Newton
Vermilion
5,6
1,2
B-1, 1
-------
APPENDIX B-l:
Table 1 Units Designating Substitution and Compensating Units for 1999
Substitution Units
State
IN
Table 1 Units
Plant Name Units State
IN
Substitution Units
Plant Name
H T Pritchard
Units
5
KY
Coleman C1,C2 ^
KY
R D Green
G1,G2
MD
MS
R D Morrow
1,2
MD
MI
Morgantown 1,2 ^-
MD
MN
MO
High Bridge 6 ^-
MO
T ihnrlir 1 ^ 1 >\ ^-
MO
MO
Montrose 1,2,3 ^
Sioux 1,2 ^
MI
MI
MI
Chalk Point
Dan E Kam
JR Whiting
J C Weadlock
3
2
1,2,3
7,8
MN
MN
High Bridge
Sherburne County
3,4,5
1,2
MO
MO
James River
Southwest
3,4
1
MO
MO
Meramec
Rush Island
1,2,3
1,2
MO
KS
Hawthorn
La Cygne
5
1
MO
c,iMr-v ~\ ^-
MO
Sibley
1,2
MO
MO
Thomas Hill
MB 3
NH
MA
Mount Tom
1
B-1,2
-------
APPENDIX B-l:
Table 1 Units Designating Substitution and Compensating Units for 1999
Substitution Units
State
NY
Table 1 Units
Plant Name
Northport
Units State
1,2,3
^
W
NY
Substitution Units
Plant Name
Northport
Units
4
OH
Ashtabula
7
OH
Avon Lake
12
^^
^
OH
OH
OH
OH
Acme
Ashtabula
Lake Shore
Bay Shore
13,14,15,16,91,92
8,9,10,11
18,91,92,93,94
1,2,3,4
OH
Avon Lake
9,10
OH
Conesville
4
^
OH
J M Stuart
1,2,3,4
OH
OH
OH
OH
Edgewater
Niles
R E Burger
WHSammis
13
1,2
5,6,7,8
5,6,7
OH
Miami Fort
7
^
w
OH
OH
OH
OH
PA
PA
Edgewater
R E Burger
Gorge
Toronto
Bruce Mansfield
New Castle
11,12
1,2,3,4
25,26
9,10,11
1,2
1,2
KY
East Bend
2
OH
Picway
9
^
OH
Poston
1,2,3
PA
Armstrong
1
^
WV
Albright
1
PA
Armstrong
2
^
WV
Albright
2
PA
Hatfield's Ferry
3
PA
Martin's Creek
1,2
_».
PA
Mitchell
33
^^
^P
PA
Martin's Creek
3,4
WI
Edgewater
4
^
w
WI
Edgewater
3
WI
Genoa
1
WI
Nelson Dewey
1,2
^^
^
WI
WI
Alma
J P Madgett
B4,B5
Bl
WI
Rock River
1,2
WI
Pulliam
8
WV
Albright
3
*
*
WI
WI
Pulliam
Weston
5,6,7
1,2
MD
R P Smith
9
B-1,3
-------
APPENDIX B-l:
Table 1 Units Designating Substitution and Compensating Units for 1999
Substitution Units
Table 1 Units Substitution Units
State Plant Name Units State Plant Name Units
wv
Fort Martin
2
^
MD
R P Smith
11
wv
Harrison
1
^^
^^
WV
Rivesville
7,8
Compensating Units
Table 1 Units Compensating Units
State Plant Name Units State Plant Name Units
OH Edgewater 13| ^- I MA BraytonPoint 1,2
B-1,4
-------
APPENDIX B-2: 2000 DEDUCTION FOR EXCEEDING 1999 PHASE I EXTENSION
PROJECTED EMISSIONS LIMITATION
State
AL
FL
GA
GA
GA
GA
GA
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
MD
MD
MD
MD
NJ
NJ
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
TN
TN
TN
TN
Plant Name
Colbert
Crist
Jack Mcdonouah
Wanslev
Yates
Yates
Yates
Baillv
Baillv
Cavuaa
Cavuaa
Gibson
Michiaan Citv
R Gallaaher
R Gallaaher
R Gallaaher
R Gallaaher
Wabash River
Wabash River
Wabash River
Wabash River
Coleman
Coleman
Coleman
E W Brown
E W Brown
Ghent
Green River
Hmo&L Station 2
Hmo&L Station 2
Paradise
C P Crane
Chalk Point
Moraantown
Moraantown
B L Enaland
B L Enaland
Cardinal
Conesville
Conesville
Eastlake
Gen J M Gavin
Gen J M Gavin
Muskinaum River
Muskinaum River
Muskinaum River
Muskinaum River
Niles
Niles
Picwav
R E Buraer
R E Buraer
R E Buraer
R E Buraer
Armstrona
Brunner Island
Brunner Island
Conemauah
Conemauah
Hatfield's Ferrv
Hatfield's Ferrv
Hatfield's Ferrv
Portland
Portland
Sunburv
Sunburv
Cumberland
Cumberland
Gallatin
Gallatin
Unit ID
5
7
MB1
2
Y1BR
Y6BR
Y7BR
7
8
1
2
4
12
1
2
3
4
1
2
5
6
Cl
C2
C3
2
3
1
5
HI
H2
3
1
1
1
2
1
2
1
1
3
5
1
2
1
2
3
4
1
2
9
5
6
7
8
1
2
3
1
2
1
2
3
1
2
3
4
1
2
1
2
Ph I Ext 2000 Allowance
Type Deduction
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
TRANSFER
TRANSFER
CONTROL
CONTROL
TRANSFER
TRANSFER
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
TRANSFER
CONTROL
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
CONTROL
TRANSFER
TRANSFER
0
0
0
0
0
0
0
0
0
0
0
6734
0
0
0
0
0
0
642
0
3659
0
0
0
0
0
0
0
1061
1712
0
0
0
8669
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
B-2, 1
-------
APPENDIX B-2: 2000 DEDUCTION FOR EXCEEDING 1999 PHASE I EXTENSION
PROJECTED EMISSIONS LIMITATION
Ph I Ext 2000 Allowance
State Plant Name Unit ID Type Deduction
TN Gallatin 3 TRANSFER 0
TN Gallatin 4 TRANSFER 0
WV Fort Martin 1 TRANSFER 0
WV Fort Martin 2 TRANSFER 0
WV Harrison 1 CONTROL 0
WV Harrison 2 CONTROL 0
WV Harrison 3 CONTROL 0
WV Mt Storm 1 TRANSFER 0
WV Mt Storm 2 TRANSFER 0
WV Mt Storm 3 CONTROL 0
B-2, 2
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE I UNITS FOR 1998 AND 1999
State Plant Name
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
Colbert
Colbert
Colbert
Colbert
Colbert
Colbert
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
Gadsden
Gadsden
Big Bend
Big Bend
Big Bend
Big Bend
Big Bend
Big Bend
Crist
Crist
Crist
Crist
Scholz
Scholz
Arkwright
Arkwright
Arkwright
Arkwright
Arkwright
Bowen
Bowen
Bowen
Bowen
Hammond
Hammond
Hammond
Hammond
Hammond
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Stack/Unit ID
CSCO14(1, 2, 3,4)
1
2
3
4
5
CSOCAN (1 , 2)
1
2
CSOCBN (3, 4)
3
4
5
1
2
XS12(BB01, BB02)
BB01
BB02
XS23 (BB03, BB04)
BB03
BB04
4
5
6
7
1
2
CS001 (1 , 2, 3, 4)
1
2
3
4
1BLR
2BLR
3BLR
4BLR
CS001 (1 , 2, 3)
1
2
3
4
CS001 (1 , 2)
1
2
CS002 (3, 4)
Unit Tvne
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
1998
SO2 Utilization
Emissions (mmBtu)
13,688,471
1 1 ,842,057
1 1 ,608,467
10,521,841
27,619,312
16,687,420
16,356,089
18,250,153
16,100,133
55,502,484
3,41 1 ,299
3,271 ,925
26,361 ,877
25,476,465
26,111,060
36,267,261
4,108,663
5,008,436
18,656,237
35,964,652
1 ,583,869
2,415,353
1,138,948
1 ,048,245
1,220,110
797,426
46,331 ,230
37,829,783
63,956,453
47,544,565
4,057,785
5,257,052
4,656,394
18,223,752
13,350,533
16,451,112
26,653
47,608
25,864
25,669
41 ,489
4,751
4,463
90,881
16,544
3,255
3,872
14,461
29,005
1,877
2,877
4,272
34,016
28,130
47,897
35,108
9,842
13,217
32,342
56,643
1999
Percent Change,
1998-1999
SO2 Utilization SO2 Utilization
Emissions (mmBtu) Emissions (mmBtu)
12,943,613
13,543,511
12,242,925
10,357,632
26,136,552
19,395,339
15,425,345
19,463,758
17,436,563
55,088,509
3,203,864
3,083,316
24,289,751
24,843,034
22,280,740
29,950,140
4,655,839
3,438,040
18,654,562
35,766,644
2,268,731
2,483,103
956,636
1 ,093,075
1 ,340,936
1 ,302,409
40,516,647
47,588,155
51 ,726,332
56,716,400
5,405,746
4,903,152
4,332,31 1
28,036,147
13,400,598
13,491,886
22,601
46,972
29,118
28,502
43,508
4,242
4,289
80,704
14,910
3,329
2,391
13,233
26,748
1,557
1,733
4,089
28,631
34,348
37,294
39,881
10,346
19,579
28,996
48,692
-5.44%
14.37%
5.47%
-1 .56%
-5.37%
16.23%
-5.69%
6.65%
8.30%
-0.75%
-6.08%
-5.76%
-7.86%
-2.49%
-14.67%
-17.42%
13.32%
-31 .36%
-0.01 %
-0.55%
43.24%
2.80%
-16.01%
4.28%
9.90%
63.33%
-12.55%
25.80%
-19.12%
19.29%
33.22%
-6.73%
-6.96%
53.84%
0.38%
-17.99%
-15.20%
-1 .34%
12.58%
1 1 .04%
4.87%
-10.71%
-3.90%
-1 1 .20%
-9.88%
2.27%
-38.25%
-8.49%
-7.78%
-17.05%
-39.76%
-4.28%
-15.83%
22.10%
-22.14%
13.60%
5.12%
48.13%
-10.35%
-14.04%
B-3, 1
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE I UNITS FOR 1998 AND 1999
1998
State Plant Name
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
IA
IA
IA
IA
IA
IA
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
Harllee Branch
Harllee Branch
Jack Mcdonough
Jack Mcdonough
Jack Mcdonough
Kraft
Kraft
Kraft
Kraft
Mcintosh
Mitchell
Wansley
Wansley
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Burlington
Des Moines
George Neal North
Milton L Kapp
Prairie Creek
Riverside
Baldwin
Baldwin
Baldwin
Coffeen
Coffeen
Coffeen
Grand Tower
Havana
Hennepin
Hennepin
Hennepin
Hutsonville
Hutsonville
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Stack/Unit ID
3
4
CS001 (MB1, MB2)
MB1
MB2
CS001 (1 , 2, 3)
1
2
3
1
3
1
2
Y1BR
CS001 (Y2BR, Y3BR)
Y2BR
Y3BR
CS002 (Y4BR, Y5BR)
Y4BR
Y5BR
Y6BR
Y7BR
1
11
1
2
4
9
1
2
3
CS0001 (1 , 2)
1
2
9
6
CS3(1, 2)
1
2
5
6
CS1 (1,2)
1
2
CS2 (3, 4)
Unit Tvne
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Substitution
Substitution
Tablel
Tablel
SO2 Utilization
Emissions (mmBtu)
24,716,035
28,122,964
16,039,404
19,355,611
2,430,615
1,960,136
4,977,302
7,791 ,088
4,595,267
49,668,355
48,149,781
3,531 ,547
4,503,564
3,787,505
6,401 ,735
4,344,893
13,969,410
15,552,726
11,743,015
0
9,767,070
12,293,176
10,102,922
6,283,598
27,377,162
35,735,840
46,260,316
12,847,399
28,483,817
3,949,534
61 ,257
3,345,169
15,865,737
2,449,651
2,476,690
16,642,916
16,895,957
28,516
5,906
6,716
4,621
44,760
42,489
131
6,865
9,136
11,192
12,150
5,847
0
3,974
5,282
4,035
1,435
71 ,396
92,968
120,253
49,413
9,188
29
46,809
5,238
5,666
8,280
7,937
1999
Percent Change,
1998-1999
SO2 Utilization SO2 Utilization
Emissions (mmBtu) Emissions (mmBtu)
22,932,668
24,325,002
15,633,200
14,883,963
2,586,590
2,979,207
6,125,772
7,499,008
4,621 ,450
51 ,825,369
45,235,063
4,575,331
5,696,913
4,695,297
5,726,354
6,821 ,224
14,029,905
15,927,124
13,326,811
0
9,089,694
1 1 ,001 ,299
10,107,574
5,936,674
25,862,726
36,155,350
34,819,083
17,489,341
27,231,154
3,175,149
84,268
3,841,714
12,303,540
2,384,627
2,503,864
14,362,052
16,222,770
24,212
6,759
6,182
4,430
43,290
37,418
179
7,191
8,588
9,001
10,447
6,502
0
3,420
4,437
3,773
1,879
65,231
91,310
88,703
47,61 1
6,813
28
27,532
5,189
5,463
7,627
7,952
-7.22%
-13.50%
-2.53%
-23.10%
6.42%
51 .99%
23.07%
-3.75%
0.57%
4.34%
-6.05%
29.56%
26.50%
23.97%
-10.55%
56.99%
0.43%
2.41 %
13.49%
0.00%
-6.94%
-10.51%
0.05%
-5.52%
-5.53%
1.17%
-24.73%
36.13%
-4.40%
-19.61%
37.56%
14.84%
-22.45%
-2.65%
1.10%
-13.70%
-3.98%
-15.09%
14.44%
-7.95%
-4.13%
-3.28%
-1 1 .93%
36.64%
4.75%
-6.00%
-19.58%
-14.02%
1 1 .20%
0.00%
-13.94%
-16.00%
-6.49%
30.94%
-8.63%
-1 .78%
-26.24%
-3.65%
-25.85%
-3.45%
-41.18%
-0.94%
-3.58%
-7.89%
0.19%
B-3, 2
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE I UNITS FOR 1998 AND 1999
State Plant Name
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Kincaid
Kincaid
Kincaid
Meredosia
Newton
Vermilion
Vermilion
Vermilion
Wood River
Bailly
Bailly
Bailly
Breed
Cayuga
Cayuga
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Elmer W Stout
Elmer W Stout
Elmer W Stout
F B Culley
F B Culley
F B Culley
Frank E Ratts
Frank E Ratts
Gibson
Gibson
Gibson
Gibson
Gibson
Gibson
H T Pritchard
H T Pritchard
H T Pritchard
Stack/Unit ID
3
4
CSS (5, 6)
5
6
CS0102(1,2)
1
2
5
1
CSS (1,2)
1
2
1
XS12(7, 8)
7
8
1
1
2
CS001 (1 , 2, 3)
1
2
3
CS002 (4, 5, 6)
4
5
6
50
60
70
XS23 (2, 3)
2
3
1SG1
2SG1
CS0003 (1 , 2)
1
2
XS34 (3, 4)
3
4
CS596 (5, 6)
5
6
Tin t Tvne
Tabel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Tablel
1998
SO2 Utilization
Emissions (mmBtu)
16,246,827
15,657,774
16,131,320
14,904,104
18,743,889
30,554,552
8,114,710
30,901 ,900
3,484,888
5,717,555
475,387
10,663,125
21,683,417
0
36,106,576
24,672,500
15,187,611
15,722,352
16,620,156
15,129,975
15,465,474
1 1 ,649,523
6,373,331
6,765,079
24,602,220
7,665,616
24,969,662
8,756,973
8,486,975
42,521 ,424
39,961 ,024
35,238,356
48,852,984
2,725,130
5,325,128
7,636
46,417
10,941
7,508
12,220
1
4,334
0
51 ,345
37,593
46,294
42,899
6,638
7,392
25,931
7,687
9,236
9,393
94,431
51,189
7,512
1999
Percent Change,
1998-1999
SO2 Utilization SO2 Utilization
Emissions (mmBtu) Emissions (mmBtu)
15,836,007
15,627,050
16,107,187
16,183,167
31 ,384,634
23,830,039
10,944,500
41 ,277,526
3,268,808
5,605,084
318,431
12,681,533
21,611,162
0
29,784,383
32,916,838
14,250,422
13,829,890
14,254,172
14,347,485
14,919,136
15,082,320
7,716,376
7,104,368
27,163,753
7,733,260
22,066,761
5,598,320
9,725,809
47,059,174
43,412,460
41,312,568
47,769,475
2,797,197
6,165,568
8,165
19,867
12,450
9,935
10,833
0
3,813
0
38,153
45,309
26,131
26,545
7,967
7,812
28,801
8,634
6,136
1 1 ,044
84,282
56,662
9,133
-2.53%
-0.20%
-0.15%
8.58%
67.44%
-22.01 %
34.87%
33.58%
-6.20%
-1 .97%
-33.02%
18.93%
-0.33%
0.00%
-17.51%
33.42%
-6.17%
-12.04%
-14.24%
-5.17%
-3.53%
29.47%
21 .07%
5.02%
10.41%
0.88%
-1 1 .63%
-36.07%
14.60%
10.67%
8.64%
17.24%
-2.22%
2.64%
15.78%
6.93%
-57.20%
13.79%
32.33%
-1 1 .35%
-100.00%
-12.02%
0.00%
-25.69%
20.53%
-43.55%
-38.12%
20.02%
5.68%
1 1 .07%
12.32%
-33.56%
17.58%
-10.75%
10.69%
21 .58%
B-3, 3
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE I UNITS FOR 1998 AND 1999
1998
State Plant Name
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
KS
KS
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
Michigan City
Petersburg
Petersburg
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R Gallagher
Tanners Creek
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Warrick
Warrick
Warrick
Warrick
Warrick
La Cygne
Quindaro
Coleman
Coleman
Coleman
Cooper
Cooper
Cooper
E W Brown
E W Brown
E W Brown
E W Brown
East Bend
Elmer Smith
Elmer Smith
Elmer Smith
Ghent
Green River
H L Spurlock
Hmp&L Station 2
Hmp&L Station 2
Paradise
R D Green
R D Green
Stack/Unit ID
12
1
2
CS0001 (1 , 2)
1
2
CS0002 (3, 4)
