United States
Environmental Protection
Agency
Office of Air and Radiation
Acid Rain Division (6204J)
EPA-430-R-99-010
July 1999
EPA 1998 Compliance Report
Acid Rain Program
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The Acid Rain Program is working to significantly reduce electric utilties 'emissions ofsuljur
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system oftradable SO2 emissions allowances is a landmark use of market incentives in
environmental protection.
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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 being implemented in two phases: Phase I began in 1995 for SO2 and 1996 for
NOX, and will last until 1999; Phase II for both pollutants begins in 2000 and is expected to involve over
2,000 units. In 1998, there were 408 units affected by the SO2 provisions of the Acid Rain Program, 235
of which were also affected for NOX, and an additional 305 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 SO2 component of the Acid Rain Program represents a dramatic departure from traditional command
and control regulatory methods that establish source-specific emissions limitations. Instead, the program
introduces a trading system for SO2 that facilitates lowest-cost emissions reductions and an overall
emissions cap that ensures the 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 affected utilities. Flexibility is introduced to this command and control measure, however,
through compliance options such as emissions averaging, whereby a utility can meet the standard
emission limitations by averaging the emissions rates of two or more boilers. This allows utilities to
over-control at units where it is technically easier to control emissions, thereby achieving emissions
reductions at a lower cost. Additionally, beginning in 1997, certain Phase II units could elect to become
affected for NOX early. 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 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 1 4
SO2 Results
Program 4
Compliance Results 5
Allowance Market 8
NOX Results
Program 11
Phase I Units 12
Phase I Compliance Results 13
Phase II Early Election Units 14
Phase II Early Election Compliance Results 15
Monitoring Update 17
Conclusion 18
Appendix A: Phase I Affected And Early Election Units in 1998
Appendix B-l: Table 1 Units Designating Substitution and Compensating Units - 1998
Appendix B-2: List of Phase I Extension Units and 1998 Deductions for Exceeding 1998 Projected
Emissions Limitations
Appendix B-3: Emissions and Utilization of Phase I Units, 1997 and 1998
Appendix B-4: Emissions and Allowance Holdings of Phase I Units
Appendix C-l: List of Averaging Plans and Results in 1998
Appendix C-2: Compliance Results for the 265 Phase INOX Affected Units in 1998
Appendix C-3: Compliance Results for the 275 Early Election Units in 1998
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1998 Compliance Report Page 1
TO THE READER:
The Acid Rain Program 1998 Compliance Report summarizes compliance results that, for the fourth
consecutive year since the Acid Rain Program began, showlOO percent compliance with both sulfur
dioxide (SO2) and nitrogen oxide (NOx) requirements. Over the past year there were also a number of
significant Program improvements.
First, the allowance transfer deadline, the date by which a unit's allowance account is required to hold
enough allowances to account for the previous year's SO2 emissions, was changed from January 30th
to March 1 (Feb. 29 for leap years). This allows affected facilities additional time to determine their
previous year's SO2 emissions and to ensure the availability of sufficient allowances to account for
those emissions.
Second, in order to expedite transfers and reduce transaction costs the Acid Rain Program revised its
regulations to allow an authorized account representative to specify allowance accounts to which
allowances can be transferred without requiring the buyer's signature on each individual allowance
transfer form.
Third, to avoid the imposition of extremely large excess emissions penalties for minor, inadvertent
accounting errors, the Acid Rain Program now allows for the transfer of unused allowances from unit
accounts at the same source to account for the emissions at a unit that lacks sufficient allowances. This
leads to a smaller penalty, more in line with the violation, while still ensuring the environmental
objective.
Fourth, the monitoring rule have was revised to enhance flexibility for industry by reducing monitoring
requirements for certain units with low mass emissions, creating new monitoring options for some units,
reducing certain quality assurance requirements, and increasing fuel sampling flexibility for certain units.
The sum of these changes make the rule more efficient and less burdensome for the regulated
community, EPA, and the States.
Finally, the Acid Rain Program permits regulation was revised to make new and retired unit exemptions
easier for sources to comply with and simpler for the States to administer. These changes provide
States with additional flexibility in meeting public notice requirements in the issuance of Acid Rain
permits and allow for "direct/final" issuance of draft and proposed Acid Rain permits. The Program
also eased public notice requirements related to the appointment of, and changes to, the designated
representative and alternate designated representative.
We will continue to look for ways to improve the Acid Rain Program as we prepare for the year 2000
and the beginning of Phase II, and will work with all interested persons in ensuring that the Acid Rain
Program meets its environmental goals with minimum cost and burden for affected sources and States.
Brian J. McLean, Director
Acid Rain Program
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1998 Compliance Report Page 2
SUMMARY
100 Percent Compliance with both SO2 and NOX Requirements in 1998
All 713 boilers and combustion turbines (referred to as "units") affected by the SO2 and NOX
regulations of the Acid Rain Program in 1998 successfully met their emissions compliance obligations.
4 All 408 units subject to SO2 requirements in 1998 held sufficient allowances to cover their
emissions. Of the 5,300,861 allowances deducted from compliance accounts almost all (5,298,498
or 99.96 percent) were for emissions, but other deductions were also made as required by the Acid
Rain Program regulations.
4 All 540 units subject to the NOX requirements in 1998 demonstrated compliance with applicable
annual emission limitations. Of these 540 units, 235 were also subject to SO2 requirements, while
305 units were affected only for NOX (30 Phase I units and 275 Phase II "early election" units).
1998 SO2 Emissions of Phase I Units were 24 Percent Below Allowable Level
SO2 emissions in 1998 were 1.7 million tons (or 24 percent) below the 7 million ton allowable level as
determined by 1998 allowance allocations. Since an additional 7.9 million allowances were carried
over, or banked, from 1997, the overall number of allowances available in 1998 was 14.9 million, of
which affected units consumed only about 35 percent. Actual emissions for the 408 units participating
in 1998 were 5.3 million tons, down 180,000 tons from emissions of the 423 units affected in 1997.
1998 Phase I Unit NOX Emission Rates 41 Percent Below 1990; NOX Tons 29 Percent
Lower Than in 1990
Emission rates for the 265 Phase I utility units dropped by 41 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 0.41
Ibs/mmBtu; this rate is 16 percent below the compliance rate of 0.49 Ibs/mmBtu for these units. NOX
emission levels for these units were 390,254 tons (or 29 percent) below 1990 levels.
1998 NOX Emission Rates of Early Election Units Even Lower Than Rates for Phase I
Units
For the 275 Phase II units which elected to meet Phase INOX rates early, emission rates dropped from
an average of 0.46 Ibs/mmBtu in 1990 to 0.38 Ibs/mmBtu in 1998, a 17 percent decrease and 19 percent
below the compliance rate of 0.47 Ibs/mmBtu for these units. Therefore, while utilization of these units
increased by 28 percent between 1990 and 1998, NOX tons increased by only 8 percent.
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1998 Compliance Report Page 3
Monitoring Performance Excellent Once Again
For the fourth 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 II 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, 3.0 percent; and NOX
monitors, 3.1 percent.
Availability: SO2 and flow monitors achieved a median availability of 99.5 and 99.7 percent,
respectively, while NOX monitors achieved a median reliability of 99.2 percent.
SO2 Market Active; Volume of Allowances Transferred Between Distinct Entities in 1998
Continues to Increase
Activity in the allowance market continued to increase in 1998. The volume of allowances transferred
between unrelated parties in economically significant trades increased from 7.9 million in 1997 to 9.5
million in 1998.
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1998 Compliance Report
Page 4
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 1997, 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
SO2
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
171
94
275
540
1999
263
Variable
Variable
Variable
111
94
Variable
Variable
SO, PROGRAM
408 Units Underwent Annual Reconciliation for SO2 in 1998
There were 398 affected utility units and 10 opt-in units that underwent annual reconciliation in 1998 to
determine whether sufficient allowances were held to cover emissions. These 408 units are listed in
Appendix A and include 263 utility units specifically required to participate during Phase I, 135 utility
units not initially required to participate until Phase II, but electing to participate early as part of
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1998 Compliance Report Page 5
multi-unit compliance plans1, and 10 other units that elected to join as part of the Opt-in Program2.
There were 8 fewer units undergoing annual reconciliation than in 1997.
1998 SO2 Emissions Target was 6.97 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 1998, the emissions target established by the program for the 408 participating units was
6.97 million tons. However, the total allowable SO2 emission level in 1998 was actually 14.93 million
tons, consisting of the 6.97 million 1998 allowances granted through the program and an additional 7.96
million allowances carried over, or banked, from 1997.
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 1998 were also made available through the allowance auctions, held annually
since 1993. Other allowances issued in 1998 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 II, 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 1998 SO2 Allowable Emissions Level by 24 Percent
The Phase I units affected in 1998 emitted at a level approximately 24 percent below 1998 allocations,
as shown in Exhibit 3. This percentage is about the same as in 1997, with both emissions and
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 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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1998 Compliance Report
Page 6
allocations registering slight decreases. Appendix B-3 reports the 1998 emission and utilization levels
for all Phase I affected units, as well as a comparison to these levels in 1997.
Relative to 1997, the 263 Table 1 units decreased their emissions by about 110,000 tons, or more than
two percent in 1998, while increasing their utilization by just over one half of one percent. The 4.7
million tons emitted by these Table 1 units were still substantially below their 1998 allocation of 5.6
million allowable tons.
Exhibit 2
Origin of 1998 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 1998 ALLOCATION
BANKED 1997 ALLOWANCES
TOTAL 1998 ALLOWABLE
Number of
Allowances
5,550,820
178,211
948,708
150,000
15,838
97,932
27,656
6,969,165
7,959,676
14,928,841
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 1999.
Banked Allowances are those held over from 1995 through 1997
which can be used for compliance in 1998 or any future year.
Substitution and compensating units in 1998 expended about the same percentage of their annual
allocation as in 1997. In 1998, these 135 units were responsible for emitting approximately 550,000
tons of SO2, about 58 percent of their 950,000 allocation. In 1997, 153 substitution and compensating
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1998 Compliance Report
Page 7
Exhibit 3
Summary of SO2 Emissions versus Allocations
(Millions of Tons)
0 u
1
1 Table 1 Units
• S&C Units
^J aher
| TOTALS
'95Allocation
5.55
1.33
1.86
8.74
'95 Emissions
4.45
0.85
0.00
5.30
'96Allocation
5.55
1.18
1.57
8.30
'96 Emissions
4.77
0.63
0.04
5.44
'97Allocation
5.55
1.04
0.56
7.15
'97Emissions
4.77
0.62
0.08
5.47
'98Allocation
5.55
0.95
0.45
6.95
'98 Emissions
4.66
0.55
0.08
5.29
units emitted approximately 620,000 tons of SO2, or 60 percent of their 1.04 million allowable level.
Three new opt-in units joined the program in 1998, raising the total allocation to 98,000 allowances and
the emissions level to 80,000 tons. The percentage of emissions to allowances allocated to opt-in units
in 1998 increased by approximately 1% compared to 1997.
Deducting Allowances for Compliance
The total number of allowances deducted in 1998 was 5,300,861 which represents approximately 76
percent of all 1998 allowances issued. Almost all (99.95 percent) of the deducted allowances were for
emissions. Exhibit 4 displays these allowance deductions, as well as the remaining bank of 1995
through 1998 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
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1998 Compliance Report Page 8
surrendered to cover the total number of tons emitted. If no apportionment was made, EPA deducted
allowances equally among the units sharing the stack to cover total emissions reported by the stack.
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 units4.
For 1998, all 19 control units demonstrated meeting the 90 percent reduction requirement and,
therefore, did not surrender any 1998 extension allowances. The 1998 tonnage emissions limitation,
though, was exceed by five control units and eleven transfer units and resulted in a surrender of a total
of 99,240 vintage 1999 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 408 units affected in 1998 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
408 sources to be in compliance in 1998 and significantly reduced the cost of achieving these emissions
reductions as compared to the cost of a technological mandate.
Qualifying technology is defined in 40 CFR 72.2
4 Beginning in 1997, each of the 19 units designated as control units was required to show it had reduced
its annual emission 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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1998 Compliance Report Page 9
Exhibit 4
SO2 Allowance Reconciliation Summary
Total Allowances Held in Accounts as of 3/1/99 (1995 through 1998 Vintages)* 14,928,841
Table 1 Unit Accounts 8,585,043
Substitution & Compensating Unit Accounts 1,306,220
Opt-in Accounts 83,962
Other Accounts** 4,953,616
1998 Allowances Deducted for Emissions 5,298,498
Table 1 Unit Accounts 4,664,898
Substitution & Compensating Unit Accounts 553,349
Opt-in Unit Accounts 80,251
1998 Allowances Deducted Under Special Phase I Provisions*** 2,363
Table 1 Unit Accounts 65
Substitution & Compensating Unit Accounts 1,755
Opt-in Unit Accounts 543
Banked Allowances 9,627,980
Table 1 Unit Accounts 3,920,080
Substitution & Compensating Unit Accounts 751,116
Opt-in Unit Accounts 3,168
Other Accounts** 4,953,616
* The number of allowances held in the Allowance Tracking System (ATS) accounts equals the number of 1998 allowances allocated
(see Exhibit 2) plus the number of 1997 banked allowances. March 1, 1999 represents the Allowance Transfer Deadline, the point in
time at which the 1998 Phase I affected unit accounts are frozen and after which no transfers of 1995 through 1998 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 1998 (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 was $207/ton at the 1999 allowance auction. Prices have
remained in the $205 to $215 range since January of 1999. 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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1998 Compliance Report
Page 10
Exhibit 5
SO7 Allowance Prices
250
M o n th -Y e a r
Activity in the allowance market created under the Acid Rain Program remained strong in 1998, with
1,584 transactions moving about 13.5 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 transferred rose from 7.9 million
in 1997 to 9.5 million in 1998. A record 70 percent of annual activity consisted of allowances
transferred between economically distinct organizations, with more than half representing allowances
directly acquired by utilities.
The most active market segment in 1998 in terms of allowance volume was composed of exchanges
between brokers/traders and utilities, accounting for 6.3 million allowances. The next most active was
the reallocation category, which covered an additional 3.2 million allowances. The category of transfers
between unrelated utilities increased to 1.9 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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1998 Compliance Report
Page 11
Exhibit 6
Volume of SO2 Allowances in Economically Significant Transfers
ro
I
< Ji
M— -=
O ^
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1998 Compliance Report
Page 12
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 1998
In 1998, 265 coal-fired utility units were subject to the Title IV Phase I emission limitations for NOX.5
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 II. Exhibit 7 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 INOX 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.
I
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 1998. As in
1996 and 1997, averaging was the most widely chosen compliance option. For 1998, there were 24
averaging plans involving 204 Phase INOX units. See Appendix C-l: List of Averaging Plans and
Compared with 1997, the universe of units remained the same, except that Mt. Storm Unit 2 (WV) was
added because its compliance extension expired and Gadsby Unit 3 (UT) was deleted because it was mistakenly
identified in previous years as a coal-fired utility unit.
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1998 Compliance Report
Page 13
Results in 1998.
Exhibit 8
Compliance Options Chosen in 1998
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 1998, 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 19906 to 1998, the average NOX emission rate of the 265 Phase I units declined by 41% (from
0.70 Ib/mmBtu to 0.41 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).
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 1998 were 29 percent lower than in 1990, but 3 percent
higher than in 1997. While this is the second year total NOX mass emissions have increased, the ascent
can be attributed in part to greater electrical production, as evidenced by an increase in heat input in
1997 and 1998 of 3 percent and 6 percent, respectively, compared to 1996. Without further reductions
in emissions rates, NOX emissions would be expected to rise with increased utilization.
1 For a more detailed description of the 1990 baseline refer to the Acid Rain Program 1996 Compliance
Report.
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1998 Compliance Report
Page 14
Exhibit 9
Average NOX Emission Rates for 265 Phase 1 Units
NOx Rate
(Ih/mmBtu)
1.00
0.80
0.60
0.40
0.20
0.00
0.77
0.52
Weighted Average
Emissions Limitation
0X49)
0.45
0.36
0.44
0.36
0.43
0.37
1990 1996 1997 1998
D Table 1 Units (171) D Substitution Units (94)
Exhibit 10
NOV Mass Emissions for 265 Phase I Units
Tons
1,200,000
800,000
400,000
n
287,583
1,046,339
239,373
669,017
241,694
676,797
257,176
686,492
1990 1996 1997 1998
D Table 1 Units (171) D Substitution Units (94)
PHASE II EARLY ELECTION UNITS
275 Units Were Subject to Early Election Requirements in 1998
Nineteen ninety-eight was the second year in which early election utility units were required to meet the
-------
1998 Compliance Report
Page 15
Phase INOX limit7. Exhibit 11 shows the number of Early Election units by boiler type and their
corresponding emission limit.
