United States
Environmental Protection
Agency
Office of Air and Radiation EPA-430-R-98-012
Acid Rain Division (6204J) August 1998
EPA 1997 Compliance Report
Acid Rain Program
10
S02
at
I
c
_o
I
1990
1997
NOx
0.5
1990
1997
ACID
PROG RAM
-------
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 1997, there were 423 units affected by the SO2 provisions of the Acid Rain Program, 187
of which were also affected for NOX, and an additional 351 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 30-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.
-------
Table of Contents
Letter from the Director 1
Summary 2
Affected Population in Phase 1 4
SO2 Results
Program 5
Compliance Results 8
Allowance Market 11
NOX Results
Program 13
Phase I Units 13
Phase I Compliance Results 15
Phase II Early Election Units 17
Phase II Early Election Compliance Results 18
Monitoring Update 20
Conclusion 22
Appendix A: Phase I Affected And Early Election Units in 1997
Appendix B-l: Table 1 Units Designating Substitution and Compensating Units - 1997
Appendix B-2: List of Phase I Extension Units and 1998 Deductions for Exceeding 1997 Projected
Emissions Limitations
Appendix B-3: Emissions and Utilization of Phase I Units, 1996 and 1997
Appendix B-4: Emissions and Allowance Holdings of Phase I Units
Appendix C-l: List of Averaging Plans and Results in 1997
Appendix C-2: Compliance Results for the 265 Phase INOX Affected Units in 1997
Appendix C-3: Compliance Results for the 272 Early Election Units in 1997
-------
1997 Compliance Report Page 1
TO THE READER:
The 1997 Compliance Report once again announces 100 percent compliance with the Acid Rain
Program, now in its third year of sulfur dioxide (SO2) compliance and its second year of nitrogen oxides
(NOX) compliance. Affected facilities continued to exceed the targets set for both pollutants by the
Clean Air Act Amendments of 1990. The early reductions seen in 1995 and 1996 for SO2 continue,
with affected utility units beating their 1997 target by 23 percent. The overcompliance with the NOX
target also continues, achieving an average emission rate for Phase I units 16 percent below the
compliance rate.
Trading activity in the SO2 arena continues to rise dramatically; the number of private trades between
economically distinct organizations in 1997 is greater than the number of corresponding trades in all
previous years combined. This increasingly active market, coupled with the success of the industry in
exceeding compliance goals, has encouraged EPA to continue in its efforts to support other programs
seeking to implement trading in order to achieve environmental goals at lower costs.
The Acid Rain Program is continually striving to find new ways to improve the efficiency with which it
carries out its mission. For example, despite the addition of compliance determinations for 272 new
Phase II early election units and supplemental determinations of compliance with Phase I extension
provisions for 1997, EPA was able to complete the annual reconciliation process in the same amount of
time as it did for 1996. This faster completion time was facilitated by fewer errors in submission of
emissions data by the sources, which reduced the need for subsequent resubmissions; the improved
quality of these data reports were in turn facilitated by the improvements to the Emissions Tracking
System made by EPA which allowed faster feedback to be provided to sources each quarter.
I would like to thank those in the industry for their efforts to work in partnership with EPA. We expect
to continue our efforts by making improvements in our rules and procedures, as well as upgrading the
Emissions and Allowance Tracking Systems. Together, we can improve the efficiency of the Acid Rain
Program and realize its significant environmental benefits.
Brian J. McLean, Director
Acid Rain Program
-------
1997 Compliance Report Page 2
SUMMARY
100 Percent Compliance for both SO2 and NOX in 1997
All 774 boilers and combustion turbines (referred to as "units") affected by the SO2 and NOX
regulations of the Acid Rain Program in 1997 successfully met their emissions compliance obligations.1
All 423 units subject to SO2 requirements in 1997 held sufficient allowances to cover their
emissions. The 5,480,210 allowances deducted from compliance accounts represent approximately
77 percent of all 1997 allowances issued and 41 percent of all 1995, 1996, and 1997 allowances that
were available for compliance. Almost all of the deducted allowances (5,474,440, or 99.9 percent)
were for emissions, but other deductions were also made as required by the Acid Rain regulations.
All 537 units subject to the NOX requirements in 1997 demonstrated compliance with applicable
annual emission limitations. Of these 537 units, 239 were also subject to SO2 requirements, while
298 units were affected only for NOX (26 Phase I units and 272 Phase II "early election" units).
1997 SO2 Emissions of Phase I Units were 23 Percent Below Allowable Level
SO2 emissions in 1997 were 1.7 million tons (or 23 percent) below the 7.1 million ton allowable level as
determined by 1997 allowance allocations. Since an additional 6.3 million allowances were carried
over, or banked, from 1996, the overall number of allowances available in 1997 was 13.4 million, of
which affected units exhausted only about 41 percent. Actual emissions for the 423 units participating
in 1997, measured by continuous emission monitoring systems (CEMS), were 5.5 million tons, up less
than 100,000 tons from emissions of the 431 units affected in 1996.
1997 Phase I Unit NOX Emission Rates 41 Percent Below 1990; NOX Tons 32 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 0.69 pounds of NOX per million Btu of heat input (Ib/mmBtu) to an average of 0.40
Ibs/mmBtu, 17 percent below the compliance rate of 0.48 Ibs/mmBtu for these units. Emission levels
for these units were 409,322 tons (or 32 percent) below 1990 levels.
1997 NOX Emission Rates of Early Election Units Even Lower Than Phase I Units'
^our units have been "conditionally" deemed to be in compliance with their NOX requirements, two early
election units and two Table 1 units. The two Table 1 units are awaiting a final determination on their AEL
demonstration period petition, the two early election units are awaiting a change in their permit conditions.
-------
1997 Compliance Report Page 3
For the 272 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 1997, 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 24 percent between 1990 and 1997, NOX tons increased by only 2 percent.
Monitoring Performance Excellent Once Again
For the third 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 utility units affected by both Phase I and Phase II of the
program.
Accuracy: 98.4 percent of the installed and tested monitors met the required relative
accuracy standards on the first attempt, while less than two percent needed
appropriate monitor adjustments to meet the standards; SO2 monitors achieved a
median relative accuracy (i.e., deviation from the reference test method) of 3.2
percent; flow monitors, 3.5 percent; and NOX monitors, 3.3 percent.
Reliability: SO2 and flow monitors achieved a median reliability of 99.3 and 99.5 percent,
respectively, while NOX monitors achieved a median reliability of 98.8 percent.
SO2 Market Active; Volume of Allowances Transferred Between Distinct Entities in 1997
Exceeds the Total of 1994,1995, and 1996 Combined
Activity in the allowance market continued to increase in 1997. The volume of allowances transferred
between unrelated parties in economically significant trades increased from 4.4 million in 1996 to 7.9
million in 1997. More than 80 percent of Phase I and Phase II affected utility companies have already
engaged in at least one private transfer registered in ATS.
Following the all-time low cost of allowances of $68 at the 1996 allowance auction, prices increased to
$110 in the 1997 auction. Later in 1997, prices dipped again to a low of $88, to finish in 1997 at about
$100. Prices have increased again in the first half of 1998, with the auction price of $117 and market
indices of approximately $190 in June.
-------
1997 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
Variable
Variable
Variable
111
95
Variable
Variable
1999
263
Variable
Variable
Variable
111
95
Variable
Variable
This report discusses the process and results of determining compliance for these Phase I affected units.
Detailed appendices provide information on 1997 emissions and utilization for both SO2 and NOX
affected sources, allowance holdings and deductions for SO2 sources, and explanations of averaging
plans and compliance flexibility and requirements for NOX sources.
-------
1997 Compliance Report Page 5
SO2 PROGRAM
423 Units Underwent Annual Reconciliation for SO2 in 1997
There were 416 affected utility units and seven opt-in units that underwent annual reconciliation in 1997
to determine whether sufficient allowances were held to cover emissions. These 423 units are listed in
Appendix A and include 263 utility units specifically required to participate during Phase I, 153 utility
units not initially required to participate until Phase II, but electing to participate early as part of
multi-unit compliance plans, and seven other units that elected to join as part of the Opt-in Program.
The core 263 utility units, residing at 110 power plants, were selected by Congress in the 1990
Amendments to the Clean Air Act because they were the highest emitting and largest units. These units
emitted 57 percent of all utility emissions in 1985, and had emission rates ranging from 2.5 to 10.2 Ibs
of SO2/mmBtu of heat input, with an average of 4.2 Ibs/mmBtu. These units are often referred to as
"Table 1 units" because they are officially listed in Table 1 of the allowance allocation regulation, 40
CFR73.10.
An additional 153 utility units affected in 1997 have been designated by certain Table 1 units to serve
either as substitution or compensating units2. Appendix B-l delineates the relation of these units to
their Table 1 counterparts. In 1997, there were 152 substitution units and one compensating unit
designated.
The seven opt-in units that entered the program in July 1996 remain in the program. 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.
In 1997, there were 8 fewer units undergoing annual reconciliation than in 1996, and 22 fewer than in
1995. The change in number of units affected by the Phase I SO2 provisions is due to the entry and exit
of units in accordance with substitution and compensating plans of one or more of the original 263
Table 1 units and the entry of opt-in sources.
New Requirements for Phase I Extension Units in 1997
Under the Acid Rain Program, certain units applied for and received approval of Phase I Extension
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.
-------
1997 Compliance Report Page 6
plans during the Phase I permitting process. These units fell into two categories: "control units" which
were required to cut their emission by 90 percent using qualifying technology3 by 1997, and "transfer
units" which reassigned their emissions reduction obligations to a control unit. Both kinds of units
received extra SO2 emissions allowances to cover the SO2 they emitted beyond their basic Phase I
allocations during 1995 and 1996. In addition, the control units were given Phase I extension
allowances for 1997, 1998, and 1999. A total of 3.5 million allowances was distributed to all Phase I
extension control and transfer units.
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.
For 1997, all 19 control units demonstrated meeting the 90 percent reduction requirement and,
therefore, did not surrender any 1997 extension allowances. The 1997 tonnage emissions limitation,
though, was exceed by six control units and ten transfer units and resulted in a surrender of a total of
92,768 vintage 1998 allowances. The deduction amounts for each Phase I extension unit are included in
Appendix B-2.
1997 SO2 Emissions Target was 7.1 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 1997, the emissions target established by the program for the 423 participating units was
7.1 million tons. However, the total allowable SO2 emission level in 1997 was actually 13.4 million
tons, consisting of the 7.1 million 1997 allowances granted through the program and an additional 6.3
million allowances carried over, or banked, from 1996.
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 1997 were also made available through the allowance auctions, held annually
since 1993. Other allowances issued in 1997 were from bonus 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.
Qualifying technology is defined in 40 CFR 72.2
-------
1997 Compliance Report
Page 7
Exhibit 2
Origin of 1997 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
Conservation Allowances
TOTAL 1997 ALLOCATION
BANKED 1996 ALLOWANCES
TOTAL 1997 ALLOWABLE
Number of
Allowances
5,550,820
271,334
1,024,178
150,000
15,838
95,882
27,578
11,834
7,147,464
6,288,335
13,435,799
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.
Conservation Allowances are awarded to utilities that undertake
efficiency and renewable energy measures prior to their first
compliance year. The allowances come from a special
Conservation and Renewable Energy Reserve set aside when the
initial allowance allocation was made.
Banked Allowances are those held over from 1995 and 1996
which can be used for compliance in 1997 or any future year.
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.
-------
1997 Compliance Report
Page .
SO2 COMPLIANCE RESULTS
Phase I Units Better 1997 SO2 Allowable Emissions Level by 23 Percent
The Phase I units affected in 1997 emitted at a level approximately 23 percent below 1997 allocations,
as shown in Exhibit 3. Although this percentage is significantly lower than in 1996, it is not due to an
increase in emissions but rather due to a decrease in allocations, primarily due to the much lower
number of Phase I extension allowances allocated for 1997. The Phase I units emitted 5.5 million tons
of SO2, expending only about 41 percent of the 13.4 million allowances available in 1997. Appendix B-
3 reports the 1997 emission and utilization levels for all Phase I affected units, as well as a comparison
to these levels in 1996 and 1995.
Exhibit 3
Summary of SO2 Emissions versus Allocations
(Millions of Tons)
10
8
Allowances
1995
1996
Allowances
1997
Emissions
Allowances
Emissions
I
Emissions
Table 1 Units
S&CUnteS*
Other**
TOTALS
=1
H
'95 Allocation
5.55
1.33
1.86
8.74
'95 Errissions
4.45
0.85
0.00
5.30
'96 Allocation
5.55
1.18
1.57
8.30
'96 Errissions
4.77
0.63
0.04
5.44
'97 Allowances
5.55
1.04
0.56
7.15
'97 Emssions
4.77
0.62
0.08
5.47
* There were 182 substitution and compensating units in 1995 and 161 and 153 such units in 1996 and 1997,
respectively.
** "The soot* of the "other" emissions in 1996 and 1997 is the 7 opt-in units. The "other"
allocations in all years consist of Phase I Extension, opt-in, small desel, conservation and annual
auction allowances.
Relative to 1996, the 263 Table 1 units increased their emissions by less than 10,000 tons, or less than
one percent in 1997, while increasing their utilization by three percent. The 4.8 million tons emitted by
these Table 1 units were still substantially below their 1997 allocation of 5.6 million allowable tons.
-------
1997 Compliance Report Page 9
Just over half of the Table 1 units (52 percent) increased their emissions relative to 1996 by an average
of 3,400 tons. Most of the remaining Table 1 units (44 percent) decreased their emissions from 1996
levels by an average of 3,900 tons. The remaining eight Table 1 units maintained the same zero
emission level of 1996.
In terms of utilization, almost half (46 percent) of Table 1 units decreased their levels by an average of
10 percent, while just over half (51 percent) increased their utilization since 1996 by an average of 27
percent.
Substitution and compensating units in 1997 expended a larger percentage of their annual allocation
than in 1996. In 1997, these 153 units were responsible for emitting approximately 621,000 tons of
SO2, about 60 percent of their 1.04 million allocation. In 1996, 161 substitution and compensating units
emitted approximately 610,000 tons of SO2, or slightly more than half of their allowable level.
Of the 153 units in 1997, 44 percent increased their emissions relative to 1996 by an average of 1,500
tons, while 30 percent of the units decreased their emissions by an average of 900 tons. The remainder
of the units maintained their status as zero emitters.
Forty two percent of substitution and compensating units increased their utilization between 1996 and
1997, while 34 percent of units experienced a decrease in utilization. The remaining 24 percent of
substitution and compensating units were not utilized again in 1997.
Opt-in units received 95,882 allowances in 1997 as a reflection of their baseline emissions levels, but
contributed only 77,037 tons to 1997 emission levels. Although this is an increase of approximately
40,000 tons over 1996, the 1997 data represent operations for the entire calendar year of 1997, whereas
in 1996, the opt-in units were only affected for the second half of the year.
Deducting Allowances for Compliance
The total number of allowances deducted in 1997 was 5,480,210 which represents approximately 77
percent of all 1997 allowances issued. Almost all (99.9 percent) of the deducted allowances were for
emissions. Exhibit 4 on the following page displays these allowance deductions, as well as the
remaining bank of 1995, 1996, and 1997 allowances.
At an individual unit, the number of allowances surrendered was equal to the number of tons emitted at
the unit, except where the unit shared a common stack with other units. For the purposes of
surrendering allowances for emissions at a common stack, the utility was allowed to choose the
proportion of allowances deducted from each unit sharing the stack, as long as enough allowances were
surrendered to cover the total 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-3 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.
In 1997, Phase I units had a total of 5,474,440 allowances deducted for emissions. Of the 423 units,
Paradise Unit 3 in Kentucky for the third year in a row surrendered the most allowances for emissions
(173,285), an increase of 18 percent over 1996. Fifty units were not operated at all during the year and
-------
1997 Compliance Report Page 10
surrendered no allowances. Half of the units surrendered under 7,000 allowances, while the average
number of allowances deducted at a unit was 12,944.
The remaining 0.1 percent (5,770) of allowance deductions were made for underutilization and control-
by-contract, which are explained in detail in Appendix B-4.
Exhibit 4
SO2 Allowance Reconciliation Summary
Total Allowances Held in Accounts as of 1/30/98 (1995,1996, & 1997 Vintages)* 13,435,799
Table 1 Unit Accounts 7,942,551
Substitution & Compensating Unit Accounts 1,288,988
Opt-in Accounts 85,126
Other Accounts** 4,119,134
1997 Allowances Deducted for Emissions 5,474,440
Table 1 Unit Accounts 4,774,609
Substitution & Compensating Unit Accounts 620,794
Opt-in Unit Accounts 79,037
1997 Allowances Deducted Under Special Phase I Provisions*** 5,770
Table 1 Unit Accounts 1,733
Substitution & Compensating Unit Accounts 2,949
Opt-in Unit Accounts 1,309
Banked Allowances 7,955,368
Table 1 Unit Accounts 3,166,209
Substitution & Compensating Unit Accounts 665,245
Opt-in Unit Accounts 4,780
Other Accounts** 4,119,134
* The number of allowances held in the Allowance Tracking System (ATS) accounts equals the number of 1997 allowances allocated
(see Exhibit 2) plus the number of 1996 banked allowances. January 30, 1998 represents the Allowance Transfer Deadline, the point
in time at which the 1997 Phase I affected unit accounts are frozen and after which no transfers of 1995,1996, and 1997 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 control-by-contract provisions in 1997 (see Appendix B-4 for a thorough
explanation).
-------
1997 Compliance Report
Page 11
SO2 ALLOWANCE MARKET
The flexibility provided by the Acid Rain Program enabled the 423 units affected in 1997 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 423
sources to be in compliance in 1997 and significantly reduced the cost of achieving these emissions
reductions as compared to the cost of a technological mandate.
The marginal cost of reducing a ton of 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 dropped to a low of just $68/ton at the 1996 allowance auction.
Following this low, however, the price of a current vintage year allowance climbed to $110 in the 1997
auction, after which time it dipped once again into the $88 range, only to finish 1997 at about $100.
Prices have increased during the first half of 1998, with a March 1998 auction price of $117 and market
indices of approximately $190/ton in June, 1998. 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 two brokerage firms, Emissions Exchange Corporation and Cantor
Fitzgerald Environmental Brokerage Services, and a market survey conducted by Fieldston Publications.
Exhibit 5
Allo/vance Price in dollars
2OO
Cantor Fitzgerald
Emissions Exchange*
Reldston Publications
18O
160
14O
12O
1OO
SO
60
12/94
6/95
12/95 6/96
Manth/Ve
* Errissicns Exchange dsoondnued their price index in May 1SBa
12/96
6/97
12/97
6/98
-------
1997 Compliance Report
Page 12
Activity in the allowance market created under the Acid Rain Program continued to grow in 1997, with
1,429 transactions moving over 15 million allowances reported to 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
1.9 million in 1995 to 4.4 million in 1996 and to 7.9 million in 1997, as shown in Exhibit 6. The total for
1997 exceeds the total of the three previous years combined. Growth is also evident in the subset of
economically significant transfers representing only those allowances acquired by utilities (rather than all
those exchanged by unrelated parties through the market); volume has increased from 700,000
allowances in 1995 to 1.6 million in 1996 and to 2.8 million in 1997. In addition, more than 80 percent
of the accounts established for affected units under the program have been involved in at least one
private transfer registered in ATS. Almost half of allowances with vintage years 1995 and 1996 have
been involved in at least one transfer as well. To date, approximately 35 percent of 1997 allowances
have been involved in a transfer under the Acid Rain Program.