3
4
U4
1
CS005 (2, 3, 5, 6)
2
3
5
6
XS123(1,2, 3)
1
2
3
4
1
2
C1
C2
C3
CS1 (1,2)
1
2
1
CS003 (2, 3)
2
3
2
XS12(1,2)
1
2
1
5
1
H1
H2
3
G1
G2
Tin t Tvne
Tabel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Opt-In
Opt-In
Opt-In
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
SO2 Utilization
Emissions (mmBtu)
28,722,177
16,853,716
32,849,989
6,484,783
8,078,498
9,757,824
8,730,732
21 ,095,772
10,195,928
5,345,939
5,574,897
6,735,426
18,378,868
12,261,983
12,265,399
12,241,810
18,411,332
34,557,496
6,966,804
10,837,598
7,993,759
11,281,190
6,162,103
12,814,633
6,033,395
10,629,369
22,188,450
41 ,851 ,087
10,447,080
21,192,016
39,524,506
6,883,122
21 ,451 ,848
12,326,347
12,467,753
59,456,328
19,256,597
16,646,528
16,672
2,247
4,136
22,954
27,642
32,017
851
48,580
78,964
34,078
6,319
2,985
13,908
9,677
14,568
17,613
6,762
35,473
13,064
7,011
7,396
14,438
14,941
2,397
2,130
126,946
1,828
2,136
1999
Percent Change,
1998-1999
SO2 Utilization SO2 Utilization
Emissions (mmBtu) Emissions (mmBtu)
24,416,874
14,887,120
31,640,108
7,555,385
7,205,560
7,904,914
8,295,461
32,193,717
7,004,060
5,320,471
3,366,728
5,016,853
18,221,805
1 1 ,529,866
13,478,104
13,388,356
22,001 ,632
47,751 ,036
7,717,137
9,454,607
11,006,016
1 1 ,332,658
6,790,255
13,586,572
5,957,448
9,673,102
24,995,749
47,901 ,080
1 1 ,055,201
21,616,916
38,957,054
6,090,354
22,882,357
1 1 ,604,941
13,603,299
65,709,524
17,055,276
18,192,091
10,512
2,202
4,945
24,027
25,850
34,708
461
49,210
83,243
36,413
10,906
2,411
11,138
12,879
13,420
19,882
7,051
38,513
18,096
8,402
6,452
11,122
16,444
2,560
3,246
145,724
2,544
2,300
-14.99%
-1 1 .67%
-3.68%
16.51%
-10.81%
-18.99%
-4.99%
52.61 %
-31 .31 %
-0.48%
-39.61 %
-25.52%
-0.85%
-5.97%
9.89%
9.37%
19.50%
38.18%
10.77%
-12.76%
37.68%
0.46%
10.19%
6.02%
-1 .26%
-9.00%
12.65%
14.46%
5.82%
2.01 %
-1 .44%
-1 1 .52%
6.67%
-5.85%
9.11%
10.52%
-1 1 .43%
9.28%
-36.95%
-2.00%
19.56%
4.67%
-6.48%
8.40%
-45.83%
1 .30%
5.42%
6.85%
72.59%
-19.23%
-19.92%
33.09%
-7.88%
12.88%
4.27%
8.57%
38.52%
19.84%
-12.76%
-22.97%
10.06%
6.80%
52.39%
14.79%
39.17%
7.68%
B-3, 4
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE I UNITS FOR 1998 AND 1999
State Plant Name
KY
MA
MA
MA
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
MN
MN
MN
MN
MN
MN
MN
MN
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
Shawnee
Brayton Point
Brayton Point
Mount Tom
C P Crane
C P Crane
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Morgantown
Morgantown
R P Smith
R P Smith
Dan E Karn
J C Weadock
J C Weadock
J C Weadock
J H Campbell
J H Campbell
J H Campbell
J R Whiting
J R Whiting
J R Whiting
High Bridge
High Bridge
High Bridge
High Bridge
High Bridge
Sherburne County
Sherburne County
Sherburne County
Asbury
Hawthorn
James River
James River
James River
Labadie
Labadie
Labadie
Labadie
Meramec
Meramec
Meramec
Montrose
Stack/Unit ID
10
1
2
1
1
2
CSE12(1,2)
1
2
3
1
2
9
11
2
CS0009 (7, 8)
7
8
CS0009 (1 , 2)
1
2
1
2
3
CS0001 (3, 4, 5, 6)
3
4
5
6
CS1 (1,2)
1
2
1
5
3
4
5
1
2
3
4
1
2
3
1
Tin t Tvne
Tabel
Compensating
Compensating
Substitution
Tablel
Tablel
Tablel
Tablel
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Substitution
Substitution
Tablel
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Tablel
1998
SO2 Utilization
Emissions (mmBtu)
7,598,398
17,886,343
18,403,534
10,400,402
12,220,342
10,972,712
23,306,258
21 ,586,648
17,351,546
33,077,778
43,364,798
152,062
2,977,734
13,176,629
11,669,816
11,474,188
13,474,893
24,729,551
6,127,827
7,251 ,809
7,786,674
1 ,553,609
1 ,543,292
7,083,980
10,753,526
43,745,696
50,587,266
12,859,011
20,633,908
3,121,544
3,737,611
5,934,107
42,347,449
34,534,886
40,580,655
39,516,498
4,991 ,896
4,792,250
6,900,132
11,013,403
1,560
9,739
9,744
8,417
15,224
13,636
44,721
7,732
34,953
44,953
117
2,262
8,426
12,330
22,693
3,940
4,561
4,755
4,044
8,958
8,212
7,106
1,409
1,708
2,810
15,654
12,987
14,602
14,354
1,670
1,541
3,706
4,072
1999
Percent Change,
1998-1999
SO2 Utilization SO2 Utilization
Emissions (mmBtu) Emissions (mmBtu)
6,330,697
18,653,762
17,930,549
10,409,818
1 1 ,048,746
15,139,746
25,083,406
24,512,463
19,066,892
37,938,653
32,452,376
175,810
3,581,919
16,529,722
9,008,727
12,791,726
17,949,073
23,950,447
7,071 ,532
7,721 ,975
9,344,917
989,385
1,614,894
5,593,372
8,615,703
44,597,306
53,564,282
13,164,172
2,624,153
3,099,540
4,501 ,874
8,057,047
39,840,374
44,817,914
35,440,21 1
32,026,366
7,116,930
7,057,121
8,901 ,583
10,737,171
1,597
10,328
10,030
7,172
12,942
18,121
45,450
7,898
41,194
34,325
133
2,664
10,282
10,701
24,089
3,835
4,090
4,925
3,482
10,756
8,046
821
1,001
1,438
2,588
10,184
10,959
9,033
8,605
1,897
1,798
3,902
2,644
-16.68%
4.29%
-2.57%
0.09%
-9.59%
37.98%
7.63%
13.55%
9.89%
14.70%
-25.16%
15.62%
20.29%
25.45%
-22.80%
1 1 .48%
33.20%
-3.15%
15.40%
6.48%
20.01 %
-36.32%
4.64%
-21 .04%
-19.88%
1 .95%
5.88%
2.37%
-87.28%
-0.70%
20.45%
35.78%
-5.92%
29.78%
-12.67%
-18.95%
42.57%
47.26%
29.01 %
-2.51 %
2.37%
6.05%
2.94%
-14.79%
-14.99%
32.89%
1 .63%
2.15%
17.86%
-23.64%
13.68%
17.77%
22.03%
-13.21%
6.15%
-2.66%
-10.33%
3.58%
-13.90%
20.07%
-2.02%
-88.45%
-28.96%
-15.81%
-7.90%
-34.94%
-15.62%
-38.14%
-40.05%
13.59%
16.68%
5.29%
-35.07%
B-3, 5
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE I UNITS FOR 1998 AND 1999
State Plant Name
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MS
MS
MS
MS
NH
NH
NJ
NJ
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
OH
OH
OH
OH
OH
OH
OH
Montrose
Montrose
Montrose
New Madrid
New Madrid
Rush Island
Rush Island
Sibley
Sibley
Sibley
Sibley
Sioux
Sioux
Southwest
Thomas Hill
Thomas Hill
Thomas Hill
Jack Watson
Jack Watson
R D Morrow
R D Morrow
Merrimack
Merrimack
B L England
B L England
Dunkirk
Dunkirk
Dunkirk
Greenidge
Milliken
Milliken
Milliken
Northport
Northport
Northport
Northport
Port Jefferson
Port Jefferson
Acme
Acme
Acme
Acme
Acme
Acme
Ashtabula
Stack/Unit ID
CS023 (2, 3)
2
3
1
2
1
2
CS0001 (1 , 2, 3)
1
2
3
1
2
1
MB1
MB2
MBS
4
5
1
2
1
2
1
2
CS0003 (3, 4)
3
4
6
XS12(1,2)
1
2
1
2
3
4
3
4
13
14
15
16
91
92
7
Unit Tvne
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Substitution
Tablel
Tablel
Substitution
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
1998
SO2 Utilization
Emissions (mmBtu)
10,380,984
1 1 ,783,069
42,006,552
46,640,504
40,512,757
42,312,616
3,195,388
3,125,667
26,076,510
24,814,785
30,562,053
16,707,842
15,127,247
23,711,214
47,129,420
18,271,530
32,387,107
14,398,624
15,094,507
9,625,002
21 ,653,842
7,658,545
6,770,210
12,014,610
14,506,026
8,538,897
12,085,829
12,008,990
12,065,492
17,255,806
19,356,322
12,918,579
9,726,121
1 1 ,039,434
0
0
0
0
0
0
9,268,567
8,875
8,735
9,018
13,485
13,924
27,056
18,885
23,062
6,837
3,080
4,722
9,916
18,528
32,033
4,267
4,383
12,126
22,794
15,694
1,084
37,527
9,027
8,572
2,764
4,866
10,502
1,136
4,185
3,171
0
0
0
0
0
0
26,164
1999
Percent Change,
1998-1999
SO2 Utilization SO2 Utilization
Emissions (mmBtu) Emissions (mmBtu)
12,714,292
1 1 ,602,632
45,150,430
34,610,571
36,010,237
42,175,356
3,387,394
3,180,319
26,234,888
28,960,864
23,062,994
15,623,175
14,575,377
25,046,252
60,434,841
16,484,019
36,679,476
12,358,012
1 1 ,789,856
9,547,754
20,639,634
7,429,902
8,076,956
11,671,411
12,125,304
8,188,414
12,902,644
12,635,866
21 ,821 ,549
21 ,528,869
12,999,243
19,613,318
7,026,559
11,512,191
0
0
0
0
0
0
8,120,031
7,025
9,570
6,863
12,653
14,543
26,183
25,148
18,624
3,538
3,139
5,220
12,768
14,038
32,552
3,572
3,642
12,479
22,320
14,323
978
36,414
8,865
7,524
5,228
5,003
7,001
1,313
2,325
2,025
0
0
0
0
0
0
22,153
22.48%
-1 .53%
7.48%
-25.79%
-11.11%
-0.32%
6.01 %
1 .75%
0.61 %
16.71%
-24.54%
-6.49%
-3.65%
5.63%
28.23%
-9.78%
13.25%
-14.17%
-21 .89%
-0.80%
-4.68%
-2.99%
19.30%
-2.86%
-16.41%
-4.10%
6.76%
5.22%
80.86%
24.76%
-32.84%
51 .82%
-27.76%
4.28%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
-12.39%
-20.85%
9.56%
-23.90%
-6.17%
4.45%
-3.23%
33.16%
-19.24%
-48.25%
1 .92%
10.55%
28.76%
-24.23%
1 .62%
-16.29%
-16.91%
2.91%
-2.08%
-8.74%
-9.78%
-2.97%
-1 .79%
-12.23%
89.15%
2.82%
-33.34%
15.58%
-44.44%
-36.14%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
-15.33%
B-3, 6
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE I UNITS FOR 1998 AND 1999
1998
State Plant Name
OH Ashtabula
OH Ashtabula
OH Ashtabula
OH Ashtabula
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Ashtabula
Avon Lake
Avon Lake
Avon Lake
Avon Lake
Bay Shore
Bay Shore
Bay Shore
Bay Shore
Bay Shore
Cardinal
Cardinal
Conesville
Conesville
Conesville
Conesville
Conesville
Eastlake
Eastlake
Eastlake
Eastlake
Eastlake
Edgewater
Edgewater
Edgewater
Gen J M Gavin
Gen J M Gavin
Gorge
Gorge
J M Stuart
J M Stuart
J M Stuart
J M Stuart
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Lake Shore
Lake Shore
Stack/Unit ID
CS1 (8, 9, 10, 11)
8
9
10
11
9
10
11
12
CSS (1 , 2, 3, 4)
1
2
3
4
1
2
CS012(1,2)
1
2
3
4
1
2
3
4
5
11
12
13
1
2
25
26
1
2
3
4
CS001 (1,2,3,4,5)
1
2
3
4
5
18
91
Unit Tvne
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
SO2 Utilization
Emissions (mmBtu)
0
0
287,495
530,174
0
1,437,105
0
36,413,732
6,462,382
6,807,479
7,261 ,342
9,238,904
32,017,382
34,846,000
6,163,071
6,974,286
7,761 ,567
32,772,680
6,31 1 ,370
6,852,009
8,079,638
10,573,149
36,867,392
0
0
1 ,228,962
78,819,640
94,637,496
0
0
37,286,928
40,858,280
32,223,074
33,318,570
14,334,231
15,054,039
14,714,973
16,147,978
14,395,578
3,627,698
0
2,048
0
1,222
0
27,714
1 1 ,472
95,520
33,017
30,089
17,937
72,035
11,186
1 1 ,992
12,985
18,497
56,01 1
0
0
7
15,085
18,718
0
0
27,024
29,520
23,21 1
23,603
119,171
1,811
0
1999
Percent Change,
1998-1999
SO2 Utilization SO2 Utilization
Emissions (mmBtu) Emissions (mmBtu)
279,973
0
512,626
450,475
0
3,083,112
0
36,160,588
6,453,497
4,892,897
7,622,340
10,722,321
27,853,645
29,083,402
5,376,545
6,256,606
4,940,431
38,097,747
5,215,645
5,849,349
6,407,370
9,870,191
29,051 ,400
0
0
1 ,041 ,857
89,167,280
65,991 ,259
0
0
33,941 ,546
32,282,115
34,980,662
42,381 ,845
15,868,388
14,701,108
13,793,625
14,024,499
14,372,849
3,158,746
0
3,865
0
1,714
0
31,154
7,980
60,413
34,358
25,887
1 1 ,548
83,894
10,490
12,441
12,349
19,978
60,129
0
0
20
8,717
6,529
0
0
24,210
23,091
25,129
29,557
135,558
1,527
0
0.00%
78.31 %
-15.03%
0.00%
114.54%
0.00%
-0.70%
-0.14%
-28.12%
4.97%
16.06%
-13.00%
-16.54%
-12.76%
-10.29%
-36.35%
16.25%
-17.36%
-14.63%
-20.70%
-6.65%
-21 .20%
0.00%
0.00%
-15.22%
13.13%
-30.27%
0.00%
0.00%
-8.97%
-20.99%
8.56%
27.20%
10.70%
-2.34%
-6.26%
-13.15%
-0.16%
-12.93%
0.00%
88.72%
0.00%
40.26%
0.00%
12.41%
-30.44%
-36.75%
4.06%
-13.97%
-35.62%
16.46%
-6.22%
3.74%
-4.90%
8.01%
7.35%
0.00%
0.00%
185.71%
-42.21%
-65.12%
0.00%
0.00%
-10.41%
-21 .78%
8.26%
25.23%
13.75%
-15.68%
0.00%
B-3, 7
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE I UNITS FOR 1998 AND 1999
1998
State Plant Name
OH Lake Shore
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
PA
PA
PA
PA
PA
PA
PA
Lake Shore
Lake Shore
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Niles
Niles
Niles
Picway
Poston
Poston
Poston
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
Toronto
Toronto
Toronto
WH Sammis
WH Sammis
WH Sammis
Walter C Beckjord
Walter C Beckjord
Armstrong
Armstrong
Bruce Mansfield
Bruce Mansfield
Brunner Island
Brunner Island
Brunner Island
Stack/Unit ID
92
93
94
CS056 (5-1 , 5-2, 6)
6
7
5-1
5-2
03014(1,2,3,4)
1
2
3
4
5
XS12(1,2)
1
2
9
1
2
3
CS0001 (1,2,3,4,5,6,7,8)
1
2
3
4
5
6
7
8
9
10
11
5
6
7
5
6
1
2
1
2
03102(1,2)
1
2
Unit Tvne
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
SO2 Utilization
Emissions (mmBtu)
0
0
0
13,624,571
29,030,836
1 ,373,320
1 ,374,643
9,969,079
10,138,733
1 1 ,271 ,723
10,897,014
27,975,016
7,625,299
5,534,045
4,802,830
0
0
0
0
0
0
0
23
22,906
10,366,887
9,213,604
0
0
0
19,236,457
29,506,312
44,358,048
15,957,426
29,796,457
1 1 ,997,280
1 1 ,802,474
52,609,590
42,620,088
17,977,978
21 ,591 ,769
0
0
0
19,614
36,473
152,316
15,307
21 ,636
13,385
0
0
0
38,543
0
0
0
16,812
20,352
45,828
20,329
39,455
18,227
17,658
7,527
6,765
48,020
1999
SO2 Utilization
Emissions (mmBtu)
0
0
0
14,296,977
40,335,185
1,673,166
1 ,669,393
3,607,991
6,358,846
7,348,251
4,487,600
35,774,715
6,183,854
6,582,973
3,795,836
0
0
0
0
0
0
0
482,744
557,221
8,972,115
9,084,270
0
0
0
17,509,532
45,848,958
37,729,229
16,565,264
29,571 ,498
8,714,032
10,502,470
40,265,916
45,017,219
14,119,976
17,835,199
0
0
0
18,199
40,559
78,543
22,096
19,292
9,385
0
0
0
49,189
0
0
0
19,111
36,395
44,027
14,764
26,050
12,471
15,125
7,491
9,438
40,437
Percent Change,
1998-1999
SO2 Utilization
Emissions (mmBtu)
0.00%
0.00%
0.00%
4.94%
38.94%
21 .83%
21 .44%
-63.81 %
-37.28%