Exhibit 11
Distribution of 1998 Early Election Units by Boiler Type
Boiler Type
Tangentially -fired
Dry Bottom Wall-fired
Total
Standard
Emission Limit
0.45
0.50
Operating Group 1,
Phase 2 Units
300
314
614
Early Election
Units
171
104
275
Percent of
Units Electing
57%
33%
45%
EARLY ELECTION COMPLIANCE RESULTS
For 1998, EPA determined that all 275 units complied with the Phase I, Group 1 emission limitations
and have continued eligibility for Early Election in 1999 through 2007. See Appendix C-3: Compliance
Results for the 275 Early Election Units in 1998.
Average NOX emission rates for Early Election units have declined by 17%, from 0.46 Ib/mmBtu in
1990 to 0.38 Ib/mmBtu in 1998. This decline is less dramatic than the decline at Phase INOX units
because 51% of the Early Election units are newer units already subject to the New Source Performance
Standards (NSPS) NOX emission limits. The overall NOX emission rate for these units is comparable to
the average rate of 0.41 Ib/mmBtu for all Phase INOX units. Exhibit 12 summarizes the NOX emission
rate reductions from 1990 to 1998 by boiler type for the 265 Early Election units that were operating in
1990.
7 Compared with 1997, the universe of early election units remained the same, except for W C Dale Units
3 and 4 (KY) and H L Spurlock Unit 2 (KY), which were added after being inadvertently omitted in 1997.
-------
1998 Compliance Report
Page 16
Exhibit 12
Average NOX Emission Rate for 265 Early Election Units (Operating in 1990)
0.80
0.60
NOx Rate
(Ih/mmBtu)
0.40
0.20
0.00
Tangentially-Fired Boilers
Emissions Limit (0.45)
0.45
0.37
0.37
Dry-Bottom Wall-Fired Boilers
remissions Limit (0.50)
0.47
0.38
0.39
1990 1997 1998 1990 1997 1998
NOX Mass Emissions Reduction
The total NOX mass emissions from the operating Early Election units increased by 106,619 tons (or I
percent) from 19908 to 1998, reflecting an increase in utilization (see Exhibit 13). For the 265 Early
Election units operating in 1990, heat input increased during the eight year period by approximately
28%.
The 1990 NOX mass emissions value differs slightly from the value in the 1997 NOX Compliance report
due to corrected estimates of heat input for ten units.
-------
1998 Compliance Report
Page 17
Exhibit 13
NOX Mass Emissions for 265 Early Election Units (Operating in 1990)
1,OUU,UUU
,2UU,UUU
NOx
_ eon 000
4UU,UUU
n
572,357
716,480
583,782
750,872
623,402
772,054
1990
1997
1998
DT-Fired Units (163) DDE Units (102)
SO2 AND NOX MONITORING IN 1998
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 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 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 will also be 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
-------
1998 Compliance Report
Page 18
equal to 10 percent for flow (beginning January 1, 2000, the flow standard for superior accuracy will
also be 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 16 highlights the relative accuracy results achieved by Acid Rain CEMS in
1998.
Exhibit 14
1998 Relative Accuracy Test Audit (RATA) Results
Mean Relative Accuracy
Median Relative Accuracy
Percent Meeting Relative Accuracy
Standard
SO2 Concentration
4.2%
3.0%
95%
Volumetric Flow Rate
3.7%
3.0%
97%
NOX Rate
4.1%
3.1%
91%
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 17 shows the monitor availabilities reported in 1998 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
1998 CEMS Availability
Parameter
SO2
Flow
NOX
Median % Availability at End of 1998
Coal-Fired Units
99.5
99.7
99.2
Oil and Gas Units
98.5
98.8
98.0
CONCLUSION
1998 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 1998, all Phase I affected utility units
not only met their compliance goals, but exceeded them, achieving an overall reduction of 390,254 tons
-------
1998 Compliance Report Page 19
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 275 Phase IINOX early election units
had increased emissions of eight 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 19959.
One factor mitigating the benefit of the over compliance 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, and 24 percent of 1998 allowances that were not retired for
compliance purposes can be used to cover emissions in a later year. However, immediate health and
environmental benefits are arguably more valuable than a benefit 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.
After the year 2000 when both programs are in full implementation, SO2 emissions are expected to
decline steadily to 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 are continuing
the success in 1998. The significant progress evident at this stage of the program is encouraging.
Through the continued efforts of Phase I participants and by additional reductions from Phase II 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.
9 U.S. Geological Survey, Trends in Precipitation Chemistry in the United States, 1983-94 - An Analysis
of the Effects in 1995 of Phase I of the CAAA of 1990, Title IV, USGS 96-0346, Washington, DC, June 1996.
-------
1998 Compliance Report Page 20
Appendices A to C-3 were created using a variety of tools. They are not available in PDF; please
download them at:
http://www.epa.gov/acidrain/cmprpt9 8/appendix. zip
-------
ST
AL
AL
AL
AL
AR
AR
AR
AZ
AZ
AZ
AZ
AZ
CO
CO
GA
APPENDIX A:
Plant Name
Charles R Lowman
Colbert
E C Gaston
Gadsden
Flint Creek
Independence
White Bluff
Apache
Cholla
Coronado
Navajo
Springerville
Craig
Comanche
Hammond
PHASE
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
1
I AFFECTED (X)
S02
X
X
X
X
X
X
X
X
X
X
X
X
X
NOx
E
E
X
X
X
X
X
X
X
X
X
X
X
X
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
X
AND EARLY ELECTION (E)
ST
CO
CO
CO
CO
CO
CT
FL
FL
FL
FL
FL
FL
FL
FL
GA
GA
IA
Plant Name
Cherokee
Pawnee
Rawhide
Ray D Nixon
Valmont
Bridgeport Harbor
Big Bend
C D Mclntosh
Crist
Crystal River
Deerhaven
St Johns River
Scholz
Seminole
Arkwright
Bowen
George Neal South
UNITS IN
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
4
1998
S02
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N<
E
E
E
E
E
E
E
X
E
X
X
X
X
E
E
E
E
E
E
X
X
E
E
X
X
X
X
X
X
X
X
E
-------
ST
GA
GA
GA
GA
GA
GA
GA
GA
IA
IA
IA
IA
IA
APPENDIX A: PHASE]
Plant Name Unit ID
2
3
4
Harllee Branch 1
2
o
6
4
Jack McDonough MB 1
MB2
Kraft 1
2
o
J
Mcintosh 1
Mitchell 3
Scherer 3
4
Wansley 1
2
Yates Y1BR
Y2BR
Y3BR
Y4BR
Y5BR
Y6BR
Y7BR
Ames 7
8
Burlington 1
Council Bluffs 1
2
3
Des Moines 1 1
George Neal North 1
2
3
AFFECTED (X) AND EARLY ELECTION (E) UNITS IN 1998
S02
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
NOx
X
X
X
X
X
X
X
X
X
X
X
X
E
X
X
X
X
X
X
X
X
X
E
E
X
E
E
E
E
E
ST Plant Name Unit ID
IA Lansing 4
IA Louisa 101
IA Milton L Kapp 2
IA Ottumwa 1
IA Prairie Creek 4
IA Riverside 9
IL Baldwin 1
2
3
IL Coffeen 1
2
IL Crawford 7
8
IL Dallman 33
IL Fisk 19
IL Grand Tower 7
8
9
IL Havana 1
2
3
4
5
6
7
8
IL Hennepin 1
2
IL Hutsonville 5
6
S02
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N<
E
E
X
E
X
X
X
E
E
E
E
X
X
X
X
X
X
IL Joppa Steam
X
X
IN
Dean H Mitchell
A,2
-------
ST
IL
IL
IL
IL
IL
IL
IL
IN
IN
IN
IN
IN
IN
APPENDIX
Plant Name
Kincaid
Meredosia
Newton
Vermilion
Waukegan
Will County
Wood River
A B Brown
Bailly
Breed
Cayuga
Clifty Creek
Wabash River
A: PHASE]
Unit ID
2
3
4
5
6
1
2
01
02
03
04
05
1
2
1
2
7
8
o
5
4
1
1
2
7
8
1
1
2
1
2
o
3
4
5
6
1
AFFECTED (X) AND EARLY ELECTION (E) UNITS IN 1998
S02
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
NOx
X
X
X
X
X
X
X
X
X
X
X
X
X
X
E
E
E
E
E
E
X
X
X
ST Plant Name
IN Elmer W Stout
IN F B Culley
IN Frank E Ratts
IN Gibson
IN H T Pritchard
IN Merom
IN Michigan City
IN Petersburg
IN R M Schahfer
IN R Gallagher
IN Rockport
IN State Line
IN Tanners Creek
KY H L Spurlock
Unit ID
5
6
11
50
60
70
2
3
1SG1
2SG1
1
2
3
4
3
4
5
6
1SG1
2SG1
12
1
2
3
4
15
17
18
1
2
o
5
4
MB1
MB2
o
3
U4
1
S02
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N<
E
E
E
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
E
E
X
X
X
X
E
E
E
X
X
X
X
E
E
E
X
A,3
-------
APPENDIX A: PHASE]
ST
IN
IN
KS
KS
KS
KS
KY
KY
KY
KY
KY
KY
KY
KY
KY
Plant Name
Warrick
Whitewater Valley
La Cygne
Nearman Creek
Quindaro
Riverton
Cane Run
Coleman
Cooper
D B Wilson
E W Brown
East Bend
Elmer Smith
Ghent
Green River
Unit ID
2
3
5
6
1
2
3
4
1
2
1
2
1
2
39
40
4
5
6
Cl
C2
C3
1
2
Wl
1
2
o
J
2
1
2
1
5
AFFECTED (X) AND EARLY ELECTION (E) UNITS IN 1998
S02
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
NOx
X
X
X
X
E
E
X
E
X
E
E
E
E
E
X
X
X
X
X
E
X
X
X
X
X
X
X
ST
KY
KYI
KY
KY
KY
KY
KY
LA
LA
LA
LA
MA
MA
MD
MD
MD
MD
Plant Name
Hmp&L Station 2
Mill Creek
Paradise
R D Green
Shawnee
Trimble County
WC Dale
Big Cajun 2
Dolet Hills
R S Nelson
Rodemacher
Brayton Point
Mount Tom
C P Crane
Chalk Point
Morgantown
R P Smith
Unit ID
2
HI
H2
1
2
3
4
3
Gl
G2
10
1
3
4
2B1
2B2
2B3
1
6
2
2
1
2
1
2
3
1
2
9
11
S02
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
NOx
E
X
X
E
E
E
E
X
X
E
E
E
E
E
E
E
E
E
X
X
X
X
X
X
MI B C Cobb
MO Montrose
X
X
A,4
-------
APPENDIX A: PHASE I AFFECTED (X) AND EARLY ELECTION (E) UNITS IN 1998
ST
MI
MI
MI
MI
MI
MI
MN
MN
MN
MN
MO
MO
MO
MO
MO
MO
NC
Plant Name
Dan E Karn
JB Sims
J C Weadock
J H Campbell
J R Whiting
Presque Isle
Clay Boswell
High Bridge
Hoot Lake
Sherburne County
Asbury
Hawthorn
latan
James River
Labadie
Meramec
Cliffside
Unit ID
5
2
o
J
1
8
1
2
1
3
7
8
9
3
3
4
5
6
2
1
2
1
5
1
3
4
5
1
2
3
4
1
2
o
5
4
1
S02
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
NOx
E
E
E
E
X
E
E
E
E
E
E
X
X
X
X
E
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
E
ST Plant Name
MO New Madrid
MO Rush Island
MO Sibley
MO Sioux
MO Sikeston
MO Southwest
MO Thomas Hill
MS Jack Watson
MS R D Morrow
MS Victor J Daniel Jr
MT Colstrip
MT Lewis & Clark
NC Buck
NV Mohave
Unit ID
2
3
1
2
1
2
1
2
3
1
2
1
1
MB1
MB2
MBS
4
5
1
2
1
2
1
2
3
4
Bl
5
6
7
8
9
1
S02
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N<
X
X
X
X
E
X
X
X
X
X
X
X
X
E
E
E
E
E
E
E
E
E
E
E
A,5
-------
ST
NC
NC
NC
NC
ND
ND
ND
NE
NE
NE
NE
NE
NH
NJ
NM
OH
APPENDIX A:
Plant Name
Dan River
G G Allen
Marshall
Riverbend
Antelope Valley
Leland Olds
Stanton
Gerald Gentleman
Gerald Whelan
Nebraska City
North Omaha
Platte
Merrimack
B L England
Escalante
Ashatabula
PHASE
Unit ID
2
3
4
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
2
1
2
1
7
I AFFECTED (X)
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
E
X
X
X
X
E
X X
AND EARLY ELECTION
ST Plant Name
NV North Valmy
NV Reid Gardner
NY CRHuntley
NY Dunkirk
NY Greenidge
NY Kintigh
NY Milliken
NY Northport
NY Oswego
NY Port Jefferson
NY Rosetom
NY S A Carlson
OH Acme
OH Kyger Creek
(E) UNITS IN
Unit ID
2
1
2
4
67
68
1
2
o
5
4
6
1
1
2
1
2
o
5
4
4
5
6
3
4
1
2
9
10
11
12
13
14
15
16
91
92
1
1998
S02
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
NOx
E
E
E
E
E
E
E
E
X
X
X
E
X
X
E
E
E
E
A,6
-------
ST
APPENDIX A: PHASE I AFFECTED (X) AND EARLY ELECTION (E) UNITS IN 1998
Plant Name Unit ID SO2 NOx ST Plant Name Unit ID SO2
OH Avon Lake
OH Bay Shore
OH Cardinal
OH Conesville
OH Eastlake
OH Edgewater
OH Gen JM Gavin
OH Gorge
OH J M Stuart
8
9
10
11
9
10
11
12
1
2
o
5
4
1
2
1
2
o
5
4
5
6
1
2
3
4
5
11
12
13
1
2
25
26
1
2
3
4
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X X
X X
E
E
X X
X X
X X
X X
X
X
X
X X
X
X
X X
X X
X
X
X
X
OH Lake Shore
OH Miami Fort
OH Muskingum
OH Niles
OH Picway
OH Poston
OH RE Burger
OH Toronto
OH W H Sammi
NOx
OH Walter C Beckjord 5
X
X
OH W H Zimmer
PA Mitchell
2
3
4
5
18
91
92
93
94
5-1
5-2
6
7
1
2
3
4
5
1
2
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
1
2
3
1
2
3
4
5
6
7
8
9
10
11
5
6
7
1
33
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
E
X
A,7
-------
ST
APPENDIX A:
Plant Name
PHASE I AFFECTED (X) AND EARLY ELECTION (E) UNITS IN 1998
Unit ID SO2 NOx ST Plant Name Unit ID SO2
OK
OK
OK
OR
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
TN
Muskogee
Northeastern
Sooner
Boardman
Armstrong
Bruce Mansfield
Brunner Island
Cheswick
Conemaugh
Cromby
Eddy stone
Hatfield's Ferry
Homer City
Keystone
Martins Creek
John Sevier
6
4
5
6
3313
3314
1
2
ISO
1
2
1
2
3
1
2
o
J
1
1
2
1
1
2
1
2
o
J
1
2
o
J
1
2
1
2
3
4
1
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
E
E
E
E
E
E
E
E
X
X
X
X
E
X
X
X
X
X
X
E
E
E
E
E
E
E
E
X
X
E
PA Montour 1
2
PA New Castle 1
2
3
4
5
PA Portland 1
2
PA Shawville 1
2
3
4
PA Sunbury 3
4
PA Titus 1
2
3
SC Cross 1
2
SC W S Lee 1
2
3
TN Allen 1
2
3
TN Cumberland 1
2
TN DuPont JVD1
Johnsonville JVD2
JVD3
JVD4
TN Gallatin 1
2
3
4
TX San Miguel SM-1
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
E
E
X
X
E
E
E
X
X
X
X
X
X
X
X
E
E
E
E
E
E
E
E
X
X
X
X
E
NOx
A,8
-------
ST
TN
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
APPENDIX
Plant Name
Johnsonville
Big Brown
Coleto Creek
Gibbons Creek
Harrington
J K Spruce
J T Deely
Limestone
Martin Lake
Monticello
Oklaunion
Pirkey
Sam Seymour
A: PHASE]
Unit ID
2
3
4
1
2
o
3
4
5
6
7
8
9
10
1
2
1
1
06 IB
062B
063B
BLR1
1
2
LIM1
LIM2
1
2
o
J
1
2
o
J
1
1
1
2
o
J
AFFECTED (X) AND EARLY ELECTION (E) UNITS IN 1998
S02
X
X
X
X
X
X
X
X
X
X
NOx
E
E
E
X
X
X
X
X
X
X
X
X
X
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
TX Sandow
TX Tolk
TX W A Parish
TX Welsh
UT Bonanza
UT Carbon
UT Hunter
UT Huntington
UT Intermountain
VA Chesapeake
VA Chesterfield