Exhibit 6
Volume of SO2 Allowances in Economically Significant Transfers
Volume of Allcwvanoes
10,OOO,OOO
8,000,000
6,000,000
4,000,000
2,000,000
1994
1995
1998
1997
EPA seeks to minimize transaction costs to parties trading allowances in the market by quickly and
efficiently recording transfers reported to the Agency in ATS. In 1997, EPA processed 89 percent of
allowance transactions within 24 hours of receipt, up slightly from the 1996 rate of 83 percent. Ninety-
eight percent were processed within 5 days. These 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.
-------
1997 Compliance Report Page 13
NOX PROGRAM
Instead of using allowance trading to facilitate emissions reductions, the Title IVNOX program establishes
standard emission limitations for affected units. Title IV of the 1990 Clean Air Act Amendments required
EPA to establish NOX annual average emission limits (in pounds of NOX per million British thermal units
of fuel consumed (Ib/mmBtu)) for coal-fired electric utility units in two phases.
In April 1995, EPA promulgated 40 CFR Part 76 which established NOX emission limits beginning on
January 1, 1996 for Group 1 boilers that were also part of the Phase I SO2 program. (Group 1 boilers are
dry bottom, wall-fired boilers and tangentially fired boilers.) Phase I dry bottom wall-fired boilers are
subject to a NOX emission limit of 0.50 Ib/mmBtu; Phase I tangentially fired boilers are subject to a NOX
emission limit of 0.45 Ib/mmBtu.
In addition, the April 1995 regulations allowed Phase II Group 1 units to use an "Early Election"
Compliance Option. Under this regulatory provision, Group 1, Phase II NOx affected units can
demonstrate compliance with the higher Phase I limits for their boiler type from 1997 through 2007 and
not meet the more stringent Phase II limits until 2008. If the utility fails to meet this annual limit for the
boiler during any year, the unit is subject to the more stringent Phase II limit for Group 1 boilers
beginning in 2000, or the year following the exceedance, whichever is later.
In December 1996, EPA revised the NOX emission limits for Phase II, Group 1 boilers (0.46 Ib/mmBtu for
dry bottom wall-fired boilers and 0.40 Ib/mmBtu for tangentially fired boilers) and established emission
limits for cell burner, cyclones, wet bottom and vertically-fired boilers (referred to as "Group 2 boilers")
effective on January 1, 2000. As a result of the April 1995 and December 1996 rulemakings, NOX
reductions were projected to be approximately 400,000 tons per year in 1996 through 1999 (Phase I),
and 2,060,000 tons per year in 2000 and subsequent years (Phase II).
PHASE I NOX UNITS
265 Phase I Units Were Subject to Emission Limitations in 1997
In 1997, 265 coal-fired utility units were subject to the Title IV Phase I emission limitations for NOX, an
increase of 26 units from 1996. The 265 Phase INOX affected units include 170 Table 1 units and 95
substitution units whose owners chose to participate in Phase I as part of an SO2 compliance strategy.
This group of units (along with one additional unit whose compliance extension expired at the end of
1997) will be 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.
-------
1997 Compliance Report
Page 14
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
93
77
Substitution
Units
42
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 three additional compliance options which add flexibility to the rate-based
compliance requirements:
! Emissions Averaging. A utility can meet the standard emission limitation by averaging the heat-
input weighted annual emission rates of two or more units.
! Alternative Emission Limitation (AEL). A utility can petition for a less stringent alternative
emission limitation if it uses properly installed and operated low NOX burner technology (LNBT)
designed to meet the standard limit, but is unable to achieve that limit. EPA determines whether
an AEL is warranted based on analyses of emissions data and information about the NOX control
equipment.
! Phase INOX Extensions. Twenty-seven Group 1 boilers affected in Phase I qualified for a Phase
INOX extension for 1996. All of the extensions expired on December 31, 1996, except for one
that expired on July 31, 1997, and another that expired on December 31, 1997.
Exhibit 8 summarizes the compliance options chosen by Phase I affected NOX units for 1997. As in 1996,
averaging was the most widely chosen compliance option. For 1997, utilities submitted 24 averaging
plans involving 204 Phase INOX units. For seven plans involving 22 units, the averaging plan was not
necessary to balance compliance among units; all units within the plan met their applicable emission limit
individually. See Appendix C-l: List of Averaging Plans and Results in 1997.
-------
1997 Compliance Report
Page 15
Exhibit 8
Compliance Options Chosen in 1997
Compliance Option
Compliance with Standard Emission Limitation
Emissions Averaging
Alternative Emission Limitation
SUBTOTAL
Pending Alternative Emission Limitation Petition
Pending Alternative Emission Limitation Petition for
Partial Year Compliance
Part 76 Phase I NOX Extension
TOTAL
Number of Units
52
204
7
263
1
1
1
266
PHASE I NOX COMPLIANCE RESULTS
EPA has determined that 263 out of the 265 Phase INOX units met the required emission limit through
compliance with either the standard emission limitation, emissions averaging, or an alternative emission
limitation4. The two other Phase I units are conditionally in compliance pending a decision on their
alternative emission limitation petitions which was pending as of July 1998. The 266th unit will become a
Phase I affected unit in 1998. See Appendix C-2: Compliance Results for the 266 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
Many units emitted at rates well below the emission limits, as shown in Exhibit 9. Utilities operated the
affected group of Phase INOX boilers at NOX emission rates approximately 16 percent below the
allowable rate in 1997, compared to 18 percent below in 1996.
The analyses in this section focus on these 263 units.
-------
1997 Compliance Report
Page 16
Exhibit 9
Percentage Compliance Relative to Allowable Emission Rate in 1997
Percent Below
Applicable Limit
0 - 10%
10% - 25%
More than 25%
Total
Units Subject to
Standard Limit
20
15
17
52
Units Using
Averaging
99
87
18
204
Units Subject to
AEL Demonstration
4
2
1
7
Total
123
104
36
263
From 1990s to 1997, the average NOX emission rate of the 263 Phase I units declined by 42 percent (from
0.69 Ib/mmBtu to 0.40 Ib/mmBtu). As shown in Exhibit 10, on average, both Table 1 and substitution
units were below the average Phase I emission limit of 0.48 Ib/mmBtu (the 1997 heat input weighted
average of the applicable limits).
Exhibit 10
Average NOX Emission Rates for 263 Phase 1 Units
NOx Rate
(Ib/mmBtu)
u.ou
0.60
0.40
0.20
(\ i\i\
0.76
1997 Weighted Average
/ Emission Limitation
0.52
^ (0.48)
0.43
0.36
0.42
0.36
1990 1996 1997
D Table 1 Units (168) D Substitution Units (95)
NOX Mass Emissions Reduction
Total NOX mass emissions also declined from 1990 to 1997, but not as significantly as the NOX emission
rate. Exhibit 11 illustrates the change in NOX mass emissions from 1990 to 1997 for Table 1 and
substitution units. The Table 1 units exhibited a 36 percent reduction in NOX tons, and the substitution
units showed a 16 percent reduction. For the 263 Phase I units, annual NOX emissions reductions
For a more detailed description of the 1990 baseline refer to the Acid Rain Program 1996
Compliance Report.
-------
1997 Compliance Report
Page 17
between 1990 and 1997 totaled approximately 409,322 tons, or a 32 percent reduction. However, NOX
mass emissions in 1997 increased slightly from 1996, attributable to greater electrical production, as
evidenced by a five percent increase in heat input. Without further reductions in emissions rates, NOX
emissions would be expected to rise with increased utilization. As in 1996, the lower percentage of
reductions for substitution units is probably attributable to the fact that many of these units were already
lower emitters subject to New Source Performance Standards (NSPS).
Exhibit 11
NOV Mass Emissions for 263 Phase I Units
NOX
Tons
1,OUU,UUU
,200,000
800,000
400,000
iğ
287,583
997,586
239,437
601,162
241,733
634,115
1990 1996 1997
D Table 1 Units (168) D Substitution Units (95)
PHASE II EARLY ELECTION UNITS
272 Units Were Subject to Early Election Requirements in 1997
Nineteen ninety-seven was the first year in which utilities could choose to use the "Early Election"
compliance option provided in Part 76. Owners and operators of 272 units applied for this option.
Exhibitl2 shows the number of Early Election units by boiler type.
Exhibit 12
Distribution of 1997 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
170
102
272
Percent of
Units Electing
56.7%
32.5%
44.3%
-------
1997 Compliance Report
Page 18
PHASE II EARLY ELECTION COMPLIANCE RESULTS
For 1997, EPA determined that 270 units complied with the Phase I, Group 1 emission limitations and
have continued eligibility for Early Election in 1998 through 2007. An additional two units subject to
Early Election complied with the Phase I, Group 1 emission limit, however, their compliance is pending,
while their permit is being reviewed. See Appendix C-3: Compliance Results for the 272 Early Election
Units in 1997.
NOX Emission Rate Reduction
In 1997, many Early Election units emitted at rates well below the applicable emission limit, as shown in
Exhibit 13. Utilities operated dry-bottom wall-fired boilers atNOx emission levels approximately 23
percent below the limit of 0.50 Ib/mmBtu and tangentially fired boilers approximately 18 percent below
the limit of 0.45 Ib/mmBtu.
Exhibit 13
Percentage Compliance Relative to Emission Limits
Percent Below Applicable
Emission Limitation
0 - 10%
10 - 25%
More than 25%
Total
Early Election Units
94
112
66
272
Average NOX emission rates for Early Election units have declined by 17 percent, from 0.46 Ib/mmBtu in
1990 to 0.38 Ib/mmBtu in 1997. This decline is less dramatic than the decline at Phase INOX units
because 51 percent of the Early Election units are newer units already subject to the NSPS NOX emission
limits. The overall NOX emission rate for these units is comparable to the average rate of 0.40 Ib/mmBtu
for all Phase INOX units.
Exhibit 14 summarizes the NOX emission rate reductions from 1990 to 1997 by boiler type for the 262
Early Election units which were operating in 1990.
-------
1997 Compliance Report
Page 19
Exhibit 14
Average NOX Emission Rate for 262 Early Election Units
0.80
0.60
NOx Rate
(Ib/mmBtu)
0.40
0.20
0.00
Tangentially-Fired Boilers
Emission Limit (0.45)
~ \
0.44
0.37
Dry-Bottom Wall-Fired Boilers
Fjnission Limit (0.50)
0.47
\
0.38
1990
1997
1990
1997
NOX Mass Emissions Reduction
The total NOX mass emissions from the operating Early Election units increased by 23,887 tons (or
2 percent) from 1990 to 1997, reflecting an increase in utilization (see Exhibit 15). For the 262 Early
Election units operating in 1990, heat input increased during the seven year period by approximately
24 percent.
Exhibit 15
NOX Mass Emissions for 262 Early Election Units
1,600,000
1,200,000
NOx
Tons
800,000
400,000
575, oJ4
724,231
Dry-Bottom
Wall-Fired
Boilers (100)
T-Fired
Boilers (162)
581 843
741,909
1990
1997
-------
1997 Compliance Report
Page 20
SO2 AND NOX MONITORING IN 1997
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 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 1997.
Exhibit 16
1997 Relative Accuracy Test Audit (RATA) Results
Mean Relative Accuracy
Median Relative Accuracy
Percent Meeting Relative Accuracy
Standard
SO2 Concentration
3.9%
3.2%
97%
Volumetric Flow Rate
4.2%
3.5%
99%
NOX Rate
4.0%
3.3%
97%
Another metric used to determine the effectiveness of a CEMS is the percentage of hours that a
-------
1997 Compliance Report
Page 21
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 1997 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 17
1997 CEMS Availability
Parameter
S02
Flow
NOX
Median % Availability at End of 1997
Coal-Fired Units
99.3
99.6
99.1
Oil and Gas Units
98.3
98.7
97.7
-------
1997 Compliance Report Page 22
CONCLUSION
Both the Acid Rain Program's rate-based approach to NOX reduction and cap-and-trade approach to SO2
reduction have been very successful. In 1997, all 502 Phase I affected utility units not only met their
compliance goals, but exceeded them, achieving an overall reduction of 409,322 tons of NOX from 1990
levels despite an increase in generation, and maintaining the extraordinary reductions of more than 5
million tons of SO2 from 1980 levels, first achieved in 1995. Additionally, the 272 Phase II units newly
affected for NOX in 1997 under the early election program had increased emissions of only two percent
since 1990, while their utilization increased by 24 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 19956.
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,
and 23 percent of 1997 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 have been very
successful in 1997. 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 NOV emissions will be achieved.
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.
-------
APPENDIX A: PHASE I AFFECTED (/) AND EARLY ELECTION (E) UNITS IN 1997
ST Plant Name Unit ID SO2 NOx ST Plant Name Unit ID SO2 NOx
AL
AL
AL
AL
AR
AR
AR
AZ
AZ
AZ
AZ
AZ
CO
CO
Charles R Lowman
Colbert
E C Gaston
Gadsden
Flint Creek
Independence
White Bluff
Apache
Cholla
Coronado
Navajo
Springerville
Craig
Comanche
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
E
E
f /
/
/
/
/
/
/
/
/
/
/
/
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
CO
CO
CO
CO
CO
CT
FL
FL
FL
FL
FL
FL
FL
FL
GA
GA
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
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
E
E
E
E
E
E
E
f
f
f
f /
E
f /
f /
f /
/ /
E
E
E
E
E
E
f /
f /
E
E
f /
/ /
f /
/ /
r f
r s
r s
r s
A, 1
-------
APPENDIX A: PHASE I AFFECTED (/) AND EARLY ELECTION (E) UNITS IN 1997
ST
GA
GA
GA
GA
GA
GA
GA
GA
GA
IA
IA
IA
IA
IA
Plant Name
Hammond
Harllee Branch
Jack Mcdonough
Kraft
Mcintosh
Mitchell
Scherer
Wansley
Yates
Ames
Burlington
Council Bluffs
Des Moines
George Neal North
Unit ID SO2 NOx
1 / /
2 / /
3 / /
4 / /
1 /
2 / /
3 /
4 /
MB1 / /
MB2 / /
1 / /
2 / /
3 / /
1 / /
3 / /
3 /
4 E
1 / /
2 / /
Y1BR / /
Y2BR / /
Y3BR / /
Y4BR / /
Y5BR / /
Y6BR / /
Y7BR / /
7 E
8 E
1 / /
1 E
2 E
3 E
11 /
1 /
2 E
3 E
ST
IA
IA
IA
IA
IA
IA
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
Plant Name
Lansing
Louisa
Milton L Kapp
Ottumwa
Prairie Creek
Riverside
Baldwin
Coffeen
Collins
Crawford
Dallman
Fisk
Grand Tower
Havana
Hennepin
Hutsonville
Unit ID
4
101
2
1
4
9
1
2
3
1
2
1
2
3
7
8
33
19
7
8
9
1
2
3
4
5
6
7
8
2
5
6
SO2 NOx
E
E
/ /
E
/ /
/ /
/
/
/ /
/
/
/
/
/
E
E
E
E
/ /
/ /
/ /
/
/
/
/
/
/
/
/
/ /
/ /
/ /
IA George Neal South
A, 2
-------
APPENDIX A: PHASE I AFFECTED (/) AND EARLY ELECTION (E) UNITS IN 1997
ST Plant Name Unit ID SO2 NOx ST Plant Name Unit ID SO2 NOx
IL
IL
IL
IL
IL
IL
IL
IL
IN
IN
IN
IN
IN
Joppa Steam
Kincaid
Meredosia
Newton
Vermilion
Waukegan