-34.81 %
-58.82%
27.88%
-18.90%
18.95%
-20.97%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
2098786.96%
2332.64%
-13.45%
-1 .40%
0.00%
0.00%
0.00%
-8.98%
55.39%
-14.94%
3.81 %
-0.75%
-27.37%
-1 1 .01 %
-23.46%
5.62%
-21 .46%
-17.40%
0.00%
0.00%
0.00%
-7.21%
1 1 .20%
-48.43%
44.35%
-10.83%
-29.88%
0.00%
0.00%
0.00%
27.62%
0.00%
0.00%
0.00%
13.67%
78.83%
-3.93%
-27.37%
-33.98%
-31 .58%
-14.34%
-0.48%
39.51%
-15.79%
B-3, 8
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE I UNITS FOR 1998 AND 1999
1998
State Plant Name
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
Brunner Island
Cheswick
Conemaugh
Conemaugh
Hatfield's Ferry
Hatfield's Ferry
Hatfield's Ferry
Hatfield's Ferry
Martins Creek
Martins Creek
Martins Creek
Martins Creek
Martins Creek
Mitchell
New Castle
New Castle
Portland
Portland
Shawville
Shawville
Shawville
Shawville
Shawville
Sunbury
Sunbury
Allen
Allen
Allen
Cumberland
Cumberland
DuPont Johnsonville
DuPont Johnsonville
DuPont Johnsonville
DuPont Johnsonville
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Stack/Unit ID
3
1
1
2
XS123(1,2, 3)
1
2
3
CS102(1,2)
1
2
3
4
33
1
2
1
2
1
2
CS1 (3, 4)
3
4
3
4
1
2
3
1
2
JVD1
JVD2
JVD3
JVD4
CSGA12(1,2)
1
2
CSGA34 (3, 4)
3
4
CSJO10(1,2, 3, 4, 5, 6, 7, 8, 9, 10)
1
2
3
4
Tin t Tvne
Tabel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Opt-In
Opt-In
Opt-In
Opt-In
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
SO2 Utilization
Emissions (mmBtu)
38,668,683
25,447,980
64,682,996
72,193,913
33,536,438
29,112,948
29,387,244
6,486,775
6,021 ,584
1 1 ,288,576
10,631,226
16,084,774
0
0
8,564,817
10,950,567
8,432,824
8,234,692
12,435,105
12,289,735
8,357,434
9,405,060
13,314,521
17,881,872
18,246,196
93,425,640
77,445,408
0
0
0
0
16,675,013
13,358,894
18,006,243
14,508,353
8,391 ,787
6,454,090
5,676,977
7,806,189
47,679
32,177
3,874
4,347
150,868
15,834
4,742
4,347
1,050
0
0
9,772
12,126
12,864
12,365
33,535
10,307
1 1 ,970
5,671
7,378
7,162
10,610
9,891
0
0
0
0
40,664
45,551
114,588
1999
Percent Change,
1998-1999
SO2 Utilization SO2 Utilization
Emissions (mmBtu) Emissions (nunBtii)
39,197,191
32,658,260
69,486,114
55,907,023
30,551 ,752
22,255,667
32,926,994
5,094,585
4,913,542
8,148,433
10,305,450
15,416,659
0
0
8,426,585
1 1 ,751 ,042
7,078,616
8,503,856
11,014,863
8,973,627
5,180,806
6,304,698
9,851 ,081
10,664,977
13,303,435
73,656,897
105,807,314
0
0
0
0
19,169,909
17,111,033
20,933,769
19,865,790
8,581 ,945
8,748,656
7,790,561
8,704,533
30,751
41 ,602
4,472
3,421
141,872
13,972
2,248
3,310
994
0
0
1 1 ,220
15,099
10,974
12,853
27,959
6,099
7,480
3,997
4,393
5,291
7,070
8,851
0
0
0
0
37,124
47,717
119,778
1 .37%
28.33%
7.43%
-22.56%
-8.90%
-23.55%
12.05%
-21 .46%
-18.40%
-27.82%
-3.06%
-4.15%
0.00%
0.00%
-1 .61 %
7.31 %
-16.06%
3.27%
-1 1 .42%
-26.98%
-38.01 %
-32.96%
-26.01 %
-40.36%
-27.09%
-21.16%
36.62%
0.00%
0.00%
0.00%
0.00%
14.96%
28.09%
16.26%
36.93%
2.27%
35.55%
37.23%
1 1 .51 %
-35.50%
29.29%
15.44%
-21 .30%
-5.96%
-1 1 .76%
-52.59%
-23.86%
-5.33%
0.00%
0.00%
14.82%
24.52%
-14.69%
3.95%
-16.63%
-40.83%
-37.51%
-29.52%
-40.46%
-26.12%
-33.36%
-10.51%
0.00%
0.00%
0.00%
0.00%
-8.71%
4.76%
4.53%
B-3, 9
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE I UNITS FOR 1998 AND 1999
State
TN
TN
TN
TN
TN
TN
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
wv
wv
wv
wv
wv
wv
Plant Name
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Alma
Alma
Alma
Alma
Alma
Alma
Alma
Edgewater
Edgewater
Genoa
J P Madgett
Nelson Dewey
Nelson Dewey
Nelson Dewey
North Oak Creek
North Oak Creek
North Oak Creek
North Oak Creek
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Rock River
Rock River
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
Weston
Weston
Albright
Albright
Albright
Fort Martin
Fort Martin
Harrison
Stack/Unit ID
5
6
7
8
9
10
CS2 (B1 , B2, B3)
B1
B2
B3
CS1 (B1 , B2, B3, B4, B5)
B4
B5
3
4
1
B1
CS1 (1,2)
1
2
1
2
3
4
CS56 (5, 6)
5
6
7
8
1
2
CSS (5, 6)
5
6
CS4 (7, 8)
7
8
1
2
1
2
3
1
2
XS123(1,2, 3)
Un t Tvne
Tabel
Tablel
Tablel
Tablel
Tablel
Tablel
Opt-In
Opt-In
Opt-In
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
1998
SO2 Utilization
Emissions (mmBtu)
6,805,978
7,370,703
7,852,052
8,457,149
9,737,698
8,049,553
663,744
602,030
565,438
3,122,034
4,318,051
5,01 1 ,080
20,197,100
16,559,515
25,231 ,992
6,172,813
7,216,679
0
0
0
0
3,766,998
5,003,476
7,422,811
11,212,789
4,083,241
4,957,022
10,136,963
16,111,857
20,272,864
18,324,182
3,956,520
6,830,073
1 ,843,436
1 ,623,422
6,078,740
34,726,484
30,423,447
1,287
6,517
1,973
8,391
9,031
5,223
10,861
0
0
0
0
1,884
1,569
2,283
1,532
1,898
16,781
26,529
1,111
1,922
2,202
1,929
7,228
41 ,641
37,663
6,934
1999
Percent Change,
1998-1999
SO2 Utilization SO2 Utilization
Emissions (mmBtu) Emissions (mmBtu)
7,690,236
7,812,089
8,973,487
7,349,441
10,876,009
8,505,788
544,455
460,323
499,689
2,496,086
3,249,944
3,809,692
18,569,057
20,395,109
25,466,640
6,991 ,292
7,093,604
0
0
0
0
4,010,079
6,006,083
5,722,099
10,395,306
2,259,634
1 ,948,975
15,289,701
13,120,528
20,083,880
19,699,186
4,182,326
5,893,048
2,125,873
2,179,803
9,852,124
39,694,066
37,345,654
757
3,060
1,356
6,624
12,513
5,333
13,280
0
0
0
0
2,278
1,264
2,196
656
741
15,736
17,153
1,263
1,778
2,500
2,523
1 1 ,640
50,943
48,158
6,835
12.99%
5.99%
14.28%
-13.10%
1 1 .69%
5.67%
-17.97%
-23.54%
-1 1 .63%
-20.05%
-24.74%
-23.97%
-8.06%
23.16%
0.93%
13.26%
-1 .71 %
0.00%
0.00%
0.00%
0.00%
6.45%
20.04%
-22.91 %
-7.29%
-44.66%
-60.68%
50.83%
-18.57%
-0.93%
7.50%
5.71 %
-13.72%
15.32%
34.27%
62.08%
14.30%
22.75%
-41.18%
-53.05%
-31 .27%
-21 .06%
38.56%
2.11%
22.27%
0.00%
0.00%
0.00%
0.00%
20.91%
-19.44%
-3.81%
-57.18%
-60.96%
-6.23%
-35.34%
13.68%
-7.49%
13.53%
30.79%
61 .04%
22.34%
27.87%
-1 .43%
B-3, 10
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE I UNITS FOR 1998 AND 1999
1998
State
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
Plant Name
Harrison
Harrison
Harrison
Kammer
Kammer
Kammer
Kammer
Mitchell
Mitchell
Mitchell
Mt Storm
Mt Storm
Mt Storm
Mt Storm
Rivesville
Rivesville
Stack/Unit ID
1
2
3
03013(1,2,3)
1
2
3
03012(1,2)
1
2
030(1,2)
1
2
3
7
8
Tin t Tvne
Tabel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
SO2 Utilization
Emissions (mmBtu)
46,082,925
51 ,433,080
55,241 ,467
13,479,546
12,639,201
13,391,834
44,346,849
48,141,367
41 ,523,871
39,716,905
47,191,480
819,610
2,531 ,623
108,618
59,330
106,759
4,576
624
1,995
1999
Percent Change,
1998-1999
SO2 Utilization SO2 Utilization
Emissions (mmBtu) Emissions (mmBtu)
51 ,023,022
44,723,816
48,979,700
11,856,165
15,026,115
12,839,130
42,576,634
44,230,623
39,788,598
36,646,063
39,419,794
576,450
3,849,565
104,231
55,046
101,124
3,481
444
2,954
10.72%
-13.04%
-1 1 .34%
-12.04%
18.89%
-4.13%
-3.99%
-8.12%
-4.18%
-7.73%
-16.47%
-29.67%
52.06%
-4.04%
-7.22%
-5.28%
-23.93%
-28.85%
48.07%
NOTES: (a) Identifies the affected unit as listed in Table 1, as a subsitution or compensating unit, or as an opt-in unit.
B-3, 11
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
Plant Name
Colbert
Colbert
Colbert
Colbert
Colbert
Colbert
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
Gadsden
Gadsden
Big Bend
Big Bend
Big Bend
Big Bend
Big Bend
Big Bend
Crist
Crist
Crist
Crist
Scholz
Scholz
Arkwright
Arkwright
Arkwright
Arkwright
Arkwright
Bowen
Bowen
Bowen
Bowen
Hammond
Hammond
Stack/Unit ID
CSCO14(1, 2, 3,4)
1
2
3
4
5
CSOCAN (1 , 2)
1
2
CSOCBN (3, 4)
3
4
5
1
2
XS12(BB01, BB02)
BB01
BB02
XS23 (BB03, BB04)
BB03
BB04
4
5
6
7
1
2
CS001 (1 , 2, 3, 4)
1
2
3
4
1BLR
2BLR
3BLR
4BLR
CS001 (1 , 2, 3)
1
Unit Type (a)
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
SO2 SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1998(b) 1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
26,653
47,608
25,864
25,669
41 ,489
4,751
4,463
90,881
16,544
3,255
3,872
14,461
29,005
1,877
2,877
4,272
34,016
28,130
47,897
35,108
9,842
22,601
46,972
29,118
28,502
43,508
4,242
4,289
80,704
14,910
3,329
2,391
13,233
26,748
1,557
1,733
4,089
28,631
34,348
37,294
39,881
10,346
13,213
14,907
14,995
15,005
36,202
17,624
18,052
17,828
18,773
58,265
5,158
5,374
27,662
26,387
26,036
6,400
9,953
9,374
18,695
30,846
8,282
8,572
2,437
2,240
3,944
3,159
54,838
53,329
69,862
69,852
8,549
27,111
36,234
36,810
37,703
52,155
17,517
13,931
16,237
14,545
84,395
4,742
4,789
44,340
44,158
13,851
9,826
37,585
33,007
42,331
67,343
33,431
32,124
5,385
4,794
9,906
7,552
94,106
110,322
138,458
151,649
19,496
5,959
6,236
5,637
4,769
46,972
16,219
12,899
15,034
13,468
43,508
4,242
4,289
39,545
41,159
10,798
4,112
3,329
2,391
13,233
26,748
1,557
1,733
1,023
1,022
1,022
1,022
28,631
34,348
37,294
39,881
3,448
21,152
29,998
31,173
32,934
5,183
1,298
1,032
1,203
1,077
40,887
500
500
4,795
2,999
3,053
5,714
34,256
30,616
29,098
40,595
31 ,874
30,391
4,362
3,772
8,884
6,530
65,475
75,974
101,164
1 1 1 ,768
16,048
B-4, 1
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
IA
IA
IA
IA
IA
IA
IL
IL
IL
Plant Name
Hammond
Hammond
Hammond
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Jack Mcdonough
Jack Mcdonough
Jack Mcdonough
Kraft
Kraft
Kraft
Kraft
Mcintosh
Mitchell
Wansley
Wansley
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Burlington
Des Moines
George Neal North
Milton L Kapp
Prairie Creek
Riverside
Baldwin
Baldwin
Baldwin
Stack/Unit ID
2
3
4
CS001 (1 , 2)
1
2
CS002 (3, 4)
3
4
CS001 (MB1, MB2)
MB1
MB2
CS001 (1 , 2, 3)
1
2
3
1
3
1
2
Y1BR
CS001 (Y2BR, Y3BR)
Y2BR
Y3BR
CS002 (Y4BR, Y5BR)
Y4BR
Y5BR
Y6BR
Y7BR
1
11
1
2
4
9
1
2
3
Unit Type (a)
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
SO2 SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1998(b) 1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
13,217
32,342
56,643
28,516
5,906
6,716
4,621
44,760
42,489
131
6,865
9,136
11,192
12,150
5,847
0
3,974
5,282
4,035
1,435
71 ,396
92,968
120,253
19,579
28,996
48,692
24,212
6,759
6,182
4,430
43,290
37,418
179
7,191
8,588
9,001
10,447
6,502
0
3,420
4,437
3,773
1,879
65,231
91,310
88,703
8,977
8,676
36,650
19,221
22,735
31 ,280
31 ,042
19,386
20,058
2,265
2,137
4,121
7,146
10,792
68,908
63,708
9,533
6,855
6,767
8,676
9,162
24,108
20,915
10,428
2,259
2,571
13,437
7,965
3,885
46,052
48,695
46,644
20,780
19,879
104,458
37,988
55,559
54,792
53,601
49,144
51 ,832
3,858
3,695
6,242
9,627
34,655
122,624
108,981
32,220
20,781
20,430
25,674
27,619
75,847
61 ,808
24,317
0
10,692
43,424
24,488
1 1 ,332
66,785
92,331
89,755
3,449
3,449
19,579
14,498
14,498
24,346
24,346
12,106
12,106
1,452
1,692
3,615
6,182
4,430
43,290
37,418
179
3,595
3,596
4,294
4,294
9,001
10,447
6,502
0
3,420
4,437
3,773
1,879
65,231
91,310
88,703
17,331
16,430
84,879
23,490
41 ,061
30,446
29,255
37,038
39,726
2,406
2,003
2,627
3,445
30,225
79,334
71 ,563
32,041
17,186
16,834
21 ,380
23,325
66,846
51 ,361
17,815
0
7,272
23 38,964
20,715
9,453
1,554
1,021
1,052
B-4, 2
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
Plant Name
Coffee n
Coffeen
Coffeen
Grand Tower
Havana
Hennepin
Hennepin
Hennepin
Hutsonville
Hutsonville
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Kincaid
Kincaid
Kincaid
Meredosia
Newton
Vermilion
Vermilion
Vermilion
Wood River
Bailly
Bailly
Bailly
Breed
Cayuga
Cayuga
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Stack/Unit ID
CS0001 (1 , 2)
1
2
9
6
CSS (1,2)
1
2
5
6
CS1 (1,2)
1
2
CS2 (3, 4)
3
4
CSS (5, 6)
5
6
CS0102(1,2)
1
2
5
1
CSS (1,2)
1
2
1
XS12(7, 8)
7
8
1
1
2
CS001 (1 , 2, 3)
1
2
3
Unit Type (a)
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
SO2 SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1998(b) 1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
49,413
9,188
29
46,809
5,238
5,666
8,280
7,937
7,636
46,417
10,941
7,508
12,220
1
4,334
0
51 ,345
37,593
46,294
47,61 1
6,813
28
27,532
5,189
5,463
7,627
7,952
8,165
19,867
12,450
9,935
10,833
0
3,813
0
38,153
45,309
26,131
12,925
39,102
6,479
34
9,847
20,182
9,661
9,837
12,259
10,487
1 1 ,947
1 1 ,061
11,119
10,341
34,564
37,063
15,227
14,599
12,972
9,735
0
15,818
21 ,600
20,280
36,581
37,415
19,620
19,289
19,873
17,322
30,482
6,936
62
6,847
23,182
5,565
5,588
44,959
36,098
43,886
39,456
37,136
33,246
14,412
10,881
12,641
14,320
5,028
7,972
12
14,255
32,600
30,362
43,462
53,814
17,885
12,727
13,262
17,224
30,387
6,813
28
5,176
22,356
5,189
5,463
3,813
3,814
3,976
3,976
4,082
4,083
1 1 ,920
7,947
12,450
9,935
3,976
6,857
0
1,411
2,402
0
38,153
45,309
8,711
8,710
8,710
98
95
123
34
1,671
826
376
125
41,146
32,284
39,910
35,480
33,054
29,163
2,492
2,934
191
4,385
1,052
1,115
12
12,844
30,198
30,362
5,309
8,505
153 9,021
165 3,852
169 4,383
B-4, 3
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
Plant Name