VA GlenLyn
VA Possum Point
VA Potomac River
VA Yorktown
Unit ID SO2
4
171B
172B
WAP5
WAP6
WAP7
WAP8
1
2
3
1-1
1
2
1
2
1
1SGA
2SGA
1
2
4
o
5
4
51
52
3
1
2
3
4
5
1
2
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
WA Centralia
BW21
WI Valley
X
A,9
-------
ST
APPENDIX A:
Plant Name
PHASE I AFFECTED (X) AND EARLY ELECTION (E) UNITS IN 1998
Unit ID SO2 NOx ST Plant Name Unit ID SO2
WI Alma
WI Blount Street
WI Columbia
WI Edgewater
WI Genoa
WI J P Madgett
WI Nelson Dewey
WI North Oak Creek
WI Port Washington
WI Pulliam
WI Rock River
WI South Oak Creek
BW22
Bl
B2
B3
B4
B5
8
9
1
2
o
3
4
5
1
Bl
1
2
1
2
3
4
1
2
o
5
4
5
5
6
7
8
1
2
5
6
7
8
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
E
X
X
E
E
E
E
E
X
X
X
X
X
X
X
X
X
X
X
X
X
2
3
4
WI Weston 1
2
3
WV Albright 1
2
3
WV Fort Martin 1
2
WV Harrison 1
2
3
WV Kammer 1
2
o
J
WV Mitchell 1
2
WV Mountaineer 1
WV Mt Storm 1
2
3
WV Pleasants 1
2
WV Rivesville 7
8
WV Willow Island 2
WY Dave Johnston BW41
BW42
WY JimBridger BW71
BW72
BW73
BW74
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
E
X
X
X
X
X
E
E
X
X
X
E
NOx
WY Laramie River
A,10
-------
APPENDIX A: PHASE I AFFECTED (X) AND EARLY ELECTION (E) UNITS IN 1998
ST Plant Name Unit ID SO2 NOx ST Plant Name Unit ID SO2 NOx
2 E
3 E
WY Wyodak BW91 X
-------
APPENDIX B-l:
Table 1 Units Designating Substitution and Compensating Units - 1998
Substitution Units
State
Table 1 Units
Plant Name
Units
Substitution Units
State Plant Name Units
|AL
|FL
|FL
|GA
|GA
|GA
|GA
|GA
|GA
|GA
|GA
|GA
|GA
|GA
|GA
|GA
|IL
|IL
|IL
EC Gaston
Big Bend BB(
Crist
Bo wen
Bo wen
Bo wen
Bo wen
Hammond
Hammond
Hammond
Hammond
Jack Mcdonough
Yates
Yates
Yates
Yates
Baldwin
Hennepin
Meredosia
cl ^^
1\ ^
l\ W
i OT r* 1 ^^
^OT r* 1 ^^
TOT r* 1 ^^
1OT r* I ^^
, i ^^
i | ^^
o I ^^
T I ^^
il ^
4| P^
A fP^ 1 ^^
VTD^l ^^
VTD^l ^fe
^/1T^pl ^^
V^T^D| ^^
/% I ^^
-> \ ^^
0 1 ^^
c | ^^
J I ^^
AL Gadsden
FL Big Bend
FL Crist
FL Scholz
1,2
BB04|
4,5
1,2
GA Harllee Branch
GA Harllee Branch
GA Harllee Branch
GA Harllee Branch
GA Arkwright
GA Arkwright
GA Arkwright
GA Arkwright
GA Mitchell
GA Kraft
GA Kraft
GA Kraft
GA Mclntosh
1
2
31
41
1
21
31
4
31
1
21
31
1
IL Havana
IL Wood River
1,2,3,4,5,6,7,8
1
IL Hennepin
1
IL Hutonsville
IL Newton
5,6
1,2
ITT TT- •!' ^| ^^ 1 TT 'S T ' 1 ' 1
-------
-------
UN
IKY
|MD
|MD
|MI
|MN
|MO
|MO
MO
MO
i eieisuuig i,^ ^^ |iiM 11 i i iiu/iidiu j|
Col
CP
Moi
JH
Hig
Jam
Lab
h.lT^\7 Tor^/"1 r^ i /~"> 1
r, ~ ^
, , .-% ^
^!A /n~~\ r^u^n, n^: ^ o 1
T-» ' C \ ^
Montrose 1 ,2,3 ^
Sioux 1,2
|MO
|MO
IMS
|NH
|NY
|NY
|OH
|OH
ou
Sibl
Tho
Jacl
Mei
Dur
Nor
,-,T r 0 1 ^
CY Jl F
MI J R Whiting 3
MN Sherburne County 1 ,2
T, r^~ . ~t T) ' 1 A
MO Southwest 1
MO Rush Island 1,2
MO Hawthorn 5
KS La Cygne 1
fc-lA/TO QiKlc-Tr 10
*JA xr\ T'U^ ^^ TT:II A /rm 1
h.lA/rc ^T:~+ T r~\^ :^i i
i i ^i i ^
i ;.- 1 o-i 1 ^
NY Roseton 1,2
Ashtabula 7 1 ^
Avc
r1™-,
•• OH Acme .3,14,15,16,91,92
OH Ashtabula 8,9,10,11
OH Lake Shore 18,91,92,93,94
OH Bay Shore 1,2,3,4
hJ/~\TT A,T~ T „!„ H 1A
'11 1 ^
fc-InU T A/T Qtnno^ 1 0 7 /I 1
-------
-------
OH
OH
OH
OH
Edgewater
Niles
R E Burger
W H Sammis
13
1,2
5,6,7,8
5,6,7
^
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
|OH
|OH
|PA
|PA
|PA
|PA
|wi
A K- • T-- j. -rl ^-
T-»' r\ 1 ^-
A j_ 1 1 ^-
A j_ ~\ 1 ^-
A x j.' i r\ i i "i 1 ^-
T-< 1 j_ 1 1 ^fc-
|wi
/-I 1 1 ^^
|wi
XT 1 T^v 1 f\ 1 ^fc-
|wi
|wv
|wv
|wv
|wv
TT ' 1 1 ^fc-
TT ' -> 1 ^fc-
KY East Bend 2
OH Poston 1,2,3|
WV Albright 1
WV Albright 2
PA Mitchell 33 1
PA Martin's Creek 3,4|
WI Edgewater 3|
WI Alma B4, B5
WI JPMadgett Bl
WI Rock River 1,2
WI Pulliam 5,6,7
WI Weston 1,2
MD R P Smith 9
MD RP Smith 11
WV Rivesville 7,8 1
WV Willow Island 2
Compensating Units
State
Table 1 Units
Plant Name Units
Compensating Units
State Plant Name Units
|OH
T-< 1 ± 1 0 1 ^k
MA Brayton Point 2
-------
APPENDIX B-2: 1999 DEDUCTION FOR EXCEEDING 1998 PHASE I EXTENSION
PROJECTED EMISSIONS LIMITATION
State Plant Name
Unit ID
1999 Allowance
Ph I Ext Type Deduction
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
Colbert
Crist
Jack Mcdonough
Wansley
Yates
Yates
Yates
Bailly
Bailly
Cayuga
Cayuga
Gibson
Michigan City
R Gallagher
R Gallagher
R Gallagher
R Gallagher
Wabash River
Wabash River
Wabash River
Wabash River
Coleman
Coleman
Coleman
E W Brown
E W Brown
Ghent
Green River
Hmp&L Station 2
Hmp&L Station 2
Paradise
C P Crane
Chalk Point
Morgantown
Morgantown
B L England
B L England
Cardinal
Conesville
Conesville
Eastlake
Gen J M Gavin
Gen J M Gavin
Muskingum River
Muskingum River
Muskingum River
Muskingum River
Niles
Niles
Picway
R E Burger
R E Burger
R E Burger
R E Burger
Armstrong
Brunner Island
Brunner Island
Conemaugh
Conemaugh
Hatfield's Ferry
Hatfield's Ferry
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
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
0
0
0
0
0
0
0
0
0
0
0
7214
5317
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
918
622
0
0
1197
0
0
0
0
21315
1116
5937
0
3610
6808
6522
5965
11823
10856
0
0
3760
0
0
0
0
0
0
0
0
0
0
0
B-2, 1
-------
APPENDIX B-2: 1999 DEDUCTION FOR EXCEEDING 1998 PHASE I EXTENSION
PROJECTED EMISSIONS LIMITATION
State Plant Name
Unit ID
1999 Allowance
Ph I Ext Type Deduction
PA
PA
PA
PA
PA
TN
TN
TN
TN
TN
TN
WV
WV
WV
WV
WV
WV
WV
WV
Hatfield's Ferry
Portland
Portland
Sunbury
Sunbury
Cumberland
Cumberland
Gallatin
Gallatin
Gallatin
Gallatin
Fort Martin
Fort Martin
Harrison
Harrison
Harrison
Mt Storm
Mt Storm
Mt Storm
3
1
2
3
4
1
2
1
2
3
4
1
2
1
2
3
1
2
3
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
CONTROL
CONTROL
TRANSFER
TRANSFER
CONTROL
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
B-2, 2
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 1998
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
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
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
CS001 (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
Unit Type (a)
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
1997
SO2 Utilization
Emissions (mmBtu)
27,220
50,803
24,949
26,165
36,094
4,716
4,876
82,191
20,303
2,563
4,354
10,243
19,563
1,280
2,112
3,431
37,241
33,675
40,828
42,319
8,609
10,745,711
12,048,491
9,359,699
11,770,490
27,875,666
14,950,877
16,144,807
17,580,910
16,180,310
46,377,835
3,257,292
3,258,590
25,060,591
30,800,835
26,885,523
37,274,636
3,014,961
5,324,877
12,828,682
23,238,171
840,579
1 ,337,456
595,763
884,920
919,471
701,745
49,977,072
45,321,466
54,811,544
57,170,903
3,940,166
3,355,443
1998
SO2 Utilization
Emissions (mmBtu)
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
13,688,471
11,842,057
11,608,467
10,521,841
27,619,312
16,687,420
16,356,089
18,250,153
16,100,133
55,502,484
3,411,299
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
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
-2.08%
-6.29%
3.67%
-1.90%
14.95%
0.74%
-8.47%
10.57%
-18.51%
27.00%
-11.07%
41.18%
48.26%
46.64%
36.22%
24.51%
-8.66%
-16.47%
17.31%
-17.04%
14.32%
27.39%
-1.71%
24.03%
-10.61%
-0.92%
1 1 .61 %
1 .31 %
3.81 %
-0.50%
19.67%
4.73%
0.41%
5.19%
-17.29%
-2.88%
-2.70%
36.28%
-5.94%
45.43%
54.77%
88.43%
80.59%
91.17%
18.46%
32.70%
13.63%
-7.30%
-16.53%
16.68%
-16.84%
2.99%
56.67%
B-3, 1
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 1998
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
IA
IA
IA
IA
IA
IA
IL
IL
IL
IL
IL
Plant Name
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
Coffeen
Coffeen
Stack/Unit ID
3
4
CS001 (1 , 2)
1
2
CS002 (3, 4)
3
4
CS001 (MB1 , MB2)
MB1
MB2
XS123(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
Unit Type (a)
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
1997
SO2 Utilization
Emissions (mmBtu)
16,571
29,845
53,136
28,284
7,267
6,175
3,892
34,105
32,258
130
6,412
8,923
9,393
9,702
6,352
0
4,040
4,839
2,985
2,545
88,439
92,284
95,312
47,756
4,809,927
23,714,698
13,643,892
13,727,469
25,801,742
25,840,817
17,391,180
18,039,198
1 ,485,281
1,775,138
4,273,319
7,719,743
4,404,128
45,956,580
45,215,913
2,562,462
3,568,288
3,782,679
5,505,970
4,525,391
12,553,519
12,915,696
10,287,375
0
9,719,336
10,867,684
8,488,312
6,955,832
34,346,752
35,355,084
37,180,092
13,363,732
1998
SO2 Utilization
Emissions (mmBtu)
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
49,413
4,656,394
18,223,752
13,350,533
16,451,112
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
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
-20.24%
8.37%
6.60%
0.82%
-18.73%
8.76%
18.73%
31 .24%
31 .72%
0.77%
7.06%
2.39%
19.15%
25.23%
-7.95%
0.00%
-1.63%
9.15%
35.18%
-43.61%
-19.27%
0.74%
26.17%
3.47%
-3.19%
-23.15%
-2.15%
19.84%
-4.21 %
8.83%
-7.77%
7.30%
63.65%
10.42%
16.47%
0.92%
4.34%
8.08%
6.49%
37.82%
26.21 %
0.13%
16.27%
-3.99%
1 1 .28%
20.42%
14.15%
0.00%
0.49%
13.12%
19.02%
-9.66%
-20.29%
1.08%
24.42%
-3.86%
B-3, 2
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 1998
State Plant Name
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IN
IN
IN
IN
IN
Coffeen
Grand Tower
Havana
Havana
Havana
Havana
Havana
Havana
Havana
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
Newton
Vermilion
Vermilion
Vermilion
Wood River
Bailly
Bailly
Bailly
Breed
Cayuga
Stack/Unit ID
2
9
1
2
3
4
5
6
7
8
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
2
CSS (1,2)
1
2
1
XS12(7, 8)
7
8
1
1
Unit Type (a)
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Substitution
Table 1
Table 1
Table 1
Table 1
1997
SO2 Utilization
Emissions (mmBtu)
18,586
0
0
0
0
0
0
0
0
47,346
8,640
10,982
7,731
7,998
8,472
41,096
15,950
16,698
13,619
6,208
0
4,736
0
56,992
31,126,083
7,209,130
0
0
0
0
0
0
0
0
6,127,376
14,943,169
3,962,435
4,920,046
15,784,056
13,883,968
14,698,413
15,562,767
16,251,487
15,991,784
18,383,480
22,185,732
10,034,553
8,356,418
30,265,558
1 ,488,706
2,826,121
513,068
12,242,636
19,485,943
0
36,475,622
1998
SO2 Utilization
Emissions (mmBtu)
9,188
0
5
9
39
41
29
24
30
46,809
5,238
5,666
8,280
7,937
7,636
46,417
10,941
7,508
14,298
12,220
1
4,334
0
51 ,345
28,483,817
3,949,534
0
10,635
19,243
83,760
86,786
61 ,257
51 ,653
64,432
3,345,169
15,865,737
2,449,651
2,476,690
16,642,916
16,895,957
16,246,827
15,657,774
16,131,320
14,904,104
18,743,889
30,554,552
8,114,710
30,901,900
31,776,832
3,484,888
5,717,555
475,387
10,663,125
21,683,417
0
36,106,576
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
-50.56%
0.00%
NA
NA
NA
NA
NA
NA
NA
-1.13%
-39.38%
-48.41%
7.10%
-0.76%
-9.87%
12.95%
-31.40%
-55.04%
4.99%
96.84%
NA
-8.49%
0.00%
-9.91 %
-8.49%
-45.21%
0.00%
NA
NA
NA
NA
NA
NA
NA
-45.41%
6.17%
-38.18%
-49.66%
5.44%
21 .69%
10.53%
0.61 %
-0.74%
-6.80%
1 .96%
37.72%
-19.13%
269.80%
4.99%
134.09%
102.31%
-7.34%
-12.90%
1 1 .28%
0.00%
-1.01%
B-3, 3
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 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
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
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
Michigan City
Petersburg
Petersburg
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R Gallagher
Tanners Creek
Wabash River
Wabash River
Wabash River
Stack/Unit ID
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
12
1
2
CS0001 (1 , 2)
1
2
CS0002 (3, 4)
3
4
U4
1
XS2356 (2, 3, 5, 6)
2
Unit Type (a)
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
1997
SO2 Utilization
Emissions (mmBtu)
51,796
44,612
48,844
7,444
6,561
22,717
5,152
8,566
7,989
79,183
49,170
8,909
15,262
2,893
4,162
25,662
21,183
61,344
1,051
37,577
33,321,734
15,465,093
13,905,955
15,588,922
15,077,344
14,905,050
14,827,092
6,831,371
5,794,145
20,926,892
6,571,635
19,032,117
7,431,668
6,728,905
34,509,324
36,456,884
35,455,094
47,452,516
2,270,877
6,791,206
25,071,593
17,617,335
32,198,117
7,671,999
8,015,384
6,067,619
5,817,989
31,794,760
7,893,969
4,391,103
1998
SO2 Utilization
Emissions (mmBtu)
37,593
46,294
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
24,672,500
15,187,611
15,722,352
16,620,156
15,129,975
15,465,474
11,649,523
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
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
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
-27.42%
3.77%
-12.17%
-10.83%
12.67%
14.15%
49.20%
7.82%
17.57%
19.26%
4.11%
-15.68%
9.24%
-22.33%
-0.62%
-10.55%
30.49%
-47.81%
-19.03%
29.28%
-25.96%
-1.79%
13.06%
6.62%
0.35%
3.76%
-21 .43%
-6.70%
16.76%
17.56%
16.65%
31 .20%
17.83%
26.13%
23.22%
9.61 %
-0.61%
2.95%
20.00%
-21 .59%
14.56%
-4.33%
2.02%
-15.47%
0.79%
60.82%
50.06%
-33.65%
29.16%
21 .74%
B-3, 4
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 1998
State
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
KY
MA
MA
MD
MD
MD
MD
Plant Name
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
Shawnee
Brayton Point
Mount Tom
C P Crane
C P Crane
Chalk Point
Chalk Point
Stack/Unit ID
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
10
2
1
1
2
CSE12(1,2)
1
Unit Type (a)
Table 1
Table 1
Table 1
Opt In
Opt In
Opt In
Table 1
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Table 1
Compensating
Substitution
Table 1
Table 1
Table 1
1997
SO2 Utilization
Emissions (mmBtu)
79,037
39,864
6,927
4,052
15,985
18,600
16,037
15,818
5,869
30,538
13,083
7,688
7,399
12,409
15,669
2,142
2,482
173,285
1,004
1,323
2,204
10,646
9,742
12,740
17,050
39,789
3,873,572