Will County
Wood River
A B Brown
Bailly
Breed
Cayuga
Clifty Creek
1
2
3
4
5
6
1
2
01
02
03
04
05
06
1
2
1
2
7
8
3
4
1
1
2
7
8
1
1
2
1
2
3
4
5
6
/ / IN Dean H Mitchell
/ /
/ /
/ /
/ /
/ / IN Elmer W Stout
/
/
IN F B Culley
/ /
/ /
/ / IN Frank ERatts
/ /
/ /
/ IN Gibson
/ /
/ /
/ / IN HTPritchard
/ /
E
E
IN Merom
E
E
IN Michigan City
/
IN Petersburg
E
E
/
/ IN R M Schahfer
/
/ / IN R Gallagher
/ /
/
/
/ IN Rockport
/
/
/ IN State Line
IN Tanners Creek
4
5
6
11
50
60
70
2
3
1SG1
2SG1
1 Ğ
2
3
4
3
4
5
6
1SG1
2SG1
12
1 Ğ
2
3
4
15
17
18
1 Ğ
2
3 Ğ
4 Ğ
MB1
MB2
3
U4
E
E
E
E
f /
/ /
/ /
f /
/ /
f /
/ /
/ /
f /
/ /
f /
/
/
/ /
/ /
E
E
f
f /
/ /
/
/
E
E
E
/ /
/ /
/ /
f /
E
E
E
f
-------
APPENDIX A: PHASE I AFFECTED (/) AND EARLY ELECTION (E) UNITS IN 1997
ST Plant Name Unit ID SO2 NOx
SO2 NOx
IN
IN
IN
KS
KS
KS
KS
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
Wabash River
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
H L Spurlock
1
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
3
2
1
2
1
5
1
/ / KY
/ /
/ /
/ / KY
/ /
/
/
/ KY
/
KY
E
E
KY
/
/ KY
E
LA
/ /
E
E LA
E LA
E
E LA
/ / MA
/ /
/ / MA
/ / MD
/ /
E MD
/ /
/ /
/ /
MD
/ /
/ MD
/ /
/ / MI
/ /
MI
/ /
Hmp&L Station 2
Mill Creek
Paradise
R D Green
Shawnee
Trimble County
Big Cajun 2
Dolet Hills
R S Nelson
Rodemacher
Brayton Point
Mount Tom
C P Crane
Chalk Point
Morgantown
R P Smith
B C Cobb
Dan E Karn
HI
H2
1
2
3
4
3
Gl
G2
10
1
2B1
2B2
2B3
1
6
2
2
1
1
2
1
2
3
4
1
2
9
11
4
5
1
2
' /
/ /
E
E
E
E
/
/ /
/ /
/
E
E
E
E
E
E
E
/
/
/
'
/ /
/ /
/
/
/ /
/ /
/ /
/ /
/ E
E
/
/
A, 4
-------
APPENDIX A: PHASE I AFFECTED (/) AND EARLY ELECTION (E) UNITS IN 1997
ST Plant Name
MI J B Sims
MI J C Weadock
MI J H Campbell
MI J R Whiting
MI Presque Isle
MN ClayBoswell
MN High Bridge
MN Hoot Lake
MN Sherburne County
MO Asbury
MO Hawthorn
MO latan
MO James River
MO Labadie
MO Meramec
MO Montrose
Unit ID SO2 NOx
3 E
7 / E
8 / E
1 / /
2 /
3 /
1 E
2 /
3 / E
7 E
8 E
9 E
3 E
3 / /
4 / /
5 / /
6 / /
2 E
1 / /
2 / /
1 /
5 / /
1 /
3 / /
4 / /
5 / /
1 / /
2 / /
3 / /
4 / /
1 / /
2 / /
3 / /
4 / /
1 / /
2 / /
3 / /
ST
MO
MO
MO
MO
MO
MO
MO
MS
MS
MS
MT
MT
NC
NC
E
NC
Plant Name
New Madrid
Rush Island
Sibley
Sioux
Sikeston
Southwest
Thomas Hill
Jack Watson
R D Morrow
Victor J Daniel Jr
Colstrip
Lewis & Clark
Buck
Cliffside
Dan River
Unit ID
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
2
3
4
5
1
2
SO2 NO:
,
/
/ /
/ /
/
/
/
/
/
E
/ /
/
/
/ /
/ /
/ /
/ /
/ /
/
/
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
A, 5
-------
APPENDIX A: PHASE I AFFECTED (/) AND EARLY ELECTION (E) UNITS IN 1997
ST Plant Name
Unit ID SO2 NOx ST
3 E NC
NC
NC
ND
ND
ND
NE
NE
NE
NE
NE
NH
NJ
NM
NV
NV
NV
NY
Plant Name
G G Allen
Marshall
Riverbend
Antelope Valley
Leland Olds
Stanton
Gerald Gentleman
Gerald Whelan
Nebraska City
North Omaha
Platte
Merrimack
B L England
Escalante
Mohave
North Valmy
Reid Gardner
CRHuntley
Unit ID
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
1
2
1
2
4
67
68
SO2 N(
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
/
/
/
/
E
E
E
E
E
E
E
E
A, 6
-------
APPENDIX A: PHASE I AFFECTED (/) AND EARLY ELECTION (E) UNITS IN 1997
ST Plant Name Unit ID SO2 NOx ST Plant Name Unit ID SO2 NOx
NY Dunkirk 1 E
2 / E
3 S S
4 / /
NY Greenidge 6 / /
NY Kintigh 1 E
NY Milliken 1 / /
2 / /
NY Northport 1 /
2 /
3 /
4 /
NY Oswego 4 /
5 /
6 /
NY Port Jefferson 3 /
4 /
NY Roseton 1 /
2 /
NY S A Carlson 9 E
10 E
11 E
12 E
OH Acme 13 /
14 /
15
16 /
91 /
92 /
OH Ashtabula 7 / /
8 /
9 /
10 /
11 /
OH Avon Lake 9 /
10 /
11 /
12 /
A, 7
-------
APPENDIX A: PHASE
ST Plant Name Unit ID
I AFFECTED (/) AND EARLY ELECTION (E) UNITS IN 1997
SO2 NOx ST Plant Name Unit ID SO2
NOx
OH Bay Shore
OH Cardinal
OH Conesville
OH Eastlake
OH Edgewater
OH Gen JM Gavin
OH Gorge
OH JM Stuart
OH Kyger Creek
OH Lake Shore
OH Miami Fort
1 /
2 /
3 S
4 /
1 /
2 /
1 /
2 /
3 /
4 /
5
6
1 /
2 /
3 S
4 /
5 /
11 /
12 /
13
1 /
2 /
25 /
26 /
1
2 /
3 S
4 /
1 /
2 /
3 S
4 /
5 /
18 /
91
92 /
93 /
94 /
5-1 /
5-2
6 /
7 /
OH Muskingum River 1
2 /
3 S
4 /
5 /
OH Niles 1 /
2 /
OH Picway 9 /
/
/ OH Poston 1 /
E 2 /
E 3 /
/ OH RE Burger 1 /
/ 2 /
S 3 S
/ 4 /
5 /
6 /
7 /
8 /
/
OH Toronto 9 /
10 /
11 /
/ OH W H Sammis 5 /
/ 6 /
7 /
/
OH W H Zimmer 1
OH Walter C Beckjord 5 /
6 /
OK Muskogee 4
5
6
OK Northeastern 3313
3314
/
OK Sooner 1
2
OR Boardman ISO
E
/
/ PA Armstrong 1 /
2 /
,
/
/
/
/
/
/
/
E
/
/
E
E
E
E
E
E
E
/
/
A, 8
-------
APPENDIX A: PHASE I AFFECTED (/) AND EARLY ELECTION (E) UNITS IN 1997
ST Plant Name
Unit ID
SO2 NOx
ST Plant Name
Unit ID SO2 NOx
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
Bruce Mansfield
Brunner Island
Cheswick
Conemaugh
Cromby
Eddy stone
Hatfield's Ferry
Homer City
Keystone
Martins Creek
Mitchell
Montour
New Castle
Portland
Shawville
1
2
3
1
2
3
1
1
2
1
1
2
1
2
3
1
2
3
1
2
1
2
3
4
33
1
2
1
2
3
4
5
1
2
1
2
/ /
/ / PA Sunbury
E
/ / PA Titus
/ /
/ /
/ / SC Cross
E
/ /
/ /
SC W S Lee
E
E
E TN Allen
/
/
/ TN Cumberland
E
E TN DuPont
E Johnsonville
E
E
TN Gallatin
/ /
/ /
/
/
TN John Sevier
/ /
E
E
TN Johnsonville
/ /
/ /
E
E
E
/ /
/ /
/ /
/ / TX Big Brown
3 /
4 /
3 /
4 /
1
2
3
1
2
1
2
3
1 /
2 /
3 S
1 /
2 /
JVD1 /
JVD2 /
JVD3 /
JVD4 /
1 /
2 /
3 /
4 /
1
2
3
4
1 /
2 /
3 /
4 /
5 /
6 /
7 /
8 /
9 /
10 /
1
/
/
/
/
E
E
E
E
E
E
E
/
/
/
/
E
E
E
E
/
/
/
/
/
/
/
/
/
/
E
A, 9
-------
APPENDIX A: PHASE I AFFECTED (/) AND EARLY ELECTION (E) UNITS IN 1997
ST
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
Plant Name
Coleto Creek
Gibbons Creek
Harrington
J K Spruce
J T Deely
Limestone
Martin Lake
Monticello
Oklaunion
Pirkey
Sam Seymour
San Miguel
Sandow
Tolk
W A Parish
Welsh
Unit ID
2
1
1
061B
062B
063B
BLR1
1
2
LIM1
LIM2
1
2
3
1
2
3
1
1
1
2
3
SM-1
4
171B
172B
WAP5
WAP6
WAP7
WAP8
1
2
SO2 NOx
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
ST
UT
UT
UT
UT
UT
UT
VA
VA
VA
VA
VA
VA
WA
WI
WI
WI
WI
Plant Name
Bonanza
Carbon
Gadsby
Hunter
Huntington
Intermountain
Chesapeake
Chesterfield
Glen Lyn
Possum Point
Potomac River
Yorktown
Centralia
Alma
Blount Street
Columbia
Edgewater
Unit ID
3
1-1
1
2
3
1
2
1
1SGA
2SGA
1
2
4
3
4
51
52
3
1
2
3
4
5
1
2
BW21
BW22
B4
B5
8
9
1
2
3
4
SO2 NOx
E
E
E
E
/
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
E
/ /
/ /
E
E
E
E
/
/
A, 10
-------
APPENDIX A: PHASE I AFFECTED (/) AND EARLY ELECTION (E) UNITS IN 1997
ST Plant Name
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
WI Valley
WI Weston
WV Albright
Unit ID SO2 NOx
5 E
1 / /
Bl / /
1 /
2 /
1 /
2 /
3 /
4 /
1 /
2 /
3 /
4 /
5 /
5 /
6 /
7 / /
8 / /
1 /
2 /
5 / /
6 / /
7 / /
8 / /
1 /
2 /
3 /
4 /
1 / /
2 / /
3 /
1 / /
2 / /
3 / /
ST Plant Name
WV Kammer
WV Mitchell
WV Mountaineer
WV Mt Storm
WV Pleasants
WV Rivesville
WV Willow Island
WY Dave Johnston
WY Jim Bridger
WY Laramie River
WY Wyodak
* NOx extension granted
December 31, 1997.
Unit ID SO2 NOx
1 /
2 /
3 /
1 / /
2 / /
1 E
1 / /
2* /
3 / /
1 /
2 /
7 /
8 /
1 /
2 /
BW41 E
BW42 E
BW71 /
BW72 /
BW73 /
BW74 E
1 E
2 E
3 E
BW91 /
to Mt Storm Unit 2 through
WV Fort Martin
WV Harrison
A, 11
-------
APPENDIX B-l:
Table 1 Units Designating Substitution and Compensating Units - 1997
Substitution Units
State
Table 1 Units
Plant Name
Units
State
Substitution Units
Plant Name
Units
AL EC Gaston
FL Big Bend
FL Crist
GA Bowen
GA Bowen
GA Bowen
GA Bowen
GA Hammond
GA Hammond
GA Hammond
GA Hammond
GA Jack Mcdonough
GA Yates
GA Yates
GA Yates
GA Yates
IL Baldwin
IL Kincaid
IL Meredosia
IL Vermilion
IN Petersburg
BB01,BB02,BB03
1BLR
2BLR
3BLR
4BLR
MB2
Y2BR
Y3BR
Y4BR
Y5BR
1,2
1,2
AL
FL
FL
GA
GA
GA
GA
GA
IL
IL
IL
IL
IL
IL
IL
Gadsden
FL Big Bend
Crist
Scholz
GA Harllee Branch
GA Harllee Branch
GA Harllee Branch
GA Harllee Branch
GA Arkwright
GA Arkwright
GA Arkwright
GA Arkwright
Mitchell
Kraft
Kraft
Kraft
Mclntosh
Havana
Collins
Meredosia
Hutsonville
Newton
Grand Tower
Vermilion
IN H T Pritchard
1,2
BB04
4,5
1,2
1
1,2,3,4,5,6,7,8
1,2,3
1,2,3,4,6
5,6
1,2
7,8
1
B-2, 1
-------
APPENDIX B-l:
Table 1 Units Designating Substitution and Compensating Units - 1997
State
KY
Table 1 Units
Plant Name
Coleman
Substitution Units
Units State
C1,C2
MD
MD
MD
MI
MN
MO
MO
C P Crane
Chalk Point
Morgantown
J H Campbell
High Bridge
James River
Labadie
2
1,2
1,2
1,2
6
5
1,2,3,4
MO
MO
MO
Montrose
Sioux
Sibley
1,2,3
1,2
3
MO
NH
NY
Thomas Hill
Merrimack
Dunkirk
MB1,MB2
1,2
3,4
NY
Northport
1,2,3
OH
Ashtabula
7
OH
Avon Lake
12
^
fe,
w
^
w
^
w
fe,
w
^
1 W
^
w
^
w
^
w
^
^
1 W
^
w
^
w
^
^
^
^.
KY
Substitution Units
Plant Name
R D Green
Units
G1,G2
MS
MD
MD
R D Morrow
Chalk Point
Chalk Point
1,2
4
3
MI
MI
MI
MI
MI
Dan E Karn
J R Whiting
JH Campbell
JC Weadock
BC Cobb
1,2
2,3
3
7,8
4
MN
MN
High Bridge
Sherburne County
3,4,5
1,2
MO
MO
James River
Southwest
3,4
1
MO
MO
Meramec
Rush Island
1,2,3,4
1,2
MO
KS
MO
Hawthorn
La Cygne
Sibley
5
1
1,2
MO
MA
Thomas Hill
Mount Tom
MB3
1
NY
NY
NY
NY
Oswego
Roseton
Dunkirk
Northport
4,5,6
1,2
2
4
OH
OH
OH
OH
OH
Acme
Ashtabula
Lake Shore
Bay Shore
Avon Lake
13,14,15,16,91,92
8,9,10,11
18,91,92,93,94
1,2,3,4
9,10
B-2, 2
-------
APPENDIX B-l:
Table 1 Units Designating Substitution and Compensating Units - 1997
State
OH
Substitution Units
Table 1 Units Substitution Units
Plant Name Units State Plant Name
Conesville 4 ^ OH J M Stuart
Units
1,2,3,4
OH
OH
OH
OH
Edgewalei 1 j ^
Niles 1,2
R E Burger 5,6,7,8
WHSammis 5,6,7
OH
IS /T' ' F1 ri H ^k
OH Edgewater
OH RE Burger
OH Gorge
OH Toronto
PA Bruce Mansfield
PA New Castle
KY East Bend
11,12
1,2,3,4
25,26
9,10,11
1,2
1,2
2
OH
IVwav Q ^ HH P^st^n
1,2,3
PA
PA
PA
WV Albright
WV Albright
PA
PA Mitchell
1
2
33
PA Martin's Creek
3,4
WI
TA t '\ ^^
WI Edgewater
3
WI
/~i i ^^
WI
WI
WI Alma
WI J P Madgett
WI Rock River
Piilliam ğ ^
WI Pulliam
B4, B5
Bl
1,2
5,6,7
WV
Albright 3 ^
MD R P Smith
9
WV
F^rt Martin 9 ^ MT> P P Smith
11
WV
WV
WV Rivesville
TT ' ~? ^^
WV Willow Island
7,8
2
State
on
Compensating Units
Table 1 Units Compensating Units
Plant Name Units State Plant Name
Units
7
B-2,3
-------
APPENDIX B-2: List of Phase I Extension Units and 1998 Deductions for Exceeding 1997 Projected Emissions
Limitations
State
AL
FL
GA
GA
GA
GA
GA
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
MD
MD
MD
MD
NJ
NJ
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
TN
TN
Plant Name
Colbert
Crist
Jack Mcdonouah
Wanslev
Yates
Yates
Yates
Baillv
Baillv
Cavuaa
Cavuaa
Gibson
Michigan Citv
R Gallagher
R Gallaaher
R Gallaaher
R Gallaaher
Wabash River
Wabash River
Wabash River
Wabash River
Coleman
Coleman
Coleman
E W Brown
E W Brown
Ghent
Green River
Hmo&L Station 2
Hmc&L Station 2
Paradise
C P Crane
Chalk Point
Moraantown
Moraantown
B L Enaland
B L Enaland
Cardinal
Conesville
Conesville
Eastlake
Gen J M Gavin
Gen J M Gavin
Muskinaum River
Muskinaum River
Muskinaum River
Muskinaum River
Niles
Niles
Picwav
R E Buraer
R E Buraer
R E Buraer
R E Buraer
Armstrona
Brunner Island
Brunner Island
Conemauah
Conemauah
Hatfield's Ferrv
Hatfield's Ferrv
Hatfield's Ferrv
Portland
Portland
Sunburv
Sunburv
Cumberland
Cumberland
Unit ID
5
7
MB1
2
Y1BR
Y6BR
Y7BR
7
8
1
2
4
12
1
2
3
4
1
2
5
6
Cl
C2
C3
2
3
1
5
HI
H2
3
1
1
1
2
1
2
1
1
3
5
1
2
1
2
3
4
1
2
9
5
6
7
8
1
2
3
1
2
1
2
3
1
2
3
4
1
2
Ph I Ext
Type
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
TRANSFER
TRANSFER
CONTROL
CONTROL
TRANSFER
TRANSFER
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
TRANSFER
CONTROL
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
CONTROL
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
CONTROL
1998 Allowance
Deduction
0
0
0
0
0
0
0
0
0
0
0
5609
3236
0
0
0
0
250
0
0
0
0
0
0
0
0
0
0
630
942
0
0
0
1863
0
0
0
10670
2871
4424
0
5379
4902
14921
3096
12198
14559
0
0
7218
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
-------
APPENDIX B-2: List of Phase I Extension Units and 1998 Deductions for Exceeding 1997 Projected Emissions
Limitations
State
TN
TN
TN
TN
WV
WV
WV
WV
WV
WV
WV
WV
Plant Name
Gallatin
Gallatin
Gallatin
Gallatin
Fort Martin
Fort Martin
Harrison
Harrison
Harrison
Mt Storm
Mt Storm
Mt Storm
Unit ID
1
2
3
4
1
2
1
2
3
1
2
3
Ph I Ext
Type
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
TRANSFER
CONTROL
CONTROL
CONTROL
TRANSFER
TRANSFER
CONTROL
1998 Allowance
Deduction
0
0
0
0
0
0
0
0
0
0
0
0
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1996 AND 1997
State Plant Name
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
AL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
Colbert
Colbert
Colbert
Colbert
Colbert
Colbert
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
E C Gaston
Gadsden
Gadsden
Big Bend
Big Bend
Big Bend
Big Bend
Big Bend
Big Bend
Crist
Crist
Crist
Crist
Scholz
Scholz
Arkwright
Arkwright
Arkwright
Arkwright
Arkwright
Bowen
Bowen
Bowen
Bowen
Hammond
Hammond
Hammond
Hammond
Hammond
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Harllee Branch
Stack/Unit ID
CSCO14(1,2, 3, 4)
1
2
3
4
5
CSOCAN(1,2)
1
2
CSOCBN (3, 4)
3
4
5
1
2
CS001 (BB01, BB02)
BB01
BB02
XS23 (BB03, BB04)
BB03
BB04
4
5
6
1
1
2
CS001 (1,2,3,4)
1
2
3
4
1BLR
2BLR
3BLR
4BLR
CS001 (1,2,3)
1
2
3
4
CS001 (1,2)
1
2
CS002 (3, 4)
3
1996
SO2 Utilization
Unit Tvoe (a) Emissions fmmBtu)
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
Table 1
Table 1
Substitution
Substitution
Substitution
31,939
58,218
22,028
19,812
33,819
4,893
5,168
76,818
19,081
2,513
2,566
13,304
14,853
2,735
3,186
4,386
34,032
36,655
46,269
40,205
7,246
14,364
26,616
39,409
12,952,183
12,618,216
10,114,184
13,855,269
34,058,704
15,064,260
16,306,916
14,032,114
14,192,836
48,089,378
3,518,404
3,649,976
31,111,381
31,794,469
28,490,272
35,141,092
3,215,872
3,291,052
16,798,233
17,764,345
1,099,257
1,316,280
815,186
754,577
920,206
850,114
44,244,090
47,089,666
61,120,578
52,430,313
3,515,633
2,751,274
3,572,759
19,191,000
14,360,313
14,456,249
19,090,017
B-3,1
1997 Percent Change. 1996-1997
SO2 Utilization SO2 Utilization
Emissions fmmBtu) Emissions fmmBtu)
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
16,571
29,845
53,136
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
4,809,927
23,714,698
13,643,892
13,727,469
25,801,742
-14.78%
-12.74%
13.26%
32.07%
6.73%
-3.62%
-5.65%
6.99%
6.40%
1.99%
69.68%
-23.01%
31.71%
-53.20%
-33.71%
-21.77%
9.43%
-8.13%
-11.76%
5.26%
18.81%
15.36%
12.13%
34.83%
-17.04%
-4.52%
-7.46%
-15.05%
-18.15%
-0.75%
-0.99%
25.29%
14.00%
-3.56%
-7.42%
-10.72%
-19.45%
-3.13%
-5.63%
6.07%
-6.25%
61.80%
-23.63%
30.81%
-23.53%
1.61%
-26.92%
17.27%
-0.08%
-17.45%
12.96%
-3.75%
-10.32%
9.04%
12.08%
21.96%
34.63%
23.57%
-4.99%
-5.04%
35.16%
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1996 AND 1997
1996
1997
Percent Change. 1996-1997
State
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
GA
IA
IA
IA
IA
IA
IA
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
Plant Name
Harllee Branch
Jack Mcdonough
Jack Mcdonough
Jack Mcdonough
Kraft
Kraft
Kraft
Kraft
Mcintosh
Mitchell
Wansley
Wansley
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Burlington
Des Moines
George Neal North
Milton L Kapp
Prairie Creek
Riverside
Baldwin
Baldwin
Baldwin
Coffeen
Coffeen
Coffeen
Collins
Collins
Collins
Collins
Grand Tower
Grand Tower
Stack/Unit ID
4
CS001 (MB1, MB2)
MB1
MB2
CS001 (1,2,3,4)
1
2
3
1
3
1
2
Y1BR
CS001 (Y2BR, Y3BR)
Y2BR
Y3BR
CS002 (Y4BR, Y5BR)
Y4BR
Y5BR
Y6BR
Y7BR
1
11
1
2
4
9
1
2
3
CS0001 (1,2)
1
2
CS1230(1,2, 3)
1
2
3
7