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Elmer W Stout
Elmer W Stout
Elmer W Stout
F B Culley
F B Culley
F B Culley
Frank E Ratts
Frank E Ratts
Gibson
Gibson
Gibson
Gibson
Gibson
Gibson
H T Pritchard
H T Pritchard
H T Pritchard
Michigan City
Petersburg
Petersburg
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R Gallagher
Tanners Creek
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Warrick
Stack/Unit ID
CS002 (4, 5, 6)
4
5
6
50
60
70
XS23 (2, 3)
2
3
1SG1
2SG1
CS0003 (1 , 2)
1
2
XS34 (3, 4)
3
4
CS596 (5, 6)
5
6
12
1
2
CS0001 (1 , 2)
1
2
CS0002 (3, 4)
3
4
U4
1
CS005 (2, 3, 5, 6)
2
3
5
6
XS123(1,2, 3)
Unit Type (a)
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
SO2 SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1998(b) 1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
42,899
6,638
7,392
25,931
7,687
9,236
9,393
94,431
51,189
7,512
16,672
2,247
4,136
22,954
27,642
32,017
851
48,580
78,964
26,545
7,967
7,812
28,801
8,634
6,136
1 1 ,044
84,282
56,662
9,133
10,512
2,202
4,945
24,027
25,850
34,708
461
49,210
83,243
19,552
18,851
19,844
4,253
5,229
25,883
4,703
18,603
9,131
9,296
44,288
44,956
45,033
44,200
1,458
6,325
25,553
18,011
35,496
7,115
7,980
7,159
8,386
27,209
5,379
3,135
4,111
4,023
13,462
14,774
12,087
34,618
8,565
8,153
29,700
9,347
38,206
14,258
11,918
68,746
65,137
69,168
99,319
3,011
6,557
77,113
2,412
5,400
12,954
12,785
13,121
14,689
142,162
15,673
9,847
1 1 ,499
9,334
28,580
8,849
8,848
8,848
7,967
7,812
28,801
8,634
0
6,136
1 1 ,044
43,427
40,855
28,331
28,331
2,822
6,311
10,512
2,202
4,945
12,282
1 1 ,745
12,602
13,248
34,708
461
8,297
5,182
7,813
27,918
140 5,785
46 3,193
100 25,670
598
341
899
713
38,206
8,122
874
25,319
24,282
40,837
70,988
189
246
66,601
210
455
672
1,040
519
1,441
107,454
15,212
1,550
6,317
1,521
662
B-4, 4
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
IN
IN
IN
IN
KS
KS
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
MA
MA
MA
MD
MD
MD
MD
MD
MD
Plant Name
Warrick
Warrick
Warrick
Warrick
La Cygne
Quindaro
Coleman
Coleman
Coleman
Cooper
Cooper
Cooper
E W Brown
E W Brown
E W Brown
E W Brown
East Bend
Elmer Smith
Elmer Smith
Elmer Smith
Ghent
Green River
H L Spurlock
Hmp&L Station 2
Hmp&L Station 2
Paradise
R D Green
R D Green
Shawnee
Brayton Point
Brayton Point
Mount Tom
C P Crane
C P Crane
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Stack/Unit ID
1
2
3
4
1
2
C1
C2
C3
CS1 (1,2)
1
2
1
CS003 (2, 3)
2
3
2
XS12(1,2)
1
2
1
5
1
H1
H2
3
G1
G2
10
1
2
1
1
2
CSE12(1,2)
1
2
3
SO2
Emissions
Unit Type (a) 1998(b)
Opt-In
Opt-In
Opt-In
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Compensating
Compensating
Substitution
Tablel
Tablel
Tablel
Tablel
Substitution
34,078
6,319
2,985
13,908
9,677
14,568
17,613
6,762
35,473
13,064
7,011
7,396
14,438
14,941
2,397
2,130
126,946
1,828
2,136
1,560
9,739
9,744
8,417
15,224
13,636
44,721
7,732
SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
36,413
10,906
2,411
11,138
12,879
13,420
19,882
7,051
38,513
18,096
8,402
6,452
11,122
16,444
2,560
3,246
145,724
2,544
2,300
1,597
10,328
10,030
7,172
12,942
18,121
45,450
7,898
30,372
30,732
27,668
29,577
23,489
4,109
10,954
12,502
12,015
7,254
14,917
6,923
10,623
25,413
17,447
6,348
14,031
33,701
7,614
22,181
17,900
17,059
57,613
5,041
5,827
9,902
15,085
15,838
10,708
10,058
8,987
21 ,333
23,690
9,000
26,889
29,954
28,906
38,281
1 1 ,297
7,818
13,478
14,995
15,862
13,675
28,708
22,972
33,638
87,703
29,713
8,147
18,231
135,908
14,979
53,604
9,609
8,311
244,152
7,367
8,538
26,394
1 1 ,360
1 1 ,035
15,576
66,953
22,61 1
30,240
30,290
20,268
25,821
29,549
27,873
36,413
10,906
2,411
11,138
12,879
13,420
6,561
13,321
7,051
10,813
27,700
18,096
2,521
5,881
6,452
11,122
16,444
2,560
3,246
145,724
2,544
2,300
1,597
10,328
10,030
7,172
12,942
18,121
22,986
22,464
7,898
134 934
405
1,033
1,868
391
5,407
2,340
2,116
2,442
7,114
15,387
15,921
22,825
60,003
11,617
5,626
12,350
129,456
3,857
37,160
7,049
5,065
98,428
4,823
6,238
24,797
1,032
1,005
2,311 6,093
54,01 1
4,490
7,254
7,826
12,370
B-4, 5
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
MD
MD
MD
MD
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
MN
MN
MN
MN
MN
MN
MN
MN
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
Plant Name
Morgantown
Morgantown
R P Smith
R P Smith
Dan E Karn
J C Weadock
J C Weadock
J C Weadock
J H Campbell
J H Campbell
J H Campbell
J R Whiting
J R Whiting
J R Whiting
High Bridge
High Bridge
High Bridge
High Bridge
High Bridge
Sherburne County
Sherburne County
Sherburne County
Asbury
Hawthorn
James River
James River
James River
Labadie
Labadie
Labadie
Labadie
Meramec
Meramec
Meramec
Montrose
Montrose
Montrose
Montrose
Stack/Unit ID
1
2
9
11
2
CS0009 (7, 8)
7
8
CS0009 (1 , 2)
1
2
1
2
3
CS0001 (3, 4, 5, 6)
3
4
5
6
CS1 (1,2)
1
2
1
5
3
4
5
1
2
3
4
1
2
3
1
CS023 (2, 3)
2
3
Unit Type (a)
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Substitution
Substitution
Tablel
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
SO2 SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1998(b) 1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
34,953
44,953
117
2,262
8,426
12,330
22,693
3,940
4,561
4,755
4,044
8,958
8,212
7,106
1,409
1,708
2,810
15,654
12,987
14,602
14,354
1,670
1,541
3,706
4,072
8,875
41,194
34,325
133
2,664
10,282
10,701
24,089
3,835
4,090
4,925
3,482
10,756
8,046
821
1,001
1,438
2,588
10,184
10,959
9,033
8,605
1,897
1,798
3,902
2,644
7,025
34,332
37,467
386
3,128
10,984
5,473
5,451
18,773
22,453
4,188
4,304
5,498
299
242
410
4,158
4,681
4,727
15,764
6,927
2,536
4,304
4,722
39,055
36,718
39,249
34,994
1,816
1,948
4,166
7,196
7,984
9,824
62,425
42,273
556
2,691
11,312
4,865
6,908
1 1 ,352
15,147
4,220
4,501
5,419
3,397
1,937
2,022
9,485
16,114
16,227
45,191
21 ,707
5,037
7,740
5,400
12,112
12,968
1 1 ,448
1 1 ,032
3,017
3,280
5,976
4,445
5,863
7,500
41,194
34,325
133
2,664
10,282
4,422
6,279
10,320
13,769
3,835
4,090
4,925
201
336
1,154
1,791
4,955
5,801
8,046
821
1,001
1,438
2,588
10,184
10,959
9,033
8,605
1,897
1,798
3,902
2,644
3,674
3,351
21 ,231
7,948
423
27
1,030
443
629
1,032
1,378
385
411
494
3,196
1,601
868
7,694
11,159
10,426
37,145
20,886
4,036
6,302
2,812
1,928
2,009
2,415
2,427
1,120
1,482
2,074
1,801
2,189
4,149
B-4, 6
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MS
MS
MS
MS
NH
NH
NJ
NJ
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
OH
OH
OH
Plant Name
New Madrid
New Madrid
Rush Island
Rush Island
Sibley
Sibley
Sibley
Sibley
Sioux
Sioux
Southwest
Thomas Hill
Thomas Hill
Thomas Hill
Jack Watson
Jack Watson
R D Morrow
R D Morrow
Merrimack
Merrimack
B L England
B L England
Dunkirk
Dunkirk
Dunkirk
Greenidge
Milliken
Milliken
Milliken
Northport
Northport
Northport
Northport
Port Jefferson
Port Jefferson
Acme
Acme
Acme
Stack/Unit ID
1
2
1
2
CS0001 (1 , 2, 3)
1
2
3
1
2
1
MB1
MB2
MBS
4
5
1
2
1
2
1
2
CS0003 (3, 4)
3
4
6
XS12(1,2)
1
2
1
2
3
4
3
4
13
14
15
Unit Type (a)
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Substitution
Tablel
Tablel
Substitution
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
SO2 SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1998(b) 1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
8,735
9,018
13,485
13,924
27,056
18,885
23,062
6,837
3,080
4,722
9,916
18,528
32,033
4,267
4,383
12,126
22,794
15,694
1,084
37,527
9,027
8,572
2,764
4,866
10,502
1,136
4,185
3,171
0
0
0
9,570
6,863
12,653
14,543
26,183
25,148
18,624
3,538
3,139
5,220
12,768
14,038
32,552
3,572
3,642
12,479
22,320
14,323
978
36,414
8,865
7,524
5,228
5,003
7,001
1,313
2,325
2,025
0
0
0
27,497
31 ,625
26,935
30,146
2,782
3,332
15,170
21 ,976
23,067
3,906
9,980
18,880
14,011
17,439
35,734
4,571
5,002
9,922
21 ,421
8,822
14,886
12,268
13,690
7,342
10,876
12,083
19,289
23,476
25,783
5,516
10,194
12,006
0
12
16
27,497
31 ,425
15,134
17,248
5,598
8,326
18,152
45,197
38,088
4,230
9,980
18,880
14,011
26,818
52,075
5,186
7,085
12,825
22,674
20,287
2,803
29,305
15,095
15,589
15,934
9,316
19,953
9,486
32,397
14,058
10,228
15,846
0
0
0
9,570
6,863
12,653
14,543
3,927
5,237
17,019
25,148
18,624
3,538
3,139
5,220
12,768
14,038
32,552
3,572
3,642
12,479
22,320
14,323
978
25,490
10,924
8,865
3,729
3,795
5,228
5,003
7,001
1,313
2,325
2,025
0
0
0
17,927
24,562
2,481
2,705
1,671
3,089
1,133
20,049
19,464
692
6,841
13,660
1,243
12,780
19,523
1,614
3,443
346
354
5,964
1,825
3,815
4,171
6,724
12,205
5,521
14,725
4,483
25,396
12,745
7,903
13,821
0
0
0
B-4, 7
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Plant Name
Acme
Acme
Acme
Ashtabula
Ashtabula
Ashtabula
Ashtabula
Ashtabula
Ashtabula
Avon Lake
Avon Lake
Avon Lake
Avon Lake
Bay Shore
Bay Shore
Bay Shore
Bay Shore
Bay Shore
Cardinal
Cardinal
Conesville
Conesville
Conesville
Conesville
Conesville
Eastlake
Eastlake
Eastlake
Eastlake
Eastlake
Edgewater
Edgewater
Edgewater
Gen J M Gavin
Gen J M Gavin
Gorge
Gorge
J M Stuart
Stack/Unit ID
16
91
92
7
CS1 (8,9,10, 11)
8
9
10
11
9
10
11
12
CSS (1 , 2, 3, 4)
1
2
3
4
1
2
CS012(1,2)
1
2
3
4
1
2
3
4
5
11
12
13
1
2
25
26
1
Unit Type (a)
Substitution
Substitution
Substitution
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
SO2 SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1998(b) 1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
0
0
0
26,164
2,048
0
1,222
0
27,714
1 1 ,472
95,520
33,017
30,089
17,937
72,035
11,186
1 1 ,992
12,985
18,497
56,01 1
0
0
7
15,085
18,718
0
0
27,024
0
0
0
22,153
3,865
0
1,714
0
31,154
7,980
60,413
34,358
25,887
1 1 ,548
83,894
10,490
12,441
12,349
19,978
60,129
0
0
20
8,717
6,529
0
0
24,210
1,930
740
662
18,351
7,487
7,016
6,155
6,452
8,763
7,879
12,771
33,413
7,414
6,957
7,585
12,481
37,568
42,008
4,615
5,360
6,029
53,463
8,551
9,471
10,984
15,906
37,349
1,062
1,145
5,536
113,172
115,070
2,503
2,791
41,189
0
0
0
23,260
911
0
1,680
1,467
672
2,000
980
32,791
1,758
1,477
2,108
3,035
63,577
61 ,477
12,546
14,635
12,125
87,460
11,015
13,063
12,966
20,977
63,135
0
0
200
9,156
35,605
0
0
43,633
0
0
0
22,153
866
0
1,600
1,399
0
1,714
0
31,154
1,676
1,404
2,011
2,889
60,413
34,358
1 1 ,949
13,938
1 1 ,548
83,894
10,490
12,441
12,349
19,978
60,129
0
0
20
8,717
6,529
0
0
24,210
0
0
0
1,107
45
0
80
68
672
286
980
1,637
82
73
97
146
3,164
27,119
597
697
577
3,566
525
622
617
999
3,006
0
0
180
439
29,076
0
0
19,423
B-4, 8
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Plant Name
J M Stuart
J M Stuart
J M Stuart
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Lake Shore
Lake Shore
Lake Shore
Lake Shore
Lake Shore
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Niles
Niles
Niles
Picway
Poston
Poston
Poston
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
Stack/Unit ID
2
3
4
CS001 (1,2,3,4,5)
1
2
3
4
5
18
91
92
93
94
CS056 (5-1 , 5-2, 6)
6
7
5-1
5-2
03014(1,2,3,4)
1
2
3
4
5
XS12(1,2)
1
2
9
1
2
3
CS0001 (1,2,3,4,5,6,7,8)
1
2
3
4
5
Unit Type (a)
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
SO2
Emissions
1998(b)
29,520
23,21 1
23,603
119,171
1,811
0
0
0
0
19,614
36,473
152,316
15,307
21 ,636
13,385
0
0
0
38,543
SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
23,091
25,129
29,557
135,558
1,527
0
0
0
0
18,199
40,559
78,543
22,096
19,292
9,385
0
0
0
49,189
39,041
38,712
40,925
18,773
18,072
17,439
18,218
18,247
4,508
44
80
62
102
12,475
42,216
417
417
16,312
15,533
15,293
12,914
44,364
7,608
9,975
5,404
0
0
0
2,820
2,751
2,891
2,956
3,371
36,057
42,818
46,727
27,612
27,612
27,612
27,612
27,612
1,603
0
0
0
0
30,410
56,021
1,933
1,941
13,533
24,039
28,020
16,877
142,332
6,799
13,416
9,857
0
0
0
0
0
0
0
343
23,091
25,129
29,557
27,111
27,111
27,112
27,112
27,112
1,527
0
0
0
0
14,797
40,559
1,701
1,701
12,889
22,894
26,686
16,074
22,096
6,489
12,803
9,385
0
0
0
0
0
0
0
343
12,966
17,689
17,170
501
12 489
44 456
77 423
51 449
76
0
0
0
0
15,613
15,462
232
240
644
1,145
1,334
803
120,236
310
613
472
0
0
0
0
0
0
0
0
B-4, 9
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
Plant Name
R E Burger
R E Burger
R E Burger
Toronto
Toronto
Toronto
WH Sammis
WH Sammis
WH Sammis
Walter C Beckjord
Walter C Beckjord
Armstrong
Armstrong
Bruce Mansfield
Bruce Mansfield
Brunner Island
Brunner Island
Brunner Island
Brunner Island
Cheswick
Conemaugh
Conemaugh
Hatfield's Ferry
Hatfield's Ferry
Hatfield's Ferry
Hatfield's Ferry
Martins Creek
Martins Creek
Martins Creek
Martins Creek
Martins Creek
Mitchell
New Castle
New Castle
Portland
Portland
Shawville
Shawville
Stack/Unit ID
6
7
8
9
10
11
5
6
7
5
6
1
2
1
2
CS102(1,2)
1
2
3
1
1
2
XS123(1,2, 3)
1
2
3
CS102(1,2)
1
2
3
4
33
1
2
1
2
1
2
Unit Type (a)
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
SO2
Emissions
1998(b)
0
0
0
16,812
20,352
45,828