4,755,001
17,074,386
11,713,016
12,777,383
12,080,812
22,244,140
43,169,137
7,372,206
10,496,532
12,638,043
11,091,506
6,128,337
11,663,764
5,534,775
10,048,618
20,628,855
50,645,676
11,998,464
20,955,232
38,733,307
5,782,136
23,080,348
11,602,514
12,675,842
72,721,248
15,541,123
18,062,324
8,930,212
18,916,857
11,867,279
9,725,873
13,359,231
17,952,950
1998
SO2 Utilization
Emissions (mmBtu)
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
1,560
9,744
8,417
15,224
13,636
44,721
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
7,598,398
18,403,534
10,400,402
12,220,342
10,972,712
23,306,258
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
-0.09%
-14.51%
-8.78%
-26.33%
-12.99%
-47.97%
-9.16%
1 1 .35%
15.22%
16.16%
-0.15%
-8.81%
-0.04%
16.35%
-4.65%
1 1 .90%
-14.18%
-26.74%
82.07%
61 .45%
-29.22%
-8.47%
-13.60%
19.50%
-20.02%
12.40%
43.92%
41 .65%
7.64%
4.69%
-4.01%
1 .33%
-17.23%
-19.95%
-5.50%
3.25%
-36.75%
1.71%
0.55%
9.87%
9.01 %
5.78%
7.56%
-17.36%
-12.93%
1.13%
2.04%
19.04%
-7.06%
6.24%
-1.64%
-18.24%
23.91 %
-7.84%
-14.91%
-2.71 %
-12.36%
25.65%
-17.86%
29.82%
B-3, 5
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 1998
State
MD
MD
MD
MD
MD
MD
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
MO
MO
MO
MO
Plant Name
Chalk Point
Chalk Point
Morgantown
Morgantown
R P Smith
R P Smith
Dan E Karn
J H Campbell
J H Campbell
J H Campbell
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
New Madrid
New Madrid
Rush Island
Rush Island
Stack/Unit ID
2
3
1
2
9
11
2
CS0009 (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
1
2
1
2
Unit Type (a)
Table 1
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Table 1
Substitution
Substitution
Table 1
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
1997
SO2 Utilization
Emissions (mmBtu)
2,716
39,650
33,341
71
2,264
9,694
21,219
4,801
3,848
9,132
9,236
9,297
1,164
1,780
3,633
12,452
15,063
12,635
13,777
3,147
3,388
3,364
2,705
6,684
8,924
10,474
13,484
11,659
21,531,764
7,631,900
38,101,385
31,834,220
92,709
2,986,412
16,458,054
15,183,312
19,817,269
7,534,265
1,150,622
1,616,997
3,694,447
10,898,522
50,979,544
44,659,663
14,205,505
25,785,864
2,276,282
3,692,173
6,726,246
30,729,514
35,276,040
36,859,037
38,871,905
4,756,769
5,293,610
4,832,568
10,856,432
11,916,991
12,520,698
37,657,244
48,200,332
39,221,199
33,936,175
1998
SO2 Utilization
Emissions (mmBtu)
7,732
34,953
44,953
117
2,262
8,426
22,693
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
8,735
9,018
13,485
13,924
21,586,648
17,351,546
33,077,778
43,364,798
152,062
2,977,734
13,176,629
13,474,893
24,729,551
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
3,737,61 1
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
10,380,984
11,783,069
42,006,552
46,640,504
40,512,757
42,312,616
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
184.68%
-11.85%
34.83%
64.79%
-0.09%
-13.08%
6.95%
-0.96%
5.09%
-1.91%
-11.09%
-23.57%
21 .05%
-4.04%
-22.65%
25.71%
-13.78%
15.57%
4.19%
-46.93%
-54.52%
10.17%
50.54%
32.78%
-2.12%
-13.90%
0.01%
19.43%
0.25%
127.36%
-13.18%
36.22%
64.02%
-0.29%
-19.94%
-11.25%
24.79%
3.35%
35.02%
-4.56%
91 .75%
-1.33%
-14.19%
13.27%
-9.48%
-19.98%
37.13%
1.23%
-11.78%
37.81 %
-2.10%
10.10%
1.66%
4.94%
-9.47%
42.78%
1.45%
-12.89%
-5.89%
1 1 .55%
-3.24%
3.29%
24.68%
B-3, 6
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 1998
State
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MS
MS
MS
MS
MS
NH
NH
NJ
NJ
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
OH
OH
Plant Name
Sibley
Sibley
Sibley
Sibley
Sioux
Sioux
Southwest
Thomas Hill
Thomas Hill
Thomas Hill
Jack Watson
Jack Watson
R D Morrow
R D Morrow
Victor J Daniel Jr
Merrimack
Merrimack
B L England
B L England
Dunkirk
Dunkirk
Dunkirk
Greenidge
Milliken
Milliken
Milliken
Northport
Northport
Northport
Northport
Oswego
Oswego
Oswego
Port Jefferson
Port Jefferson
Roseton
Roseton
Acme
Acme
Stack/Unit ID
CS0001 (1 , 2, 3)
1
2
3
1
2
1
MB1
MB2
MBS
4
5
1
2
1
1
2
1
2
CS0003 (3, 4)
3
4
6
XS12(1,2)
1
2
1
2
3
4
4
5
6
3
4
1
2
13
14
Unit Type (a)
Substitution
Substitution
Table 1
Table 1
Table 1
Substitution
Table 1
Table 1
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
1997
SO2 Utilization
Emissions (mmBtu)
19,839
30,140
24,968
3,785
3,382
4,978
11,224
11,749
30,551
5,072
4,255
11,632
13,509
26,144
15,485
1,787
34,072
8,126
5,620
4,868
2,661
4,279
822
0
0
1,080
1,890
1,602
4,380
7,132
0
0
3,298,131
3,238,192
23,606,317
26,885,257
23,482,964
14,063,350
14,948,531
22,396,264
48,569,132
13,197,197
33,634,910
14,735,176
13,281,477
33,717,920
10,134,559
24,340,602
7,573,153
9,896,490
10,571,064
11,521,991
7,315,437
10,772,403
11,167,395
8,862,375
20,781,446
7,753,803
20,283,682
0
0
5,955,023
10,691,389
7,149,114
9,526,581
16,206,427
0
0
1998
SO2 Utilization
Emissions (mmBtu)
27,056
18,885
23,062
6,837
3,080
4,722
9,916
18,528
32,033
4,267
4,383
8,109
12,126
22,794
15,694
1,084
37,527
9,027
8,572
2,764
4,866
10,502
1,136
0
3,982
1,121
4,185
3,171
10,538
14,192
0
0
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
23,039,448
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
0
8,095,710
5,315,851
9,726,121
11,039,434
19,694,318
26,363,992
0
0
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
36.38%
-37.34%
-7.63%
80.63%
-8.93%
-5.14%
-11.65%
57.70%
4.85%
-15.87%
3.01%
-30.29%
-10.24%
-12.81%
1.35%
-39.34%
10.14%
1 1 .09%
52.53%
-43.22%
82.86%
145.43%
38.20%
0.00%
NA
3.80%
121.43%
97.94%
140.59%
98.99%
0.00%
0.00%
-3.12%
-3.47%
10.46%
-7.70%
30.15%
18.80%
1.20%
5.87%
-2.96%
38.45%
-3.71 %
-2.28%
13.65%
-31 .67%
-5.03%
-1 1 .04%
1.13%
-31 .59%
13.66%
25.90%
16.72%
12.19%
7.54%
36.14%
-16.97%
149.64%
-36.31%
0.00%
NA
-10.73%
-9.03%
54.42%
106.73%
62.68%
0.00%
0.00%
B-3, 7
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 1998
State
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Plant Name
Acme
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
15
16
91
92
7
CS1 (8,9, 10, 11)
8
9
10
11
9
10
11
12
035(1,2,3,4)
1
2
3
4
1
2
03012(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
Substitution
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
1997
SO2 Utilization
Emissions (mmBtu)
0
0
0
0
39,662
6,942
483
4,274
0
28,037
13,874
84,875
58,818
31,975
16,424
83,428
16,379
15,487
16,084
26,322
53,952
0
0
3
16,854
16,812
0
0
23,885
0
0
0
0
12,618,530
0
0
191,965
2,020,623
597,938
4,816,566
0
32,607,684
6,545,978
7,024,540
7,316,921
10,813,196
30,461,782
36,443,680
7,169,706
7,275,241
7,352,729
37,503,728
7,958,930
7,503,532
8,015,486
13,078,361
27,418,308
0
0
190,520
86,726,768
74,801,544
0
0
33,042,560
1998
SO2 Utilization
Emissions (mmBtu)
0
0
0
0
26,164
2,048
0
1,222
0
27,714
11,472
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
0
9,268,567
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
6,311,370
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
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
0.00%
0.00%
0.00%
0.00%
-34.03%
-70.50%
-100.00%
-71.41%
0.00%
-1.15%
-17.31%
12.54%
-43.87%
-5.90%
9.21%
-13.66%
-31.71%
-22.57%
-19.27%
-29.73%
3.82%
0.00%
0.00%
133.33%
-10.50%
1 1 .34%
0.00%
0.00%
13.14%
0.00%
0.00%
0.00%
0.00%
-26.55%
0.00%
0.00%
49.76%
-73.76%
-100.00%
-70.16%
0.00%
1 1 .67%
-1.28%
-3.09%
-0.76%
-14.56%
5.11%
-4.38%
-14.04%
-4.14%
5.56%
-12.61%
-20.70%
-8.68%
0.80%
-19.16%
34.46%
0.00%
0.00%
545.06%
-9.12%
26.52%
0.00%
0.00%
12.85%
B-3, 8
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 1998
State
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
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
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
03056(5-1,5-2,6)
5-1
5-2
6
7
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
Unit Type (a)
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
1997
SO2 Utilization
Emissions (mmBtu)
28,883
25,127
26,949
111,419
497
0
0
0
0
10,087
38,666
161,924
21,872
13,340
16,843
0
0
0
46,842
40,245,244
35,157,140
37,297,652
14,525,068
15,156,232
15,150,482
14,638,612
14,960,636
1,692,121
0
0
0
0
876,111
876,111
7,661,698
36,213,342
12,198,445
9,313,687
11,202,854
11,861,307
37,710,912
7,712,996
3,337,159
5,797,157
0
0
0
0
0
0
0
754,982
648,775
1998
SO2 Utilization
Emissions (mmBtu)
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
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
0
0
0
1 ,373,320
1 ,374,643
13,624,571
29,030,836
9,969,079
10,138,733
11,271,723
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
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
2.21 %
-7.63%
-12.42%
6.96%
264.39%
0.00%
0.00%
0.00%
0.00%
94.45%
-5.67%
-5.93%
-30.02%
62.19%
-20.53%
0.00%
0.00%
0.00%
-17.72%
1 .52%
-8.35%
-10.67%
-1.31%
-0.67%
-2.87%
10.31%
-3.78%
114.39%
0.00%
0.00%
0.00%
0.00%
56.75%
56.90%
77.83%
-19.83%
-18.28%
8.86%
0.61 %
-8.13%
-25.82%
-1.14%
65.83%
-17.15%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
-100.00%
-96.47%
B-3, 9
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 1998
State
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
PA
PA
Plant Name
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
Shawville
Shawville
Stack/Unit ID
7
8
10
11
9
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
CS1 (3, 4)
3
Unit Type (a)
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
1997
SO2 Utilization
Emissions (mmBtu)
0
0
0
16,619
33,154
30,208
14,542
33,099
16,282
16,847
6,555
7,123
44,391
52,349
47,510
3,754
3,502
138,630
23,661
2,082
1,938
1,080
0
0
11,574
17,463
15,230
15,609
33,064
10,903,432
10,116,964
0
0
0
20,677,232
38,089,788
34,854,765
12,225,260
27,984,274
10,871,651
11,549,498
50,690,148
43,678,116
16,560,069
21,563,393
45,583,894
37,412,616
66,299,762
61,034,531
24,642,421
29,327,176
35,212,528
9,668,016
9,896,340
6,918,551
5,638,557
16,667,369
0
0
7,648,014
11,972,331
9,672,852
9,861,149
10,382,892
1998
SO2 Utilization
Emissions (mmBtu)
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
33,535
10,366,887
9,213,604
0
0
0
19,236,457
29,506,312
44,358,048
15,957,426
29,796,457
11,997,280
11,802,474
52,609,590
42,620,088
17,977,978
21,591,769
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
11,288,576
10,631,226
16,084,774
0
0
8,564,817
10,950,567
8,432,824
8,234,692
12,435,105
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
0.00%
0.00%
0.00%
1.16%
-38.61%
51.71%
39.80%
19.20%
1 1 .95%
4.81 %
14.83%
-5.03%
8.18%
-8.92%
-32.27%
3.20%
24.13%
8.83%
-33.08%
127.76%
124.30%
-2.78%
0.00%
0.00%
-15.57%
-30.56%
-15.54%
-20.78%
1 .42%
-4.92%
-8.93%
0.00%
0.00%
0.00%
-6.97%
-22.53%
27.27%
30.53%
6.48%
10.35%
2.19%
3.79%
-2.42%
8.56%
0.13%
-15.17%
-31 .98%
-2.44%
18.28%
36.09%
-0.73%
-16.54%
-32.90%
-39.15%
63.16%
88.55%
-3.50%
0.00%
0.00%
1 1 .99%
-8.53%
-12.82%
-16.49%
19.77%
B-3, 10
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 1998
State Plant Name
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
Wl
Wl
Wl
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
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Alma
Alma
Alma
Alma
Alma
Alma
Edgewater
Edgewater
Genoa
J P Madgett
Stack/Unit ID
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
5
6
7
8
9
10
CS1 (B1 , B2, B3, B4, B5)
B1
B2
B3
B4
B5
3
4
1
B1
Unit Type (a)
Table 1
Table 1
Table 1
Tablel
Tablel
Tablel
Table 1
Table 1
Opt In
Opt In
Opt In
Opt In
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Opt In
Opt In
Opt In
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
1997
SO2 Utilization
Emissions (mmBtu)
11,343
11,326
6,754
7,134
7,436
9,846
11,122
0
0
0
0
50,974
66,129
115,938
5,608
1,620
7,968
12,750
4,946
12,363,361
8,209,041
8,102,198
14,847,074
16,492,487
17,656,804
1 1 1 ,236,832
118,698,432
0
0
0
0
14,146,293
13,928,512
17,014,207
18,173,564
6,385,030
8,774,006
8,605,129
8,448,481
7,847,835
6,274,393
8,278,704
9,340,449
9,054,961
6,274,673
NA
NA
NA
2,637,034
3,645,037
4,010,042
19,448,932
23,336,894
21,777,568
1998
SO2 Utilization
Emissions (mmBtu)
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
6,517
1,973
8,391
9,031
5,223
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
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
5,011,080
20,197,100
16,559,515
25,231,992
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
-9.13%
5.69%
-16.03%
3.42%
-3.68%
7.76%
-11.07%
0.00%
0.00%
0.00%
0.00%
-20.23%
-31.12%
-1.16%
16.21%
21 .79%
5.31 %
-29.17%
5.60%
-0.60%
1.81%
16.08%
-10.32%
8.42%
3.34%
-16.01%
-34.75%
0.00%
0.00%
0.00%
0.00%
17.88%
-4.09%
5.83%
-20.17%
31 .43%
-26.44%
-34.03%
-7.60%
-13.28%
17.47%
-5.15%
-9.46%
7.54%
28.29%
NA
NA
NA
18.39%
18.46%
24.96%
3.85%
-29.04%
15.86%
B-3,11
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 1998
State
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
wv
wv
wv
wv
wv
Plant Name
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
Kammer
Mitchell
Mitchell
Mitchell
Mt Storm
Stack/Unit ID
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
3
03012(1,2)
1
2
030(1,2)
Unit Type (a)
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Tablel
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
1997
SO2 Utilization
Emissions (mmBtu)
6,092
0
0
0
0
2,141
1,540
2,264
1,560
1,776
15,452
25,934
1,318
1,678
1,578
1,682
9,380
42,733
44,413
6,298
126,273
57,239
92,716
8,239,503
8,457,749
0
0
0
0
3,268,887