8
Unit Tvoe fa)
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
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
S02
Emissions
18,544
4,658
5,713
4,129
33,612
37,059
103
4,869
5,211
7,139
6,786
6,309
0
3,782
5,989
2,744
2,285
92,492
75,793
105,553
43,755
1,237
3,271
2,686
Utilization
fmmBtu)
25,267,007
14,011,717
13,696,390
1,626,008
1,220,370
2,376,381
6,698,411
3,956,533
40,844,610
44,775,798
2,858,072
3,418,865
3,189,297
3,775,583
3,086,657
11,140,080
10,667,714
9,611,935
0
9,453,477
11,236,532
8,290,105
5,487,073
35,993,704
29,324,128
40,432,952
16,654,324
31,814,222
6,755,310
6,510,067
9,007,079
1,402,802
1,190,947
S02
Emissions
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
734
3,606
3,733
Utilization
fmmBtu)
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
31,126,083
11,265,975
9,640,762
12,954,183
1,414,896
1,511,250
S02
Emissions
52.52%
56.01%
8.09%
-5.74%
1.47%
-12.96%
26.21%
31.69%
71.23%
31.57%
42.97%
0.68%
0.00%
6.82%
-19.20%
8.78%
11.38%
-4.38%
21.76%
-9.70%
9.14%
-40.66%
10.24%
38.98%
Utilization
fmmBtu)
2.27%
24.12%
31.71%
-8.65%
45.46%
79.82%
15.25%
11.31%
12.52%
0.98%
-10.34%
4.37%
18.61%
45.83%
46.61%
12.69%
21.07%
7.03%
0.00%
2.81%
-3.28%
2.39%
26.77%
-4.58%
20.57%
-8.05%
-19.76%
-2.16%
66.77%
48.09%
43.82%
0.86%
26.89%
B-3,2
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1996 AND 1997
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
IL
IL
IL
IL
IN
IN
IN
Grand Tower
Havana
Havana
Havana
Havana
Havana
Havana
Havana
Havana
Havana
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
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Newton
Newton
Vermilion
Vermilion
Vermilion
Wood River
Bailly
Bailly
Bailly
Stack/Unit ID
9
XS18(1,2, 3, 4, 5, 6, 7, 8)
1
2
3
4
5
6
7
8
2
5
6
CS1 (1,2)
1
2
CS2 (3, 4)
3
4
CSS (5, 6)
5
6
CS0102(1,2)
1
2
CS0001 (1,2,3,4)
1
2
3
4
5
6
1
2
CSS (1,2)
1
2
1
XS12(7, 8)
7
8
1996
SO2 Utilization
Unit Tvoe (a) Emissions fmmBtu)
Table 1
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
Substitution
Substitution
Substitution
Substitution
Table 1
Substitution
Substitution
Substitution
Substitution
Table 1
Substitution
Table 1
Table 1
13,596
0
39,842
10,772
8,529
8,572
8,071
8,644
20,051
6,672
15,943
112
11,148
15,404
579
0
3,835
5,945,488
0
0
0
0
0
0
0
0
15,675,990
4,959,359
3,814,018
14,960,182
15,969,238
15,215,573
13,102,754
15,574,434
14,937,071
20,133,483
21,671,782
1,044,625
708,893
664,115
903,356
11,667,552
373,709
27,174,200
32,173,480
358,330
743,988
0
12,840,429
18,413,238
1997 Percent Change. 1996-1997
SO2 Utilization SO2 Utilization
Emissions fmmBtu) Emissions fmmBtu)
18,586
0
38,878
8,640
10,982
7,731
7,998
8,472
41,096
11,912
15,950
268
16,698
13,619
6,208
0
4,736
7,209,130
0
0
0
0
0
0
0
0
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
1,374,433
1,491,596
1,085,073
1,254,116
10,034,553
861,578
8,356,418
30,265,558
1,488,706
2,826,121
513,068
12,242,636
19,485,943
36.70%
0.00%
-2.42%
-19.79%
28.76%
-9.81%
-0.90%
-1 .99%
104.96%
78.54%
0.04%
139.29%
49.78%
-11.59%
972.19%
0.00%
23.49%
21.25%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
-4.67%
-20.10%
29.00%
5.51%
-13.06%
-3.40%
18.77%
4.35%
7.06%
-8.69%
2.37%
31.57%
110.41%
63.39%
38.83%
-14.00%
130.55%
-69.25%
-5.93%
315.46%
279.86%
n/a
-4.66%
5.83%
Breed
Table 1
0.00%
0.00%
B-3,3
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1996 AND 1997
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
IN
IN
IN
IN
Cayuga
Cayuga
Clifty Creek
Cliffy Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Elmer W Stout
Elmer W Stout
Elmer W Stout
FBCulley
FBCulley
FBCulley
Frank E Rafts
Frank E Rafts
Gibson
Gibson
Gibson
Gibson
Gibson
Gibson
H T Pritchard
H T Pritchard
H T Pritchard
Michigan City
Petersburg
Petersburg
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R Gallagher
R Gallagher
Tanners Creek
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Wabash River
Stack/Unit ID
1
2
CS001 (1,2,3)
1
2
3
CS002 (4, 5, 6)
4
5
6
50
60
70
XS23 (2, 3)
2
3
1SG1
2SG1
CS0003 (1 , 2)
1
2
XS34 (3, 4)
3
4
CS596 (5, 6)
5
6
12
1
2
CS0001 (1,2)
1
2
CS0002 (3, 4)
3
4
U4
1
CS0005 (2, 3, 5, 6)
2
3
5
6
1996
SO2 Utilization
Unit Tvoe (a) Emissions fmmBtu)
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
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
38,676
32,134
50,661
53,668
6,045
5,466
26,764
4,800
5,284
8,066
91,546
44,266
7,068
14,841
10,473
16,002
21,609
28,826
59,876
4,197
38,986
31,117,238
24,405,552
16,465,964
15,821,604
16,401,939
16,332,747
18,078,609
16,547,688
5,588,803
4,806,792
24,589,328
5,328,808
20,119,291
4,590,729
7,114,275
37,712,577
41,393,737
30,798,399
37,063,085
1,463,618
5,275,111
30,794,272
17,644,936
32,737,948
6,645,958
8,185,232
11,064,458
9,937,363
30,441,214
5,111,474
4,532,020
4,199,125
3,972,597
17,273,741
1997 Percent Change. 1996-1997
SO2 Utilization SO2 Utilization
Emissions fmmBtu) Emissions fmmBtu)
56,992
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
36,475,622
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
3,873,572
4,755,001
17,074,386
47.36%
61.19%
-11.94%
-8.99%
23.14%
20.03%
-15.12%
7.33%
62.11%
-0.95%
-13.50%
11.08%
26.05%
2.84%
-72.38%
-73.99%
18.76%
-26.51%
2.45%
-74.96%
-3.61%
17.22%
36.53%
-6.08%
-12.11%
-4.96%
-7.69%
-17.55%
-10.40%
22.23%
20.54%
-14.89%
23.32%
-5.40%
61.88%
-5.42%
-8.49%
-11.93%
15.12%
28.03%
55.16%
28.74%
-18.58%
-0.16%
-1 .65%
15.44%
-2.08%
-45.16%
-41.45%
4.45%
54.44%
-3.11%
-7.75%
19.70%
-1.15%
B-3,4
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1996 AND 1997
State
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
Warrick
Wai-rick
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
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 Tvoe fa)
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 Utilization
Emissions fmmBtu)
37,290
55,629
6,372
1,715
17,749
19,919
19,488
16,652
5,500
33,012
11,023
6,280
7,484
10,192
13,334
2,315
3,578
146,291
1,085
2,314
2,399
9,479
7,314
15,581
13,163
37,211
6,195,697
4,496,464
6,377,241
26,106,280
44,868,034
1,535,354
10,119,011
11,620,382
11,302,035
6,203,553
11,866,456
5,585,611
9,847,964
25,069,168
43,733,535
8,264,788
19,624,228
38,126,562
4,951,922
19,356,664
12,528,434
13,374,978
60,987,316
18,663,054
16,982,755
9,307,313
17,544,316
9,908,995
12,760,058
10,904,815
19,675,719
B-3,5
S02
Emissions
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
Utilization
fmmBtu)
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
S02
Emissions
111.95%
-28.34%
8.71%
136.27%
-9.94%
-6.62%
-17.71%
-5.01%
6.71%
-7.49%
18.69%
22.42%
-1.14%
21.75%
17.51%
-7.47%
-30.63%
18.45%
-7.47%
-42.83%
-8.13%
12.31%
33.20%
-18.23%
29.53%
6.93%
Utilization
fmmBtu)
89.05%
184.17%
89.44%
-14.79%
-3.79%
380.16%
3.73%
8.76%
-1 .86%
-1.21%
-1.71%
-0.91%
2.04%
-17.71%
15.81%
45.18%
6.78%
1.59%
16.77%
19.24%
-7.39%
-5.23%
19.24%
-16.73%
6.36%
-4.05%
7.82%
19.76%
-23.78%
22.51%
-8.76%
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1996 AND 1997
State Plant Name
MD
MD
MD
MD
MD
MD
MD
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
MN
MN
MN
MN
MN
MN
MN
MN
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
Chalk Point
Chalk Point
Chalk Point
Morgantown
Morgantown
R P Smith
R P Smith
B C Cobb
Dan E Karn
Dan E Karn
J C Weadock
J C Weadock
J C Weadock
J H Campbell
J H Campbell
J H Campbell
J H Campbell
J R Whiting
J R Whiting
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
Meramec
Stack/Unit ID
2
3
4
1
2
9
11
4
1
2
CS0009 (7, 8)
7
8
CS0009 (1 , 2)
1
2
3
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
4
1996
SO2 Utilization
Unit Tvoe (a) Emissions fmmBtu)
Table 1
Substitution
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
Substitution
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
Substitution
2,678
1,354
37,236
35,542
78
2,069
6,336
9,765
9,506
10,792
22,771
22,141
4,433
4,236
3,768
10,156
6,339
8,352
2,358
4,874
8,513
11,681
6,899
51,536
36,790
3,344
3,522
5,682
4,678
16,341,786
4,153,249
6,556,094
37,010,782
35,650,179
107,596
2,833,072
11,310,884
16,478,448
15,850,441
8,551,701
9,538,250
15,942,587
20,946,592
47,025,128
7,084,353
6,515,893
1,397,090
1,915,234
5,087,413
9,292,112
51,389,952
51,477,248
11,502,268
26,458,409
2,206,094
3,885,157
7,562,737
37,988,343
20,875,392
42,373,060
31,934,417
3,684,584
4,040,199
6,226,032
5,282,678
1997 Percent Change. 1996-1997
SO2 Utilization SO2 Utilization
Emissions fmmBtu) Emissions fmmBtu)
2,716
1,155
39,650
33,341
71
2,264
3,979
8,807
9,694
10,679
21,219
23,853
3,558
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
7,040
21,531,764
7,631,900
5,790,004
38,101,385
31,834,220
92,709
2,986,412
6,805,495
14,730,605
16,458,054
6,903,489
12,153,154
15,183,312
19,817,269
49,783,254
5,626,938
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
10,263,395
1.42%
-14.70%
6.48%
-6.19%
-8.97%
9.42%
-37.20%
-9.81%
1.98%
-1 .05%
-6.82%
7.73%
-19.74%
13.34%
2.12%
-10.08%
45.70%
11.31%
-50.64%
-63.48%
-57.32%
6.60%
118.34%
-75.48%
-62.55%
-5.89%
-3.80%
-40.80%
50.49%
31.76%
83.76%
-11.69%
2.95%
-10.70%
-13.84%
5.41%
-39.83%
-10.61%
3.83%
-19.27%
27.41%
-4.76%
-5.39%
5.87%
-20.57%
15.63%
-17.64%
-15.57%
-27.38%
17.29%
-0.80%
-13.24%
23.50%
-2.54%
3.18%
-4.97%
-11.06%
-19.11%
68.98%
-13.01%
21.72%
29.10%
31.02%
-22.38%
94.28%
B-3,6
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1996 AND 1997
State Plant Name
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MS
MS
MS
MS
NH
NH
NJ
NJ
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
Montrose
Montrose
Montrose
Montrose
New Madrid
New Madrid
Rush Island
Rush Island
Sibley
Sibley
Sibley
Sibley
Sioux
Sioux
Southwest
Thomas Hill
Thomas Hill
Thomas Hill
Jack Watson
Jack Watson
R D Morrow
R D Morrow
Merrimack
Merrimack
B L England
B L England
Dunkirk
Dunkirk
Dunkirk
Dunkirk
Greenidge
Milliken
Milliken
Milliken
North port
North port
North port
North port
Oswego
Oswego
Stack/Unit ID
1
CS023 (2, 3)
2
3
1
2
1
2
CS0001 (1,2,3)
1
2
3
1
2
1
MB1
MB2
MBS
4
5
1
2
1
2
1
2
2
CS0003 (3, 4)
3
4
6
XS12(1,2)
1
2
1
2
3
4
4
5
1996
SO2 Utilization
Unit Tvoe (a) Emissions fmmBtu)
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
Table 1
Table 1
Table 1
Substitution
Table 1
Table 1
Substitution
Table 1
Table 1
Substitution
Substitution
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
Substitution
2,877
5,431
8,855
8,007
13,225
14,044
17,893
22,358
34,038
3,066
2,934
4,685
9,798
19,627
43,588
4,847
3,749
10,606
24,037
18,568
1,752
10,711
31,867
7,144
4,471
6,060
3,484
4,649
1,384
0
0
11,154,264
10,700,341
9,451,260
37,130,588
38,456,072
37,060,698
39,943,130
3,323,704
3,278,399
25,052,823
16,705,724
26,575,398
11,742,780
13,624,236
22,154,212
45,296,444
14,560,545
32,937,887
15,620,857
12,152,295
7,621,232
19,712,188
9,042,302
11,703,690
7,118,127
10,792,925
10,116,478
5,512,986
10,957,583
11,668,817
11,054,751
17,346,236
8,524,632
16,800,166
0
0
1997 Percent Change. 1996-1997
SO2 Utilization SO2 Utilization
Emissions fmmBtu) Emissions fmmBtu)
2,705
6,684
8,924
10,474
13,484
11,659
19,839
30,140
24,968
3,785
3,382
4,978
11,224
11,749
30,551
5,072
4,255
13,509
26,144
15,485
1,787
8,265
34,072
8,126
5,620
4,868
2,661
4,279
822
0
0
10,856,432
11,916,991
12,520,698
37,657,244
48,200,332
39,221,199
33,936,175
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
10,134,559
24,340,602
7,573,153
9,896,490
5,266,461
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
-5.98%
23.07%
0.78%
30.81%
1.96%
-16.98%
10.88%
34.81%
-26.65%
23.45%
15.27%
6.25%
14.55%
-40.14%
-29.91%
4.64%
13.50%
27.37%
8.77%
-16.60%
2.00%
-22.84%
6.92%
13.75%
25.70%
-19.67%
-23.62%
-7.96%
-40.61%
0.00%
0.00%
-2.67%
11.37%
32.48%
1.42%
25.34%
5.83%
-15.04%
-0.77%
-1 .23%
-5.77%
60.93%
-11.64%
19.76%
9.72%
1.09%
7.23%
-9.36%
2.12%
-5.67%
9.29%
32.98%
23.48%
-16.25%
-15.44%
-26.01%
-2.06%
13.89%
32.69%
-1 .69%
-4.30%
-19.83%
19.80%
-9.04%
20.74%
0.00%
0.00%
B-3,7
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1996 AND 1997
State Plant Name
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
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Oswego
Port Jefferson
Port Jefferson
Roseton
Roseton
Acme
Acme
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
Stack/Unit ID
6
3
4
1
2
13
14
15
16
91
92
7
CS1 (8,9, 10, 11)
8
9
10
11
9
10
11
12
CSS (1 , 2, 3, 4)
1
2
3
4
1
2
CS012(1,2)
1
2
3
4
1
2
3
4
5
11
12
13
1
2
1996
SO2 Utilization
Unit Tvoe (a) Emissions fmmBtu)
Substitution
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
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
772
2,835
4,499
2,903
4,021
0
0
0
0
0
0
41,910
25,409
1,231
3,668
0
27,863
25,025
76,138
28,212
25,264
12,794
58,778
13,095
13,779
10,599
22,538
60,719
0
0
4
28,370
40,672
3,242,998
5,475,689
8,003,758
6,148,402
7,670,038
0
0
0
0
0
0
12,131,030
1,841,817
1,608,432
2,174,929
2,343,541
1,685,434
5,121,816
0
34,561,596
7,693,884
6,622,437
7,582,696
10,498,676
29,017,768
26,408,584
5,267,264
5,867,919
5,872,821
27,390,004
6,729,324
7,530,250
5,833,256
11,184,656
31,917,980
0
0
169,446
85,368,952
100,099,832
1997 Percent Change. 1996-1997
SO2 Utilization SO2 Utilization
Emissions fmmBtu) Emissions fmmBtu)
1,080
1,890
1,602
4,380
7,132
0
0
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
5,955,023
10,691,389
7,149,114
9,526,581
16,206,427
0
0
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
39.90%
-33.33%
-64.39%
50.88%
77.37%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
-5.36%
-72.68%
-60.76%
16.52%
0.00%
0.62%
-44.56%
11.48%
108.49%
26.56%
28.37%
41.94%
25.08%
12.40%
51.75%
16.79%
-11.14%
0.00%
0.00%
-25.00%
-40.59%
-58.66%
83.63%
95.25%
-10.68%
54.94%
111.30%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
4.02%
-100.00%
-100.00%
-91.17%
-13.78%
-64.52%
-5.96%
0.00%
-5.65%
-14.92%
6.07%
-3.51%
3.00%
4.98%
38.00%
36.12%
23.98%
25.20%
36.92%
18.27%
-0.35%
37.41%
16.93%
-14.10%
0.00%
0.00%
12.44%
1.59%
-25.27%
B-3,8
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1996 AND 1997
State Plant Name
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Gorge
Gorge
J M Stuart
J M Stuart
J M Stuart
J M Stuart
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Lake Shore
Lake Shore
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
Miles
Miles
Miles
Picway
Poston
Poston
Poston
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
R E Burger
Stack/Unit ID
25
26
1
2
3
4
CS001 (1,2,3,4,5)
1
2
3
4
5
18
91
92
93
94
6
7
CS056(5-1,5-2, 6)
5-1
5-2
CS014(1,2, 3, 4)
1
2
3
4
5
XS12(1,2)
1
2
9
1
2
3
CS0001 (1,2,3,4,5,6,7,8)
1
2
3
4
5
6
7
8
1996
SO2 Utilization
Unit Tvoe (a) Emissions fmmBtu)
Substitution
Substitution
Substitution
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
Table 1
Table 1
0
0
22,910
28,054
25,957
22,226
123,599
1,433
0
0
0
0
38,985
14,421
160,368
20,223
22,485
15,071
0
0
0
62,557
0
0
32,856,554
39,776,416
36,913,980
31,602,492
15,541,682
15,701,555
15,148,702
14,375,389
16,381,780
2,396,829
0
0
0
0
12,392,706
38,049,581
516,801
516,801
9,743,860
10,890,512
11,872,478
11,380,074
36,993,688
7,986,488
5,619,661
5,014,683
0
0
0
0
0
0
0
342,333
345,590
12,358,365
10,058,514
1997 Percent Change. 1996-1997
SO2 Utilization SO2 Utilization
Emissions fmmBtu) Emissions fmmBtu)
0
0
23,885
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