20,329
39,455
18,227
17,658
7,527
6,765
48,020
47,679
32,177
3,874
4,347
150,868
15,834
4,742
4,347
1,050
0
0
9,772
12,126
12,864
12,365
SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
0
0
0
19,111
36,395
44,027
14,764
26,050
12,471
15,125
7,491
9,438
40,437
30,751
41 ,602
4,472
3,421
141,872
13,972
2,248
3,310
994
0
0
1 1 ,220
15,099
10,974
12,853
3,371
11,818
13,626
5,315
9,505
10,274
26,496
43,773
47,380
9,811
25,235
14,031
15,024
10,510
1 1 ,537
27,030
30,282
52,404
38,139
81 ,384
91 ,607
36,835
36,338
39,210
12,327
12,483
12,553
1 1 ,548
1,101
1,367
1,520
5,784
9,961
10,048
10,048
515
25,428
25,363
0
0
0
20,066
38,215
46,486
18,952
43,169
14,520
15,692
8,908
10,162
18,952
23,686
33,434
49,133
12,945
12,398
51 ,231
36,964
55,096
7,551
7,451
2,562
3,779
1,272
105
117
66,448
18,640
1 1 ,082
13,106
493
24,201
24,152
0
0
0
19,111
36,395
44,027
14,764
26,050
12,471
15,125
7,491
9,438
17,868
22,569
30,751
41 ,602
4,472
3,421
50,732
36,599
54,541
7,112
6,860
2,248
3,310
994
0
0
1 1 ,220
15,099
10,974
12,853
22
1,227
1,211
0
0
0
955
1,820
2,459
4,188
17,119
2,049
567
1,417
724
1,084
1,117
2,683
7,531
8,473
8,977
499
365
555
439
591
314
469
278
105
117
55,228
3,541
108
253
B-4, 10
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
PA
PA
PA
PA
PA
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Plant Name Stack/Unit ID
Shawville CS1 (3, 4)
Shawville 3
Shawville 4
Sunbury 3
Sunbury 4
Allen 1
Allen 2
Allen 3
Cumberland 1
Cumberland 2
DuPont Johnsonville JVD1
DuPont Johnsonville JVD2
DuPont Johnsonville JVD3
DuPont Johnsonville JVD4
Gallatin CSGA12(1,2)
Gallatin 1
Gallatin 2
Gallatin CSGA34 (3, 4)
Gallatin 3
Gallatin 4
Johnsonville CSJO1 0(1,2, 3, 4, 5, 6, 7, 8, 9, 1 0)
Johnsonville 1
Johnsonville 2
Johnsonville 3
Johnsonville 4
Johnsonville 5
Johnsonville 6
Johnsonville 7
Johnsonville 8
Johnsonville 9
Johnsonville 10
Alma CS2 (B1 , B2, B3)
Alma B1
Alma B2
Alma B3
Alma CS1 (B1 , B2, B3, B4, B5)
Alma B4
Alma B5
Unit Type (a)
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Opt-In
Opt-In
Opt-In
Opt-In
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Opt-In
Opt-In
Opt-In
Substitution
Substitution
SO2
Emissions
1998(b)
33,535
10,307
1 1 ,970
5,671
7,378
7,162
10,610
9,891
0
0
0
0
40,664
45,551
114,588
1,287
6,517
SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
27,959
6,099
7,480
3,997
4,393
5,291
7,070
8,851
0
0
0
0
37,124
47,717
119,778
757
3,060
13,846
13,700
8,530
11,149
14,917
16,329
15,258
114,325
126,157
1,778
1,778
1,777
1,777
17,400
16,855
19,493
20,701
7,585
7,828
8,189
7,780
8,023
7,682
8,744
8,471
6,894
7,351
537
518
455
2,207
3,624
15,486
12,850
16,030
13,649
34,438
36,556
37,436
235,645
245,652
0
0
0
0
22,849
19,909
28,229
26,427
14,063
13,454
15,409
13,348
1 1 ,230
1 1 ,906
13,981
13,728
17,190
14,804
608
612
513
8,714
18,226
15,380
12,579
6,099
7,480
3,997
4,393
5,291
7,070
8,851
0
0
0
0
19,615
17,509
24,483
23,234
12,089
12,323
10,974
12,261
10,833
1 1 ,004
12,640
10,353
15,320
1 1 ,981
273
232
252
1,329
1,731
106
271
9,931
6,169
30,441
32,163
32,145
228,575
236,801
0
0
0
0
3,234
2,400
3,746
3,193
1,974
1,131
4,435
1,087
397
902
1,341
3,375
1,870
2,823
335
380
261
7,385
16,495
B-4, 11
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
Plant Name
Edgewater
Edgewater
Genoa
J P Madgett
Nelson Dewey
Nelson Dewey
Nelson Dewey
North Oak Creek
North Oak Creek
North Oak Creek
North Oak Creek
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Rock River
Rock River
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
Weston
Weston
Albright
Albright
Albright
Fort Martin
Fort Martin
Harrison
Harrison
Harrison
Harrison
Kammer
Kammer
Kammer
Stack/Unit ID
3
4
1
B1
CS1 (1,2)
1
2
1
2
3
4
CS56 (5, 6)
5
6
7
8
1
2
CSS (5, 6)
5
6
CS4 (7, 8)
7
8
1
2
1
2
3
1
2
XS123(1,2, 3)
1
2
3
03013(1,2,3)
1
2
Unit Type (a)
Substitution
Tablel
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
SO2
Emissions
1998(b)
1,973
8,391
9,031
5,223
10,861
0
0
0
0
1,884
1,569
2,283
1,532
1,898
16,781
26,529
1,111
1,922
2,202
1,929
7,228
41 ,641
37,663
6,934
108,618
SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
1,356
6,624
12,513
5,333
13,280
0
0
0
0
2,278
1,264
2,196
656
741
15,736
17,153
1,263
1,778
2,500
2,523
1 1 ,640
50,943
48,158
6,835
104,231
4,493
24,099
22,103
6,407
5,852
6,504
5,083
5,005
5,229
6,154
2,097
2,844
7,317
7,312
5,398
4,034
9,416
1 1 ,723
15,754
15,375
1,579
3,580
4,831
5,024
1 1 ,684
40,496
40,116
68,078
64,488
57,730
18,247
18,948
15,786
36,598
41,191
12,885
12,247
14,617
0
0
0
0
1,050
1,570
1,400
2,500
20,924
13,673
10,064
12,753
17,147
16,634
1,500
2,000
3,634
3,041
13,390
51 ,452
48,640
2,422
2,090
2,825
32,444
41,313
1,356
6,624
12,513
5,333
6,594
6,686
0
0
0
0
912
1,366
1,264
2,196
656
741
8,469
7,267
8,659
8,494
1,263
1,778
2,500
2,523
1 1 ,640
50,943
48,158
2,009
2,029
2,797
30,899
39,346
14,430
29,974
28,678
7,552
5,653
7,931
0
0
0
0
138
204
136
304
20,268
12,932
1,595
5,486
8,488
8,140
237
222
1,134
518
1,750
509
482
413
61
28
1,545
1,967
B-4, 12
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE I UNITS FOR 1999
State
WV
wv
WV
wv
wv
wv
wv
wv
wv
wv
Plant Name
Kammer
Mitchell
Mitchell
Mitchell
Mt Storm
Mt Storm
Mt Storm
Mt Storm
Rivesville
Rivesville
Stack/Unit ID
3
CS012(1,2)
1
2
CSO(1,2)
1
2
3
7
8
Unit Type (a)
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
SO2
Emissions
1998(b)
59,330
106,759
4,576
624
1,995
SO2 1999 Held in Allowances Deducted Under Allowances
Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
1999(b) Allocated (c) as of 3/1/00 Emissions (d) Provisions (e) to 2000
55,046
101,124
3,481
444
2,954
16,932
42,823
44,312
42,570
34,644
56,589
1,009
3,059
35,447
44,242
45,859
103,790
77,853
108,656
1,066
2,984
33,986
27,022
28,024
50,562
50,562
3,481
444
2,954
1,461
17,220
17,835
53,228
27,291
105,175
622
30
NOTES:
(a) Identifies the affected unit as listed in Table 1, or as a substitution, compensating, or opt-in unit.
(b) Both 1998 and 1999 emissions appear as reported by CEMS under the Acid Rain Program.
(c) This column lists allowances allocated under the following provisions: Initial Allocation (to Table 1 units), allowances for substitution and
compensating units, Phase I Extension Allowances, Early Reduction Credits, and Conservation allowances.
(d) This column displays the 1999 emissions for units that are not connected to a common stack. For units sharing a common stack, an apportionment was
made either by the unit or by EPA to divide up the stack's emissions among the units sharing the stack.
(e) This column displays the sum of allowance deductions made for underutilization and state cap provisions.
B-4, 13
-------
APPENDIX C
Appendix C-l: List of Averaging Plans and Results in 1999
Appendix C-2: Compliance Results for the 265 NOX Affected Units in 1999
Appendix C-3: Compliance Results for the 274 Early Election Units in 1999
-------
Appendix C-l: List of Averaging Plans and Results in 1999
Company
ORB Code Plant Name, State and Units
Plant Limit
Plan Rate
AES Greenidge LLC
2527 Greenidge NY 6
2535 MillikenNY1.2
0.45
0.30
Allegheny Energy Supply
Ameren Services
Ameren Services
Cinergy Corp.
3942 Albright WV 1-3
3178 Armstrong PA 1,2
3944 Harrison WV 1-3
3943 Fort Martin WV 1
3181 Mitchell PA 33
6004 PleasantsPAl,2
1570 R P Smith PA 9, 1 1
862 Grand Tower IL 07-09
863 Hutsonville IL 05, 06
864 MeredosialL 01-05
6017 Newton IL 1,2
2103 LabadieMOl-4
2104 MeramecMOl-4
6155 Rush Island MO 1,2
1001 CayugaINl,2
6018 East Bend 2
6113 Gibson IN 1-4
2832 Miami Fort OH 6
1008 R Gallagher IN 1-4
1010 Wabash River IN 2, 3, 5, 6
2830 Walter C Beckjord 5, 6
0.49
0.45
0.45
0.32
0.45
0.18
0.48
0.42
C-l, 1
-------
Appendix C-l: List of Averaging Plans and Results in 1999
Company
ORB Code Plant Name, State and Units
Plant Limit
Plan Rate
Dairy land Power Cooperative
Dynegy Midwest Generation, Inc.
East Kentucky Power Cooperative
4140 AlmaWIB4,B5
4143 Genoa WI 1
4271 JPMadgettWIBl
889 Baldwin IL 3
892 Hennepin IL 2
897 Vermilion IL 1,2
1384 Cooper KYI, 2
0.48
0.43
0.45
0.40
0.50
0.42
FirstEnergy Corporation
Hoosier Energy Rec., Inc.
6094 Bruce Mansfield PA 1 , 2
2857 EdgewaterOH13
2858 Gorge OH 25, 26
3138 New Castle PA 1,2
2867 Toronto OH 10, 11
2864 RE Burger OH 7, 8
2866 WHSammisOH5,6
1 043 Frank E Ratts IN 1 SGI , 2SG1
0.50
0.43
0.50
0.47
IES Utilities, Inc.
1104 Burlington IA 1
1073 Prairie Creek IA 4
0.47
0.29
C-l, 2
-------
Appendix C-l: List of Averaging Plans and Results in 1999
Company
ORB Code Plant Name, State and Units
Plant Limit
Indianapolis Power & Light
LG&E Energy Corporation
990
991
994
Elmer W Stout IN 50, 60, 70
H T Pritchard IN 3-6
Petersburg IN 1-4
1355
1356
1357
EW Brown KYI -3
Ghent KY 1
Green River KY 5
Northern States Power Company
1912
6090
High Bridge MN 3-6
Sherbume County MN 1 , 2
PP&L
Sithe
3140
3148
3152
Brunner Island PA 1-3
Martins Creek PA 1,2
Sunbury PA 3, 4
3113
Portland PA 1,2
South Mississippi Elec. Power
Assoc.
6061
RD Morrow MS 1,2
Plan Rate
0.35
0.41
0.31
0.36
0.26
0.46
C-l, 3
-------
Appendix C-l: List of Averaging Plans and Results in 1999
Company
ORB Code Plant Name, State and Units
Plant Limit
Plan Rate
Southern Company
Springfield (MO), City Utilities of
TVA
699 ArkwrightGAl-4
703 Bowen GA 1BLR - 4BLR
641 Crist FL 4-7
26 ECGastonAL 1-5
7 GadsdenAL 1-2
708 Hammond GA 1-4
709 Harllee Branch GA 2
7 1 0 Jack McDonough GA MB 1 , MB2
2049 Jack Watson MS 4, 5
733 Kraft GA 1-3
6124 MclntoshGAl
727 Mitchell GA 3
6257 Scherer GA 3
6052 WansleyGAl,2
728 Yates GA Y1BR - Y7BR
642 ScholzFLl,2
6073 Victor J Daniel Jr MS 1 , 2
0.46 0.44
2161 James River MO 3-5
6195 Southwest MO 1
0.50 0.44
47 Colbert AL 1-5
3403 GallatinTNl-4
3406 Johnsonville TN 1 - 1 0
0.48 0.42
4040 Port Washington WI 1 -4
C-l, 4
-------
Appendix C-l: List of Averaging Plans and Results in 1999
Company
ORB Code Plant Name, State and Units
Plant Limit
Plan Rate
Wisconsin Public Service Corp.
4041
4042
4072
4078
South Oak Creek WI 5-8
Valley (WEPCO)WI 1-4
Pulliam WI 7, 8
WestonWIl-3
C-l, 5
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1999
1999
ST
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
FL
FL
FL
FL
FL
FL
FL
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
Plant Name
Colbert
Colbert
Colbert
Colbert
Colbert
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
Gadsden
Gadsden
Big Bend
Crist
Crist
Crist
Crist
Scholz
Scholz
Arkwright
Arkwright
Arkwright
Arkwright
Bowen
Bowen
Bowen
Bowen
Hammond
Hammond
Hammond
Operating Utility
TVA
TVA
TVA
TVA
TVA
Alabama Power Co
Alabama Power Co
Alabama Power Co
Alabama Power Co
Alabama Power Co
Alabama Power Co
Alabama Power Co
Tampa Electric Co
Gulf Power Co
Gulf Power Co
Gulf Power Co
Gulf Power Co
Gulf Power Co
Gulf Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
ORIS
Code
47
47
47
47
47
26
26
26
26
26
7
7
645
641
641
641
641
642
642
699
699
699
699
703
703
703
703
708
708
708
Boiler
1
2
3
4
5
1
2
3
4
5
1
2
BB04
4
5
6
7
1
2
1
2
3
4
1BLR
2BLR
3BLR
4BLR
1
2
3
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
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Emission
Limit
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.45
0.50
0.50
0.45
0.45
0.45
0.45
0.50
0.50
0.50
Actual
Emission
Rate
0.44
0.44
0.44
0.44
0.40
0.50
0.50
0.47
0.47
0.40
0.61
0.63
0.44
0.41
0.48
0.49
0.52
0.66
0.67
0.74
0.74
0.74
0.74
0.42
0.43
0.42
0.42
0.78
0.78
0.78
AEL or
Avg. Plan
Limit
0.47
0.47
0.47
0.47
0.47
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
Avg. Plan
Rate
0.42
0.42
0.42
0.42
0.42
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
1990
Emission
Rate
0.80
0.67
0.83
0.86
0.78
0.90
0.78
0.80
0.80
0.78
0.51
0.56
0.46
0.43
0.49
1.04
1.16
0.69
0.80
0.90
0.90
0.90
0.90
0.67
0.65
0.56
0.58
0.84
0.84
0.84
Change from
1990 to
1999
-45%
-34%
-47%
-49%
-49%
-44%
-36%
-41%
-41%
-49%
19%
12%
-5%
-4%
-2%
-53%
-55%
-4%
-16%
-18%
-18%
-18%
-18%
-37%
-34%
-25%
-28%
-7%
-7%
-7%
C-2,1
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1999
1999
ST
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
IA
IA
IA
IA
IL
IL
IL
IL
IL
IL
IL
Plant Name
Hammond
Harllee Branch
Jack McDonough
Jack McDonough
Kraft
Kraft
Kraft
Me into sh
Mitchell
Scherer
Wansley
Wansley
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Burlington
Milton L Kapp
Prairie Creek
Riverside
Baldwin
Grand Tower
Grand Tower
Grand Tower
Hennepin
Hutsonville
Hutsonville
Operating Utility
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Savannah Electric & Power
Savannah Electric & Power
Savannah Electric & Power
Savannah Electric & Power
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
Georgia Power Co
IES Utilities, Inc.