5,354,200
6,492,200
9,850,126
4,227,957
4,871,904
15,182,914
9,504,521
22,009,580
19,063,307
4,399,791
5,695,054
1 ,269,279
1 ,333,070
7,411,488
36,022,017
37,187,816
48,646,367
48,426,987
45,939,810
13,727,107
15,078,749
17,379,095
40,025,964
50,581,435
1998
SO2 Utilization
Emissions (mmBtu)
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
59,330
106,759
6,172,813
7,216,679
0
0
0
0
3,766,998
5,003,476
7,422,81 1
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
46,082,925
51,433,080
55,241,467
13,479,546
12,639,201
13,391,834
44,346,849
48,141,367
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
78.28%
0.00%
0.00%
0.00%
0.00%
-12.00%
1 .88%
0.84%
-1.79%
6.87%
8.60%
2.29%
-15.71%
14.54%
39.54%
14.68%
-22.94%
-2.56%
-15.20%
10.10%
-13.98%
3.65%
15.15%
-25.08%
-14.67%
0.00%
0.00%
0.00%
0.00%
15.24%
-6.55%
14.33%
13.83%
-3.42%
1 .75%
-33.23%
69.52%
-7.89%
-3.88%
-10.07%
19.93%
45.23%
21 .78%
-17.98%
-3.60%
-18.19%
-5.27%
6.21 %
20.25%
-1.80%
-16.18%
-22.94%
10.80%
-4.82%
B-3, 12
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1997 AND 1998
State
wv
wv
wv
wv
wv
wv
Plant Name
Mt Storm
Mt Storm
Mt Storm
Rivesville
Rivesville
Willow Island
Stack/Unit ID
1
2
3
7
8
2
Unit Type (a)
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
1997
SO2 Utilization
Emissions (mmBtu)
4,052
235
1,234
8,067
35,476,403
36,446,948
45,013,972
299,093
1,531,972
8,554,928
1998
SO2 Utilization
Emissions (mmBtu)
4,576
624
1,995
7,870
41,523,871
39,716,905
47,191,480
819,610
2,531,623
8,015,622
Percent Change, 1997-1998
SO2 Utilization
Emissions (mmBtu)
12.93%
165.53%
61 .67%
-2.44%
17.05%
8.97%
4.84%
174.03%
65.25%
-6.30%
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, 13
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
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
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
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
CS001 (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
Unit Type (a)
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
SO2
Emissions
1997 (b)
27,220
50,803
24,949
26,165
36,094
4,716
4,876
82,191
20,303
2,563
4,354
10,243
19,563
1,280
2,112
3,431
37,241
33,675
40,828
42,319
8,609
SO2
Emissions
1998(b)
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
1998
Allowances
Allocated (c)
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
8,977
Held in
Unit Accounts
as of 3/1/99
21 ,577
28,046
28,275
28,493
48,561
14,332
14,082
15,002
14,000
45,632
5,226
4,909
49,712
47,169
15,759
7,797
30,887
27,505
38,097
64,922
27,026
26,429
4,016
3,622
7,030
5,461
123,284
85,123
116,493
116,905
14,228
15,084
Allowances Deducted Under Allowances
Deducted for Special Phase I Carried Over
Emissions (d) Provisions (e) to 1999
7,679
6,719
6,460
5,795
47,608
13,062
12,802
13,638
12,031
41 ,489
4,751
4,463
46,712
44,169
12,173
4,371
3,255
3,872
14,461
29,005
1,877
2,877
1,068
1,068
1,068
1,068
34,016
28,130
47,897
35,108
3,281
3,281
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
13,898
21 ,327
21,815
22,698
953
1,270
1,280
1,364
1,969
4,143
475
446
3,000
3,000
3,586
3,426
27,632
23,633
23,636
35,917
25,149
23,552
2,948
2,554
5,962
4,393
89,268
56,993
68,596
81 ,797
10,947
1 1 ,803
B-4, 1
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
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
IA
IA
IA
IA
IA
IA
IL
IL
IL
IL
IL
Plant Name
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
Coffeen
Coffeen
Stack/Unit ID
3
4
CS001 (1 , 2)
1
2
CS002 (3, 4)
3
4
MB1
CS001 (MB1 , MB2)
MB2
XS123(1,2, 3)
1
2
3
1
3
1
2
Y1BR
Y2BR
CS001 (Y2BR, Y3BR)
Y3BR
Y4BR
CS002 (Y4BR, Y5BR)
Y5BR
Y6BR
Y7BR
1
11
1
2
4
9
1
2
3
CS0001 (1 , 2)
1
Unit Type (a)
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
SO2
Emissions
1997 (b)
16,571
29,845
53,136
28,284
7,267
6,175
3,892
34,105
32,258
130
6,412
8,923
9,393
9,702
6,352
0
4,040
4,839
2,985
2,545
88,439
92,284
95,312
47,756
SO2
Emissions
1998(b)
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
49,413
1998
Allowances
Allocated (c)
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
12,925
Held in
Unit Accounts
as of 3/1/99
14,483
81 ,025
34,938
48,995
51 ,834
50,880
44,016
46,032
5,125
4,794
7,304
1 1 ,232
28,484
109,452
100,342
23,227
17,359
17,095
21 ,566
23,025
62,931
53,043
19,736
0
9,598
35,269
20,558
8,882
74,791
97,625
127,677
15,570
Allowances Deducted Under Allowances
Deducted for Special Phase I Carried Over
Emissions (d) Provisions (e) to 1999
3,280
13,217
16,171
16,171
28,322
28,321
14,258
14,258
1,532
1,236
3,138
6,716
4,621
44,760
42,489
131
3,433
3,432
4,568
4,568
11,192
12,150
5,847
0
3,974
5,282
4,035
1,435
71 ,396
92,968
120,253
15,473
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
1 1 ,203
67,808
18,767
32,824
23,512
22,559
29,758
31 ,774
3,593
3,558
4,166
4,516
23,863
64,692
57,853
23,096
13,926
13,663
16,998
18,457
51 ,739
40,893
13,889
0
5,624
29,987
16,523
7,447
3,395
4,657
7,424
97
B-4, 2
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IN
IN
IN
IN
IN
Plant Name
Coffeen
Grand Tower
Havana
Havana
Havana
Havana
Havana
Havana
Havana
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
Newton
Vermilion
Vermilion
Vermilion
Wood River
Bailly
Bailly
Bailly
Breed
Cayuga
Stack/Unit ID
2
9
1
2
3
4
5
6
7
8
CS3(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
2
CS3(1, 2)
1
2
1
XS12(7, 8)
7
8
1
1
Unit Type (a)
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Substitution
Table 1
Table 1
Table 1
Table 1
SO2
Emissions
1997 (b)
18,586
0
0
0
0
0
0
0
0
47,346
8,640
10,982
7,731
7,998
8,472
41,096
15,950
16,698
13,619
6,208
0
4,736
0
56,992
SO2
Emissions
1998(b)
9,188
0
5
9
39
41
29
24
30
46,809
5,238
5,666
8,280
7,937
7,636
46,417
10,941
7,508
14,298
12,220
1
4,334
0
51 ,345
1998
Allowances
Allocated (c)
39,102
6,479
34
43
34
34
34
34
34
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
6,346
12,972
9,735
0
15,826
21 ,590
20,280
36,581
Held in
Unit Accounts
as of 3/1/99
34,070
9,245
11
63
61
61
61
61
61
61
7,847
47,246
5,442
5,917
36,840
29,751
35,908
32,363
29,835
26,723
25,556
24,527
11,105
7,629
14,422
6,659
8,340
12
7,687
21 ,946
30,362
62,163
Allowances Deducted Under Allowances
Deducted for Special Phase I Carried Over
Emissions (d) Provisions (e) to 1999
33,940
9,188
0
5
9
39
41
29
24
30
6,101
40,708
5,238
5,666
4,140
4,140
3,969
3,968
3,818
3,818
23,208
23,209
10,941
7,508
14,298
4,631
7,589
1
1,417
2,917
0
51 ,345
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
130
57
11
58
52
22
20
32
37
31
1,746
6,538
204
251
32,700
25,611
31 ,939
28,395
26,017
22,905
2,348
1,318
164
121
124
2,028
751
11
6,270
19,029
30,362
10,818
B-4, 3
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
Plant Name
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
Michigan City
Petersburg
Petersburg
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R Gallagher
Tanners Creek
Wabash River
Wabash River
Wabash River
Stack/Unit ID
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
12
1
2
CS0001 (1 , 2)
1
2
CS0002 (3, 4)
3
4
U4
1
XS2356 (2, 3, 5, 6)
2
Unit Type (a)
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
SO2
Emissions
1997 (b)
51,796
44,612
48,844
7,444
6,561
22,717
5,152
8,566
7,989
79,183
49,170
8,909
15,262
2,893
4,162
25,662
21,183
61,344
1,051
37,577
SO2
Emissions
1998(b)
37,593
46,294
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
1998
Allowances
Allocated (c)
37,415
19,620
19,289
19,873
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
Held in
Unit Accounts
as of 3/1/99
57,450
22,036
17,908
18,492
18,414
16,400
29,074
6,900
7,756
26,723
8,331
19,603
14,363
12,015
60,782
57,182
59,533
90,808
2,699
5,463
78,549
2,384
4,368
12,378
15,442
17,676
15,800
116,844
7,716
10,380
Allowances Deducted Under Allowances
Deducted for Special Phase I Carried Over
Emissions (d) Provisions (e) to 1999
37,593
15,432
15,431
15,431
14,299
14,300
14,300
6,638
7,392
25,931
7,687
0
9,236
9,393
48,712
45,719
50,854
335
2,479
5,033
16,672
2,247
4,136
10,208
12,746
14,599
13,043
32,017
851
7,324
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
19,857
6,604
2,477
3,061
4,115
2,100
14,774
262
364
792
644
19,603
5,127
2,622
12,070
1 1 ,463
8,679
90,473
220
430
61 ,877
137
232
2,170
2,696
3,077
2,757
84,827
6,865
3,056
B-4, 4
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
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
KY
MA
MA
MD
MD
MD
MD
Plant Name
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
Shawnee
Brayton Point
Mount Tom
C P Crane
C P Crane
Chalk Point
Chalk Point
Stack/Unit ID
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
10
2
1
1
2
CSE12(1,2)
1
Unit Type (a)
Table 1
Table 1
Table 1
Opt In
Opt In
Opt In
Table 1
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Table 1
Compensating
Substitution
Table 1
Table 1
Table 1
SO2
Emissions
1997 (b)
79,037
39,864
6,927
4,052
15,985
18,600
16,037
15,818
5,869
30,538
13,083
7,688
7,399
12,409
15,669
2,142
2,482
173,285
1,004
1,323
2,204
10,646
9,742
12,740
17,050
39,789
SO2
Emissions
1998(b)
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
1,560
9,744
8,417
15,224
13,636
44,721
1998
Allowances
Allocated (c)
4,111
4,023
13,462
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
17,920
17,085
57,613
5,041
5,827
9,902
15,838
10,708
10,058
8,987
21 ,333
Held in
Unit Accounts
as of 3/1/99
12,615
11,132
38,820
26,927
28,645
26,880
36,643
12,025
6,694
15,386
1 1 ,672
16,120
12,233
25,592
22,811
34,716
86,062
17,643
2,204
5,007
110,586
21 ,803
46,364
9,804
7,808
216,485
9,195
10,674
18,052
29,975
14,921
64,309
17,202
27,900
Allowances
Deducted for
Emissions (d)
7,600
9,187
24,469
26,689
26,233
26,042
34,078
6,319
2,985
13,908
9,677
14,568
5,812
11,801
6,762
11,701
23,772
13,064
2,103
4,908
7,396
14,438
14,941
2,397
2,130
126,946
1,828
2,136
1,560
9,744
8,417
15,224
13,636
23,068
Deducted Under
Special Phase I
Provisions (e)
0
0
0
0
543
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
1,636
0
0
0
Allowances
Carried Over
to 1999
5,015
1,945
14,351
238
1,869
838
2,565
5,706
3,709
1,478
1,995
1,552
6,421
13,791
16,049
23,015
62,290
4,579
101
99
103,190
7,365
31 ,423
7,407
5,678
89,539
7,367
8,538
16,492
20,231
4,868
49,085
3,566
4,832
B-4, 5
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
MD
MD
MD
MD
MD
MD
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
MO
MO
MO
MO
Plant Name
Chalk Point
Chalk Point
Morgantown
Morgantown
R P Smith
R P Smith
Dan E Karn
J H Campbell
J H Campbell
J H Campbell
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
New Madrid
New Madrid
Rush Island
Rush Island
Stack/Unit ID
2
3
1
2
9
11
2
CS0009 (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
1
2
1
2
Unit Type (a)
Table 1
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Table 1
Substitution
Substitution
Table 1
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
SO2
Emissions
1997 (b)
2,716
39,650
33,341
71
2,264
9,694
21,219
4,801
3,848
9,132
9,236
9,297
1,164
1,780
3,633
12,452
15,063
12,635
13,777
3,147
3,388
3,364
2,705
6,684
8,924
10,474
13,484
11,659
SO2
Emissions
1998(b)
7,732
34,953
44,953
117
2,262
8,426
22,693
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
8,735
9,018
13,485
13,924
1998
Allowances
Allocated (c)
23,690
9,000
34,332
37,467
386
3,128
10,984
18,773
22,453
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
27,497
31 ,625
26,935
30,146
Held in
Unit Accounts
as of 3/1/99
28,253
19,000
45,499
56,019
673
4,408
1 1 ,276
8,804
16,158
5,673
3,349
1,946
2,891
10,788
15,649
16,242
37,704
7,461
3,910
5,144
3,488
16,711
14,237
15,801
15,392
2,871
2,873
5,516
4,276
4,362
4,974
13,202
33,276
14,684
15,026
Allowances
Deducted for
Emissions (d)
21 ,653
7,732
34,953
44,953
117
2,262
8,426
8,004
14,689
4,755
251
251
1,279
2,263
4,216
4,742
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
4,153
4,722
8,735
9,018
13,485
13,924
Deducted Under
Special Phase I
Provisions (e)
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
65
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Allowances
Carried Over
to 1999
6,600
1 1 ,268
10,546
1 1 ,066
556
2,146
2,850
800
1,469
918
3,098
1,695
1,612
8,525
1 1 ,433
1 1 ,500
29,427
355
2,501
3,436
678
1,057
1,250
1,199
1,038
1,201
1,332
1,810
204
209
252
4,467
24,258
1,199
1,102
B-4, 6
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MS
MS
MS
MS
MS
NH
NH
NJ
NJ
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
OH
OH
Plant Name
Sibley
Sibley
Sibley
Sibley
Sioux
Sioux
Southwest
Thomas Hill
Thomas Hill
Thomas Hill
Jack Watson
Jack Watson
R D Morrow
R D Morrow
Victor J Daniel Jr
Merrimack
Merrimack
B L England
B L England
Dunkirk
Dunkirk
Dunkirk
Greenidge
Milliken
Milliken
Milliken
Northport
Northport
Northport
Northport
Oswego
Oswego
Oswego
Port Jefferson
Port Jefferson
Roseton
Roseton
Acme
Acme
Stack/Unit ID
CS0001 (1 , 2, 3)
1
2
3
1
2
1
MB1
MB2
MBS
4
5
1
2
1
1
2
1
2
CS0003 (3, 4)
3
4
6
XS12(1,2)
1
2
1
2
3
4
4
5
6
3
4
1
2
13
14
Unit Type (a)
Substitution
Substitution
Table 1
Table 1
Table 1
Substitution
Table 1
Table 1
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
SO2
Emissions
1997 (b)
19,839
30,140
24,968
3,785
3,382
4,978
11,224
11,749
30,551
5,072
4,255
11,632
13,509
26,144
15,485
1,787
34,072
8,126
5,620
4,868