0
0
33,042,560
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
7,661,698
36,213,342
876,111
876,111
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
10,903,432
10,116,964
0.00%
0.00%
4.26%
2.96%
-3.20%
21.25%
-9.85%
-65.32%
0.00%
0.00%
0.00%
0.00%
-0.82%
-30.05%
0.97%
8.15%
-40.67%
11.76%
0.00%
0.00%
0.00%
-25.12%
0.00%
0.00%
0.57%
1.18%
-4.76%
18.02%
-6.54%
-3.47%
0.01%
1.83%
-8.68%
-29.40%
0.00%
0.00%
0.00%
0.00%
-38.18%
-4.83%
69.53%
69.53%
25.19%
-14.48%
-5.64%
4.23%
1.94%
-3.42%
-40.62%
15.60%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
120.54%
87.73%
-11.77%
0.58%
B-3,9
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1996 AND 1997
State Plant Name
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
PA
PA
PA
Toronto
Toronto
Toronto
WH Sammis
WHSammis
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
Shawville
Sunbury
Sunbury
Stack/Unit ID
9
10
11
5
6
1
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
4
3
4
1996
SO2 Utilization
Unit Tvoe (a) Emissions fmmBtu)
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
Table 1
Table 1
Table 1
0
0
0
12,247
30,444
27,966
22,761
40,041
16,496
15,654
5,831
8,159
47,771
44,832
39,980
3,376
3,732
153,413
24,601
2,442
3,016
728
0
0
11,963
13,820
10,587
13,474
29,884
9,511
10,939
0
0
0
17,229,437
40,507,621
39,173,092
15,965,398
27,366,092
11,760,419
10,843,803
39,049,744
51,758,064
19,038,246
21,075,806
39,299,942
32,374,384
56,341,839
60,156,610
32,091,132
33,885,414
27,107,067
10,422,634
7,831,516
5,348,032
8,813,199
9,346,753
0
0
8,004,960
9,654,232
7,071,835
8,841,290
12,231,908
9,337,793
7,316,803
8,495,968
1997 Percent Change. 1996-1997
SO2 Utilization SO2 Utilization
Emissions fmmBtu) Emissions fmmBtu)
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
11,343
11,326
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
12,363,361
8,209,041
8,102,198
0.00%
0.00%
0.00%
35.70%
8.90%
8.02%
-36.11%
-17.34%
-1 .30%
7.62%
12.42%
-12.70%
-7.08%
16.77%
18.83%
11.20%
-6.16%
-9.64%
-3.82%
-14.74%
-35.74%
48.35%
0.00%
0.00%
-3.25%
26.36%
43.86%
15.85%
10.64%
19.26%
3.54%
0.00%
0.00%
0.00%
20.01%
-5.97%
-11.02%
-23.43%
2.26%
-7.56%
6.51%
29.81%
-15.61%
-13.02%
2.31%
15.99%
15.56%
17.67%
1.46%
-23.21%
-13.45%
29.90%
-7.24%
26.37%
29.37%
-36.02%
78.32%
0.00%
0.00%
-4.46%
24.01%
36.78%
11.54%
-15.12%
32.40%
12.19%
-4.63%
B-3,10
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1996 AND 1997
State Plant Name
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
Wl
Wl
Wl
Wl
Wl
Wl
Wl
Wl
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
Edgewater
Edgewater
Genoa
J P Madgett
Nelson Dewey
Nelson Dewey
Nelson Dewey
North Oak Creek
North Oak Creek
North Oak Creek
North Oak Creek
Pulliam
Pulliam
Pulliam
Pulliam
Stack/Unit ID
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 (B4, B5)
B4
B5
3
4
1
B1
CS1 (1, 2)
1
2
1
2
3
4
CS56 (5, 6)
5
6
7
1996
SO2 Utilization
Unit Tvoe (a) Emissions fmmBtu)
Table 1
Table 1
Table 1
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
Substitution
Substitution
Substitution
Table 1
Table 1
Substitution
Table 1
Table 1
Table 1
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
5,434
6,503
8,395
9,524
13,252
0
0
0
0
55,363
61,303
126,367
3,471
1,482
7,378
11,420
4,145
3,836
0
0
0
0
1,518
1,574
13,232,597
15,751,898
13,330,030
88,223,696
121,294,176
0
0
0
0
14,169,010
15,977,846
15,888,894
18,810,130
8,771,161
8,608,948
9,183,864
8,805,822
5,801,129
8,424,067
10,200,693
10,405,425
7,736,863
9,778,394
1,924,740
2,887,317
4,283,009
21,529,980
17,924,364
15,667,498
6,313,485
6,231,595
0
0
0
0
2,476,389
3,796,526
6,789,476
1997 Percent Change. 1996-1997
SO2 Utilization SO2 Utilization
Emissions fmmBtu) Emissions fmmBtu)
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
6,092
0
0
0
0
2,141
1,540
14,847,074
16,492,487
17,656,804
111,236,832
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
2,637,034
3,645,037
4,010,042
19,448,932
23,336,894
21,777,568
8,239,503
8,457,749
0
0
0
0
3,268,887
5,354,200
6,492,200
24.29%
9.70%
-11.42%
3.38%
-16.07%
0.00%
0.00%
0.00%
0.00%
-7.93%
7.87%
-8.25%
61.57%
9.31%
8.00%
11.65%
19.32%
58.81%
0.00%
0.00%
0.00%
0.00%
41.04%
-2.16%
12.20%
4.70%
32.46%
26.08%
-2.14%
0.00%
0.00%
0.00%
0.00%
-0.16%
-12.83%
7.08%
-3.38%
-27.20%
1.92%
-6.30%
-4.06%
35.28%
-25.52%
-18.84%
-10.23%
17.04%
-35.83%
37.01%
26.24%
-6.37%
-9.67%
30.20%
39.00%
30.51%
35.72%
0.00%
0.00%
0.00%
0.00%
32.00%
41.03%
-4.38%
B-3,11
-------
APPENDIX B-3: EMISSIONS AND UTILIZATION OF PHASE 1 UNITS, 1996 AND 1997
State
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
wv
wv
wv
wv
wv
wv
Plant Name
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
Mt Storm
Mt Storm
Rivesville
Rivesville
Willow Island
Willow Island
Stack/Unit ID
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
CS013(1,2, 3)
1
2
3
CS012(1,2)
1
2
CSO(1,2)
1
2
3
7
8
1
2
Unit Tvoe fa)
Table 1
Substitution
Substitution
Table 1
Table 1
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
Table 1
Table 1
Table 1
Substitution
Substitution
Substitution
Substitution
S02
Emissions
2,445
1,337
1,389
13,543
20,718
1,106
2,021
1,449
1,962
9,246
33,684
37,468
16,469
119,369
53,152
107,211
5,096
233
1,037
1,872
6,739
Utilization
fmmBtu)
10,388,203
4,420,448
4,396,844
14,710,533
9,735,973
18,264,686
18,247,312
3,536,812
6,567,751
1,190,327
1,675,656
7,663,974
26,435,504
29,454,119
50,422,229
49,485,012
46,729,368
15,233,808
12,862,993
14,005,666
47,955,776
34,334,844
40,588,560
43,397,872
28,675,658
287,932
1,232,614
1,841,991
7,224,854
S02
Emissions
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
4,052
235
1,234
1,790
8,067
Utilization
fmmBtu)
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
35,476,403
36,446,948
45,013,972
299,093
1,531,972
1,713,256
8,554,928
S02
Emissions
-7.40%
16.68%
27.86%
14.10%
25.18%
19.17%
-16.97%
8.90%
-14.27%
1.45%
26.86%
18.54%
-61.76%
5.78%
7.69%
-13.52%
-20.49%
0.86%
19.00%
-4.38%
19.71%
Utilization
fmmBtu)
-5.18%
-4.35%
10.80%
3.21%
-2.38%
20.50%
4.47%
24.40%
-13.29%
6.63%
-20.44%
-3.29%
36.26%
26.26%
-3.52%
-2.14%
-1 .69%
-9.89%
17.23%
24.09%
-16.54%
47.32%
-12.60%
-16.02%
56.98%
3.88%
24.29%
-6.99%
18.41%
NOTES: (a) Identifies the affected unit as listed in Table 1, or as a substitution, compensating, or opt-in unit.
B-3,12
-------
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
GA
GA
GA
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
Hammond
Hammond
Harllee B anch
Harllee B anch
Harllee B anch
Harllee B anch
Harllee B anch
Harllee B anch
Jack Mcdonough
Jack Mcdonough
Jack Mcdonough
Kraft
Kraft
Kraft
Kraft
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
3
4
CS001 (1 , 2)
1
2
CS002 (3, 4)
3
4
CS001 (MB1, MB2)
MB1
MB2
CS001 (1 , 2, 3, 4)
1
2
3
Unit Type (a)
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
SO2
Emissions
1996 (b)
31,939
58,218
22,028
19,812
33,819
4,893
5,168
76,818
19,081
2,513
2,566
13,304
14,853
2,735
3,186
4,386
34,032
36,655
46,269
40,205
7,246
14,364
26,616
39,409
18,544
4,658
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
16,571
29,845
53,136
28,284
7,267
1997
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
8,676
36,650
19,221
22,735
31,280
31,042
19,386
20,058
2,265
2,137
4,121
Held in
Unit Accounts
as of 1/30/98
14,781
20,654
19,207
20,849
55,883
20,277
21,191
19,849
25,106
39,407
6,303
6,911
38,367
47,216
40,281
10,488
23,497
22,485
29,645
33,239
20,024
19,969
2,437
2,240
3,944
3,159
40,784
65,469
87,459
89,372
8,549
8,977
8,676
60,946
30,640
41,182
47,122
46,406
38,772
40,116
4,293
4,369
7,305
Allowances
Deducted for
Emissions (d)
6,417
7,515
5,927
7,361
50,803
11,996
12,953
13,625
12,540
36,094
4,716
4,876
36,986
45,205
14,212
6,091
2,563
4,354
10,243
19,563
1,280
2,112
858
858
858
857
37,241
33,675
40,828
42,319
2,870
2,870
2,869
16,571
14,923
14,922
26,568
26,568
14,142
14,142
1,433
1,712
4,122
Deducted Under Allowances
Special Phase I Carried Over
Provisions to 1998
8,364
13,139
13,280
13,488
5,080
8,281
8,238
6,224
12,566
3,313
1,587
2,035
1,381
2,011
26,069
4,397
20,934
18,131
19,402
13,676
18,744
17,857
1,579
1,382
3,086
2,302
3,543
31,794
46,631
47,053
5,679
6,107
5,807
44,375
15,717
26,260
20,554
19,838
24,630
25,974
2,860
2,657
3,183
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
IA
IA
IA
IA
IA
IA
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
IL
Plant Name
Mcintosh
Mtehell
Wansley
Wansley
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Yates
Bur ngton
Des Moines
George Neal North
Milton L Kapp
Pra rie Creek
Riverside
Baldwin
Baldwin
Baldwin
Coffeen
Coffeen
Coffeen
Collins
Collins
Collins
Collins
Grand Tower
Grand Tower
Grand Tower
Ha ana
Ha ana
Ha ana
Ha ana
Ha ana
Ha ana
Ha ana
Ha ana
Ha ana
Hennepin
Hutsonville
Hutsonville
Joppa Steam
Joppa Steam
Joppa Steam
Stack/Unit ID
1
3
1
2
Y1BR
CS001 (Y2BR, Y3BR)
Y2BR
Y3BR
CS002 (Y4BR, Y5BR)
Y4BR
Y5BR
Y6BR
Y7BR
1
11
1
2
4
9
1
2
3
CS0001 (1 , 2)
1
2
CS1 230(1, 2, 3)
1
2
3
7
8
9
XS18(1, 2, 3, 4, 5, 6, 7, 8)
1
2
3
4
5
6
7
8
2
5
6
CS1 (1 , 2)
1
2
Unit Type (a)
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Substitution
Substitution
Tablel
Tablel
SO2
Emissions
1996 (b)
5,713
4,129
33,612
37,059
103
4,869
5,211
7,139
6,786
6,309
0
3,782
5,989
2,744
2,285
92,492
75,793
105,553
43,755
1,237
3,271
2,686
13,596
0
39,842
10,772
8,529
8,572
SO2
Emissions
1997(b)
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
734
3,606
3,733
18,586
0
38,878
8,640
10,982
7,731
1997
Allowances
Allocated (c)
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
39,102
1,217
1,050
1,856
1,068
1,015
6,479
34
43
34
34
34
34
34
34
20,182
9,661
9,837
12,259
10,487
Held in
Unit Accounts
as of 1/30/98
10,261
21,584
86,728
79,977
14,234
13,710
13,534
17,352
18,324
48,216
41,830
15,660
0
8,296
26,872
15,578
7,542
92,821
95,044
97,851
15,509
35,360
3,203
2,642
5,080
3,690
3,892
18,802
350
43
34
34
34
34
34
34
41,466
8,721
11,062
28,446
23,130
Allowances
Deducted for
Emissions (d)
6,175
3,892
34,105
32,258
130
3,206
3,206
4,462
4,461
9,393
9,702
6,352
0
4,040
4,839
2,985
2,545
88,439
92,284
95,312
15,364
32,392
245
245
244
3,606
3,733
18,586
0
0
0
0
0
0
0
0
38,878
8,640
10,982
3,865
3,866
Deducted Under Allowances
Special Phase I Carried Over
Provisions to 1998
4,086
17,692
52,623
47,719
14,104
10,504
10,328
12,890
13,863
38,823
32,128
9,308
0
4,256
201 (e) 21,832
12,593
4,997
4,382
53 (e) 2,707
2,539
145
2,968
2,958
2,397
4,836
84
159
216
23 (e) 327
30 (e) 13
23 (e) 1 1
23 (e) 1 1
23 (e) 1 1
23 (e) 1 1
23 (e) 1 1
23 (e) 1 1
1,624
81
80
24,581
19,264
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
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
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Joppa Steam
Kincaid
Kincaid
Kincaid
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Meredosia
Newton
Newton
Vermilion
Vermilion
Vermilion
Wood River
Bailly
Bailly
Bailly
Breed
Cayuga
Cayuga
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Clifty Creek
Elmer W Stout
Elmer W Stout
Elmer W Stout
F B Culley
F B Culley
F B Culley
Frank E Rafts
Frank E Rafts
Gibson
Gibson
Gibson
Gibson
Gibson
Gibson
Stack/Unit ID
CS2 (3, 4)
3
4
CSS (5, 6)
5
6
CS0102(1, 2)
1
2
CS0001 (1 , 2, 3, 4)
1
2
3
4
5
6
1
2
CSS (1 , 2)
1
2
1
XS12(7, 8)
7
8
1
1
2
CS001 (1 , 2, 3)
1
2
3
CS002 (4, 5, 6)
4
5
6
50
60
70
XS23 (2, 3)
2
3
1SG1
2SG1
CS0003 (1 , 2)
1
2
XS34 (3, 4)
3
4
Unit Type (a)
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
SO2
Emissions
1996 (b)
8,071
8,644
20,051
6,672
15,943
112
11,148
15,404
579
0
3,835
0
38,676
32,134
50,661
53,668
6,045
5,466
26,764
4,800
5,284
8,066
91,546
44,266
SO2
Emissions
1997(b)
7,998
8,472
41,096
11,912
15,950
268
16,698
13,619
6,208
0
4,736
0
56,992
51,796
44,612
48,844
7,444
6,561
22,717
5,152
8,566
7,989
79,183
49,170
1997
Allowances
Allocated (c)
11,947
11,061
11,119
10,341
34,564
37,063
1,245
1,355
1,173
1,078
15,227
44
14,599
6,346
12,972
9,735
0
15,981
21,592
20,280
36,581
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
Held in
Unit Accounts
as of 1/30/98
27,960
25,301
22,952
20,618
33,564
37,063
3,310
3,660
2,746
3,143
16,328
407
16,928
14,495
16,086
19,122
12
5,840
19,550
53,390
72,517
66,877
22,350
19,254
19,886
20,761
19,418
25,512
7,703
6,872
23,548
6,760
24,264
13,798
10,708
51,581
53,347
54,897
48,392
Allowances
Deducted for
Emissions (d)
3,999
3,999
4,236
4,236
20,548
20,548
3,129
3,392
2,478
2,913
15,950
268
16,698
13,619
2,173
4,035
0
1,610
3,126
0
56,992
51,796
14,871
14,871
14,870
16,281
16,281
16,282
7,444
6,561
22,717
5,152
0
8,566
7,989
38,879
40,304
39,798
9,372
Deducted Under Allowances
Special Phase I Carried Over
Provisions to 1998
23,961
21,302
18,716
16,382
13,016
16,515
181
268
268
230
378
139
230
876
1147(e) 12,766
1258(e) 13,829
12
4,230
16,424
53,390
15,525
15,081
7,479
4,383
5,016
4,480
3,137
9,230
259
311
831
1,608
24,264
5,232
2,719
12,702
13,043
15,099
39,020
H T Pritchard
CS596 (5, f
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
KS
KS
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
KY
Plant Name
H T Pritchard
H T Pritchard
Michigan City
Petersburg
Petersburg
RGallaghe
RGallaghe
RGallaghe
RGallaghe
RGallaghe
RGallaghe
Tanners Creek
Wabash Rive
Wabash Rive
Wabash Rive
Wabash Rive
Wabash Rive
Wabash Rive
Warrick
Warrick
Warrick
Warrick
Warrick
La Cygne
Quindaro
Cole man
Cole man
Cole man
Cooper
Cooper
Cooper
E W Brown
E W Brown
E W Brown
E W Brown
East Bend
Elmer Smith
Elmer Smith
Elmer Smith
Ghent
Green River
H L Spurlock
Hmp&L Station 2
Hmp&L Station 2
Paradise
R D Green
R D Green
Stack/Unit ID
5
6
12
1
2
CS0001 (1 , 2)
1
2
CS0002 (3, 4)
3
4
U4
1
CS0005 (2, 3, 5, 6)
2
3
5
6
XS123(1, 2, 3)
1
2
3
4
1
2
C1
C2
C3
CS1 (1 , 2)
1
2
1
CS003 (2, 3)
2
3
2
XS12(1, 2)
1
2
1
5
1
H1
H2
3
G1
G2
Unit Type (a)
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Opt-In
Opt-In
Opt-In
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
SO2
Emissions
1996 (b)
14,841
10,473
16,002
21,609
28,826
59,876
4,197
38,986
37,290
55,629
6,372
1,715
17,749
19,919
19,488
16,652
5,500
33,012
11,023
6,280
7,484
10,192
13,334
2,315
3,578
146,291
1,085
2,314
SO2
Emissions
1997(b)
15,262
2,893
4,162
25,662
21,183
61,344
1,051
37,577
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
1997
Allowances
Allocated (c)
1,458
6,325
25,553
18,011
35,496
7,115
7,980
7,159
8,386
27,209
5,502
3,135
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
17,887
17,053
57,613
5,041
5,827
Held in
Unit Accounts
as of 1/30/98
2,347
6,889
76,494
3,134
4,382
16,595
16,509
13,659
13,136
142,970
3,801
6,116
6,445
7,800
24,302
27,472
31,793
25,861
40,358
7,208
6,637
16,398
19,084
16,456
10,199
21,273
21,757
33,787
81,493
18,735
2,400
5,600
85,270
26,598
39,852
9,441
7,957
277,612
9,658
11,170
Allowances
Deducted for
Emissions (d)
2,254
6,655
15,262
2,893
4,162
12,543
13,119
10,842
10,341
61,344
1,051
5,439
4,847
5,995
21,296
25,917
27,571
25,549
39,864
6,927
4,052
15,985
18,600
16,037
5,220
10,598
5,869
9,975
20,563
13,083
2,306
5,382
7,399
12,409
15,669
2,142
2,482
173,285
1,004
1,323
Deducted Under Allowances
Special Phase I Carried Over
Provisions to 1998
93
234
61,232
241
220
4,052
3,390
2,817
2,795
81,626
2,750
677
1,598
1,805
3,006
1,555
1309(e) 2,913
312
494
281
2,585
413
484
419
4,979
10,675
15,888