Interstate Power Co
IES Utilities, Inc.
MidAmerican Energy Company
Illinova Power Marketing, Inc.
CIPSCO
CIPSCO
CIPSCO
Illinova Power Marketing, Inc.
CIPSCO
CIPSCO
ORIS
Code
708
709
710
710
733
733
733
6124
727
6257
6052
6052
728
728
728
728
728
728
728
1104
1048
1073
1081
889
862
862
862
892
863
863
Boiler
4
2
MB1
MB2
1
2
3
1
3
3
1
2
Y1BR
Y2BR
Y3BR
Y4BR
Y5BR
Y6BR
Y7BR
1
2
4
9
3
7
8
9
2
5
6
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
Standard Limitation
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Emission
Limit
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.45
0.45
0.50
0.50
0.50
0.45
0.45
0.45
Actual
Emission
Rate
0.45
0.69
0.33
0.33
0.55
0.55
0.55
0.81
0.57
0.26
0.41
0.41
0.40
0.44
0.44
0.37
0.37
0.29
0.29
0.22
0.33
0.38
0.33
0.34
0.72
0.8
0.65
0.53
0.56
0.60
AEL or
Avg. 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
0.47
0.47
0.45
0.45
0.45
0.45
0.45
0.45
0.45
Actual
Avg. Plan
Rate
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
0.29
0.29
0.40
0.32
0.32
0.32
0.40
0.32
0.32
1990
Emission
Rate
1.20
0.99
0.66
0.60
0.40
0.40
0.40
0.83
0.61
0.20
0.73
0.67
0.56
0.62
0.62
0.56
0.65
0.67
0.61
0.63
0.80
1.05
0.82
0.67
0.78
0.96
0.64
0.59
0.70
0.67
Change from
1990 to
1999
-63%
-30%
-50%
-45%
39%
39%
39%
-3%
-7%
29%
-44%
-39%
-29%
-29%
-29%
-34%
-43%
-57%
-52%
-65%
-59%
-64%
-60%
-49%
-7%
-17%
-2%
-10%
-20%
-10%
C-2,2
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1999
1999
ST
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
Plant Name
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Newton
Newton
Vermilion
Vermilion
Cayuga
Cayuga
Elmer W Stout
Elmer W Stout
Elmer W Stout
F B Culley
F B Culley
Frank E Ratts
Frank E Ratts
Gibson
Gibson
Gibson
Gibson
H T Pritchard
H T Pritchard
Operating Utility
Electric Energy Inc
Electric Energy Inc
Electric Energy Inc
Electric Energy Inc
Electric Energy Inc
Electric Energy Inc
CIPSCO
CIPSCO
CIPSCO
CIPSCO
CIPSCO
CIPSCO
CIPSCO
Illinova Power Marketing, Inc.
Illinova Power Marketing, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
Indianapolis Power & Light
Indianapolis Power & Light
Indianapolis Power & Light
Southern Indiana Gas & Elec
Southern Indiana Gas & Elec
Hoosier Energy REC, Inc.
Hoosier Energy REC, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
Indianapolis Power & Light
Indianapolis Power & Light
ORIS
Code
887
887
887
887
887
887
864
864
864
864
864
6017
6017
897
897
1001
1001
990
990
990
1012
1012
1043
1043
6113
6113
6113
6113
991
991
Boiler
1
2
3
4
5
6
1
2
3
4
5
1
2
1
2
1
2
50
60
70
2
3
1SG1
2SG1
1
2
3
4
3
4
Compliance Approach
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Emission
Limit
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
Actual
Emission
Rate
0.18
0.18
0.18
0.18
0.17
0.17
0.53
0.53
0.53
0.53
0.55
0.17
0.29
0.45
0.45
0.31
0.33
0.37
0.38
0.37
0.45
0.45
0.48
0.47
0.45
0.45
0.46
0.41
0.68
0.68
AEL or
Avg. Plan
Limit
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.48
0.48
0.45
0.45
0.45
0.50
0.50
0.48
0.48
0.48
0.48
0.45
0.45
Actual
Avg. Plan
Rate
0.32
0.32
0.32
0.32
0.32
0.32
0.32
0.40
0.40
0.42
0.42
0.35
0.35
0.35
0.47
0.47
0.42
0.42
0.42
0.42
0.35
0.35
1990
Emission
Rate
0.56
0.56
0.56
0.56
0.56
0.56
0.50
0.50
0.50
0.50
0.67
0.47
0.39
0.94
0.74
0.42
0.47
0.63
0.65
0.71
1.05
1.23
1.08
1.09
1.03
1.12
0.52
0.66
0.74
0.74
Change from
1990 to
1999
-68%
-68%
-68%
-68%
-70%
-70%
5%
5%
5%
5%
-18%
-64%
-26%
-52%
-39%
-26%
-30%
-41%
-42%
-48%
-57%
-64%
-56%
-57%
-56%
-60%
-12%
-38%
-8%
-8%
C-2, 3
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1999
1999
ST
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
KS
KS
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
Plant Name
H T Pritchard
H T Pritchard
Petersburg
Petersburg
Petersburg
Petersburg
R Gallagher
R Gallagher
R Gallagher
R Gallagher
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
La Cygne
Quindaro
Coleman
Coleman
Coleman
Cooper
Cooper
E W Brown
E W Brown
E W Brown
East Bend
Elmer Smith
Ghent
Green River
H L Spurlock
Operating Utility
Indianapolis Power & Light
Indianapolis Power & Light
Indianapolis Power & Light
Indianapolis Power & Light
Indianapolis Power & Light
Indianapolis Power & Light
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
PSI Energy, Inc.
Kansas City Power & Light
Board of Public Util, KS City
Big Rivers Electric
Big Rivers Electric
Big Rivers Electric
East Kentucky Power Coop
East Kentucky Power Coop
Kentucky Utilities Co
Kentucky Utilities Co
Kentucky Utilities Co
Cincinnati Gas & Electric Co
Owensboro City of
Kentucky Utilities Co
Kentucky Utilities Co
East Kentucky Power Coop
ORIS
Code
991
991
994
994
994
994
1008
1008
1008
1008
1010
1010
1010
1010
1010
1241
1295
1381
1381
1381
1384
1384
1355
1355
1355
6018
1374
1356
1357
6041
Boiler
5
6
1
2
3
4
1
2
3
4
1
2
3
5
6
2
2
Cl
C2
C3
1
2
1
2
3
2
2
1
5
1
Compliance Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Standard Limitation
Emission
Limit
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
0.45
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.50
0.45
0.45
0.50
0.50
Actual
Emission
Rate
0.37
0.37
0.26
0.33
0.33
0.32
0.46
0.46
0.42
0.42
0.15
0.49
0.57
0.49
0.38
0.29
0.38
0.44
0.45
0.44
0.42
0.42
0.50
0.40
0.40
0.41
0.41
0.41
0.41
0.42
AEL or
Avg. Plan
Limit
0.45
0.45
0.45
0.45
0.45
0.45
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.50
0.50
0.46
0.46
0.46
0.48
0.46
0.46
Actual
Avg. Plan
Rate
0.35
0.35
0.35
0.35
0.35
0.35
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
0.42
0.41
0.41
1990
Emission
Rate
0.67
0.47
0.56
0.63
0.37
0.37
0.74
0.95
0.95
0.95
0.52
0.95
0.92
0.85
0.37
0.29
0.64
1.41
1.29
1.14
0.90
0.90
1.00
0.59
0.57
0.31
0.86
0.56
0.84
0.90
Change from
1990 to
1999
-45%
-21%
-53%
-48%
-11%
-14%
-38%
-52%
-56%
-56%
-71%
-48%
-38%
-42%
2%
0%
-40%
-69%
-65%
-61%
-53%
-53%
-50%
-32%
-30%
32%
-52%
-27%
-51%
-53%
C-2,4
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1999
1999
ST
KY
KY
KY
KY
MD
MD
MD
MD
MD
MD
MI
MN
MN
MN
MN
MN
MN
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
Plant Name
HMP&L Station 2
HMP&L Station 2
R D Green
R D Green
Chalk Point
Chalk Point
Morgantown
Morgantown
R P Smith
R P Smith
J H Campbell
High Bridge
High Bridge
High Bridge
High Bridge
Sherburne County
Sherburne County
Hawthorn
latan
James River
James River
James River
Labadie
Labadie
Labadie
Labadie
Meramec
Meramec
Meramec
Meramec
Operating Utility
WKE Station Two, Inc.
WKE Station Two, Inc.
Big Rivers Electric
Big Rivers Electric
PEPCO
PEPCO
PEPCO
PEPCO
Potomac Edison Co
Potomac Edison Co
Consumers Energy Co
Northern States Power Co
Northern States Power Co
Northern States Power Co
Northern States Power Co
Northern States Power Co
Northern States Power Co
Kansas City Power & Light
Kansas City Power & Light
Springfield City of (MO)
Springfield City of (MO)
Springfield City of (MO)
Union Electric Co
Union Electric Co
Union Electric Co
Union Electric Co
Union Electric Co
Union Electric Co
Union Electric Co
Union Electric Co
ORIS
Code
1382
1382
6639
6639
1571
1571
1573
1573
1570
1570
1710
1912
1912
1912
1912
6090
6090
2079
6065
2161
2161
2161
2103
2103
2103
2103
2104
2104
2104
2104
Boiler
HI
H2
Gl
G2
1
2
1
2
9
11
1
3
4
5
6
1
2
5
1
3
4
5
1
2
3
4
1
2
3
4
Compliance Approach
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
AEL Demonstration
AEL Demonstration
AEL Demonstration
AEL Demonstration
Averaging Plan
Averaging Plan
AEL Demonstration
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Emission
Limit
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.50
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
Actual
Emission
Rate
0.48
0.48
0.41
0.41
0.76
0.81
0.63
0.61
0.46
0.41
0.46
0.55
0.55
0.55
0.55
0.27
0.27
0.35
0.28
0.55
0.52
0.58
0.13
0.14
0.14
0.15
0.46
0.38
0.57
0.33
AEL or
Avg. Plan
Limit
0.86
1.20
0.70
0.70
0.49
0.49
0.55
0.46
0.46
0.46
0.46
0.46
0.46
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
Actual
Avg. Plan
Rate
0.45
0.45
0.31
0.31
0.31
0.31
0.31
0.31
0.44
0.44
0.44
0.18
0.18
0.18
0.18
0.18
0.18
0.18
0.18
1990
Emission
Rate
1.34
1.34
0.41
0.45
1.35
1.35
0.95
0.95
0.87
0.78
0.69
0.48
0.48
0.48
0.48
0.45
0.45
0.36
0.31
1.02
0.87
0.93
0.62
0.62
0.62
0.62
0.82
0.63
0.96
1.17
Change from
1990 to
1999
-64%
-64%
0%
-9%
-44%
-40%
-34%
-36%
-47%
-47%
-33%
15%
15%
15%
15%
-40%
-40%
-3%
-9%
-46%
-40%
-38%
-79%
-77%
-77%
-76%
-44%
-39%
-40%
-72%
C-2, 5
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1999
1999
ST
MO
MO
MO
MO
MO
MO
MO
MS
MS
MS
MS
MS
MS
NY
NY
NY
NY
NY
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Plant Name
Montrose
Montrose
Montrose
Rush Island
Rush Island
Southwest
Thomas Hill
Jack Watson
Jack Watson
R D Morrow
R D Morrow
Victor J Daniel Jr
Victor J Daniel Jr
Dunkirk
Dunkirk
Greenidge
Milliken
Milliken
Ashtabula
Conesville
Conesville
Eastlake
Eastlake
Eastlake
Eastlake
Edgewater
Gorge
Gorge
Miami Fort
Picway
Operating Utility
Kansas City Power & Light
Kansas City Power & Light
Kansas City Power & Light
Union Electric Co
Union Electric Co
Springfield City of (MO)
Associated Electric Coop Inc
Mississippi Power Co
Mississippi Power Co
South Mississippi Electric Pwr
South Mississippi Electric Pwr
Mississippi Power Co
Mississippi Power Co
Niagara Mohawk Power Corp
Niagara Mohawk Power Corp
NGE Generation, Inc.
NGE Generation, Inc.
NGE Generation, Inc.
Cleveland Electric Ilium
Columbus Southern Power
Columbus Southern Power
Cleveland Electric Ilium
Cleveland Electric Ilium
Cleveland Electric Ilium
Cleveland Electric Ilium
Ohio Edison Co
Ohio Edison Co
Ohio Edison Co
Cincinnati Gas & Electric Co
Columbus Southern Power
ORIS
Code
2080
2080
2080
6155
6155
6195
2168
2049
2049
6061
6061
6073
6073
2554
2554
2527
2535
2535
2835
2840
2840
2837
2837
2837
2837
2857
2858
2858
2832
2843
Boiler
1
2
3
1
2
1
MB3
4
5
1
2
1
2
3
4
6
1
2
7
3
4
1
2
3
4
13
25
26
6
9
Compliance Approach
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Actual AEL or
Emission Emission Avg. Plan
Limit Rate Limit
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.45
0.50
0.33
0.40
0.40
0.15
0.14
0.32
0.31
0.51
0.69
0.45
0.47
0.32
0.27
0.36
0.36
0.31
0.30
0.30
0.40
0.45
0.43
0.43
0.37
0.40
0.35
0.37
Not Oper.
Not Oper.
0.51
0.41
0.45
0.45
0.50
0.46
0.46
0.50
0.50
0.46
0.46
0.45
0.45
0.45
0.50
0.50
0.50
0.48
Actual
Avg. Plan
Rate
0.18
0.18
0.44
0.44
0.44
0.46
0.46
0.44
0.44
0.30
0.30
0.30
0.43
0.43
0.43
0.42
1990
Emission
Rate
0.32
0.34
0.34
0.63
0.63
0.47
0.31
1.10
1.22
0.42
0.43
0.27
0.28
0.48
0.48
0.55
0.66
0.59
0.61
0.93
0.55
0.49
0.68
0.54
0.51
0.87
0.00
0.00
0.73
0.87
Change from
1990 to
1999
2%
17%
17%
-76%
-78%
-32%
0%
-54%
-43%
8%
10%
20%
-4%
-26%
-26%
-44%
-55%
-49%
-34%
-52%
-22%
-12%
-46%
-26%
-31%
-57%
-30%
-53%
C-2,6
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1999
1999
ST
OH
OH
OH
OH
OH
OH
OH
OH
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
Plant Name
R E Burger
R E Burger
Toronto
Toronto
WHSammis
WHSammis
Walter C Beckjord
Walter C Beckjord
Armstrong
Armstrong
Bruce Mansfield
Bruce Mansfield
Brunner Island
Brunner Island
Brunner Island
Cheswick
Conemaugh
Conemaugh
Martins Creek
Martins Creek
Mitchell
New Castle
New Castle
Portland
Portland
Shawville
Shawville
Shawville
Shawville
Sunbury
Operating Utility
Ohio Edison Co
Ohio Edison Co
Ohio Edison Co
Ohio Edison Co
Ohio Edison Co
Ohio Edison Co
Cincinnati Gas & Electric Co
Cincinnati Gas & Electric Co
West Perm Power Co
West Perm Power Co
Pennsylvania Power Co.
Pennsylvania Power Co.
PP&L
PP&L
PP&L
Duquesne Light Co
Sithe Northeast Management Co.
Sithe Northeast Management Co.
PP&L
PP&L
West Perm Power Co
Ohio Edison Co
Ohio Edison Co
Sithe Northeast Management Co.
Sithe Northeast Management Co.
Sithe Northeast Management Co.
Sithe Northeast Management Co.
Sithe Northeast Management Co.
Sithe Northeast Management Co.
Sunbury Generation, LLC
ORIS
Code
2864
2864
2867
2867
2866
2866
2830
2830
3178
3178
6094
6094
3140
3140
3140
8226
3118
3118
3148
3148
3181
3138
3138
3113
3113
3131
3131
3131
3131
3152
Boiler
7
8
10
11
5
6
5
6
1
2
1
2
1
2
3
1
1
2
1
2
33
1
2
1
2
1
2
3
4
3
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 Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Actual AEL or
Emission Emission Avg. Plan
Limit Rate Limit
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.45
0.50
0.50
0.45
0.45
0.50
0.50
0.45
0.45
0.50
0.53
0.64
Not Oper.