2,661
4,279
822
0
0
1,080
1,890
1,602
4,380
7,132
0
0
SO2
Emissions
1998(b)
27,056
18,885
23,062
6,837
3,080
4,722
9,916
18,528
32,033
4,267
4,383
8,109
12,126
22,794
15,694
1,084
37,527
9,027
8,572
2,764
4,866
10,502
1,136
0
3,982
1,121
4,185
3,171
10,538
14,192
0
0
1998
Allowances
Allocated (c)
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
9,427
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
371
12,365
4,499
10,194
12,006
19,147
16,872
0
12
Held in
Unit Accounts
as of 3/1/99
5,521
7,700
22,127
20,106
24,083
7,161
1 1 ,078
28,282
16,798
25,577
44,344
5,087
7,152
10,937
12,457
23,047
18,159
2,254
34,855
18,292
17,274
73,288
26,732
29,053
18,693
24,616
14,797
1,492
36,993
12,773
14,406
18,011
19,147
16,872
0
0
Allowances
Deducted for
Emissions (d)
2,705
2,706
21 ,645
18,885
23,062
6,837
3,080
4,722
9,916
18,528
32,033
4,267
4,383
8,109
12,126
22,794
15,694
1,084
20,640
16,887
9,027
4,073
4,499
2,764
4,866
10,502
1,136
0
3,982
1,121
4,185
3,171
10,538
14,192
0
0
Deducted Under
Special Phase I
Provisions (e)
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
119
0
0
0
0
0
0
0
0
0
Allowances
Carried Over
to 1999
2,816
4,994
482
1,221
1,021
324
7,998
23,560
6,882
7,049
12,311
820
2,769
2,828
331
253
2,465
1,170
14,215
1,405
8,247
69,215
22,233
26,289
13,827
14,114
13,542
1,492
33,011
1 1 ,652
10,221
14,840
8,609
2,680
0
0
B-4, 7
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Plant Name
Acme
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
15
16
91
92
7
CS1 (8,9, 10, 11)
8
9
10
11
9
10
11
12
035(1,2,3,4)
1
2
3
4
1
2
03012(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
Substitution
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
SO2
Emissions
1997 (b)
0
0
0
0
39,662
6,942
483
4,274
0
28,037
13,874
84,875
58,818
31,975
16,424
83,428
16,379
15,487
16,084
26,322
53,952
0
0
3
16,854
16,812
0
0
23,885
SO2
Emissions
1998(b)
0
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
56,011
0
0
7
15,085
18,718
0
0
27,024
1998
Allowances
Allocated (c)
16
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
Held in
Unit Accounts
as of 3/1/99
0
0
0
0
28,835
0
7,016
812
1,745
64
1,527
0
40,913
7,629
7,248
7,876
12,986
100,301
52,486
14,778
16,816
18,834
73,920
13,392
14,120
14,599
21 ,962
67,970
0
645
33
15,839
19,653
2,503
2,791
42,720
Allowances Deducted Under Allowances
Deducted for Special Phase I Carried Over
Emissions (d) Provisions (e) to 1999
0
0
0
0
26,164
0
0
637
1,411
0
1,222
0
27,714
2,490
2,627
2,799
3,556
95,520
33,017
14,074
16,015
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
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
2,671
0
7,016
175
334
64
305
0
13,199
5,139
4,621
5,077
9,430
4,781
19,469
704
801
897
1,885
2,206
2,128
1,614
3,465
1 1 ,959
0
645
26
754
935
2,503
2,791
15,696
B-4, 8
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
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
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
6
7
03056(5-1,5-2,6)
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
Unit Type (a)
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
SO2
Emissions
1997 (b)
28,883
25,127
26,949
111,419
497
0
0
0
0
38,666
10,087
161,924
21,872
13,340
16,843
0
0
0
46,842
SO2
Emissions
1998(b)
29,520
23,211
23,603
119,171
1,811
0
0
0
0
36,473
19,614
152,316
15,307
21 ,636
13,385
0
0
0
38,543
1998
Allowances
Allocated (c)
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
3,371
Held in
Unit Accounts
as of 3/1/99
38,961
37,597
38,323
24,335
24,335
24,335
24,335
24,335
3,709
0
0
0
0
24,491
50,633
2,513
2,513
37,786
38,320
42,607
41,219
114,045
9,801
16,325
14,221
0
0
0
0
0
1
2,956
4,389
2,854
Allowances Deducted Under Allowances
Deducted for Special Phase I Carried Over
Emissions (d) Provisions (e) to 1999
29,520
23,21 1
23,603
23,835
23,834
23,834
23,834
23,834
1,811
0
0
0
0
16,306
36,473
1,654
1,654
35,987
36,495
40,578
39,256
15,307
6,878
14,758
13,385
0
0
0
0
0
0
0
0
39
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
9,441
14,386
14,720
500
501
501
501
501
1,898
0
0
0
0
8,185
14,160
859
859
1,799
1,825
2,029
1,963
98,738
2,923
1,567
836
0
0
0
0
0
1
2,956
4,389
2,815
B-4, 9
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
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
PA
PA
Plant Name
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
Shawville
Shawville
Stack/Unit ID
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
CS1 (3, 4)
3
Unit Type (a)
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
SO2
Emissions
1997 (b)
0
0
0
16,619
33,154
30,208
14,542
33,099
16,282
16,847
6,555
7,123
44,391
52,349
47,510
3,754
3,502
138,630
23,661
2,082
1,938
1,080
0
0
11,574
17,463
15,230
15,609
33,064
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
33,535
1998
Allowances
Allocated (c)
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
82,006
90,904
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
13,846
Held in
Unit Accounts
as of 3/1/99
22,782
20,697
5,315
9,505
274
31 ,377
48,619
87,696
30,526
48,925
32,747
33,350
20,720
22,827
53,949
57,671
115,628
43,171
14,930
15,136
55,009
47,719
48,140
36,073
34,780
33,135
29,690
2,322
1,367
1,520
51 ,498
14,405
14,698
13,823
17,695
Allowances Deducted Under Allowances
Deducted for Special Phase I Carried Over
Emissions (d) Provisions (e) to 1999
20,389
18,115
0
0
0
16,812
20,352
45,828
20,329
39,455
18,227
17,658
7,527
6,765
21,817
26,203
47,679
32,177
3,874
4,347
55,009
47,719
48,140
8,211
7,623
4,742
4,347
1,050
0
0
9,772
12,126
12,864
12,365
16,855
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
2,393
2,582
5,315
9,505
274
14,565
28,267
41 ,868
10,197
9,470
14,520
15,692
13,193
16,062
32,132
31 ,468
67,949
10,994
1 1 ,056
10,789
0
0
0
27,862
27,157
28,393
25,343
1,272
1,367
1,520
41 ,726
2,279
1,834
1,458
840
B-4, 10
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
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
Wl
Wl
Wl
Plant Name
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
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Alma
Alma
Alma
Alma
Alma
Alma
Edgewater
Edgewater
Genoa
J P Madgett
Stack/Unit ID
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
5
6
7
8
9
10
CS1 (B1 , B2, B3, B4, B5)
B1
B2
B3
B4
B5
3
4
1
B1
Unit Type (a)
Table 1
Table 1
Table 1
Tablel
Tablel
Tablel
Table 1
Table 1
Opt In
Opt In
Opt In
Opt In
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Opt In
Opt In
Opt In
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
SO2
Emissions
1997 (b)
11,343
11,326
6,754
7,134
7,436
9,846
11,122
0
0
0
0
50,974
66,129
115,938
5,608
1,620
7,968
12,750
4,946
SO2
Emissions
1998(b)
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
6,517
1,973
8,391
9,031
5,223
1998
Allowances
Allocated (c)
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
4,493
24,099
22,103
6,407
Held in
Unit Accounts
as of 3/1/99
17,430
22,698
24,147
25,192
27,605
29,340
215,879
218,813
0
0
0
0
22,769
19,398
25,693
24,089
17,267
13,527
13,891
15,471
10,386
1 1 ,248
1 1 ,955
12,916
14,890
12,493
537
518
455
8,702
17,637
13,704
25,802
31 ,624
1 1 ,701
Allowances Deducted Under Allowances
Deducted for Special Phase I Carried Over
Emissions (d) Provisions (e) to 1999
16,680
10,307
1 1 ,970
5,671
7,378
7,162
10,610
9,891
0
0
0
0
22,320
18,344
25,188
20,363
12,567
9,679
8,448
1 1 ,680
10,179
1 1 ,024
11,718
12,659
14,594
12,040
466
424
397
2,195
3,035
1,973
8,391
9,031
5,223
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
750
12,391
12,177
19,521
20,227
22,178
205,269
208,922
0
0
0
0
449
1,054
505
3,726
4,700
3,848
5,443
3,791
207
224
237
257
296
453
71
94
58
6,507
14,602
1 1 ,731
17,411
22,593
6,478
B-4, 11
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
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
wv
wv
wv
wv
wv
wv
Plant Name
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
Kammer
Mitchell
Mitchell
Mitchell
Mt Storm
Mt Storm
Stack/Unit ID
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
3
03012(1,2)
1
2
030(1,2)
1
Unit Type (a)
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Table 1
Substitution
Substitution
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Tablel
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
SO2
Emissions
1997 (b)
6,092
0
0
0
0
2,141
1,540
2,264
1,560
1,776
15,452
25,934
1,318
1,678
1,578
1,682
9,380
42,733
44,413
6,298
126,273
57,239
92,716
SO2
Emissions
1998(b)
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
59,330
106,759
1998
Allowances
Allocated (c)
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
16,932
42,823
44,312
42,570
Held in
Unit Accounts
as of 3/1/99
1 1 ,590
13,779
0
0
0
0
970
1,290
1,900
2,700
17,058
1 1 ,537
7,128
1 1 ,331
15,327
13,854
1,300
2,300
5,836
4,970
20,618
64,608
85,160
4,149
4,197
4,317
38,749
36,653
38,646
29,811
32,485
114,600
Allowances Deducted Under Allowances
Deducted for Special Phase I Carried Over
Emissions (d) Provisions (e) to 1999
5,195
5,666
0
0
0
0
810
1,074
1,569
2,283
1,532
1,898
6,480
10,301
13,934
12,595
1,111
1,922
2,202
1,929
7,228
41,641
37,663
2,177
2,403
2,354
36,904
34,908
36,806
28,392
30,938
53,380
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
6,395
8,113
0
0
0
0
160
216
331
417
15,526
9,639
648
1,030
1,393
1,259
189
378
3,634
3,041
13,390
22,967
47,497
1,972
1,794
1,963
1,845
1,745
1,840
1,419
1,547
61 ,220
B-4, 12
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
WV
wv
WV
wv
wv
Plant Name
Mt Storm
Mt Storm
Rivesville
Rivesville
Willow Island
Stack/Unit ID
2
3
7
8
2
Unit Type (a)
Table 1
Table 1
Substitution
Substitution
Substitution
SO2
Emissions
1997 (b)
4,052
235
1,234
8,067
SO2
Emissions
1998(b)
4,576
624
1,995
7,870
1998
Allowances
Allocated (c)
34,644
56,589
1,009
3,059
7,765
Held in
Unit Accounts
as of 3/1/99
96,588
59,130
1,690
4,635
17,190
Allowances
Deducted for
Emissions (d)
53,379
4,576
624
1,995
7,870
Deducted Under
Special Phase I
Provisions (e)
0
0
0
0
0
Allowances
Carried Over
to 1999
43,209
54,554
1,066
2,640
9,320
NOTES:
(a) Identifies the affected unit as listed in Table 1, or as a substitution, compensating, or opt-in unit.
(b) Both 1997 and 1998 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 1998 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-l: List of Averaging Plans and Results in 1998
Company
Allegheny Power System
Ameren Services
Ameren Services
Cinergy Corp.
Dairyland Power
Cooperative
ORIS
Code
Plant Name, State and
Units
3942
3178
3944
3943
3181
6004
157O
Albright WV 1-3
Armstrong PA 1 , 2
Harrison WV 1-3
Fort Martin WV 1
Mitchell PA 33
Pleasants PA 1 , 2
R P Smith PA 9, 11
862
863
864
6017
Grand Tower IL O7-O9
Hutsonville IL O5, O6
Meredosia IL O1-O5
Newton IL 1, 2
21O3
2104
6155
Labadie MO 1-4
Meramec MO 1-4
Rush Island MO 1, 2
1OO1
6018
6113
2832
1OO8
1010
2830
Cayuga IN 1, 2
East Bend 2
Gibson IN 1-4
Miami Fort OH 6
R Gallagher IN 1-4
Wabash River IN 2, 3, 5, 6
Walter C Beckjord 5, 6
41 4O
4143
4271
Alma Wl B4, B5
Genoa Wl 1
J P Madqett Wl B1
Plant
Limit
C-l, 1
-------
Appendix C-l: List of Averaging Plans and Results in 1998
Company
East Kentucky Power
Cooperative
FirstEnergy
GPU Generation, Inc.
Hoosier Energy Rec., Inc.
Illinois Power Company
Indianapolis Power & Light
LG&E Energy Corporation
ORIS Plant Name, State and
Code Units
1384 Cooper KY 1 , 2
6O94 Bruce Mansfield PA 1 , 2
2857 Edgewater OH 13
2858 Gorge OH 25, 26
3138 New Castle PA 1 , 2
2867 Toronto OH 1 O, 1 1
2864 R E Burger OH 7, 8
2866 W H Sammis OH 5, 6
3113 Portland PA 1 , 2
Frank E Ratts IN 1SG1,
1043 2SG1
889 Baldwin IL 3
892 Hennepin IL 2
897 Vermilion IL 1, 2
99O Elmer W Stout IN 5O, 6O, 7O
991 H T Pritchard IN 3-6
994 Petersburg IN 1-4
1355 E W Brown KY 1-3
1356 Ghent KY 1
1 357 Green River KY 5
Plant
Limit
O.5O
O.5O
0.45
O.5O
0.45
O.45
O.46
Plan
Rate
O.42
O.46
0.31
O.49
0.40
O.37
O.42
C-l, 2
-------
Appendix C-l: List of Averaging Plans and Results in 1998
Company
NGE Generation, Inc.
Northern States Power
Company
PP&L
South Mississippi Elec.
Power Assoc.
Southern Company
Southern Company
ORIS Plant Name, State and
Code Units
2527 Greenidge NY 6
2535 Milliken NY 1 , 2
1912 High Bridge MN 3-6
6O9O Sherburne County MN 1 , 2
314O Brunner Island PA 1-3
3148 Martins Creek PA 1, 2
3152 SunburyPAS, 4
6O61 R D Morrow MS 1 , 2
26 EC Gaston AL 1 -5
7 Gadsden AL 1-2
699 Arkwright GA 1-4
703 Bowen GA 1 BLR - 4BLR
7O8 Hammond GA 1-4
7O9 Harllee Branch GA 2
71 O Jack McDonough GA MB1 ,
MB2
733 Kraft GA 1 -3
6124 Mclntosh GA 1
727 Mitchell GA 3
6257 Scherer GA 3
6052 Wansley GA 1, 2
728 Yates GAY1BR -Y7BR
Plant
Limit
O.45
O.46
0.46
0.50
O.48
0.46
Plan
Rate
O.34
O.34
0.39
0.47
O.46
0.44
C-l, 3
-------
Appendix C-l: List of Averaging Plans and Results in 1998
Company
ORIS Plant Name, State and
Code Units
Plant
Limit
Southern Company
Springfield (MO), City
Utilities of
641
2O49
642
6O73
Crist FL 4-7
Jack Watson MS 4, 5
Scholz FL1, 2
Victor J Daniel Jr MS 1 , 2
2161
6195
James River MO 3-5
Southwest MO 1
TVA
Wisconsin Electric Power
Company
Wisconsin Power & Light
Company
47
3403
34O6
Colbert AL 1-5
Gallatin TN 1-4
Johnsonville TN 1-1O
4O4O
4041
4042
Port Washington Wl 1-4
South Oak Creek Wl 5-8
Valley Wl 1-4
1 1O4
1073
Burlington IA 1
Prairie Creek IA 4
Wisconsin Public Service
Corp.