23,812
60,930
5,652
94
218
77,871
14,189
24,183
7,299
5,475
104,327
8,654
9,847
B-4, 4
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
KY
MA
MA
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
MD
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
Ml
MN
MN
MN
MN
MN
MN
MN
MN
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
Plant Name
Shawnee
Brayton Point
Mount Tom
C P Crane
C P Crane
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Chalk Point
Morgantown
Morgantown
R P Smith
R P Smith
B C Cobb
Dan E Karn
Dan E Karn
J C Weadock
J C Weadock
J C Weadock
J H Campbell
J H Campbell
J H Campbell
J H Campbell
J R Whiting
J R Whiting
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
Meramec
Stack/Unit ID
10
2
1
1
2
CSE12(1, 2)
1
2
3
4
1
2
9
11
4
1
2
CS0009 (7, 8)
7
8
CS0009 (1 , 2)
1
2
3
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
4
Unit Type (a)
Tablel
Compensating
Substitution
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Substitution
Substitution
Tablel
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
SO2
Emissions
1996 (b)
2,399
9,479
7,314
15,581
13,163
37,211
2,678
1,354
37,236
35,542
78
2,069
6,336
9,765
9,506
10,792
22,771
22,141
4,433
4,236
3,768
10,156
6,339
8,352
2,358
4,874
8,513
11,681
6,899
51,536
36,790
3,344
3,522
5,682
4,678
SO2
Emissions
1997(b)
2,204
10,646
9,742
12,740
17,050
39,789
2,716
1,155
39,650
33,341
71
2,264
3,979
8,807
9,694
10,679
21,219
23,853
3,558
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
7,040
1997
Allowances
Allocated (c)
9,902
15,838
10,708
10,058
8,987
21,333
23,690
9,000
1,519
34,332
37,467
386
3,128
5,325
10,151
10,984
5,473
5,451
18,773
22,453
25,847
4,304
5,498
299
242
410
4,158
4,681
4,727
15,764
6,927
2,536
4,304
4,722
39,055
36,718
39,249
34,994
1,816
1,948
4,166
4,507
Held in
Unit Accounts
as of 1/30/98
10,354
24,783
13,955
54,893
19,952
21,486
26,261
12,716
3,675
47,580
40,009
74
2,378
5,482
9,778
10,662
4,256
7,491
10,138
13,231
27,743
4,562
5,911
3,303
2,060
3,310
9,040
15,837
15,778
31,176
9,427
5,038
5,120
4,599
40,163
44,300
44,436
38,669
4,202
4,313
4,714
8,982
Allowances
Deducted for
Emissions (d)
2,204
10,646
9,742
12,740
17,050
18,091
21,698
2,716
1,155
39,650
33,341
71
2,264
3,979
8,807
9,694
3,868
6,811
9,205
12,014
23,853
3,558
4,801
253
356
829
2,410
4,869
4,263
9,236
9,297
1,164
1,780
3,633
12,452
15,063
12,635
13,777
3,147
3,388
3,364
7,040
Deducted Under Allowances
Special Phase I Carried Over
Provisions to 1998
8,150
14,137
4,213
42,153
221 (f) 2,681
3,395
4,563
10,000
2,520
7,930
6,668
3
114
1,503
971
968
388
680
933
1,217
3,890
1,004
1,110
3,050
1,704
2,481
6,630
10,968
11,515
21,940
130
3,874
3,340
966
27,711
29,237
31,801
24,892
1,055
925
1,350
1,942
B-4, 5
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MO
MS
MS
MS
MS
NH
NH
NJ
NJ
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
NY
OH
Plant Name
Montrose
Montrose
Montrose
Montrose
New Madrid
New Madrid
Rush Island
Rush Island
Sibley
Sibley
Sibley
Sibley
Sioux
Sioux
Southwest
Thomas Hill
Thomas Hill
Thomas Hill
Jack Watson
Jack Watson
R D Morrow
R D Morrow
Merrimack
Merrimack
B L England
B L England
Dunkirk
Dunkirk
Dunkirk
Dunkirk
Greenidge
Milliken
Milliken
Milliken
North port
North port
North port
North port
Oswego
Oswego
Oswego
Port Jefferson
Port Jefferson
Roseton
Roseton
Acme
Stack/Unit ID
1
CS023 (2, 3)
2
3
1
2
1
2
CS0001 (1 , 2, 3)
1
2
3
1
2
1
MB1
MB2
MBS
4
5
1
2
1
2
1
2
2
CS0003 (3, 4)
3
4
6
XS12(1, 2)
1
2
1
2
3
4
4
5
6
3
4
1
2
13
Unit Type (a)
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Substitution
Tablel
Tablel
Substitution
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
SO2
Emissions
1996 (b)
2,877
5,431
8,855
8,007
13,225
14,044
17,893
22,358
34,038
3,066
2,934
4,685
9,798
19,627
43,588
4,847
3,749
10,606
24,037
18,568
1,752
10,711
31,867
7,144
4,471
6,060
3,484
4,649
1,384
0
0
772
2,835
4,499
2,903
4,021
0
SO2
Emissions
1997(b)
2,705
6,684
8,924
10,474
13,484
11,659
19,839
30,140
24,968
3,785
3,382
4,978
11,224
11,749
30,551
5,072
4,255
13,509
26,144
15,485
1,787
8,265
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
1997
Allowances
Allocated (c)
7,196
7,984
9,824
27,497
31,625
26,935
30,146
2,782
3,332
15,170
21,976
23,067
3,906
9,980
18,880
14,011
17,439
35,734
4,571
5,002
9,922
21,421
8,822
14,886
9,414
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
B-4, 6
Held in
Unit Accounts
as of 1/30/98
2,840
3,370
3,560
27,497
28,625
46,168
54,185
5,120
6,749
22,034
36,270
30,484
4,540
4,480
14,380
14,011
19,887
39,161
5,794
6,864
14,544
26,770
15,822
4,412
9,414
33,216
22,319
18,058
18,271
17,378
14,832
7,403
15,612
10,103
1,121
12,365
7,437
6,602
9,607
19,147
16,872
0
Allowances
Deducted for
Emissions (d)
2,705
3,262
3,422
8,924
10,474
13,484
11,659
2,381
2,381
15,077
30,140
24,968
3,785
3,382
4,978
11,224
11,749
30,551
5,072
4,255
13,509
26,144
15,485
1,787
8,265
16,355
17,717
8,126
2,891
2,729
4,868
2,661
4,279
822
0
0
1,080
1,890
1,602
4,380
7,132
0
Deducted Under Allowances
Special Phase I Carried Over
Provisions to 1998
135
108
138
18,573
18,151
32,684
42,526
2,739
4,368
6,957
6,130
5,516
755
1,098
9,402
2,787
8,138
8,610
722
2,609
1,035
626
337
2,625
1,149
16,861
4,602
9,932
15,380
14,649
9,964
4,742
11,333
9,281
1,121
12,365
6,357
4,712
8,005
1435(e) 13,332
176(e) 9,564
0
-------
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
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
OH
Plant Name
Acme
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
Cones ille
Cones ille
Cones ille
Cones ille
Cones ille
Eastlake
Eastlake
Eastlake
Eastlake
Eastlake
Edgewater
Edgewater
Edgewater
Gen J M Gavin
Gen J M Gavin
Gorge
Gorge
J M Stuart
J M Stuart
J M Stuart
J M Stuart
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Kyger Creek
Lake Shore
Lake Shore
Lake Shore
Lake Shore
Stack/Unit ID
14
15
16
91
92
7
CS1 (8, 9, 10, 11)
8
9
10
11
9
10
11
12
CSS (1 , 2, 3, 4)
1
2
3
4
1
2
CS012(1, 2)
1
2
3
4
1
2
3
4
5
11
12
13
1
2
25
26
1
2
3
4
CS001 (1 , 2, 3, 4, 5)
1
2
3
4
5
18
91
92
93
Unit Type (a)
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
SO2
Emissions
1996 (b)
0
0
0
0
0
41,910
25,409
1,231
3,668
0
27,863
25,025
76,138
28,212
25,264
12,794
58,778
13,095
13,779
10,599
22,538
60,719
0
0
4
28,370
40,672
0
0
22,910
28,054
25,957
22,226
123,599
1,433
0
0
0
SO2
Emissions
1997(b)
0
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
28,883
25,127
26,949
111,419
497
0
0
0
1997
Allowances
Allocated (c)
12
16
1,930
740
662
18,351
10,753
9,173
8,275
8,706
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
39,041
38,712
40,925
18,773
18,072
17,439
18,218
18,247
4,508
44
80
62
Held in
Unit Accounts
as of 1/30/98
0
0
0
0
0
42,659
0
0
5,902
1,790
584
4,622
0
31,037
3,267
3,066
3,343
5,500
89,119
77,183
24,980
16,891
17,245
86,181
18,020
17,036
17,799
28,978
57,618
0
0
200
17,639
31,425
0
0
41,878
36,006
35,618
40,293
22,783
22,783
22,783
22,783
22,783
598
0
0
0
Allowances
Deducted for
Emissions (d)
0
0
0
0
0
39,662
0
0
5,345
1,597
483
4,274
0
28,037
3,052
2,775
3,052
4,995
84,875
58,818
15,888
16,087
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
28,883
25,127
26,949
22,284
22,284
22,284
22,284
22,283
497
0
0
0
Deducted Under Allowances
Special Phase I Carried Over
Provisions to 1998
0
0
0
0
0
2,997
0
0
557
193
101
348
0
3,000
215
291
291
505
4,244
18,365
9,092
804
821
2,753
1,641
1,549
1,715
2,656
3,666
0
0
197
785
14,613
0
0
17,993
7,123
10,491
13,344
499
499
499
499
500
101
0
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
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
Plant Name
Lake Shore
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Miami Fort
Muskingum Ri e
Muskingum Ri e
Muskingum Ri e
Muskingum Ri e
Muskingum Ri e
Muskingum Ri e
Miles
Miles
Miles
Picway
Poston
Poston
Poston
R E Surge
R E Surge
R E Surge
R E Surge
R E Surge
R E Surge
R E Surge
R E Surge
R E Surge
Toronto
Toronto
Toronto
WH Sammis
WH Sammis
WH Sammis
Walter C Beckiord
Walter C Beckiord
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
Stack/Unit ID
94
6
7
CS056 (5-1 , 5-2, 6)
5-1
5-2
CS014(1, 2, 3, 4)
1
2
3
4
5
XS12(1, 2)
1
2
9
1
2
3
CS0001 (1, 2, 3, 4, 5, 6, 7, 8)
1
2
3
4
5
6
7
8
9
10
11
5
6
7
5
6
1
2
1
2
CS102(1, 2)
1
2
3
1
1
2
XS123(1, 2, 3)
1
2
Unit Type (a)
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
SO2
Emissions
1996 (b)
0
38,985
14,421
160,368
20,223
22,485
15,071
0
0
0
62,557
0
0
0
12,247
30,444
27,966
22,761
40,041
16,496
15,654
5,831
8,159
47,771
44,832
39,980
3,376
3,732
153,413
SO2
Emissions
1997(b)
0
38,666
10,087
161,924
21,872
13,340
16,843
0
0
0
46,842
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
1997
Allowances
Allocated (c)
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
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
11,537
27,030
30,282
52,404
38,139
81,450
91,666
36,835
36,338
Held in
Unit Accounts
as of 1/30/98
0
11,815
49,193
1,213
1,211
46,605
35,307
43,001
45,107
98,221
7,608
9,975
17,684
3,797
3,542
4,642
0
0
0
0
2,300
2,100
25,818
24,000
0
0
0
21,500
38,000
76,730
19,394
37,080
17,096
17,689
17,963
18,848
39,615
46,901
92,661
52,542
17,623
17,253
39,840
48,042
Allowances
Deducted for
Emissions (d)
0
8,076
38,666
1,006
1,005
44,386
33,626
40,953
42,959
21,872
5,415
7,925
16,843
0
0
0
0
0
0
0
1,282
1,040
23,052
21,468
0
0
0
16,619
33,154
30,208
14,542
33,099
16,282
16,847
6,555
7,123
19,283
25,108
52,349
47,510
3,754
3,502
37,943
45,754
Deducted Under Allowances
Special Phase I Carried Over
Provisions to 1998
0
3,739
10,527
207
206
2,219
1,681
2,048
2,148
76,349
2,193
2,050
841
3,797
3,542
4,642
0
0
0
0
1,018
1,060
2,766
2,532
0
0
0
4,881
4,846
46,522
4,852
3,981
814
842
11,408
11,581
20,332
21,793
40,312
5,032
13,869
13,751
1,897
2,288
B-4, 8
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
State
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
TN
Wl
Wl
Wl
Wl
Wl
Plant Name
Hatfield's Ferry
Martins Creek
Martins Creek
Martins Creek
Martins Creek
Martins Creek
Mitchell
New Castle
New Castle
Portland
Portland
Shawville
Shawville
Shawville
Shawville
Shawville
Sunbury
Sunbury
Allen
Allen
Allen
Cumberland
Cumberland
DuPont Johnsonville
DuPont Johnsonville
DuPont Johnsonville
DuPont Johnsonville
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Gallatin
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Johnsonville
Alma
Alma
Alma
Edgewater
Edgewater
Stack/Unit ID
3
CS102(1, 2)
1
2
3
4
33
1
2
1
2
1
2
CS1 (3, 4)
3
4
3
4
1
2
3
1
2
JVD1
JVD2
JVD3
JVD4
CSGA12(1, 2)
1
2
CSGA34 (3, 4)
3
4
CSJO10(1, 2, 3, 4, 5, f
1
2
3
4
5
6
7
8
9
10
CS1 (B4, B5)
B4
B5
3
4
Unit Type (a)
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Opt-In
Opt-In
Opt-In
Opt-In
Tablel
Tablel
Tablel
Tablel
i, 7, 8, 9, 10)
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Tablel
SO2
Emissions
1996 (b)
24,601
2,442
3,016
728
0
0
11,963
13,820
10,587
13,474
29,884
9,511
10,939
5,434
6,503
8,395
9,524
13,252
0
0
0
0
55,363
61,303
126,367
3,471
1,482
7,378
SO2
Emissions
1997(b)
23,661
2,082
1,938
1,080
0
0
11,574
17,463
15,230
15,609
33,064
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
1997
Allowances
Allocated (c)
39,210
12,327
12,483
12,553
11,548
1,101
1,367
1,520
5,784
9,961
10,048
10,048
13,846
13,700
8,530
11,149
14,917
16,329
15,258
114,325
126,157
1,778
1,778
1,777
1,777
17,400
16,855
19,493
20,701
7,585
7,828
8,189
7,780
8,023
7,682
8,744
8,471
6,894
7,351
2,207
3,624
4,493
24,099
Held in
Unit Accounts
as of 1/30/98
57,679
27,556
27,288
22,664
20,080
1,134
0
0
45,304
18,090
16,180
16,584
15,978
19,165
25,511
24,324
17,029
18,410
21,518
163,284
155,249
0
0
0
0
28,217
27,854
35,426
37,316
12,916
16,724
16,522
16,227
12,637
10,676
13,397
15,010
14,612
10,056
9,299
16,817
10,831
14,583
Allowances
Deducted for
Emissions (d)
54,933
11,693
11,968
2,082
1,938
1,080
0
0
11,574
17,463
15,230
15,609
15,029
18,035
11,343
11,326
6,754
7,134
7,436
9,846
11,122
0
0
0
0
25,663
25,311
32,201
33,928
9,317
12,803
12,597
12,329
11,488
9,158
12,178
13,644
13,284
9,140
2,804
2,804
1,620
7,968
Deducted Under Allowances
Special Phase I Carried Over
Provisions to 1998
2,746
15,863
15,320
20,582
18,142
54
0
0
33,730
627
950
975
949
1,130
14,168
12,998
10,275
11,276
14,082
153,438
144,127
0
0
0
0
2,554
2,543
3,225
3,388
3,599
3,921
3,925
3,898
1,149
1,518
1,219
1,366
1,328
916
6,495
14,013
9,211
6,615
11,420
12,750
22,103
13,026
B-4, 9
-------
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
Wl
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
wv
Plant Name
J P Madgett
Nelson Dewey
Nelson Dewey
Nelson Dewey
North Oak Creek
North Oak Creek
North Oak Creek
North Oak Creek
Pulliam
Pulliam
Pulliam
Pulliam
Pulliam
Rock River
Rock River
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
South Oak Creek
Weston
Weston
Albright
Albright
Albright
Fort Martin
Fort Martin
Harrison
Harrison
Harrison
Harrison
Kammer
Kammer
Kammer
Kammer
Mitchell
Mitchell
Mitchell
Mt Storm
Mt Storm
Mt Storm
Mt Storm
Rivesville
Rivesville
Willow Island
Willow Island
Stack/Unit ID
B1
CS1 (1 , 2)
1
2
1
2
3
4
CS56 (5, 6)
5
6
7
8
1
2
CSS (5, 6)
5
6
CS4 (7, 8)
7
8
1
2
1
2
3
1
2
XS123(1, 2, 3)
1
2
3
CS013(1, 2, 3)
1
2
3
CS012(1, 2)
1
2
CSO (1 , 2)
1
2
3
7
8
1
2
Unit Type (a)
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Tablel
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Tablel
Substitution
Substitution
Substitution
Substitution
SO2
Emissions
1996 (b)
4,145
3,836
0
0
0
0
1,518
1,574
2,445
1,337
1,389
13,543
20,718
1,106
2,021
1,449
1,962
9,246
33,684
37,468
16,469
119,369
53,152
107,211
5,096
233
1,037
1,872
6,739
SO2
Emissions
1997(b)
4,946
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
4,052
235
1,234
1,790
8,067
1997
Allowances
Allocated (c)
6,407
5,852
6,504
5,083
5,005
5,229
6,154
2,097
2,844
7,317
7,312
5,398
4,034
9,416
11,723
15,754
15,375
1,579
3,580
4,831
5,024
11,684
40,496
40,116
68,078
64,488
57,730
18,247
18,948
16,932
42,823
44,312
42,570
34,644
56,589
1,009
3,059
1,855
7,765
Held in
Unit Accounts
as of 1/30/98
10,240
8,736
10,369
0
0
0
0
980
1,590
1,800
2,700
13,220
9,279
10,453
6,544
15,287
13,241
1,773
2,000
1,657
1,766
9,849
44,870
46,634
2,262
2,243
2,106
39,647
43,421
49,520
75,177
75,957
65,008
54,923
115,845
247
1,296
3,735
8,470
Allowances
Deducted for
Emissions (d)
4,946
2,998
3,094
0
0
0
0
814
1,327
1,540
2,264
1,560
1,776
9,503
5,949
13,897
12,037
1,318
1,678
1,578
1,682
9,380
42,733
44,413
2,156
2,136
2,006
37,758
41,353
47,162
25,390
31,849
46,358
46,358
4,052
235
1,234
1,790
8,067
Deducted Under Allowances
Special Phase I Carried Over
Provisions to 1998
5,294
5,738
7,275
0
0
0
0
166
263
260
436
11,660
7,503
950
595
1,390
1,204
455
322
79
84
469
2,137
2,221
106
107
100
1,889
2,068
2,358
49,787
44,108
18,650
8,565
111,793
12
62
1,945
403
NOTES:
B-4, 10
-------
APPENDIX B-4: EMISSIONS AND ALLOWANCE HOLDINGS OF PHASE 1 UNITS
SO2 SO2 1997 Held in Allowances Deducted Under Allowances
Emissions Emissions Allowances Unit Accounts Deducted for Special Phase I Carried Over
State Plant Name Stack/Unit ID Unit Type (a) 1996 (b) 1997(b) Allocated (c) as of 1/30/98 Emissions (d) Provisions to 1998
(a) Identifies the affected unit as listed in Table 1, or as a substitution, compensating, or opt-in unit.