Not Oper.
0.53
0.50
0.46
0.35
0.34
0.36
0.36
0.32
0.35
0.35
0.33
0.31
0.34
0.32
0.44
0.44
0.36
Not Oper.
Not Oper.
0.24
0.28
0.43
0.46
0.38
0.38
0.39
0.50
0.50
0.50
0.50
0.50
0.50
0.48
0.48
0.49
0.49
0.50
0.50
0.46
0.46
0.46
0.46
0.46
0.49
0.50
0.50
0.45
0.45
0.46
Actual
Avg. Plan
Rate
0.43
0.43
0.43
0.43
0.43
0.43
0.42
0.42
0.45
0.45
0.43
0.43
0.36
0.36
0.36
0.36
0.36
0.45
0.43
0.43
0.26
0.26
0.36
1990
Emission
Rate
0.66
0.72
0.00
0.00
0.52
1.10
0.72
0.71
0.90
1.04
0.98
1.13
0.65
0.71
0.83
0.71
0.65
0.71
1.03
0.93
0.68
0.00
0.00
0.46
0.66
0.99
1.02
0.83
0.82
0.93
Change from
1990 to
1999
-20%
-12%
1%
-55%
-36%
-51%
-62%
-65%
-63%
-72%
-46%
-51%
-60%
-56%
-47%
-55%
-57%
-53%
-47%
-48%
-58%
-57%
-55%
-54%
-53%
-58%
C-2,7
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1999
1999
ST
PA
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
Plant Name
Sunbury
Gallatin
Gallatin
Gallatin
Gallatin
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Alma
Alma
Genoa
J P Madgett
Port Washington
Port Washington
Port Washington
Port Washington
Port Washington
Pulliam
Pulliam
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
Operating Utility
Sunbury Generation, LLC
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
Dairy land Power Coop
Dairy land Power Coop
Dairy land Power Coop
Dairy land Power Coop
Wisconsin Electric Power Co
Wisconsin Electric Power Co
Wisconsin Electric Power Co
Wisconsin Electric Power Co
Wisconsin Electric Power Co
Wisconsin Public Service
Wisconsin Public Service
Wisconsin Electric Power Co
Wisconsin Electric Power Co
Wisconsin Electric Power Co
Wisconsin Electric Power Co
ORIS
Code
3152
3403
3403
3403
3403
3406
3406
3406
3406
3406
3406
3406
3406
3406
3406
4140
4140
4143
4271
4040
4040
4040
4040
4040
4072
4072
4041
4041
4041
4041
Boiler
4
1
2
3
4
1
2
3
4
5
6
7
8
9
10
B4
B5
1
Bl
1
2
3
4
5
7
8
5
6
7
8
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
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Actual AEL or
Emission Emission Avg. Plan
Limit Rate Limit
0.50
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
0.45
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.39
0.33
0.33
0.35
0.35
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.61
0.61
0.41
0.41
0.30
0.30
0.30
0.28
Not Oper.
0.43
0.36
0.26
0.26
0.37
0.37
0.46
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
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.47
0.47
0.48
0.48
0.48
0.48
Actual
Avg. Plan
Rate
0.36
0.42
0.42
0.42
0.42
0.42
0.42
0.42
0.42
0.42
0.42
0.42
0.42
0.42
0.42
0.43
0.43
0.43
0.43
0.35
0.35
0.35
0.35
0.33
0.33
0.35
0.35
0.35
0.35
1990
Emission
Rate
1.29
0.59
0.63
0.59
0.55
0.45
0.48
0.46
0.54
0.45
0.50
1.00
0.97
1.10
1.07
0.85
0.85
0.75
0.30
0.32
0.32
0.32
0.37
0.00
0.69
0.57
0.28
0.28
0.66
0.67
Change from
1990 to
1999
-70%
-44%
-48%
-41%
-36%
7%
0%
4%
-11%
7%
-4%
-52%
-51%
-56%
-55%
-28%
-28%
-45%
38%
-6%
-6%
-6%
-25%
-38%
-37%
-6%
-6%
-44%
-44%
C-2, 8
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1999
1999
ST
WI
WI
WI
WI
WI
WI
WI
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
WY
WY
Plant Name
Valley
Valley
Valley
Valley
Weston
Weston
Weston
Albright
Albright
Albright
Fort Martin
Harrison
Harrison
Harrison
Mitchell
Mitchell
Mt Storm
Mt Storm
Mt Storm
Pleasants
Pleasants
Jim Bridger
Jim Bridger
Operating Utility
Wisconsin Electric Power Co
Wisconsin Electric Power Co
Wisconsin Electric Power Co
Wisconsin Electric Power Co
Wisconsin Public Service
Wisconsin Public Service
Wisconsin Public Service
Monongahela Power Co
Monongahela Power Co
Monongahela Power Co
Monongahela Power Co
Monongahela Power Co
Monongahela Power Co
Monongahela Power Co
Ohio Power Co
Ohio Power Co
VEPCO
VEPCO
VEPCO
Monongahela Power Co
Monongahela Power Co
Pacificorp
Pacificorp
ORIS
Code
4042
4042
4042
4042
4078
4078
4078
3942
3942
3942
3943
3944
3944
3944
3948
3948
3954
3954
3954
6004
6004
8066
8066
Boiler
1
2
3
4
1
2
3
1
2
3
1
1
2
3
1
2
1
2
3
1
2
BW71
BW72
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
AEL Demonstration
AEL Demonstration
AEL Demonstration
AEL Demonstration
AEL Demonstration
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Emission
Limit
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.50
0.50
0.45
0.45
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.50
0.50
0.45
0.45
Actual
Emission
Rate
0.47
0.47
0.49
0.49
0.79
0.36
0.23
0.66
0.69
0.38
0.65
0.47
0.47
0.47
0.54
0.52
0.64
0.64
0.67
0.37
0.33
0.41
0.39
AEL or
Avg. Plan
Limit
0.48
0.48
0.48
0.48
0.47
0.47
0.47
0.49
0.49
0.49
0.49
0.49
0.49
0.49
0.56
0.56
0.76
0.69
0.74
0.49
0.49
Actual
Avg. Plan
Rate
0.35
0.35
0.35
0.35
0.33
0.33
0.33
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
1990
Emission
Rate
1.10
1.10
1.05
0.93
0.90
1.08
0.26
1.10
1.10
0.71
0.62
0.99
1.13
1.06
0.77
0.77
0.88
0.76
1.27
0.52
0.35
0.63
0.51
Change from
1990 to
1999
-57%
-57%
-53%
-47%
-12%
-67%
-10%
-40%
-37%
-46%
5%
-53%
-58%
-56%
-30%
-32%
-27%
-16%
-47%
-29%
-5%
-35%
-24%
C-2, 9
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1999
1999
ST Plant Name
Operating Utility
ORIS
Code
Boiler
Compliance Approach
Actual AEL or Actual 1990 Change from
Emission Emission Avg. Plan Avg. Plan Emission 1990 to
Limit Rate Limit Rate Rate 1999
WY
WY
Jim Bridger
Wyodak
Pacificorp
Pacificorp
8066 BW73 Standard Limitation 0.45 0.37
6101 BW91 Standard Limitation 0.50 0.29
0.42
0.37
-12%
-22%
C-2, 10
-------
Appendix C-3:Compliance Results for the 274 Early Election Units in 1999
ST
AL
AL
AR
AR
AR
AR
AR
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
AZ
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
CO
Plant Name
Charles R Lowman
Charles R Lowman
Flint Creek
Independence
Independence
White Bluff
White Bluff
Apache Station
Apache Station
Cholla
Cholla
Cholla
Cholla
Coronado
Coronado
Navajo
Navajo
Navajo
Springerville
Springerville
Cherokee
Cherokee
Comanche
Comanche
Craig
Craig
Craig
Pawnee
Rawhide
Ray D Nixon
Valmont
Operating Utility
Alabama Electric Coop
Alabama Electric Coop
Southwestern Electric Power
Entergy Arkansas, Inc.
Entergy Arkansas, Inc.
Entergy Arkansas, Inc.
Arkansas Power & Light Co
Arizona Electric Pwr Coop
Arizona Electric Pwr Coop
Arizona Public Service
Arizona Public Service
Arizona Public Service
Arizona Public Service
Salt River Project
Salt River Project
Salt River Project
Salt River Project
Salt River Project
Tucson Electric Power Co
Tucson Electric Power Co
Public Service Co of CO
Public Service Co of CO
Public Service Co of CO
Public Service Co of CO
Tri-State G&T Association
Tri-State G&T Association
Tri-State G&T Association
Public Service Co of CO
Platte River Power Authority
Colorado Springs Utilities
Public Service Co of CO
ORIS
Code
56
56
6138
6641
6641
6009
6009
160
160
113
113
113
113
6177
6177
4941
4941
4941
8223
8223
469
469
470
470
6021
6021
6021
6248
6761
8219
477
Boiler
2
3
1
1
2
1
2
2
3
1
2
3
4
U1B
U2B
1
2
3
1
2
3
4
1
2
Cl
C2
C3
1
101
1
5
NSPS1
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
Da
D
Da
D
Emission Actual 1999
Limit Emission Rate
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.50
0.45
0.45
0.50
0.50
0.50
0.50
0.50
0.45
0.50
0.45
0.48
0.49
0.30
0.23
0.29
0.35
0.34
0.43
0.40
0.43
0.35
0.32
0.31
0.44
0.42
0.39
0.33
0.37
0.37
0.39
0.46
0.35
0.30
0.28
0.31
0.42
0.34
0.23
0.35
0.42
0.26
1990 Change from
Emission Rate 1990 to 1999
0.62
0.66
0.31
0.34
0.35
0.29
0.34
0.58
0.58
0.46
0.42
0.36
0.38
0.51
0.51
0.41
0.41
0.37
0.34
0.33
0.73
0.51
0.24
0.31
0.39
0.40
0.28
0.62
0.43
0.54
0.17
-23%
-26%
-3%
-33%
-16%
21%
1%
-26%
-31%
-7%
-16%
-11%
-18%
-14%
-18%
-5%
-20%
-1%
9%
17%
-37%
-31%
27%
-10%
-21%
5%
21%
-63%
-19%
-23%
53%
1 New Source Performance Standard subpart
CO 1
-3, 1
-------
Appendix C-3:Compliance Results for the 274 Early Election Units in 1999
ST
CT
FL
FL
FL
FL
FL
FL
FL
FL
FL
GA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IL
IL
IL
IL
IL
IL
IL
IL
IN
Plant Name
Bridgeport Harbor
C D Mclntosh Jr
Crystal River
Crystal River
Crystal River
Deerhaven
Seminole
Seminole
St Johns River Power
St Johns River Power
Scherer
Ames
Ames
Council Bluffs
Council Bluffs
Council Bluffs
George Neal North
George Neal North
George Neal South
Lansing
Louisa
Ottumwa
Crawford
Crawford
Dallman
Fisk
Waukegan
Waukegan
Will County
Will County
A B Brown
Operating Utility
United Illuminating Co
City of Lakeland
Florida Power Corporation
Florida Power Corporation
Florida Power Corporation
Gainesville Regional Util
Seminole Electric Coop Inc
Seminole Electric Coop Inc
Jacksonville Electric Auth
Jacksonville Electric Auth
Georgia Power Co
City of Ames
City of Ames
Midamerican Energy Company
Midamerican Energy Company
Midamerican Energy Company
Midamerican Energy Company
Midamerican Energy Company
Midamerican Energy Company
Interstate Power Co
Midamerican Energy Company
IES Utilities, Inc.
Midwest Generation Erne, LLC
Midwest Generation Erne, LLC
City of Springfield, IL
Midwest Generation Erne, LLC
Midwest Generation Erne, LLC
Midwest Generation Erne, LLC
Midwest Generation Erne, LLC
Midwest Generation Erne, LLC
Southern Indiana Gas & Elec
ORIS
Code
568
676
628
628
628
663
136
136
207
207
6257
1122
1122
1082
1082
1082
1091
1091
7343
1047
6664
6254
867
867
963
886
883
883
884
884
6137
Boiler
BHB3
3
2
4
5
B2
1
2
1
2
4
7
8
1
2
3
2
3
4
4
101
1
7
8
33
19
7
8
3
4
1
NSPS1
D
D
D
D
Da
Da
Da
Da
D
D
D
D
D
D
D
D
D
D
Emission Actual 1999
Limit Emission Rate
0.45
0.50
0.45
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.50
0.50
0.45
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.18
0.47
0.43
0.49
0.48
0.48
0.45
0.42
0.49
0.49
0.27
0.35
0.41
0.40
0.37
0.46
0.43
0.48
0.37
0.43
0.26
0.33
0.32
0.37
0.40
0.35
0.31
0.33
0.43
0.31
0.42
1990 Change from
Emission Rate 1990 to 1999
0.56
0.46
0.38
0.50
0.47
0.53
0.43
0.36
0.50
0.59
0.21
0.60
0.55
0.56
0.33
0.37
1.06
0.39
0.64
0.50
0.25
0.69
0.33
0.48
0.55
0.39
0.26
0.41
0.39
0.31
0.61
-68%
2%
14%
-3%
2%
-10%
5%
17%
-3%
-18%
30%
-41%
-25%
-29%
11%
23%
-59%
22%
-42%
-13%
2%
-52%
-4%
-23%
-27%
-10%
19%
-19%
11%
2%
-31%
1 New Source Performance Standard subpart
C-3,2
-------
Appendix C-3:Compliance Results for the 274 Early Election Units in 1999
ST
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
KS
KS
KS
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
LA
LA
Plant Name
A B Brown
Dean H Mitchell
Dean H Mitchell
Dean H Mitchell
Dean H Mitchell
Merom
Merom
R M Schahfer
R M Schahfer
R M Schahfer
Rockport
Rockport
State Line
Whitewater Valley
Whitewater Valley
Nearman Creek
Riverton
Riverton
Cane Run
Cane Run
Cane Run
Dale
Dale
H L Spurlock
Mill Creek
Mill Creek
Mill Creek
Mill Creek
Trimble County
Big Cajun 2
Big Cajun 2
Operating Utility
Southern Indiana Gas & Elec
Northern Indiana Pub Serv
Northern Indiana Pub Serv
Northern Indiana Pub Serv
Northern Indiana Pub Serv
Hoosier Energy
Hoosier Energy
Northern Indiana Pub Serv
Northern Indiana Pub Serv
Northern Indiana Pub Serv
Indiana Michigan Power Co
Indiana Michigan Power Co
State Line Energy, LLC
City of Richmond, IN
City of Richmond, IN
Board of Public Util, KS City
Empire District Electric
Empire District Electric
Louisville Gas & Electric
Louisville Gas & Electric
Louisville Gas & Electric
East Kentucky Power Coop Inc
East Kentucky Power Coop Inc
East Kentucky Power Coop Inc
Louisville Gas & Electric
Louisville Gas & Electric
Louisville Gas & Electric
Louisville Gas & Electric
Louisville Gas & Electric
Cajun Electric Power
Cajun Electric Power
ORIS
Code
6137
996
996
996
996
6213
6213
6085
6085
6085
6166
6166
981
1040
1040
6064
1239
1239
1363
1363
1363
1385
1385
6041
1364
1364
1364
1364
6071
6055
6055
Boiler
2
4
5
6
11
1SG1
2SG1
15
17
18
MB1
MB2
3
1
2
Nl
39
40
4
5
6
3
4
2
1
2
3
4
1
2B1
2B2
NSPS1
Da
D
D
D
Da
Da
D
D
D
D
D
D
D
D
D
Emission Actual 1999
Limit Emission Rate
0.50
0.45
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.45
0.50
0.50
0.45
0.50
0.45
0.50
0.50
0.45
0.50
0.50
0.45
0.50
0.50
0.45
0.45
0.45
0.50
0.50
0.45
0.50
0.50
0.47
0.29
0.29
0.29
0.29
0.40
0.37
0.24
0.37
0.35
0.39
0.39
0.28
0.43
0.43
0.44
0.43
0.43
0.45
0.49
0.36
0.41
0.41
0.41
0.39
0.34
0.49
0.47
0.39
0.34
0.32
1990 Change from
Emission Rate 1990 to 1999
0.39
0.43
0.43
0.58
0.58
0.23
0.63
0.42
0.46
0.44
0.32
0.32
0.32
0.71
0.71
0.46
0.83
0.55
0.84
1.15
1.02
0.73
0.73
0.47
0.76
0.79
0.62
0.57
0.62
0.28
0.25
19%
-33%
-33%
-50%
-50%
74%
-41%
-43%
-19%
-20%
22%
22%
-13%
-39%
-39%
-4%
-48%
-22%
-46%
-57%
-65%
-44%
-44%
-13%
-49%
-57%
-21%
-18%
-37%
20%
28%
1 New Source Performance Standard subpart
C-3,3
-------
Appendix C-3:Compliance Results for the 274 Early Election Units in 1999
ST
LA
LA
LA
LA
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MN
MN
MO
MT
MT
MT
MT
MT
NC
NC
NC
NC
NC
NC
NC
NC
NC
Plant Name
Big Cajun 2
Dolet Hills
R S Nelson
Rodemacher
B C Cobb
B C Cobb
JBSims
JCWeadock
JCWeadock
J R Whiting
J R Whiting
Presque Isle
Presque Isle
Presque Isle
Clay Boswell
Hoot Lake
Sikeston
Colstrip
Colstrip
Colstrip
Colstrip
Lewis & Clark
Buck
Buck
Buck
Buck
Buck
Cliffside
Cliffside
Cliffside
Cliffside
Operating Utility
Cajun Electric Power
Central Louisiana Elec Co
Entergy Gulf States, Inc.