4O72
4O78
Pulliam Wl 7, 8
Weston Wl 1 -3
C-l, 4
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1998
1998
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
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
Hammond
Harllee Branch
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
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
708
709
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
4
2
Compliance Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
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
0.50
0.50
Actual
Emission
Rate
0.45
0.45
0.45
0.45
0.38
0.43
0.43
0.45
0.45
0.47
0.64
0.64
0.40
0.43
0.55
0.46
0.49
0.70
0.71
0.72
0.72
0.72
0.72
0.42
0.44
0.42
0.43
0.83
0.83
0.83
0.44
0.71
AELor
Avg. Plan
Limit
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.46
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
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.45
0.45
0.45
0.45
0.45
0.45
0.44
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
1.20
0.99
Change
from 1990
to 1998
-44%
-33%
-46%
-48%
-51%
-52%
-45%
-44%
-44%
-40%
25%
14%
-14%
0%
12%
-56%
-58%
2%
-11%
-20%
-20%
-20%
-20%
-37%
-32%
-25%
-26%
-1%
-1%
-1%
-63%
-28%
C-2, 1
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1998
1998
ST
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
IL
IL
IL
IL
Plant Name
Jack McDonough
Jack McDonough
Kraft
Kraft
Kraft
Mcintosh
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
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Operating Utility
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
Illinois Power Co
CIPSCO
CIPSCO
CIPSCO
Illinois Power Co
CIPSCO
CIPSCO
Electric Energy Inc
Electric Energy Inc
Electric Energy Inc
Electric Energy Inc
ORIS
Code
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
887
887
887
887
Boiler
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
1
2
3
4
Compliance Approach
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
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
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Emission
Limit
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
0.45
0.45
0.45
0.45
Actual
Emission
Rate
0.41
0.41
0.62
0.62
0.62
0.95
0.56
0.29
0.39
0.40
0.47
0.50
0.50
0.39
0.39
0.33
0.32
0.23
0.36
0.33
0.36
0.35
0.70
0.72
0.56
0.54
0.53
0.49
0.20
0.20
0.20
0.20
AELor
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
0.47
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
0.28
0.28
0.40
0.36
0.36
0.36
0.40
0.36
0.36
1990
Emission
Rate
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
0.56
0.56
0.56
0.56
Change
from 1990
to 1998
-38%
-32%
56%
56%
56%
14%
-8%
44%
-47%
-40%
-16%
-19%
-19%
-30%
-40%
-51%
-48%
-63%
-55%
-69%
-56%
-48%
-10%
-25%
-13%
-8%
-24%
-27%
-64%
-64%
-64%
-64%
C-2, 2
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1998
1998
ST
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
Plant Name
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
H T Pritchard
H T Pritchard
Petersburg
Petersburg
Petersburg
Petersburg
Operating Utility
Electric Energy Inc
Electric Energy Inc
CIPSCO
CIPSCO
CIPSCO
CIPSCO
CIPSCO
CIPSCO
CIPSCO
Illinois Power Co
Illinois Power Co
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
Indianapolis Power & Light
Indianapolis Power & Light
Indianapolis Power & Light
Indianapolis Power & Light
Indianapolis Power & Light
Indianapolis Power & Light
ORIS
Code
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
991
991
994
994
994
994
Boiler
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
5
6
1
2
3
4
Compliance Approach
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
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
0.50
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
0.45
0.45
Actual
Emission
Rate
0.20
0.20
0.47
0.47
0.47
0.47
0.52
0.21
0.36
0.44
0.44
0.32
0.33
0.35
0.38
0.34
0.46
0.46
0.49
0.49
0.50
0.50
0.41
0.42
0.71
0.71
0.40
0.40
0.30
0.36
0.39
0.33
AELor
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
0.45
0.45
0.45
0.45
0.45
0.45
Actual
Avg. Plan
Rate
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.40
0.40
0.43
0.43
0.37
0.37
0.34
0.49
0.49
0.43
0.43
0.43
0.43
0.37
0.37
0.37
0.37
0.37
0.37
0.37
0.37
1990
Emission
Rate
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
0.67
0.47
0.56
0.63
0.37
0.37
Change
from 1990
to 1998
-64%
-64%
-7%
-7%
-7%
-7%
-22%
-55%
-8%
-53%
-41%
-24%
-30%
-44%
-42%
-52%
-56%
-63%
-55%
-55%
-51%
-55%
-21%
-36%
-4%
-4%
-40%
-15%
-46%
-43%
5%
-11%
C-2, 3
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1998
1998
ST
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
MD
MD
MD
MD
Plant Name
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
HMP&L Station 2
HMP&L Station 2
R D Green
R D Green
Chalk Point
Chalk Point
Morgantown
Morgantown
Operating Utility
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
Big Rivers Electric
Big Rivers Electric
Big Rivers Electric
Big Rivers Electric
Pepco
Pepco
Pepco
Pepco
ORIS
Code
1008
1008
1008
1008
1010
1010
1010
1010
1010
1241
1295
1381
1381
1381
1384
1384
1355
1355
1355
6018
1374
1356
1357
6041
1382
1382
6639
6639
1571
1571
1573
1573
Boiler
1
2
3
4
1
2
3
5
6
2
2
Cl
C2
C3
1
2
1
2
3
2
2
1
5
1
HI
H2
Gl
G2
1
2
1
2
Compliance Approach
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
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
AEL Demonstration
AEL Demonstration
AEL Demonstration
AEL Demonstration
Emission
Limit
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
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
Actual
Emission
Rate
0.46
0.46
0.43
0.43
0.14
0.50
0.55
0.53
0.33
0.31
0.33
0.45
0.43
0.47
0.42
0.42
0.52
0.42
0.42
0.36
0.42
0.40
0.40
0.42
0.48
0.48
0.42
0.44
0.66
0.70
0.61
0.62
AEL or
Avg. Plan
Limit
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
0.86
1.20
0.70
0.70
Actual
Avg. Plan
Rate
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.42
0.42
0.42
0.42
0.42
0.43
0.42
0.42
1990
Emission
Rate
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
1.34
1.34
0.41
0.45
1.35
1.35
0.95
0.95
Change
from 1990
to 1998
-38%
-52%
-55%
-55%
-73%
-47%
-40%
-38%
-12%
7%
-48%
-68%
-67%
-59%
-53%
-53%
-48%
-29%
-26%
16%
-51%
-29%
-52%
-53%
-64%
-64%
2%
-2%
-51%
-48%
-36%
-35%
C-2, 4
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1998
1998
ST
MD
MD
MI
MN
MN
MN
MN
MN
MN
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MS
MS
MS
Plant Name
R P Smith
R P Smith
J H Campbell
High Bridge
High Bridge
High Bridge
High Bridge
Sherbume County
Sherbume County
Hawthorn
latan
James River
James River
James River
Labadie
Labadie
Labadie
Labadie
Meramec
Meramec
Meramec
Meramec
Montrose
Montrose
Montrose
Rush Island
Rush Island
Southwest
Thomas Hill
Jack Watson
Jack Watson
R D Morrow
Operating Utility
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
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 El Pwr
ORIS
Code
1570
1570
1710
1912
1912
1912
1912
6090
6090
2079
6065
2161
2161
2161
2103
2103
2103
2103
2104
2104
2104
2104
2080
2080
2080
6155
6155
6195
2168
2049
2049
6061
Boiler
9
11
1
3
4
5
6
1
2
5
1
3
4
5
1
2
3
4
1
2
3
4
1
2
3
1
2
1
MB3
4
5
1
Compliance Approach
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
Standard Limitation
Standard Limitation
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Standard Limitation
Averaging Plan
Averaging Plan
Averaging Plan
Emission
Limit
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
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.50
0.50
Actual
Emission
Rate
0.51
0.44
0.48
0.60
0.60
0.60
0.60
0.28
0.28
0.38
0.30
0.64
0.66
0.63
0.18
0.23
0.17
0.20
0.61
0.47
0.67
0.34
0.35
0.39
0.39
0.17
0.18
0.35
0.31
0.48
0.68
0.42
AEL or
Avg. Plan
Limit
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
0.45
0.45
0.50
0.48
0.48
0.50
Actual
Avg. Plan
Rate
0.44
0.44
0.34
0.34
0.34
0.34
0.34
0.34
0.48
0.48
0.48
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.22
0.48
0.45
0.45
0.47
1990
Emission
Rate
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
0.32
0.34
0.34
0.63
0.63
0.47
0.31
1.10
1.22
0.42
Change
from 1990
to 1998
-41%
-44%
-30%
26%
26%
26%
26%
-38%
-38%
6%
-3%
-37%
-24%
-32%
-71%
-63%
-73%
-68%
-26%
-25%
-30%
-71%
8%
14%
14%
-73%
-71%
-26%
0%
-56%
-44%
0%
C-2, 5
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1998
1998
ST
MS
MS
MS
NY
NY
NY
NY
NY
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
PA
PA
PA
PA
Plant Name
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
R E Burger
R E Burger
Toronto
Toronto
W H Sammis
W H Sammis
Walter C Beckjord
Walter C Beckjord
Armstrong
Armstrong
Bruce Mansfield
Bruce Mansfield
Operating Utility
South Mississippi El Pwr
Mississippi Power Co
Mississippi Power Co
Niagara Mohawk Power Corp
Niagara Mohawk Power Corp
NYSEG
NYSEG
NYSEG
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
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
Ohio Edison Co
Ohio Edison Co
ORIS
Code
6061
6073
6073
2554
2554
2527
2535
2535
2835
2840
2840
2837
2837
2837
2837
2857
2858
2858
2832
2843
2864
2864
2867
2867
2866
2866
2830
2830
3178
3178
6094
6094
Boiler
2
1
2
3
4
6
1
2
7
3
4
1
2
3
4
13
25
26
6
9
7
8
10
11
5
6
5
6
1
2
1
2
Compliance Approach
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
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
Averaging Plan
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
0.50
0.45
0.45
0.45
0.45
0.45
0.50
0.50
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
0.50
0.50
0.52
0.27
0.21
0.33
0.33
0.38
0.32
0.32
0.39
0.44
0.42
0.40
0.39
0.40
0.37
0.22
Not Oper.
Not Oper.
0.56
0.36
0.69
0.71
Not Oper.
Not Oper.
0.51
0.49
0.47
0.43
0.37
0.36
0.41
0.39
0.50
0.48
0.48
0.45
0.45
0.45
0.50
0.50
0.50
0.48
0.50
0.50
0.50
0.50
0.50
0.50
0.48
0.48
0.49
0.49
0.50
0.50
Actual
Avg. Plan
Rate
0.47
0.45
0.45
0.34
0.34
0.34
0.46
0.46
0.46
0.43
0.46
0.46
0.46
0.46
0.46
0.46
0.43
0.43
0.44
0.44
0.46
0.46
1990
Emission
Rate
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
0.66
0.72
0.00
0.00
0.52
1.10
0.72
0.71
0.90
1.04
0.98
1.13
Change
from 1990
to 1998
21%
2%
-26%
-32%
-32%
-31%
-52%
-46%
-36%
-53%
-24%
-18%
-43%
-26%
-27%
-75%
-23%
-58%
5%
-2%
-3%
-55%
-35%
-39%
-59%
-65%
-58%
-65%
C-2, 6
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1998
1998
ST
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
Plant Name
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
Sunbury
Gallatin
Gallatin
Gallatin
Gallatin
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Operating Utility
PP&L
PP&L
PP&L
Duquesne Light Co
GPU
GPU
PP&L
PP&L
West Perm Power Co
Ohio Edison Co
Ohio Edison Co
GPU
GPU
GPU
GPU
GPU
GPU
PP&L
PP&L
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
TVA
ORIS
Code
3140
3140
3140
8226
3118
3118
3148
3148
3181
3138
3138
3113
3113
3131
3131
3131
3131
3152
3152
3403
3403
3403
3403
3406
3406
3406
3406
3406
3406
3406
3406
3406
Boiler
1
2
3
1
1
2
1
2
33
1
2
1
2
1
2
3
4
3
4
1
2
3
4
1
2
3
4
5
6
7
8
9
Compliance Approach
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
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
Actual AEL or
Emission Emission Avg. Plan
Limit Rate Limit
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
0.50
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
0.41
0.41
0.34
0.37
0.36
0.34
0.44
0.44
0.39
Not Oper.
Not Oper.
0.28
0.34
0.47
0.47
0.42
0.42
0.42
0.43
0.36
0.36
0.37
0.37
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.46
0.46
0.46
0.46
0.46
0.49
0.50
0.50
0.45
0.45
0.46
0.46
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
Actual
Avg. Plan
Rate
0.39
0.39
0.39
0.39
0.39
0.44
0.46
0.46
0.31
0.31
0.39
0.39
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
1990
Emission
Rate
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
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
Change
from 1990
to 1998
-37%
-42%
-59%
-48%
-44%
-52%
-57%
-53%
-43%
-39%
-48%
-53%
-54%
-49%
-48%
-55%
-67%
-39%
-43%
-37%
-33%
4%
-2%
2%
-13%
4%
-6%
-53%
-52%
-57%
C-2, 7
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1998
1998
ST
TN
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
WI
wv
wv
wv
wv
wv
wv
wv
wv
wv
Plant Name
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
Valley
Valley
Valley
Valley
Weston
Weston
Weston
Albright
Albright
Albright
Fort Martin
Harrison
Harrison
Harrison
Mitchell
Mitchell
Operating Utility
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
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
ORIS
Code
3406
4140
4140
4143
4271
4040
4040
4040
4040
4040
4072
4072
4041
4041
4041
4041
4042
4042
4042
4042
4078
4078
4078
3942
3942
3942
3943
3944
3944
3944
3948
3948
Boiler
10
B4
B5
1
Bl
1
2
3
4
5
7
8
5
6
7
8
1
2
3
4
1
2
3
1
2
3
1
1
2
3
1
2
Compliance Approach
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
Averaging Plan
Averaging Plan
Averaging Plan
AEL Demonstration
AEL Demonstration
Actual AEL or
Emission Emission Avg. Plan
Limit Rate Limit
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
0.50
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
0.47
0.71
0.71
0.41
0.39
0.31
0.31
0.31
0.30
Not Oper.
0.36
0.36
0.29
0.29
0.38
0.38
0.43
0.43
0.51
0.51
0.86
0.85
0.20
0.62
0.68
0.39
0.57
0.46
0.46
0.46
0.55
0.55
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.49
0.49
0.49
0.49
0.49
0.49
0.49
0.56
0.56
Actual
Avg. Plan
Rate
0.42
0.45
0.45
0.45
0.45
0.36
0.36
0.36
0.36
0.37
0.37
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.37
0.37
0.37
0.44
0.44
0.44
0.44
0.44
0.44
0.44
1990
Emission
Rate
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
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
Change
from 1990
to 1998
-56%
-16%
-16%
-45%
31%
-3%
-3%
-3%
-19%
-48%
-37%
5%
5%
-43%
-43%
-61%
-61%
-51%
-45%
-4%
-21%
-22%
-44%
-38%
-45%
-8%
-54%
-59%
-57%
-28%
-28%
C-2, 8
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1998
1998
ST
WV
WV
WV
WV
WV
WY
WY
WY
WY
Plant Name
Mt Storm
Mt Storm
Mt Storm
Pleasants
Pleasants
Jim Bridger
Jim Bridger
Jim Bridger
Wyodak
Operating Utility
Vepco
Vepco
Vepco
Monongahela Power Co
Monongahela Power Co
Pacificorp
Pacificorp
Pacificorp
Pacificorp
ORIS
Code
3954
3954
3954
6004
6004
8066
8066
8066
6101
Boiler
1
2
3
1
2
BW71
BW72
BW73
BW91
Compliance Approach
AEL Demonstration
AEL Demonstration
AEL Demonstration
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Emission
Limit
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.45
0.50
Actual
Emission
Rate
0.69
0.64
0.72
0.39
0.34
0.40
0.38
0.38
0.31
AEL or
Avg. Plan
Limit
0.76
0.69
0.74
0.49
0.49
Actual
Avg. Plan
Rate
0.45
0.45
1990
Emission
Rate
0.88
0.76
1.27
0.52
0.35
0.63
0.51
0.42
0.37
Change
from 1990
to 1998
-22%
-16%
-43%
-25%
-3%
-37%
-26%
-10%
-16%
C-2, 9
-------
Appendix C-3:Compliance Results for the 275 Early Election Units in 1998
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
CT
FL
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
Bridgeport Harbor
C D Mclntosh Jr
Operating Utility
Alabama Electric Coop
Alabama Electric Coop
Southwestern Electric Power
Arkansas Power & Light Co
Arkansas Power & Light Co
Arkansas Power & Light Co
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
Colorado Springs Utilities
Public Service Co of CO
United Illuminating Co
City of Lakeland
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
568
676
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
BHB3
3
NSPS1
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
Da
D
Da
D
D
Emission Actual 1998
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
0.45
0.50
0.49
0.49
0.31
0.26
0.24
0.39
0.37
0.46
0.41
0.42
0.33
0.36
0.27
0.42
0.43
0.39
0.37
0.40
0.38
0.38
0.40
0.33
0.26
0.28
0.31
0.38
0.36
0.21
0.35
0.39
0.31
0.26
0.46
1990
Emission Rate
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
0.56
0.46
Change from
1990 to 1998
-21%
-26%
1%
-24%
-31%
34%
10%
-21%
-29%
-9%
-21%
1%
-28%
-18%
-16%
-5%
-11%
8%
12%
14%
-45%
-35%
10%
-10%
-21%
-5%
28%
-66%
-19%
-28%
82%
-54%
-1%
1 New Source Performance Standard subpart
C-3, 1
-------
Appendix C-3:Compliance Results for the 275 Early Election Units in 1998
ST
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
IN
IN
IN
IN
Plant Name
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
A B Brown
Dean H Mitchell
Dean H Mitchell
Dean H Mitchell
Operating Utility
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.