(b) Both 1996 and 1997 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 1997 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) Deducted due to underutilization provisions. There is no effective SO2 emissions cap during Phase I for units not affected by the
Acid Rain Program until Phase II. Therefore, if underutilization were not taken into account, Phase I units could potentially shift their generation
responsibilities to Phase II units without surrendering allowances for the additional emissions resulting at those units. To ensure that allowances are
surrendered in this instance, each Phase I unit must explain any underutilization during Phase I (1995-1999). Any Phase I unit that had a lower
heat input in 1996 than the average heat input during the 1985-87 baseline years (i.e., was utilized less) must surrender allowances unless it explains
this decrease by shifts in generation to sulfur-free generators (e.g., hydroelectric or nuclear generators), energy conservation, improved unit efficiency,
overutilization at other Phase I units in the dispatch system, utilization of compensating units, or a decrease in dispatch system sales. If the reasons
for the underutilization do not fall into one or more of these categories, then it is presumed that the Phase I unit shifted generation to sulfur-emitting
Phase II units and the Phase I unit has to surrender allowances. The amount of allowances surrendered is based on the amount of unexplained
underutilization and the emission rates of the Phase II units.
(f) Deduction due to control-by-contract provisions. A Table I unit is allowed to designate a Phase II unit as a substitution unit only if both units are
under the control of the same owner or operator. A Table I unit must show a certain level of ownership interest and/or share a common operator with
the substitution unit, or have a contract between the owners and operators of the units that demonstrates a certain level of control of the substitution
unit (control-by-contract) by the Table I unit's owners and operators. This contract, among other things, is required to contain a commitment to reduce
the emissions rate at the substitution unit designated under ths provision by 30 percent or more. If the substitution unit fails to meet this reduction, it is
not subject to an enforcement action, but the Phase I unit that designated it must surrender allowances to cover the additional emissions released by
the substitution unit.
B-4,11
-------
APPENDIX C
Appendix C-l: List of Averaging Plans and Results in 1997
Appendix C-2: Compliance Results for the 265 NOX Affected Units in 1997
Appendix C-3: Compliance Results for the 272 Early Election Units in 1997
-------
Appendix C-l: List of Averaging Plans and Results in 1997
Operating Utility
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
Alabama Power Co
CIPSCO
Dairyland Power Coop
East Kentucky Power Coop
Georgia Power Co
GPU
26 ECGastonALl-5
7 GadsdenALl-2
862 Grand Tower IL 07-09
863 Hutsonville IL 05, 06
864 MeredosiaILOl-05
6017 Newton ILL 2
4140 AlmaWIB4,B5
4143 Genoa WI 1
4271 JPMadgettWIBl
1384 Cooper KYI, 2
699 ArkwrightGA 1-4
703 Bowen GA 1BLR - 4BLR
708 Hammond GA 1-4
709 Harllee Branch GA 2
7 1 0 Jack Mcdonough GA MB 1 , MB2
733 Kraft GA 1-3
6124 McintoshGAl
727 Mitchell GA 3
6257 Scherer GA 3
6052 WansleyGAl,2
728 Yates GA Y1BR - Y7BR
3113 Portland PA 1,2
0.48
0.46
0.48
0.50
0.46
0.45
0.44
0.43
0.45
0.40
0.44
0.37
C-l, 1
-------
Appendix C-l: List of Averaging Plans and Results in 1997
Operating Utility
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
Gulf Power Co
Hoosier Energy
IES Utilities, Inc.
Illinois Power Co
Indianapolis Power & Light
Kentucky Utilities Company
Monongahela Power Co
641 Crist FL 4-7
2049 Jack Watson MS 4, 5
642 ScholzFLl,2
6073 Victor J Daniel Jr MS 1 . 2
1043 Frank E Ratts IN 1SG1, 2SG1
1104 Burlington IA 1
1073 Prairie Creek IA 4
889 Baldwin IL 3
892 Hennepin IL 2
897 Vermilion IL 1,2
990 Elmer W Stout IN 50, 60, 70
991 H T Pritchard IN 3-6
994 Petersburg IN 1-4
1355 EW Brown KY 1-3
1356 Ghent KYI
1357 Green River KY 5
3942 Albright WV 1-3
3178 Armstrong PA 1,2
3944 Harrison WV 1-3
3943 Fort Martin WV 1
3181 Mitchell PA 3 3
6004 PleasantsPA 1,2
1570 RP Smith PA 9, 11
0.48
0.50
0.47
0.45
0.45
0.46
0.49
0.42
0.49
0.29
0.38
0.34
0.42
0.45
C-l, 2
-------
Appendix C-l: List of Averaging Plans and Results in 1997
Operating Utility
ORIS Code Plant Name, State and Units
Plan Limit
Plan Rate
NYSEG
Northern States Power Co
Ohio Edison Co
PP&L
PSI Energy, Inc.
South Mississippi Elec Power
2527
2535
Greenidge NY 6
MillikenNYL2
1912
6090
High Bridge MN 3-6
Sherburne County MN 1, 2
6094
2857
2858
3138
2867
2864
2866
Bruce Mansfield PA 1 , 2
EdgewaterOH13
Gorge OH 25, 26
New Castle PA 1,2
Toronto OH 10, 11
R E Burger OH 7, 8
W H Sammis OH 5, 6
3140
3148
3152
Brunner Island PA 1-3
Martins Creek PA 1,2
Sunbury PA 3, 4
1001
6018
6113
2832
1008
1010
2830
CayugaINl,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
6061
RD Morrow MS 1,2
C-l, 3
-------
Appendix C-l: List of Averaging Plans and Results in 1997
Operating Utility
ORIS Code Plant Name, State and Units
Springfield City of (MO)
2161
6195
James River MO 3-5
Southwest MO 1
TVA
Union Electric Co
Wisconsin Electric Power
Wisconsin Public Service Corp
47
3403
3406
Colbert AL 1-5
GallatinTNl-4
Johnsonville TN 1-10
2103
2104
6155
LabadieMO 1-4
Meramec MO 1-4
Rush Island MO 1,2
4040
4041
4042
Port Washington WI 1-4
South Oak Creek WI 5-8
Valley WI 1-4
4072
4078
Pulliam WI 7, 8
Weston WI 1-3
Plan Limit
Plan Rate
C-l, 4
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1997
1997
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
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
Standard Limitation
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
Averaging
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
;Plan
Actual AELor Actual 1990 Change
Emission Emission Avg. Plan Avg. Plan Emission from 1990
Limit Rate Limit Rate Rate to 1997
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
0.46
0.46
0.46
0.46
0.40
0.43
0.43
0.42
0.42
0.42
0.64
0.68
0.41
0.52
0.59
0.45
0.44
0.67
0.77
0.77
0.77
0.77
0.77
0.43
0.44
0.43
0.42
0.83
0.83
0.83
0.46
0.72
0.47
0.47
0.47
0.47
0.47
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
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
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.42
0.42
0.42
0.42
0.42
0.42
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.44
0.80
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
-43%
-31%
-45%
-47%
-49%
-52%
-45%
-48%
-48%
-46%
25%
21%
-11%
21%
20%
-57%
-62%
-3%
-4%
-14%
-14%
-14%
-14%
-36%
-32%
-23%
-28%
-1%
-1%
-1%
-62%
-27%
C-2, 1
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1997
1997
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
0.42
0.42
0.62
0.62
0.62
0.86
0.62
0.30
0.41
0.41
0.45
0.48
0.48
0.39
0.39
0.33
0.31
0.29
0.35
0.29
0.36
0.33
0.73
0.76
0.61
0.49
0.53
0.54
0.28
0.28
0.26
0.26
AEL or
Avg. Plan
Limit
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.46
0.47
0.47
0.45
0.46
0.46
0.46
0.45
0.46
0.46
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
0.29
0.29
0.38
0.43
0.43
0.43
0.38
0.43
0.43
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 1997
-36%
-30%
55%
55%
55%
4%
2%
50%
-44%
-39%
-20%
-23%
-23%
-30%
-40%
-51%
-49%
-54%
-56%
-72%
-56%
-51%
-6%
-21%
-5%
-17%
-24%
-19%
-50%
-50%
-54%
-54%
C-2, 2
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1997
1997
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
Hoosier Energy
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
0.24
0.24
0.50
0.50
0.50
0.50
0.69
0.29
0.38
0.42
0.42
0.32
0.34
0.35
0.38
0.32
0.47
0.47
0.49
0.48
0.52
0.52
0.43
0.42
0.69
0.69
0.36
0.36
0.26
0.33
0.33
0.36
AEL or
Avg. Plan
Limit
0.46
0.46
0.46
0.46
0.46
0.46
0.46
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
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.38
0.43
0.43
0.34
0.34
0.34
0.49
0.49
0.43
0.43
0.43
0.43
0.34
0.34
0.34
0.34
0.34
0.34
0.34
0.34
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 1997
-57%
-57%
0%
0%
0%
0%
3%
-38%
-3%
-55%
-43%
-24%
-28%
-44%
-42%
-55%
-55%
-62%
-55%
-56%
-50%
-54%
-17%
-36%
-7%
-7%
-46%
-23%
-54%
-48%
-11%
-3%
C-2, 3
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1997
1997
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 UtiLks 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
0.43
0.43
0.40
0.40
0.15
0.58
0.59
0.48
0.40
0.34
0.34
0.46
0.46
0.48
0.40
0.40
0.48
0.42
0.42
0.40
0.43
0.41
0.40
0.44
0.48
0.46
0.38
0.46
0.65
0.65
0.63
0.64
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
0.40
0.40
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 1997
-42%
-55%
-58%
-58%
-71%
-39%
-36%
-44%
8%
17%
-47%
-67%
-64%
-58%
-56%
-56%
-52%
-29%
-26%
29%
-50%
-27%
-52%
-51%
-64%
-66%
-7%
2%
-52%
-52%
-34%
-33%
C-2, 4
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1997
1997
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
MBS
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
0.67
0.43
0.48
0.63
0.63
0.63
0.63
0.27
0.27
0.37
0.29
0.55
0.62
0.58
0.22
0.25
0.22
0.21
0.67
0.53
0.61
0.33
0.32
0.38
0.38
0.20
0.18
0.33
0.28
0.49
0.64
0.43
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
0.45
0.45
0.33
0.33
0.33
0.33
0.33
0.33
0.45
0.45
0.45
0.24
0.24
0.24
0.24
0.24
0.24
0.24
0.24
0.24
0.24
0.45
0.42
0.42
0.45
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 1997
-23%
-45%
-30%
31%
31%
31%
31%
-40%
-40%
3%
-6%
-46%
-29%
-38%
-65%
-60%
-65%
-66%
-18%
-16%
-36%
-72%
0%
12%
12%
-68%
-71%
-30%
-10%
-55%
-48%
2%
C-2, 5
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1997
1997
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
Emission
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
Actual
Emission
Rate
0.48
0.28
0.26
0.32
0.32
0.50
0.36
0.36
0.41
0.45
0.42
0.42
0.38
0.41
0.35
0.17
Not Oper.
Not Oper.
0.59
0.40
0.79
0.77
Not Oper.
Not Oper.
0.45
0.38
0.45
0.42
0.36
0.36
0.35
0.37
AEL or
Avg. Plan
Limit
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
0.45
0.42
0.42
0.40
0.40
0.40
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.43
0.45
0.45
0.43
0.43
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 1997
12%
4%
-7%
-33%
-33%
-9%
-45%
-39%
-33%
-52%
-24%
-14%
-44%
-24%
-31%
-80%
-19%
-54%
20%
7%
-13%
-65%
-38%
-41%
-60%
-65%
-64%
-67%
C-2, 6
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1997
1997
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
Emission
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
Actual
Emission
Rate
0.37
0.37
0.42
0.41
0.39
0.38
0.45
0.45
0.39
Not Oper.
Not Oper.
0.30
0.41
0.49
0.49
0.43
0.43
0.42
0.42
0.39
0.39
0.39
0.39
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
AEL or
Avg. Plan
Limit
0.47
0.47
0.47
0.47
0.47
0.49
0.50
0.50
0.45
0.45
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
0.47
Actual
Avg. Plan
Rate
0.41
0.41
0.41
0.41
0.41
0.45
0.43
0.43
0.37
0.37
0.41
0.41
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
0.65
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 1997
-43%
-48%
-49%
-42%
-40%
-46%
-56%
-52%
-43%
-35%
-38%
-51%
-52%
-48%
-48%
-55%
-67%
-34%
-38%
-34%
-29%
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 1997
1997
ST
TN
UT
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
Plant Name
Johnsonville
Gadsby
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
Operating Utility
TVA
Pacificorp
Dairyland Power Coop
Dairyland Power Coop
Dairyland Power Coop
Dairyland 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
ORIS
Code
3406
3648
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
Boiler
10
3
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
Compliance Approach
Averaging Plan
Standard Limitation
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
Emission
Limit
0.50
0.45
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
Actual
Emission
Rate
0.47
0.07
0.79
0.79
0.47
0.34
0.32
0.32
0.32
0.30
Not Oper.
0.35
0.36
0.24
0.24
0.40
0.40
0.44
0.44
0.52
0.52
0.80
0.78
0.21
0.65
0.71
0.39
0.63
0.47
0.47
0.47
0.51
AEL or
Avg. Plan
Limit
0.47
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.47
0.47
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.48
0.47
0.47
0.47
0.49
0.49
0.49
0.49
0.49
0.49
0.49
0.56
Actual
Avg. Plan
Rate
0.44
0.45
0.45
0.45
0.45
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.36
0.45
0.45
0.45
0.45
0.45
0.45
0.45
1990
Emission
Rate
1.07
0.53
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
Change
from 1990
to 1997
-56%
-87%
-7%
-7%
-37%
13%
0%
0%
0%
-19%
-49%
-37%
-14%
-14%
-39%
-40%
-60%
-60%
-50%
-44%
-11%
-28%
-19%
-41%
-35%
-45%
2%
-53%
-58%
-56%
-34%
C-2, 8
-------
Appendix C-2: Compliance Results for the 265 Phase I NOX Affected Units in 1997
1997
ST
WV
WV
WV
WV
WV
WY
WY
WY
WY
Plant Name
Mitchell
Mt Storm
Mt Storm
Pleasants
Pleasants
Jim Bridger
Jim Bridger
Jim Bridger
Wyodak
Operating Utility
Ohio Power Co
Vepco
Vepco
Monongahela Power Co
Monongahela Power Co
Pacificorp
Pacificorp
Pacificorp
Pacificorp
ORIS
Code
3948
3954
3954
6004
6004
8066
8066
8066
6101
Boiler
2
1
3
1
2
BW71
BW72
BW73
BW91
Compliance Approach
AEL Demonstration
Extension1
AEL Demonstration2
Averaging Plan
Averaging Plan
Standard Limitation
Standard Limitation
Standard Limitation
Standard Limitation
Emission
Limit
0.50
0.45
0.45
0.50
0.50
0.45
0.45
0.45
0.50
Actual
Emission
Rate
0.51
0.79
0.65
0.38
0.35
0.39
0.36
0.39
0.31
AEL or
Avg. Plan
Limit
0.56
0.49
0.49
Actual
Avg. Plan
Rate
0.45
0.45
1990
Emission
Rate
0.77
0.88
1.27
0.52
0.35
0.63
0.51
0.42
0.37
Change
from 1990
to 1997
-34%
-10%
-49%
-27%
0%
-38%
-29%
-7%
-16%
1 Extension granted through 7/31/97 and Alternative Emission Limit pending.
Alternative Emission Limitation pending.
C-2, 9
-------
Appendix C-3: Compliance Results for the 272 Early Election Units in 1997
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
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
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 Proj
Salt River Proj
Salt River Proj
Salt River Proj
Salt River Proj
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
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
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
NSPS1
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
D
Da
D
Da
D
Emission Actual
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
0.48
0.49
0.30
0.28
0.26
0.36
0.35
0.47
0.43
0.40
0.33
0.35
0.30
0.44
0.43
0.36
0.37
0.43
0.39
0.40
0.45
0.35
0.24
0.24
0.34
0.36
0.34
0.21
0.32
0.38
0.28
0.25
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
0.66
0.56
Change from
1990 to 1997
-23%
-26%
-3%
-18%
-26%
24%
3%
-19%
-26%
-13%
-21%
-3%
-21%
-14%
-16%
-12%
-10%
16%
15%
21%
-38%
-31%
0%
-23%
-13%
-10%
-13%
-66%
-26%
-30%
-58%
-55%
New Source Performance Standards subpart.
C-3, 1
-------
Appendix C-3: Compliance Results for the 272 Early Election Units in 1997
ST
FL
FL
FL
FL
FL
FL
FL
FL
FL
GA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IA
IL
IL
IL
IL
IL
IL
IL
IL
IN
IN
Plant Name
C D Mcintosh Jr
Crystal River
Crystal River
Crystal River
Deerhaven
Seminole
Seminole
St Johns River Power
St Johns River Power
Scherer
Ames
Ames
Council Bluffs
Council Bluffs
Council Bluffs
George Neal North
George Neal North
George Neal South
Lansing
Louisa
Ottumwa
Crawford
Crawford
Dallman
Fisk
Waukegan
Waukegan
Will County
Will County
A B Brown
A B Brown
Operating Utility
City of Lakeland
Florida Power Corporation
Florida Power Corporation
Florida Power Corporation
Gainesville Regional Util
Seminole Electric Coop Inc
Seminole Electric Coop Inc
Jacksonville Electric Auth
Jacksonville Electric Auth
Georgia Power Co
City of Ames
City of Ames
Midamerican Energy Company
Midamerican Energy Company
Midamerican Energy Company
Midamerican Energy Company
Midamerican Energy Company
Midamerican Energy Company
Interstate Power Co
Midamerican Energy Company
IES Utilities, Inc.
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
ORIS
Code
676
628
628
628
663
136
136
207
207
6257
1122
1122
1082
1082
1082
1091
1091
7343
1047
6664
6254
867
867
963
886
883
883
884
884
6137
6137
Boiler
3
2
4
5
B2
1
2
1
2
4
7
8
1
2
3
2
3
4
4
101
1
7
8
33
19
7
8
3
4
1
2
NSPS1
D
D
D
D
Da
Da
Da
Da
D
D
D
D
D
D
D
D
D
D
Da
Emission Actual
Limit Emission Rate
0.50
0.45
0.50
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.50
0.50
0.45
0.50
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.44
0.43
0.49
0.49
0.49
0.42
0.40
0.48
0.48
0.32
0.36
0.43
0.41
0.34
0.40
0.46
0.47
0.43
0.40
0.27
0.36
0.32
0.40
0.34
0.35
0.34
0.39
0.40
0.35
0.43
0.46
1990
Emission Rate
0.46
0.38
0.50
0.47
0.53
0.43
0.36
0.50
0.59
0.21
0.60
0.55
0.56
0.33
0.37
1.06
0.39
0.64
0.50
0.25
0.69
0.33
0.48
0.55
0.39
0.26
0.41
0.39
0.31
0.61
0.39
Change from
1990 to 1997
-4%
13%
-2%
4%
-8%
-2%
11%
-4%
-19%
52%
-40%
-22%
-27%
3%
8%
-57%
21%
-33%
-20%
8%
-48%
-3%
-17%
-38%
-10%
31%
-5%
3%
13%
-30%
18%
New Source Performance Standards subpart.