Central Louisiana Elec Co
Consumers Energy Co
Consumers Energy Co
City of Grand Haven
Consumers Energy Co
Consumers Energy Co
Consumers Energy Co
Consumers Energy Co
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Wisconsin Electric Power Co.
Minnesota Power & Light Co
Otter Tail Power Co
Sikeston Board of Mun Util
PP&L Montana, LLC
PP&L Montana, LLC
PP&L Montana, LLC
PP&L Montana, LLC
PP&L Montana, LLC
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
ORIS
Code
6055
51
1393
6190
1695
1695
1825
1720
1720
1723
1723
1769
1769
1769
1893
1943
6768
6076
6076
6076
6076
6089
2720
2720
2720
2720
2720
2721
2721
2721
2721
Boiler
2B3
1
6
2
4
5
3
7
8
1
3
7
8
9
3
2
1
1
2
3
4
Bl
5
6
7
8
9
1
2
3
4
NSPS1
D
D
D
D
Da
D
D
D
D
D
D
Da
Da
Emission Actual 1999 1990 Change from
Limit Emission Rate Emission Rate 1990 to 1999
0.50
0.50
0.45
0.50
0.45
0.45
0.50
0.45
0.45
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.29
0.44
0.41
0.42
0.36
0.38
0.41
0.35
0.34
0.31
0.38
0.48
0.46
0.47
0.35
0.39
0.24
0.41
0.37
0.43
0.45
0.38
0.42
0.43
0.45
0.42
0.43
0.41
0.39
0.39
0.42
0.24
0.62
0.20
0.38
0.38
0.36
0.51
0.44
0.44
0.82
1.04
0.49
0.53
0.66
0.42
0.58
0.51
0.42
0.43
0.34
0.35
0.57
0.59
0.54
0.57
0.45
0.51
Not Oper.
Not Oper.
Not Oper.
Not Oper.
19%
-29%
107%
10%
-6%
6%
-19%
-21%
-23%
-62%
-63%
-2%
-12%
-28%
-16%
-32%
-53%
-2%
-14%
27%
29%
-33%
-29%
-21%
-21%
-6%
-15%
1 New Source Performance Standard subpart
C-3,4
-------
Appendix C-3:Compliance Results for the 274 Early Election Units in 1999
ST
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
ND
ND
ND
ND
NE
NE
NE
NE
NE
NE
NM
NV
NV
NV
Plant Name
Cliffside
Dan River
Dan River
Dan River
G G Allen
G G Allen
G G Allen
G G Allen
G G Allen
Marshall
Marshall
Marshall
Marshall
Riverbend
Riverbend
Riverbend
Riverbend
Antelope Valley
Antelope Valley
Leland Olds
Stanton
Gerald Gentleman Sta
Gerald Gentleman Sta
Gerald Whelan Energy
Nebraska City
North Omaha
Platte
Escalante
Mohave
Mohave
North Valmy
Operating Utility
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
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Basin Electric Power
Basin Electric Power
Basin Electric Power
United Power Assn
Nebraska Public Power Dist
Nebraska Public Power Dist
City of Hastings
Omaha Public Power Dist
Omaha Public Power Dist
City of Grand Island
Plains Electric Gen & Trans
Southern California Edison
Southern California Edison
Sierra Pacific Power Co
ORIS
Code
2721
2723
2723
2723
2718
2718
2718
2718
2718
2727
2727
2727
2727
2732
2732
2732
2732
6469
6469
2817
2824
6077
6077
60
6096
2291
59
87
2341
2341
8224
Boiler
5
1
2
3
1
2
3
4
5
1
2
3
4
7
8
9
10
Bl
B2
1
10
1
2
1
1
4
1
1
1
2
1
Emission Actual 1999 1990 Change from
NSPS1 Limit Emission Rate Emission Rate 1990 to 1999
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
D 0.45
D 0.45
0.50
Da 0.45
D 0.50
D 0.50
D 0.45
D 0.50
0.45
D 0.45
Da 0.45
0.45
0.45
D 0.50
0.44
0.41
0.42
0.45
0.44
0.44
0.45
0.41
0.45
0.43
0.43
0.43
0.45
0.39
0.36
0.39
0.41
0.38
0.32
0.26
0.40
0.45
0.32
0.29
0.42
0.34
0.41
0.41
0.40
0.40
0.36
0.51
0.52
0.55
0.56
0.65
0.61
0.64
0.68
0.68
0.48
0.61
0.52
0.70
0.58
0.64
Not Oper.
Not Oper.
0.43
0.27
0.74
0.47
0.40
0.35
0.30
0.48
0.38
0.48
0.35
0.38
0.46
0.51
-13%
-20%
-23%
-20%
-32%
-28%
-30%
-40%
-34%
-11%
-29%
-17%
-36%
-33%
-44%
-11%
17%
-65%
-15%
13%
-8%
-4%
-12%
-10%
-14%
18%
4%
-13%
-30%
1 New Source Performance Standard subpart
C-3,5
-------
Appendix C-3:Compliance Results for the 274 Early Election Units in 1999
ST
NV
NV
NY
NY
NY
NY
NY
NY
NY
NY
NY
OH
OH
OH
OK
OK
OK
OK
OK
OK
OK
OR
PA
PA
PA
PA
PA
PA
PA
PA
PA
Plant Name
North Valmy
Reid Gardner
C R Huntley
C R Huntley
Dunkirk
Dunkirk
Kintigh
S A Carlson
S A Carlson
S A Carlson
S A Carlson
Conesville
Conesville
W H Zimmer
Muskogee
Muskogee
Muskogee
Northeastern
Northeastern
Sooner
Sooner
Boardman
Bruce Mansfield
Cromby
Eddy stone
Eddy stone
Homer City
Homer City
Homer City
Keystone
Keystone
Operating Utility
Sierra Pacific Power Co
Nevada Power Company
Huntley Power LLC
Huntley Power LLC
Niagara Mohawk Power Corp
Niagara Mohawk Power Corp
NGE Generation, Inc.
City of Jamestown
City of Jamestown
City of Jamestown
City of Jamestown
Columbus Southern Power
Columbus Southern Power
Cincinnati Gas & Electric Co
Oklahoma Gas & Electric Co
Oklahoma Gas & Electric Co
Oklahoma Gas & Electric Co
Central and Southwest Services
Central and Southwest Services
Oklahoma Gas & Electric Co
Oklahoma Gas & Electric Co
Portland General Electric
Pennsylvania Power Co.
Peco Energy Company
Peco Energy Company
Peco Energy Company
EME Homer City Generation, L.P.
EME Homer City Generation, L.P.
EME Homer City Generation, L.P.
Sithe Northeast Management Company
Sithe Northeast Management Company
ORIS
Code
8224
2324
2549
2549
2554
2554
6082
2682
2682
2682
2682
2840
2840
6019
2952
2952
2952
2963
2963
6095
6095
6106
6094
3159
3161
3161
3122
3122
3122
3136
3136
Boiler
2
4
67
68
1
2
1
9
10
11
12
5
6
1
4
5
6
3313
3314
1
2
1SG
3
1
1
2
1
2
3
1
2
NSPS1
Da
Da
Da
D
D
Da
D
D
D
D
D
D
D
D
D
D
Emission Actual 1999 1990 Change from
Limit Emission Rate Emission Rate 1990 to 1999
0.50
0.50
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.45
0.45
0.50
0.50
0.50
0.45
0.45
0.35
0.30
0.34
0.34
0.36
0.36
0.36
0.43
0.45
0.45
0.43
0.40
0.40
0.47
0.31
0.34
0.40
0.37
0.37
0.41
0.39
0.41
0.36
0.34
0.28
0.24
0.42
0.41
0.39
0.34
0.34
0.40
0.38
0.64
0.64
0.48
0.48
0.62
0.90
1.05
0.83
0.90
0.44
0.44
Not Oper.
0.44
0.41
0.44
0.53
0.53
0.33
0.42
0.40
0.57
0.60
0.42
0.50
1.09
1.04
0.62
0.79
0.79
-13%
-20%
-47%
-47%
-25%
-25%
-42%
-52%
-57%
-46%
-52%
-8%
-8%
-29%
-17%
-8%
-30%
-30%
23%
-7%
2%
-37%
-43%
-34%
-52%
-62%
-61%
-37%
-57%
-57%
1 New Source Performance Standard subpart
-------
Appendix C-3:Compliance Results for the 274 Early Election Units in 1999
ST
PA
PA
PA
PA
PA
PA
PA
PA
SC
SC
SC
SC
SC
TN
TN
TN
TN
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
Plant Name
Montour
Montour
New Castle
New Castle
New Castle
Titus
Titus
Titus
Cross
Cross
WSLee
WSLee
WSLee
John Sevier
John Sevier
John Sevier
John Sevier
Big Brown
Big Brown
Coleto Creek
Gibbons Creek
Harrington Station
Harrington Station
Harrington Station
J K Spruce
J T Deely
J T Deely
Limestone
Limestone
Martin Lake
Martin Lake
Operating Utility
PP&L
PP&L
Pennsylvania Power Co.
Pennsylvania Power Co.
Pennsylvania Power Co.
Sithe Northeast Management Company
Sithe Northeast Management Company
Sithe Northeast Management Company
South Carolina Pub Serv
South Carolina Pub Serv
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
TVA
TVA
TVA
TVA
Texas Utilities Electric Co
Texas Utilities Electric Co
Central Power & Light Co
Texas Municipal Power Agency
Southwestern Public Service
Southwestern Public Service
Southwestern Public Service
City of San Antonio
City of San Antonio
City of San Antonio
Houston Lighting & Power
Houston Lighting & Power
Texas Utilities Electric Co
Texas Utilities Electric Co
ORIS
Code
3149
3149
3138
3138
3138
3115
3115
3115
130
130
3264
3264
3264
3405
3405
3405
3405
3497
3497
6178
6136
6193
6193
6193
7097
6181
6181
298
298
6146
6146
Boiler
1
2
3
4
5
1
2
3
1
2
1
2
3
1
2
3
4
1
2
1
1
061B
062B
063B
**j
1
2
LIM1
LIM2
1
2
NSPS1
Da
Da
D
D
D
D
D
Da
D
D
Da
Da
D
D
Emission Actual 1999 1990 Change from
Limit Emission Rate Emission Rate 1990 to 1999
0.45
0.45
0.50
0.50
0.50
0.45
0.45
0.45
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.39
0.38
0.38
0.36
0.45
0.33
0.34
0.31
0.30
0.36
0.44
0.44
0.44
0.43
0.43
0.41
0.41
0.33
0.34
0.24
0.33
0.31
0.34
0.26
0.30
0.29
0.29
0.43
0.43
0.30
0.26
0.95
0.46
0.63
0.57
0.73
0.73
0.68
0.77
Not Oper.
0.46
0.64
0.61
0.50
0.62
0.62
0.64
0.64
0.40
0.34
0.38
0.47
0.27
0.36
0.36
Not Oper.
0.31
0.31
0.50
0.48
0.36
0.35
-59%
-18%
-39%
-37%
-38%
-55%
-50%
-60%
-22%
-31%
-28%
-13%
-31%
-31%
-36%
-36%
-16%
-1%
-37%
-30%
17%
-5%
-27%
-5%
-5%
-13%
-11%
-16%
-25%
1 New Source Performance Standard subpart
C-3,7
-------
Appendix C-3:Compliance Results for the 274 Early Election Units in 1999
ST
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
UT
UT
UT
UT
UT
UT
UT
UT
VA
VA
VA
Plant Name
Martin Lake
Monticello
Monticello
Monticello
Oklaunion
Pirkey
Sam Seymour
Sam Seymour
Sam Seymour
San Miguel
Sandow
Tolk Station
Tolk Station
W A Parish
W A Parish
W A Parish
W A Parish
Welsh
Welsh
Welsh
Bonanza
Carbon
Carbon
Hunter (Emery)
Hunter (Emery)
Huntington
Intermountain
Intermountain
Chesapeake
Chesapeake
Chesapeake
Operating Utility
Texas Utilities Electric Co
Texas Utilities Electric Co
Texas Utilities Electric Co
Texas Utilities Electric Co
West Texas Utilities Co
Southwestern Electric Power
Lower Colorado River Auth
Lower Colorado River Auth
Lower Colorado River Auth
San Miguel Electric Coop
Texas Utilities Electric Co
Southwestern Public Service
Southwestern Public Service
Houston Lighting & Power
Houston Lighting & Power
Houston Lighting & Power
Houston Lighting & Power
Southwestern Electric Power
Southwestern Electric Power
Southwestern Electric Power
Deseret Generation & Tran
Pacificorp
Pacificorp
Pacificorp
Pacificorp
Pacificorp
Intermountain Power Agency
Intermountain Power Agency
VEPCO
VEPCO
VEPCO
ORIS
Code
6146
6147
6147
6147
127
7902
6179
6179
6179
6183
6648
6194
6194
3470
3470
3470
3470
6139
6139
6139
7790
3644
3644
6165
6165
8069
6481
6481
3803
3803
3803
Boiler
3
1
2
3
1
1
1
2
3
SM-1
4
171B
172B
WAP5
WAP6
WAP7
WAP8
1
2
3
1-1
1
2
1
2
1
1SGA
2SGA
1
2
4
NSPS1
D
D
Da
D
D
D
Da
D
D
D
D
D
D
D
Da
D
D
D
Da
D
D
D
Da
Da
Emission Actual 1999
Limit Emission Rate
0.45
0.45
0.45
0.50
0.50
0.50
0.45
0.45
0.45
0.50
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.45
0.32
0.30
0.29
0.22
0.33
0.36
0.32
0.29
0.32
0.35
0.34
0.30
0.32
0.34
0.34
0.16
0.32
0.32
0.36
0.40
0.31
0.42
0.42
0.40
0.36
0.41
0.40
0.38
0.43
0.42
0.44
1990 Change from
Emission Rate 1990 to 1999
0.42
0.31
0.40
0.21
0.54
0.34
0.34
0.29
0.25
0.41
0.43
0.38
0.24
0.47
0.53
0.35
0.31
0.27
0.36
0.37
0.42
0.50
0.58
0.50
0.55
0.52
0.45
0.38
0.42
0.48
0.54
-24%
-2%
-28%
6%
-39%
5%
-6%
0%
31%
-15%
-21%
-22%
35%
-28%
-35%
-54%
2%
20%
1%
8%
-27%
-17%
-27%
-19%
-35%
-21%
-12%
1%
2%
-13%
-19%
1 New Source Performance Standard subpart
-------
Appendix C-3:Compliance Results for the 274 Early Election Units in 1999
ST
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
WA
WA
WI
WI
WI
WI
WI
WV
WY
WY
WY
WY
WY
WY
Plant Name
Chesterfield
Chesterfield
Glen Lyn
Glen Lyn
Possum Point
Potomac River
Potomac River
Potomac River
Potomac River
Potomac River
Yorktown
Yorktown
Centralia
Centralia
Blount Street
Blount Street
Columbia
Columbia
Edgewater
Mountaineer (1301)
Dave Johnston
Dave Johnston
Jim Bridger
Laramie River
Laramie River
Laramie River
Operating Utility
VEPCO
VEPCO
Appalachian Power Co
Appalachian Power Co
VEPCO
PEPCO
PEPCO
PEPCO
PEPCO
PEPCO
VEPCO
VEPCO
Pacificorp
Pacificorp
Madison Gas & Electric Co
Madison Gas & Electric Co
Wisconsin Power & Light
Wisconsin Power & Light
Wisconsin Power & Light
Appalachian Power Co
Pacificorp
Pacificorp
Pacificorp
Basin Electric Power
Basin Electric Power
Basin Electric Power
ORIS
Code
3797
3797
3776
3776
3804
3788
3788
3788
3788
3788
3809
3809
3845
3845
3992
3992
8023
8023
4050
6264
4158
4158
8066
6204
6204
6204
Boiler
3
4
51
52
3
1
2
3
4
5
1
2
BW21
BW22
8
9
1
2
5
1
BW41
BW42
BW74
1
2
3
Emission Actual 1999 1990 Change from
NSPS1 Limit Emission Rate Emission Rate 1990 to 1999
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.45
D 0.45
D 0.50
D 0.50
0.50
0.50
D 0.45
D 0.50
D 0.50
D 0.50
0.42
0.42
0.41
0.41
0.45
0.42
0.37
0.44
0.43
0.43
0.44
0.43
0.40
0.43
0.35
0.44
0.37
0.39
0.23
0.50
0.42
0.40
0.39
0.24
0.26
0.24
0.52
0.49
0.46
Not Oper.
0.60
0.51
0.44
0.64
0.46
0.72
0.57
0.57
0.40
0.45
0.71
0.61
0.46
0.49
0.21
0.47
0.48
0.54
0.41
0.35
0.32
0.42
-19%
-14%
-11%
-25%
-18%
-16%
-31%
-6%
-40%
-23%
-25%
-1%
-5%
-50%
-28%
-20%
-20%
10%
6%
-13%
-26%
-4%
-31%
-19%
-43%
1 New Source Performance Standard subpart
C-3,9
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