Commonwealth Edison Co
Commonwealth Edison Co
City of Springfield, IL
Commonwealth Edison Co
Commonwealth Edison Co
Commonwealth Edison Co
Commonwealth Edison Co
Commonwealth Edison Co
Southern Indiana Gas & Elec
Southern Indiana Gas & Elec
Northern Indiana Pub Serv
Northern Indiana Pub Serv
Northern Indiana Pub Serv
ORIS
Code
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
6137
996
996
996
Boiler
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
2
4
5
6
NSPS1
D
D
D
Da
Da
Da
Da
D
D
D
D
D
D
D
D
D
D
Da
Emission Actual 1998
Limit Emission Rate
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
0.50
0.45
0.45
0.45
0.44
0.49
0.48
0.48
0.46
0.43
0.49
0.48
0.35
0.38
0.43
0.47
0.38
0.43
0.45
0.47
0.39
0.42
0.26
0.33
0.31
0.38
0.39
0.33
0.28
0.40
0.40
0.33
0.42
0.45
0.33
0.33
0.32
1990
Emission Rate
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
0.39
0.43
0.43
0.58
Change from
1990 to 1998
17%
-3%
2%
-10%
7%
20%
-3%
-19%
68%
-36%
-21%
-17%
14%
15%
-57%
20%
-39%
-15%
2%
-52%
-7%
-21%
-29%
-15%
8%
-1%
4%
8%
-31%
14%
-24%
-24%
-45%
1 New Source Performance Standard subpart
C-3,2
-------
Appendix C-3:Compliance Results for the 275 Early Election Units in 1998
ST
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
KY
LA
LA
LA
LA
LA
LA
MI
Plant Name
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
D B Wilson
Dale
Dale
H L Spurlock
Mill Creek
Mill Creek
Mill Creek
Mill Creek
Trimble County
Big Cajun 2
Big Cajun 2
Big Cajun 2
Dolet Hills
R S Nelson
Rodemacher
B C Cobb
Operating Utility
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
Commonwealth Edison Co
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
Big Rivers 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
Cajun Electric Power
Central Louisiana Elec Co
Gulf States Utilities
Central Louisiana Elec Co
Consumers Energy Co
ORIS
Code
996
6213
6213
6085
6085
6085
6166
6166
981
1040
1040
6064
1239
1239
1363
1363
1363
6823
1385
1385
6041
1364
1364
1364
1364
6071
6055
6055
6055
51
1393
6190
1695
Boiler
11
1SG1
2SG1
15
17
18
MB1
MB2
3
1
2
Nl
39
40
4
5
6
Wl
3
4
2
1
2
3
4
1
2B1
2B2
2B3
1
6
2
4
NSPS1
D
D
D
Da
Da
D
D
D
Da
D
D
D
D
D
D
D
D
D
D
Emission Actual 1998
Limit Emission Rate
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
0.50
0.45
0.45
0.45
0.50
0.50
0.45
0.50
0.50
0.50
0.50
0.45
0.50
0.45
0.32
0.39
0.39
0.23
0.35
0.32
0.36
0.36
0.21
0.42
0.42
0.45
0.41
0.42
0.41
0.48
0.40
0.50
0.41
0.41
0.41
0.45
0.40
0.49
0.49
0.41
0.31
0.30
0.26
0.41
0.40
0.43
0.40
1990
Emission Rate
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
0.56
0.73
0.73
0.47
0.76
0.79
0.62
0.57
0.62
0.28
0.25
0.24
0.62
0.20
0.38
0.38
Change from
1990 to 1998
-45%
70%
-38%
-45%
-24%
-27%
13%
13%
-35%
-41%
-41%
-2%
-50%
-24%
-51%
-58%
-61%
-11%
-44%
-44%
-13%
-41%
-49%
-21%
-14%
-34%
10%
20%
7%
-34%
102%
13%
4%
1 New Source Performance Standard subpart
C-3, 3
-------
Appendix C-3:Compliance Results for the 275 Early Election Units in 1998
ST
MI
MI
MI
MI
MI
MI
MI
MI
MI
MN
MN
MO
MI-
MI
MI-
MI
MI
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
Plant Name
B C Cobb
J B Sims
J C Weadock
J C Weadock
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
Cliffside
Dan River
Dan River
Dan River
G G Allen
G G Allen
G G Allen
Operating Utility
Consumers Energy Co
City of Grand Haven
Consumers Energy Co
Consumers Energy Co
Consumers Energy Co
Consumers Energy Co
Upper Peninsula Power Co
Upper Peninsula Power Co
Upper Peninsula Power Co
Minnesota Power & Light Co
Otter Tail Power Co
Sikeston Board of Mun Util
Montana Power Company
Montana Power Company
Montana Power Company
Montana Power Company
Montana-Dakota Utilities Co
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
ORIS
Code
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
2721
2723
2723
2723
2718
2718
2718
Boiler
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
5
1
2
3
1
2
3
Emission Actual 1998 1990 Change from
NSPS1 Limit Emission Rate Emission Rate 1990 to 1998
0.45
Da 0.50
0.45
0.45
0.50
0.50
D 0.50
D 0.50
D 0.50
0.45
0.45
D 0.50
D 0.45
D 0.45
Da 0.45
Da 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
0.40
0.36
0.36
0.38
0.38
0.44
0.44
0.46
0.36
0.38
0.24
0.39
0.43
0.43
0.43
0.35
0.41
0.43
0.45
0.43
0.44
0.41
0.44
0.40
0.43
0.44
0.42
0.42
0.44
0.44
0.42
0.44
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.
0.51
0.52
0.55
0.56
0.65
0.61
0.64
9%
-21%
-19%
-19%
-54%
-63%
-10%
-16%
-30%
-14%
-34%
-53%
-7%
0%
27%
24%
-38%
-30%
-21%
-21%
-4%
-13%
-13%
-18%
-23%
-22%
-32%
-31%
-31%
1 New Source Performance Standard subpart
C-3,4
-------
Appendix C-3:Compliance Results for the 275 Early Election Units in 1998
ST
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
ND
ND
ND
ND
NE
NE
NE
NE
NE
NE
NM
NV
NV
NV
NV
NV
NY
NY
NY
NY
NY
NY
NY
Plant Name
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
North Valmy
Reid Gardner
C R Huntley
C R Huntley
Dunkirk
Dunkirk
Kintigh
S A Carlson
S A Carlson
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
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
Sierra Pacific Power Co
Nevada Power Company
Niagara Mohawk Power Corp
Niagara Mohawk Power Corp
Niagara Mohawk Power Corp
Niagara Mohawk Power Corp
NYSEG
City of Jamestown
City of Jamestown
ORIS
Code
2718
2718
2727
2727
2727
2727
2732
2732
2732
2732
6469
6469
2817
2824
6077
6077
60
6096
2291
59
87
2341
2341
8224
8224
2324
2549
2549
2554
2554
6082
2682
2682
Boiler
4
5
1
2
3
4
7
8
9
10
Bl
B2
1
10
1
2
1
1
4
1
1
1
2
1
2
4
67
68
1
2
1
9
10
Emission Actual 1998
NSPS1 Limit Emission Rate
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
Da 0.50
Da 0.50
0.45
0.45
0.45
0.45
Da 0.50
0.50
0.50
0.42
0.42
0.43
0.45
0.44
0.42
0.42
0.38
0.40
0.38
0.39
0.30
0.25
0.38
0.45
0.32
0.24
0.46
0.31
0.39
0.39
0.41
0.40
0.39
0.37
0.28
0.31
0.31
0.34
0.35
0.41
0.43
0.46
1990 Change from
Emission Rate 1990 to 1998
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
0.40
0.38
0.64
0.64
0.48
0.48
0.62
0.90
1.05
-38%
-38%
-11%
-26%
-15%
-40%
-28%
-41%
-8%
10%
-66%
-19%
13%
-8%
-21%
-4%
-18%
-18%
12%
7%
-13%
-24%
-8%
-25%
-52%
-52%
-29%
-27%
-34%
-52%
-56%
1 New Source Performance Standard subpart
C-3, 5
-------
Appendix C-3:Compliance Results for the 275 Early Election Units in 1998
ST
NY
NY
OH
OH
OH
OK
OK
OK
OK
OK
OK
OK
OR
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
SC
SC
SC
Plant Name
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
Montour
Montour
New Castle
New Castle
New Castle
Titus
Titus
Titus
Cross
Cross
WSLee
Operating Utility
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
Public Service Co of OK
Public Service Co of OK
Oklahoma Gas & Electric Co
Oklahoma Gas & Electric Co
Portland General Electric
Ohio Edison Co
Peco Energy Company
Peco Energy Company
Peco Energy Company
GPU
GPU
GPU
GPU
GPU
PP&L
PP&L
Ohio Edison Co
Ohio Edison Co
Ohio Edison Co
GPU
GPU
GPU
South Carolina Pub Serv
South Carolina Pub Serv
Duke Energy Corporation
ORIS
Code
2682
2682
2840
2840
6019
2952
2952
2952
2963
2963
6095
6095
6106
6094
3159
3161
3161
3122
3122
3122
3136
3136
3149
3149
3138
3138
3138
3115
3115
3115
130
130
3264
Boiler
11
12
5
6
1
4
5
6
3313
3314
1
2
1SG
3
1
1
2
1
2
3
1
2
1
2
3
4
5
1
2
3
1
2
1
NSPS1
D
D
Da
D
D
D
D
D
D
D
D
D
D
Da
Da
Emission Actual 1998
Limit Emission Rate
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
0.45
0.45
0.50
0.50
0.50
0.45
0.45
0.45
0.50
0.45
0.45
0.46
0.43
0.41
0.41
0.44
0.37
0.35
0.38
0.35
0.35
0.36
0.36
0.40
0.42
0.43
0.32
0.30
0.45
0.43
0.43
0.36
0.37
0.44
0.40
0.39
0.36
0.44
0.39
0.40
0.38
0.32
0.39
0.43
1990 Change from
Emission Rate 1990 to 1998
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
0.95
0.46
0.63
0.57
0.73
0.73
0.68
0.77
Not Oper.
0.46
0.64
-44%
-52%
-6%
-6%
-15%
-15%
-13%
-34%
-34%
8%
-14%
0%
-26%
-28%
-24%
-40%
-59%
-59%
-31%
-55%
-53%
-53%
-13%
-38%
-37%
-40%
-46%
-41%
-51%
-16%
-32%
1 New Source Performance Standard subpart
C-3,6
-------
Appendix C-3:Compliance Results for the 275 Early Election Units in 1998
ST
SC
SC
TN
TN
TN
TN
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
Plant Name
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
Martin Lake
Monticello
Monticello
Monticello
Oklaunion
Pirkey
Sam Seymour
Sam Seymour
Sam Seymour
San Miguel
Sandow
Tolk Station
Tolk Station
Operating Utility
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
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
ORIS
Code
3264
3264
3405
3405
3405
3405
3497
3497
6178
6136
6193
6193
6193
7097
6181
6181
298
298
6146
6146
6146
6147
6147
6147
127
7902
6179
6179
6179
6183
6648
6194
6194
Boiler
2
3
1
2
3
4
1
2
1
1
061B
062B
063B
**1
1
2
LIM1
LIM2
1
2
3
1
2
3
1
1
1
2
3
SM-1
4
171B
172B
NSPS1
D
D
D
D
D
Da
D
D
Da
Da
D
D
D
D
Da
D
D
D
Da
D
D
D
D
Emission Actual 1998 1990 Change from
Limit Emission Rate Emission Rate 1990 to 1998
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.45
0.45
0.45
0.50
0.45
0.45
0.45
0.44
0.44
0.41
0.41
0.42
0.42
0.34
0.35
0.28
0.34
0.36
0.29
0.26
0.38
0.32
0.32
0.41
0.41
0.34
0.32
0.35
0.29
0.32
0.23
0.46
0.36
0.34
0.33
0.30
0.40
0.35
0.33
0.29
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
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
-28%
-13%
-34%
-34%
-34%
-34%
-14%
2%
-27%
-28%
36%
-19%
-27%
5%
5%
-18%
-15%
-4%
-7%
-17%
-5%
-20%
11%
-14%
5%
0%
13%
22%
-2%
-19%
-14%
22%
1 New Source Performance Standard subpart
C-3,7
-------
Appendix C-3:Compliance Results for the 275 Early Election Units in 1998
ST
TX
TX
TX
TX
TX
TX
TX
UT
UT
UT
UT
UT
UT
UT
UT
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
VA
WA
WA
WI
Plant Name
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
Chesterfield
Chesterfield
Glen Lyn
Glen Lyn
Possum Point
Potomac River
Potomac River
Potomac River
Potomac River
Potomac River
Yorktown
Yorktown
Centralia
Centralia
Blount Street
Operating Utility
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
VEPCO
VEPCO
Appalachian Power Co
Appalachian Power Co
VEPCO
PEPCO
PEPCO
PEPCO
PEPCO
PEPCO
VEPCO
VEPCO
Pacificorp
Pacificorp
Madison Gas & Electric Co
ORIS
Code
3470
3470
3470
3470
6139
6139
6139
7790
3644
3644
6165
6165
8069
6481
6481
3803
3803
3803
3797
3797
3776
3776
3804
3788
3788
3788
3788
3788
3809
3809
3845
3845
3992
Boiler
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
8
NSPS1
D
D
D
Da
D
D
D
Da
D
D
D
Da
Da
Emission Actual 1998
Limit Emission Rate
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
0.45
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
0.33
0.32
0.41
0.37
0.33
0.34
0.36
0.36
0.40
0.42
0.40
0.41
0.40
0.42
0.40
0.44
0.44
0.45
0.42
0.42
0.40
0.36
0.44
0.42
0.39
0.43
0.40
0.44
0.44
0.44
0.39
0.43
0.38
1990 Change from
Emission Rate 1990 to 1998
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
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
-30%
-39%
17%
18%
24%
-5%
-2%
-15%
-20%
-27%
-19%
-25%
-23%
-7%
6%
4%
-9%
-17%
-19%
-14%
-13%
-27%
-18%
-11%
-33%
-13%
-39%
-23%
-23%
-3%
-5%
-46%
1 New Source Performance Standard subpart
C-3, 8
-------
Appendix C-3:Compliance Results for the 275 Early Election Units in 1998
ST Plant Name
Operating Utility
ORIS
Code
Boiler
NSPS1
Emission Actual 1998 1990 Change from
Limit Emission Rate Emission Rate 1990 to 1998
WI Blount Street
WI Columbia
WI Columbia
WI Edgewater
WV Mountaineer (1301)
WY Dave Johnston
WY Dave Johnston
WY Jim Bridger
WY Laramie River
WY Laramie River
WY Laramie River
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
3992
8023
8023
4050
6264
4158
4158
8066
6204
6204
6204
9
1
2
5
1
BW41
BW42
BW74
1
2
3
D
D
D
D
D
D
D
0.50
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.50
0.50
0.50
0.40
0.40
0.37
0.23
0.50
0.39
0.40
0.39
0.25
0.26
0.27
0.61
0.46
0.49
0.21
0.47
0.48
0.54
0.41
0.35
0.32
0.42
-35%
-13%
-24%
10%
6%
-19%
-26%
-4%
-28%
-19%
-36%
1 New Source Performance Standard subpart
C-3, 9
------- |