C-3, 2
-------
Appendix C-3: Compliance Results for the 272 Early Election Units in 1997
IN
ST
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
IN
KS
KS
KS
KY
KY
KY
KY
KY
KY
KY
KY
KY
LA
LA
LA
Dean H Mitchell
Plant Name
Dean H Mitchell
Dean H Mitchell
Dean H Mitchell
Merom
Merom
R M Schahfer
R M Schahfer
R M Schahfer
Rockport
Rockport
State Line
Whitewater Valley
Whitewater Valley
Nearman Creek
Riverton
Riverton
Cane Run
Cane Run
Cane Run
D B Wilson
Mill Creek
Mill Creek
Mill Creek
Mill Creek
Trimble County
Big Cajun 2
Big Cajun 2
Big Cajun 2
Northern Indiana Pub Serv
Operating Utility
Northern Indiana Pub Serv
Northern Indiana Pub Serv
Northern Indiana Pub Serv
Hoosier Energy
Hoosier Energy
Northern Indiana Pub Serv
Northern Indiana Pub Serv
Northern Indiana Pub Serv
Indiana Michigan Power Co
Indiana Michigan Power Co
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
Louisville Gas & Electric
Louisville Gas & Electric
Louisville Gas & Electric
Louisville Gas & Electric
Louisville Gas & Electric
Cajun Electric Power
Cajun Electric Power
Cajun Electric Power
996
ORIS
Code
996
996
996
6213
6213
6085
6085
6085
6166
6166
981
1040
1040
6064
1239
1239
1363
1363
1363
6823
1364
1364
1364
1364
6071
6055
6055
6055
4
Boiler
5
6
11
1SG1
2SG1
15
17
18
MB12
MB22
3
1
2
Nl
39
40
4
5
6
Wl
1
2
3
4
1
2B1
2B2
2B3
NSPS1
D
D
D
Da
Da
D
D
D
Da
D
D
D
D
D
D
0.45 0.34
Emission Actual
Limit Emission Rate
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.45
0.50
0.50
0.45
0.50
0.45
0.50
0.50
0.45
0.50
0.50
0.45
0.50
0.45
0.45
0.50
0.50
0.45
0.50
0.50
0.50
0.34
0.33
0.33
0.41
0.40
0.21
0.38
0.36
0.35
0.35
0.24
0.41
0.41
0.43
0.38
0.40
0.43
0.47
0.39
0.48
0.42
0.44
0.42
0.47
0.41
0.31
0.30
0.27
0.43
1990
Emission Rate
0.43
0.58
0.58
0.23
0.63
0.42
0.46
0.44
0.32
0.32
0.32
0.71
0.71
0.46
0.83
0.55
0.84
1.15
1.02
0.56
0.76
0.79
0.62
0.57
0.62
0.28
0.25
0.24
-21%
Change from
1990 to 1997
-21%
-43%
-43%
78%
-37%
-50%
-17%
-18%
9%
9%
-25%
-42%
-42%
-7%
-54%
-27%
-49%
-59%
-62%
-14%
-45%
-44%
-32%
-18%
-34%
11%
20%
13%
1 New Source Performance Standards subpart.
Conditionally in compliance pending Phase I permit review.
C-3, 3
-------
Appendix C-3: Compliance Results for the 272 Early Election Units in 1997
LA
LA
ST
LA
MI
MI
MI
MI
MI
MI
MI
MI
MI
MI
MN
MN
MO
MT
MT
MT
MT
MT
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
Dolet Hills
R S Nelson
Plant Name
Rodemacher
B C Cobb
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
Central Louisiana Elec Co
Gulf States Utilities
Operating Utility
Central Louisiana Elec Co
Consumers Energy Co
Consumers Energy Co
City of Grand Haven
Consumers Energy Co
Consumers Energy Co
Consumers Energy Co
Consumers Energy Co
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
51
1393
ORIS
Code
6190
1695
1695
1825
1720
1720
1723
1723
1769
1769
1769
1893
1943
6768
6076
6076
6076
6076
6089
2720
2720
2720
2720
2720
2721
2721
2721
2721
2721
2723
1
6
Boiler
2
4
5
3
7
8
1
3
7
8
9
3
2
1
1
2
3
4
Bl
5
6
7
8
9
1
2
3
4
5
1
D 0.50 0.45
D 0.45 0.42
Emission Actual
NSPS1 Limit Emission Rate
D 0.50
0.45
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
0.37
0.40
0.37
0.48
0.41
0.41
0.38
0.39
0.44
0.42
0.44
0.32
0.38
0.37
0.39
0.41
0.40
0.40
0.37
0.45
0.45
0.44
0.44
0.45
0.44
0.44
0.38
0.44
0.44
0.44
0.62
0.20
1990
Emission Rate
0.38
0.38
0.36
0.51
0.44
0.44
0.82
1.04
0.49
0.53
0.66
0.42
0.58
0.51
0.42
0.43
0.34
0.35
0.57
0.59
0.54
0.57
0.45
0.51
Not Oper.
Not Oper.
Not Oper.
Not Oper.
0.51
0.52
-27%
110%
Change from
1990 to 1997
-3%
5%
3%
-6%
-7%
-7%
-54%
-63%
-10%
-21%
-33%
-24%
-34%
-27%
-7%
-5%
18%
14%
-35%
-24%
-17%
-23%
-2%
-12%
-14%
-15%
New Source Performance Standards subpart.
C-3, 4
-------
Appendix C-3: Compliance Results for the 272 Early Election Units in 1997
NC
NC
ST
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
NC
ND
ND
ND
ND
NE
NE
NE
NE
NE
NE
NM
NV
NV
NV
NV
NV
Dan River
Dan River
Plant Name
G G Allen
G G Allen
G G Allen
G G Allen
G G Allen
Marshall
Marshall
Marshall
Marshall
RiverbEnd
RiverbEnd
RiverbEnd
RiverbEnd
Antelope Valley
Antelope Valley
Leland Olds
Stanton
Gerald Gentleman Sta
Gerald Gentleman Sta
Gerald Whelan Energy
Nebraska City
North Omaha
Platte
Escalante
Mohave
Mohave
North Valmy
North Valmy
Reid Gardner
Duke Energy Corporation
Duke Energy Corporation
Operating Utility
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
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
2723
2723
ORIS
Code
2718
2718
2718
2718
2718
2727
2727
2727
2727
2732
2732
2732
2732
6469
6469
2817
2824
6077
6077
60
6096
2291
59
87
2341
2341
8224
8224
2324
2
3
Boiler
1
2
3
4
5
1
2
3
4
7
8
9
10
Bl
B2
1
10
1
2
1
1
4
1
1
1
2
1
2
4
0.45 0.44
0.45 0.44
Emission Actual
NSPS1 Limit Emission Rate
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
D 0.45
D 0.45
0.50
Da 0.45
D 0.50
D 0.50
D 0.45
D 0.50
0.45
D 0.45
Da 0.45
0.45
0.45
D 0.50
Da 0.50
Da 0.50
0.43
0.44
0.44
0.43
0.43
0.43
0.44
0.44
0.44
0.42
0.40
0.43
0.43
0.29
0.28
0.27
0.40
0.48
0.34
0.26
0.43
0.31
0.37
0.39
0.42
0.39
0.30
0.29
0.27
0.55
0.56
1990
Emission Rate
0.65
0.61
0.64
0.68
0.68
0.48
0.61
0.52
0.70
0.58
0.64
Not Oper.
Not Oper.
0.43
0.27
0.74
0.47
0.40
0.35
0.30
0.48
0.38
0.48
0.35
0.38
0.46
0.51
0.40
0.38
-20%
-21%
Change from
1990 to 1997
-34%
-28%
-31%
-37%
-37%
-10%
-28%
-15%
-37%
-28%
-38%
-33%
4%
-64%
-15%
20%
-3%
-13%
-10%
-18%
-23%
11%
11%
-15%
-41%
-28%
-29%
New Source Performance Standards subpart.
C-3, 5
-------
Appendix C-3: Compliance Results for the 272 Early Election Units in 1997
NY
NY
NY
ST
NY
NY
NY
NY
NY
NY
OH
OH
OH
OK
OK
OK
OK
OK
OK
OK
OR
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
PA
C R Huntley
C R Huntley
Dunkirk
Plant Name
Dunkirk
Kintigh
S A Carlson
S A Carlson
S A Carlson
S A Carlson
Conesville
Conesville
W H Zimmer
Muskogee
Muskogee
Muskogee
Northeastern
Northeastern
Sooner
Sooner
Boardman
Bruce Mansfield
Cromby
Eddy stone
Eddy stone
Homer City
Homer City
Homer City
Keystone
Keystone
Montour
Montour
Niagara Mohawk Power Corp
Niagara Mohawk Power Corp
Niagara Mohawk Power Corp
Operating Utility
Niagara Mohawk Power Corp
Nyseg
City of Jamestown
City of Jamestown
City of Jamestown
City of Jamestown
Columbus Southern Power
Columbus Southern Power
Cincinnati Gas & Electric Co
Oklahoma Gas & Electric Co
Oklahoma Gas & Electric Co
Oklahoma Gas & Electric Co
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
2549
2549
2554
ORIS
Code
2554
6082
2682
2682
2682
2682
2840
2840
6019
2952
2952
2952
2963
2963
6095
6095
6106
6094
3159
3161
3161
3122
3122
3122
3136
3136
3149
3149
67
68
1
Boiler
2
1
9
10
11
12
5
6
1
4
5
6
3313
3314
1
2
1SG
3
1
1
2
1
2
3
1
2
1
2
NSPS1
Da
D
D
Da
D
D
D
D
D
D
D
D
D
D
0.45 0.31
0.45 0.31
0.45 0.34
Emission Actual
Limit Emission Rate
0.45
0.50
0.50
0.50
0.50
0.50
0.45
0.45
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.50
0.45
0.45
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.34
0.45
0.45
0.47
0.47
0.45
0.42
0.42
0.45
0.35
0.39
0.37
0.40
0.40
0.38
0.40
0.35
0.38
0.45
0.30
0.30
0.47
0.43
0.41
0.39
0.39
0.43
0.42
0.64
0.64
0.48
1990
Emission Rate
0.48
0.62
0.90
0.90
1.05
0.83
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
-52%
-52%
-29%
Change from
1990 to 1997
-29%
-27%
-50%
-48%
-55%
-46%
-5%
-5%
-20%
-5%
-16%
-25%
-25%
15%
-5%
-13%
-33%
-25%
-29%
-40%
-57%
-59%
-34%
-51%
-51%
-55%
-9%
New Source Performance Standards subpart.
C-3, 6
-------
Appendix C-3: Compliance Results for the 272 Early Election Units in 1997
PA
PA
PA
PA
ST
PA
PA
SC
SC
SC
SC
SC
TN
TN
TN
TN
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
New Castle
New Castle
New Castle
Titus
Plant Name
Titus
Titus
Cross
Cross
WSLee
WSLee
WSLee
John Sevier
John Sevier
John Sevier
John Sevier
Big Brown
Big Brown
Coleto Creek
Gibbons Creek
Harrington Station
Harrington Station
Harrington Station
J K Spruce
J T Deely
J T Deely
Limestone
Limestone
Martin Lake
Martin Lake
Martin Lake
Monticello
Ohio Edison Co
Ohio Edison Co
Ohio Edison Co
GPU
Operating Utility
GPU
GPU
South Carolina Pub Serv
South Carolina Pub Serv
Duke Energy Corporation
Duke Energy Corporation
Duke Energy Corporation
TVA
TVA
TVA
TVA
Texas Utilities Electric Co
Texas Utilities Electric Co
Central Power & Light Co
Texas Municipal Power Agency
Southwestern Public Service
Southwestern Public Service
Southwestern Public Service
City of San Antonio
City of San Antonio
City of San Antonio
Houston Lighting & Power
Houston Lighting & Power
Texas Utilities Electric Co
Texas Utilities Electric Co
Texas Utilities Electric Co
Texas Utilities Electric Co
3138
3138
3138
3115
ORIS
Code
3115
3115
130
130
3264
3264
3264
3405
3405
3405
3405
3497
3497
6178
6136
6193
6193
6193
7097
6181
6181
298
298
6146
6146
6146
6147
3
4
5
1
Boiler
2
3
1
2
1
2
3
1
2
3
4
1
2
1
1
061B
062B
063B
**j
1
2
LIM1
LIM2
1
2
3
1
NSPS1
Da
Da
D
D
D
D
D
Da
D
D
Da
Da
D
D
D
0.50 0.46
0.50 0.42
0.50 0.48
0.45 0.37
Emission Actual
Limit Emission Rate
0.45
0.45
0.50
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.45
0.39
0.39
0.32
0.38
0.44
0.44
0.44
0.41
0.41
0.43
0.43
0.40
0.36
0.36
0.37
0.24
0.29
0.27
0.35
0.36
0.36
0.41
0.42
0.32
0.30
0.37
0.31
0.63
0.57
0.73
0.73
1990
Emission Rate
0.68
0.77
Not Oper.
0.46
0.64
0.61
0.50
0.62
0.62
0.64
0.64
0.40
0.34
0.38
0.47
0.27
0.36
0.36
Not Oper.
0.31
0.31
0.50
0.48
0.36
0.35
0.42
0.31
-27%
-26%
-34%
-49%
Change from
1990 to 1997
-43%
-49%
-17%
-31%
-28%
-12%
-34%
-34%
-33%
-33%
0%
6%
-5%
-21%
-11%
-19%
-25%
16%
16%
-18%
-13%
-11%
-14%
-12%
0%
New Source Performance Standards subpart.
C-3, 7
-------
Appendix C-3: Compliance Results for the 272 Early Election Units in 1997
TX
TX
TX
TX
TX
ST
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
TX
UT
UT
UT
UT
UT
UT
UT
UT
VA
VA
VA
VA
VA
Monticello
Monticello
Oklaunion
Pirkey
Sam Seymour
Plant Name
Sam Seymour
Sam Seymour
San Miguel
Sandow
Tolk Station
Tolk Station
W A Parish
W A Parish
W A Parish
W A Parish
Welsh
Welsh
Welsh
Bonanza
Carbon
Carbon
Hunter (Emery)
Hunter (Emery)
Huntington
Intermountain
Intermountain
Chesapeake
Chesapeake
Chesapeake
Chesterfield
Chesterfield
Texas Utilities Electric Co
Texas Utilities Electric Co
West Texas Utilities Co
Southwestern Electric Power
Lower Colorado River Auth
Operating Utility
Lower Colorado River Auth
Lower Colorado River Auth
San Miguel Electric Coop
Texas Utilities Electric Co
Southwestern Public Service
Southwestern Public Service
Houston Lighting & Power
Houston Lighting & Power
Houston Lighting & Power
Houston Lighting & Power
Southwestern Electric Power
Southwestern Electric Power
Southwestern Electric Power
Deseret Generation & Tran
Pacificorp
Pacificorp
Pacificorp
Pacificorp
Pacificorp
Intermountain Power Agency
Intermountain Power Agency
Vepco
Vepco
Vepco
Vepco
Vepco
6147
6147
127
7902
6179
ORIS
Code
6179
6179
6183
6648
6194
6194
3470
3470
3470
3470
6139
6139
6139
7790
3644
3644
6165
6165
8069
6481
6481
3803
3803
3803
3797
3797
2
3
1
1
1
Boiler
2
3
SM-1
4
171B
172B
WAP5
WAP6
WAP7
WAP8
1
2
3
1-1
1
2
1
2
1
1SGA
2SGA
1
2
4
3
4
D
Da
D
D
NSPS1
D
Da
D
D
D
D
D
D
D
Da
D
D
D
Da
D
D
D
Da
Da
0.45
0.50
0.50
0.50
0.45
Emission
Limit
0.45
0.45
0.50
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.50
0.50
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.45
0.45
0.45
0.45
0.45
0.31
0.24
0.48
0.36
0.34
Actual
Emission Rate
0.38
0.27
0.42
0.34
0.32
0.30
0.36
0.40
0.40
0.37
0.26
0.29
0.27
0.37
0.38
0.39
0.41
0.40
0.37
0.39
0.36
0.45
0.44
0.43
0.42
0.45
0.40
0.21
0.54
0.34
0.34
1990
Emission Rate
0.29
0.25
0.41
0.43
0.38
0.24
0.47
0.53
0.35
0.31
0.27
0.36
0.37
0.42
0.50
0.58
0.50
0.55
0.52
0.45
0.38
0.42
0.48
0.54
0.52
0.49
-23%
14%
-11%
6%
0%
Change from
1990 to 1997
31%
8%
2%
-21%
-16%
25%
-23%
-25%
14%
19%
-4%
-19%
-27%
-12%
-24%
-33%
-18%
-27%
-29%
-13%
-5%
7%
-8%
-20%
-19%
-8%
New Source Performance Standards subpart.
C-3, 8
-------
Appendix C-3: Compliance Results for the 272 Early Election Units in 1997
VA
VA
VA
VA
VA
VA
ST
VA
VA
VA
VA
WA
WA
WI
WI
WI
WI
WI
WV
WY
WY
WY
WY
WY
WY
Glen Lyn
Glen Lyn
Possum Point
Potomac River
Potomac River
Potomac River
Plant Name
Potomac River
Potomac River
Yorktown
Yorktown
Centralia
Centralia
Blount Street
Blount Street
Columbia
Columbia
Edgewater
Mountaineer (1301)
Dave Johnston
Dave Johnston
Jim Bridger
Laramie River
Laramie River
Laramie River
Appalachian Power Co
Appalachian Power Co
Vepco
Pepco
Pepco
Pepco
Operating Utility
Pepco
Pepco
Vepco
Vepco
Pacificorp
Pacificorp
Madison Gas & Electric Co
Madison Gas & Electric Co
Wisconsin Power & Light
Wisconsin Power & Light
Wisconsin Power & Light
Appalachian Power Co
Pacificorp
Pacificorp
Pacificorp
Basin Electric Power
Basin Electric Power
Basin Electric Power
3776
3776
3804
3788
3788
3788
ORIS
Code
3788
3788
3809
3809
3845
3845
3992
3992
8023
8023
4050
6264
4158
4158
8066
6204
6204
6204
51
52
3
1
2
3
Boiler
4
5
1
2
BW21
BW22
8
9
1
2
5
1
BW41
BW42
BW74
1
2
3
0.45
0.45
0.45
0.45
0.45
0.45
Emission
NSPS1 Limit
0.45
0.45
0.45
0.45
0.45
0.45
0.50
0.50
0.45
D 0.45
D 0.50
D 0.50
0.50
0.50
D 0.45
D 0.50
D 0.50
D 0.50
0.42
0.39
0.45
0.42
0.39
0.44
Actual
Emission Rate
0.42
0.45
0.44
0.45
0.36
0.37
0.41
0.49
0.41
0.37
0.23
0.50
0.40
0.42
0.36
0.32
0.22
0.31
0.46
Not Oper.
0.60
0.51
0.44
0.64
1990
Emission Rate
0.46
0.72
0.57
0.57
0.40
0.45
0.71
0.61
0.46
0.49
0.21
0.47
0.48
0.54
0.41
0.35
0.32
0.42
-9%
-25%
-18%
-11%
-31%
Change from
1990 to 1997
-9%
-38%
-23%
-21%
-10%
-18%
-42%
-20%
-11%
-24%
10%
6%
-17%
-22%
-12%
-9%
-31%
-26%
New Source Performance Standards subpart.
C-3, 9
------- |